Design og modellering af metanolanlæg til VEnzin-visionen Bilag

Design og modellering
af metanolanlæg til
VEnzin-visionen
Lasse Røngaard Clausen
Polyteknisk Eksamensprojekt
MEK-ET-EP-2007-04
Marts 2007
Danmarks
Tekniske
Universitet
Institut for
Mekanik,
Energi og
Konstruktion
MEK
Energiteknik

1 Abstract
In connection with DONG Energy’s REtrol vision 1 a methanol plant is designed to
obtain optimal energy efficiency and economy.
A key element in the design is the usage of sustainable energy sources for the
methanol production.
6 different plant configurations, each with its own syngas production method, are
compared and it is concluded that the highest methanol exergy efficiency of 74 % is
achieved for the plant which uses biogas as the primary exergy source for syngas
production.
The plant that only uses electricity as exergy source is the only plant with a significant
lower methanol exergy efficiency of 67 %.
By using the waste heat from the methanol plant for district heating the energy
efficiency is increased considerably and the methanol cost is lowered.
The lowest methanol cost of 95 kr/GJex is achieved for the plant which uses
gasification of biomass and CO2 sequestration for syngas production.
The methanol cost achieved for a number of the plant configurations can therefore
compete with the commercial methanol price (142 kr/GJex) and the petrol price inc.
duties (187 kr/GJex).
It is also shown that a duty cut on the electricity price would result in a significant
reduction in methanol cost, since 39-84 % of the total costs for the 6 plant
configurations are for electricity.
Additionally it is concluded that it is economically feasible to use underground gas
storage for hydrogen and oxygen in a buffer system in connection with an electrolysis
plant integrated in a methanol plant.
The costs are reduced by operating the electrolysis plant only when the electricity
price is low while the rest of the methanol plant is in constant operation.
Simulations based on the electricity prices from DK-WEST in the period 2000-2006
and a rate of interest of 5 % show the largest cost reductions at 5000 operation hours
per year for the electrolysis plant.
The cost reductions are up to 10.5 % and 6.1 % in average at 5000 operation hours.
These cost reductions are close to the theoretical maximum for the used electricity
prices. The maximum cost reductions are in theory up to 11.5 % and 7.7 % in average
at 5000 operation hours.
The greatest cost reductions are achieved when the calculations are based on the
electricity prices with the largest standard deviation.
Finally it is concluded that suitable locations for underground gas storage of hydrogen
and oxygen are available in Denmark.
1 Originally developed by the Danish power company Elsam.
2

2 Resumé
I forbindelse med DONG Energy’s VEnzin-vision 2 er et metanolanlæg designet ud fra
optimal energiudnyttelse og økonomi.
I designet indgår anvendelsen af vedvarende energikilder til metanolproduktionen,
som et centralt element.
6 forskellige anlægskonfigurationer, med hver sin syngasproduktionsmetode,
sammenlignes, og det konkluderes, at den højeste metanolexergivirkningsgrad på 74
% opnås for et anlæg, som benytter biogas, som den primære exergikilde til
produktion af syntesegassen. Anlægget, der udelukkende benytter el som exergikilde,
er det eneste med en signifikant lavere metanolexergivirkningsgrad på 67 %.
Ved at udnytte spildvarmen fra metanolanlægget til fjernvarmeproduktion øges
energiudnyttelsen betydeligt, samtidig med at metanolomkostningerne reduceres.
Den laveste specifikke metanolomkostning på 95 kr/GJex opnås for anlægget, som
benytter forgasning af biomasse, med efterfølgende udvaskning af CO2 fra
forgasningsgassen, til syntesegasproduktion.
Den specifikke metanolomkostning for en række af anlægskonfigurationerne kan
derfor konkurrer med den kommercielle metanolpris (142 kr/GJex) og benzinprisen
inkl. afgifter (187 kr/GJex).
Det vises desuden, at en afgiftslettelse på elektriciteten vil betyde en markant
reduktion af metanolomkostningen, idet 39-84 % af de samlede omkostninger for de 6
anlægskonfigurationer er til elektricitet.
Herudover bliver det fastslået, at det er økonomisk fordelagtigt at benytte
underjordiske gaslagre til brint og ilt i et buffersystem i forbindelse med et
elektrolyseanlæg, som er en del af et metanolanlæg.
Omkostningerne bliver reduceret ved kun at have elektrolyseanlægget i drift, når elprisen
er lav, mens det resterende metanolanlæg er i drift året rundt.
Ud fra simuleringer baseret på el-priserne for DK-VEST for 2000-2006 og en
kalkulationsrente på 5 % bliver de største besparelser opnået ved ca. 5000 driftstimer
per år for elektrolyseanlægget. Besparelserne er op til 10,5 % og i gennemsnit 6,1 %
ved 5000 driftstimer.
Disse besparelser er tæt på det teoretisk maksimale for de benyttede el-priser. De
teoretisk maksimale besparelser er op til 11,5 % og i gennemsnit 7,7 % ved 5000
driftstimer.
De største besparelser bliver opnået når beregningerne baseres på de el-priser, som har
den største spredning.
Endeligt bliver det konkluderet, at der er egnede lokationer for underjordiske gaslagre
til brint og ilt i Danmark.
2 Visionen blev oprindeligt udviklet af Elsam
3

3 Forord
I forbindelse med arbejdet på dette projekt, er der en række personer som jeg gerne vil
takke:
• Mine vejledere for god vejledning og sparring gennem projektforløbet. Specielt
Brian Elmegaard for assistance med programmeringen til simuleringsværktøjet
DNA.
• Martin Møller, DONG Energy for gode råd i forbindelse med opbygningen af
simuleringsmodellen af metanolanlægget.
• Afdelingsleder Tommy Mølbak, afdeling for Modellering og Optimering, DONG
Energy for projektidéer ved opstart af projektet.
Hovedvejler:
• Docent Niels Houbak, MEK, DTU.
Medvejledere:
• Lektor Brian Elmegaard, MEK, DTU.
• Civilingeniør Torkild Christensen, afdeling for Modellering og Optimering,
DONG Energy.
4

4 Indholdsfortegnelse
1 Abstract.......................................................................2
2 Resumé .......................................................................3
3 Forord .........................................................................4
4 Indholdsfortegnelse ....................................................5
5 Indledning...................................................................7
6 Problemformulering....................................................8
7 Design og statisk modellering af metanolanlæg.........9
7.1 Modelbeskrivelse ........................................................................10
7.1.1 Kort modelbeskrivelse .........................................................................10
7.1.2 Begrundelse for modeldesign ..............................................................10
7.1.3 Simuleringsværktøjet DNA .................................................................12
7.1.3.1 Tilføjelser til DNA...........................................................................12
7.1.4 Komponentbeskrivelser .......................................................................14
7.1.5 Antagelser i modellen ..........................................................................19
7.1.6 Fastsættelse af parametre og brændselssammensætninger anvendt i
modellen 20
7.2 Anlægskonfigurationer................................................................23
7.3 Økonomi......................................................................................25
7.3.1 Komponentomkostninger.....................................................................25
7.3.2 Brændsel/input-omkostninger..............................................................26
7.4 Termoøkonomisk analyse ...........................................................29
7.4.1 Teori.....................................................................................................29
7.4.2 Resultater .............................................................................................32
7.5 Resultater.....................................................................................34
7.5.1 Anlægskonfigurationer ........................................................................34
7.5.1.1 Økonomi ..........................................................................................38
7.5.2 Parametervariation ...............................................................................45
7.5.2.1 Metanolreaktortrykket......................................................................45
7.5.2.2 Brint/kulstof-forholdet i syngassen..................................................52
7.5.2.3 Forgassertrykket...............................................................................57
7.5.2.4 Afkølingstemperaturen for den metanolholdige gas........................59
7.6 Diskussion...................................................................................61
7.6.1 Forbedring af anlægsdesign .................................................................62
7.6.2 Alternative anlægsdesign.....................................................................63
7.6.3 Integration med andre anlæg................................................................63
8 Benyttelse af underjordiske gaslagre til brint og ilt i et
metanolanlæg .................................................................65
8.1 Underjordiske brintlagre .............................................................66
8.2 Scenarier......................................................................................67
8.2.1 Scenarie 1: Det teoretisk optimale scenarie .........................................71
8.2.2 Scenarie 2: Det i praksis opnåelige scenarie........................................76
5

8.3 Resultater.....................................................................................82
8.3.1 Scenarie 1: Det teoretisk optimale scenarie .........................................82
8.3.2 Scenarie 2: Det i praksis opnåelige scenarie........................................89
8.4 Diskussion...................................................................................95
9 Konklusion................................................................99
10 Litteraturliste........................................................100
11 Nomenklaturliste..................................................103
6

5 Indledning
Baggrunden for dette projekt, om design af et metanolanlæg, er DONG Energy’s
VEnzin-vision 3 . En vision som omhandler produktion af brændsler til
transportsektoren, som metanol og etanol, i synergi med et kraftværk.
Denne produktion af brændsler til transportsektoren tænkes primært baseret på
vedvarende energikilder, som biomasse - fx i form af halm - og elektricitet - fx fra
vindmøller.
I denne rapport er det undersøgt, hvorledes et anlæg til produktion af metanol, som
kan indgå i denne vision, kan designes.
Rapporten er opdelt i 2 dele:
Den første del omhandler designet af det samlede metanolanlæg, mens den anden del,
omhandler benyttelsen af gaslagre i forbindelse med elektrolyseanlægget, som er en
del af metanolanlægget.
I problemformuleringen på næste side defineres projektet mere præcist.
3 Visionen blev oprindeligt udviklet af Elsam
7

6 Problemformulering
Et metanolanlæg optimeret ud fra optimal energiudnyttelse og økonomi ønskes
designet.
Anvendelse af vedvarende energikilder til metanolproduktionen er desuden et centralt
element i anlægsdesignet.
Metanolanlægget designes vha. en statisk model af anlægget opbygget i et
simuleringsprogram.
Ligeledes ønskes det undersøgt, hvorvidt det er økonomisk fordelagtigt at benytte
underjordiske gaslagre til brint og ilt i forbindelse med et elektrolyseanlæg, som
anvendes i et metanolanlæg.
Gaslagrene tænkes benyttet i et buffersystem, således at elektrolyseanlægget
producerer brint og ilt til lagrene, samtidig med at der er et forbrug af brint og ilt fra
lagrene til metanolproduktion. På denne måde kan driften af elektrolyseanlægget
afkobles fra det øvrige metanolanlæg.
Det undersøges, om omkostningerne kan nedsættes, ved kun at have
elektrolyseanlægget i drift når el-prisen er lav, mens det resterende metanolanlæg
opererer med et maksimum af driftstimer.
8

7 Design og statisk modellering af
metanolanlæg
I denne del af rapporten er et metanolanlæg designet og optimeret ud fra optimal
energiudnyttelse og økonomi.
Metanolanlægget er designet vha. en statisk model af anlægget opbygget i et
simuleringsprogram.
I første kapitel præsenteres modellen af metanolanlægget, og begrundelserne for
designet beskrives.
Dernæst beskrives hvilke anlægskonfigurationer, som vil blive undersøgt og hvorfor
de er relevante.
I det 3. kapitel undersøges investeringsomkostningerne samt omkostningerne
forbundet med drift og vedligehold af metanolanlægget.
Herefter udføres en termoøkonomisk analyse af metanolanlægget, for at opnå en mere
detaljeret forståelse af anlægget.
Endelig præsenteres resultaterne for de forskellige anlægskonfigurationer og for
parametervariationen for den optimale anlægskonfiguration.
I det sidste kapitel diskuteres resultaterne.
9

7.1 Modelbeskrivelse
Figur 7.1. Flowsheet for metanolanlægget. Se bilag 20 for en udgave i A3.
Elektrolysedel
Forgasserdel
Dampreformeringsdel
Metanolkonverterings-
og
destillationsdel
7.1.1 Kort modelbeskrivelse
Modellen af metanolanlægget på Figur 7.1 er opbygget af en elektrolysedel, der
producerer ilt til en forgasserdel og en dampreformeringsdel. Elektrolysedelen
producerer udover ilt også brint vha. elektrolyse af vand. Brinten blandes sammen
med forgasningsgassen fra forgasserdelen, reformergassen fra dampreformeringen og
evt. CO2 til en syntese gas (syngas).
Syngassen benyttes i en metanolkonverter til produktion af metanol. Denne metanol
destilleres herefter til den ønskede renhed.
7.1.2 Begrundelse for modeldesign
Designet af metanolanlægget er inspireret af Dong Energy’s flowsheet’s for et
metanolanlæg (se et i bilag 18), samt modellen fra kurset Thermoeconomics (bilag 19)
[Clausen et al., 2005], som blev udviklet sammen med 4 andre studerende fra DTU.
Modellen vist på Figur 7.1 er standardmodellen. Der udføres en række simuleringer
hvor dele af standardmodellen ikke benyttes.
Grunden til, at modellen er opbygget af både en forgasserdel, en dampreformeringsdel
og en CO2-tilførsel, er for at sikre fleksibiliteten for anlægget,
samtidig med at komponenterne tilsammen kan producere en velegnet syngas til
metanolproduktion, uden overskud af ilt fra elektrolyseanlægget.
Nedenfor er der kort argumenteret for hvorfor nogle af hovedkomponenterne er
medtaget i modellen, samt andre forhold vedrørende modeldesignet
Elektrolyseanlægget
Elektrolyseanlægget benyttes pga. både brint og ilt med fordel kan benyttes til
metanolproduktion. Ilt benyttes til forgasning i stedet for atmosfærisk luft, for at
undgå store mængder af inerte komponenter i forgasningsgassen, hvilket ikke er
fordelagtigt ved konverteringen til metanol i metanolreaktoren. Med samme
begrundelse er det også fordelagtigt at benytte ilt til dampreformeringen.
10

Brint er specielt fordelagtig til metanolproduktion hvis forgasningsgas samtidig
benyttes til syngasproduktionen, da brint/kulstof-forholdet i forgasningsgas er for lavt
til metanolproduktion (specielt ved recirkulation af uomsat syngas til metanolreaktor).
I stedet for at benytte vand-elektrolyse til iltproduktionen kunne en luftseparator
benyttes. Hvis ilten benyttes i en forgasser, vil den manglende brint fra
elektrolyseanlægget dog medføre, at syngassen vil have et uhensigtsmæssigt lavt
brint/kulstof-forhold. Ved at føre forgasningsgassen gennem en CO2-vasker kan
brint/kulstof-forholdet dog hæves – det medfører til gengæld en dårligere udnyttelse
af biomassen. Endelig er en luftseparator også forbundet med et stort energiforbrug,
selvom det er mindre end energiforbruget til elektrolyseanlægget.
Hvis elektriciteten, som benyttes af elektrolyseanlægget, er produceret ud fra
vedvarende energikilder, kan VE-metanol produceres. I denne situation kan
elektrolyseanlægget også benyttes som en aftager af overskuds-elektricitet – dvs.
aftage el når el-prisen er lav pga. en stor el-produktion fra de vedvarende energikilder.
Brinten produceret i et sådan tilfælde vil også direkte kunne benyttes til
metanolproduktion ved at iblande CO2 – fx indsamlet fra røggas.
Forgasser
Forgasseren er medtaget for at kunne benytte et billigere brændsel end elektricitet til
metanolproduktion, samtidig med at biomasse kan benyttes i forgasseren, og dermed
sikre at metanolen produceres ud fra en vedvarende energikilde. Hvis forgasseren
både kan operere på kul og biomasse vil det sikre en større brændselsfleksibilitet for
anlægget.
Metanol primært produceret på kul i Danmark vil muligvis ikke være
konkurrencedygtig på prisen - og samtidig vil den producerede metanol ikke være
baseret på vedvarende energikilder, hvilket kunne kompensere for den evt. højere pris
end kommercielt metanol.
Dampreformer
Dampreformeren er medtaget i modellen fordi dampreformering af naturgas er den
traditionelle metode til syngasproduktion i forbindelse med metanolproduktion. Det
giver samtidig en brændselsfleksibilitet for anlægget. Endelig vil en sådan reformer
også kunne benyttes til biogas, hvilket vil sikre at den producerede metanol
udelukkende er baseret på vedvarende energikilder.
I Danmark vil en metanolproduktion primært baseret på naturgas være
ukonkurrencedygtig, da naturgas i Danmark er væsentlig dyrere end den naturgas
kommerciel metanol bliver produceret på. Ofte foregår denne metanolproduktion ud
fra naturgas, som tidligere har været anset for et spildprodukt i forbindelse med
olieudvinding.
Udnyttelse af spildvarmen fra kompressormellemkølingen
Spildvarmen fra mellemkølingen af kompressorerne benyttes primært til tørring af
biomassen til forgasseren og sekundært til fjernvarmeproduktion. Dette gøres for at
hæve anlæggets samlede energiudnyttelse. Omkostningen ved dette er et større
kompressionsarbejde, idet syngassen ikke kan afkøles til mere end ca. 130°C (ca. 33
% større i forhold til afkøling til 30°C).
11

Udnyttelse af varme fra metanolkonverteringen og destillationen
Varmen udvundet fra metanolkonverteringskredsen benyttes til destillationen, tørring
af biomasse og til fjernvarmeproduktion.
Varmen udvundet ved den afsluttende afkøling af den metanolholdige gas i
metanolkonverteringskredsen benyttes til fjernvarmeproduktion, hvilket betyder en
lidt højere afkølingstemperatur for den metanolholdige gas, men ud fra afsnit 7.5.2.4
ses det, at det har meget begrænset betydning.
Spildvarmen fra destillationen af metanol/vand-blandingen udnyttes ligeledes til
fjernvarmeproduktion ved at tryksætte destillationsprocessen (ca. 3,5 bar).
Dette medfører at varmen, som benyttes til destillationen skal være af en lidt højere
kvalitet (forefindes ved højere temperatur). Hvis metanolkoncentrationen efter
destillationen er tilstrækkelig høj, er det imidlertid ikke noget problem (se diskussion
om dette i kapitel 7.6).
7.1.3 Simuleringsværktøjet DNA
Modellen af metanolanlægget er opbygget i simuleringsprogrammet DNA (Dynamic
Network Analysis). DNA er et komponentbaseret simuleringsværktøj, som er udviklet
på MEK-DTU. Programmet sørger for at energi- og masse-balancerne er overholdt og
har indbygget data for en række medier – både idealgasser og fluider.
Endelig er data for standardexergier også inkorporeret, hvorfor alle massestrømme i
DNA-modellen får udregnet en tilhørende kemisk exergistrøm. De fysiske
exergistrømme bliver også udregnet 4 .
Programmet er skrevet i Fortran og komponenterne i DNA er ligeledes skrevet i
Fortran.
7.1.3.1 Tilføjelser til DNA
I forbindelse med udviklingen af modellen for metanolanlægget, har det været
nødvendigt med en række tilføjelser. Det gælder tilføjelse af metanol til DNA – både
som fluid og som idealgas – og tilføjelse af en række komponenter.
7.1.3.1.1 Metanol som fluid
Metanol er tilføjet DNA ud fra data fra [Reuck, 1993]. Denne kilde indeholder
ligninger for tryk, enthalpi, entropi og indre energi som funktion af temperaturen og
specifik volumen. Disse ligninger er inkorporeret i en Fortran-rutine (bilag 35) til
DNA, hvilket medfører at hvis ligevægtstilstanden for metanol skal bestemmes ud fra
andre parametre end temperatur og specifik volumen er iteration nødvendig.
Idet Fortran-rutinen er opbygget med generelle funktioner, kan den nemt benyttes til
andre fluider, som også er beskrevet med ligninger, hvor temperaturen og specifik
volumen er benyttet som variable. Det kræver kun udskiftning af ligningerne for de
termodynamiske parametre (tryk, enthalpi, entropi og indre energi). IUPAC, som står
bag [Reuck, 1993] har blandt andet også lavet lignende bøger om N2 og CO2.
7.1.3.1.2 Metanol som idealgas
Metanol som idealgas er tilføjet DNA ud fra data fra [Reid, 1987] og [Reuck, 1993].
[Reid, 1987] indeholder standardenthalpien for metanol samt et polynomium for cp
som funktion af temperaturen:
Θ
h = −201,
3 kJ
m
mol
4 I modellen defineres nulpunktet for den fysiske exergi ved 1 bar og 15°C.
12

Ligning 7.1: Den specifikke varmekapacitet for konstant tryk for metanol
= c + c ⋅T
+ c
2
⋅T
+ c
3
⋅T
c p
0
= 21 , 15 + 7,
092 ⋅10
1
2
3
⋅T
+ 2,
587 ⋅10
⋅T
− 2,
852 ⋅10
⋅T
−2 −5
2
−8
3
[Reuck, 1993] indeholder værdien for standardentropien:
Θ
s = 239,
81 J
K⋅mol
m
J
K ⋅ mol
DNA indeholder en rutine, som kun behøver de ovenstående data for at udregne alle
de termodynamiske parametre.
7.1.3.1.3 Komponenter
Følgende komponenter er udarbejdet til DNA og benyttet i modellen. Se beskrivelse
af de relevante komponenter i afsnit 7.1.4 og dokumentation for alle komponenterne
til DNA-brugere i bilag 33. Fortran-koden for komponenterne kan ses i bilag 34. En
del af de tilføjede komponenter er modificeringer af allerede eksisterende
komponenter i DNA.
13

Navn / beskrivelse DNA-navn
Elektrolyseanlæg ELECTROLYSER
Damptørrer DRYER_04
Gasrenser GASCLE_2
Dampreformer STEAM_REFORMER
Gaskøler med udkondensering af vand GASCOOL2
Metanolreaktor MEOH_CONVERTER
Gaskøler med udkondensering af vand og metanol GASCOOL4
Blandetank MIXING_TANK
Destillationskolonne (destillationstrin) DISTILLATION_STAGE
El-motor EL_MOTOR
Massestrømsdeler med variabelt antal opdelinger SPLITTER2
Massestrømsdeler med fast opdelingsforhold SPLITTER3
Idealgasblander med variabelt antal inputstrømme MIXER_03
Trykseparator PRES_SEP
Komponent, der sætter molbrøken af en komponent i en
idealgasblanding
SET_X
Komponent, der sætter molbrøken af en komponent i en SET_X_REALFLUID
2-komponent fluid-blanding
Massestrømsmåler MEASURE_FLOW
Massestrømsindstiller SET_FLOW
Temperaturindstiller SET_TEMP
Tabel 7.1. Tilføjede komponenter til DNA.
7.1.4 Komponentbeskrivelser
Nedenfor er alle de komponenter som benyttes i modellen af metanolanlægget
beskrevet.
Elektrolyseanlæg
Elektrolyseanlægget producerer ilt og brint ved at spalte vand vha. elektricitet.
Anlægget er karakteriseret ved en virkningsgrad, som er defineret på følgende måde:
Ligning 7.2: Elektrolysevirkningsgraden
m H LHV
2 H2
P
⋅ &
η =
el
Hvor m& H er massestrømmen af brint,
2
er den elektriske effekt.
LHV H er den nedre brændværdi af brint (massebasis) og Pel
2
Anlægget kan benyttes til både høj- og lav-temperaturelektrolyse samt tryksat
elektrolyse.
DNA-navn: ELECTROLYSER
Damptørrer
Damptørreren benytter vanddamp til tørring af biomasse. Produkterne fra
komponenten er tørret biomasse og afkølet damp. Det fordampede vand fra biomassen
blandes med den tilførte damp.
I denne komponent er temperaturen af den tørrede biomasse sat lig temperaturen af
den afkølede damp – svarende til fx en fluid bed tørringsproces.
14

DNA-navn: DRYER_04
Forgasser
Forgasseren producerer forgasningsgas ud fra et fast brændsel og en oxygenholdig gas
(evt. ren oxygen). Der er også mulighed for at tilføre vand/vanddamp til forgasseren.
Forgasseren udregner gassammensætningen af forgasningsgassen vha. kemisk
ligevægt (minimering af Gibbs-energi) mellem følgende 8 komponenter: hydrogen
(H2), kulmonooxid (CO), kuldioxid (CO2), vanddamp (H2O), hydrogensulfid (H2S),
metan (CH4), nitrogen (N2) og argon (Ar).
Forgasningsgas vil typisk også indeholde klor (Cl), ammoniak (NH3), tjære og
partikler. Idet gasrensningen i modellen kun er udført ved at fjerne de uønskede
komponenter fra forgasningsgassen uden effektforbrug eller tryktab, har det meget
lille betydning, at ikke alle de omtalte komponenter forefindes i den udregnede
forgasningsgas. Den eneste omkostning ved gasrensningen i modellen er økonomisk.
DNA-navn: GASIFI_3
Gasrenser
Gasrenseren fjerner hydrogensulfiden (H2S) fra forgasningsgassen. Den eneste
omkostning ved gasrensningen er udgiften til gasrenseren.
DNA-navn: GASCLE_2
Dampreformer
Denne komponent foretager en autotermisk reformering af naturgas eller en anden
kulbrintegas. Det betyder at varmen til dampreformeringen kommer fra en delvis
oxidation af kulbrintegassen. Dermed er der tre input til reformeren: en kulbrintegas,
vanddamp og en oxygenholdig gas.
Gassammensætningen af den reformerede gas udregnes vha. kemisk ligevægt
(minimering af Gibbs-energi) mellem følgende 5 komponenter: hydrogen (H2),
kulmonooxid (CO), kuldioxid (CO2), vanddamp (H2O) og metan (CH4).
DNA-navn: STEAM_REFORMER
Metanolreaktor
Metanolreaktoren konverterer en syngas til en metanolholdig gas.
Gassammensætningen af den konverterede gas udregnes vha. kemisk ligevægt
(minimering af Gibbs-energi) mellem følgende 5 komponenter: hydrogen (H2),
kulmonooxid (CO), kuldioxid (CO2), vanddamp (H2O) og metanol (CH3OH).
I forbindelse med metanolkonverteringen er faktoren M for syngassen central:
Ligning 7.3: M-faktor for produktion af flydende brændsler
n&
H − n&
2 CO2
M =
n&
+ n&
CO2
CO
Hvis M=2 er forholdet mellem molstrømmene i syngassen således at alle 3 gasser (H2,
CO, CO2) i teorien kan omdannes helt til metanol og vand (jævnfør Ligning 7.4 og
Ligning 7.5).
Ligning 7.4: Reaktionsligning for metanolproduktion ud fra CO:
CO + 2H 2 → CH 3OH
Ligning 7.5: Reaktionsligning for metanolproduktion ud fra CO2:
15

CO2 + 3 H 2 → CH 3OH
+ H 2O
DNA-navn: MEOH_CONVERTER
Varmevekslere
Standard
Denne gruppe af varmevekslere er enten modstrømsvarmevekslere eller simple
komponenter til opvarmning (HEATSRC0) eller afkøling (HEATSNK0) af en
massestrøm. Varmeveksleren HEATEX_2 er karakteriseret ved at benytte en ”pinch
point”-temperatur (se Figur 7.3) og varmeveksleren HEATEX_4 er karakteriseret ved
at benytte en varmevekslereffektivitet – defineret som den højeste af de 2 følgende
udtryk:
T1
− T2
T4
− T3
(er for afkøling) og (er for opvarmning)
T1
− T3
T1
− T3
hvor temperaturerne er angivet på figuren nedenfor
T
T1
T4
Figur 7.2. T-Q-diagram for modstrømsvarmeveksler.
T3
T2
Q
16

T
Fordampning
Pinch points
Figur 7.3. T-Q-diagram for modstrømsvarmeveksler, som er karakteriseret ved en ”pinch point”temperatur.
DNA-navne: HEATSNK0, HEATSRC0, HEATEX_1, HEATEX_2, HEATEX_4
Med udkondensering af vand
Denne varmeveksler kan håndtere udkondensering af vand fra en gasstrøm.
Udkondenseringen forekommer hvis partialtrykket af vanddampen i gassen bliver
højere en damptrykket for vand. Komponenten sætter i denne situation partialtrykket
af vanddampen lig damptrykket for vand ved udgangstemperaturen for komponenten.
Komponenten sikrer samtidig at 2. hovedsætning ikke overtrædes ved at undersøge
”pinch point”-temperaturen hvor udkondenseringen starter (se Figur 7.4).
Komponenten kan ligeledes håndtere fordampning af det opvarmede medie (se Figur
7.3).
DNA-navn: GASCOOL2
Med udkondensering af vand og metanol
Denne varmeveksler kan håndtere udkondensering af en vand/metanol-blanding fra en
gasstrøm. Udkondenseringen forekommer hvis temperaturen af gasstrømmen afkøles
til under den temperatur, hvor en vand/metanol-blanding er i ligevægt med
partialtrykkene for vanddampen og metanoldampen i gasstrømmen.
Udkondenseringstemperaturen 5 beregnes ud fra partialtrykkene for vanddamp og
metanoldamp i gasstrømmen som tilføres komponenten.
Komponenten sikrer samtidig at 2. hovedsætning ikke overtrædes ved at undersøge
”pinch point”-temperaturen hvor udkondenseringen starter (se Figur 7.4).
Komponenten kan ligeledes håndtere fordampning af det opvarmede medie (se Figur
7.3).
5 Metoden til udregning af denne temperatur er NRTL-metoden (Non Random Two Liquid).
Interaktionskoefficienterne som er benyttet er: ∆g(metanol, vand) = -1062,616 J/mol, ∆g(vand,
metanol) = 3537,611 J/mol og α(metanol, vand) = 0,2994 og er fra [Gmehling, 1977].
Q
17

DNA-navn: GASCOOL4
T
Medie 1
Medie 2
Start på kondensation af gaskomponent(er)
”Pinch points”
Figur 7.4. T-Q-diagram for modstrømsvarmeveksler med udkondensering af vand eller en
vand/metanol-blanding.
Kompressor
Denne komponent benyttes til komprimering af en gasstrøm. Komponenten er
karakteriseret ved en isentropvirkningsgrad (sat til 0,9) og en mekanisk virkningsgrad
(sat til 0,98).
DNA-navn: COMPRE_1
Destillationskolonne
Destillationskolonnen er i denne model opbygget af mindre komponenter, såkaldte
destillationstrin. Et destillationstrin simuleres ved en beholder, som får tilført 2
massestrømme af en vand/metanol-blanding, én i gasfasen og én i væskefasen.
Herudover udgår der 2 massestrømme af en vand/metanol-blanding fra komponenten,
én i gasfasen og én i væskefasen. Disse 2 massestrømme er i ligevægt med hinanden.
Metoden til udregning af denne ligevægt er den samme, som beskrevet i fodnote 5.
Ved at koble disse destillationstrin i serie opnås en destillation af metanol/vandblandingen
(se Figur 7.5).
I modellen benyttes 17 destillationstrin og feed-massestrømmen tilføres i trin 6 (se
bilag 17)
DNA-navn: DISTILLATION_STAGE
Q
18

Massestrøm af
Metanol/vand-blanding ,
som skal destilleres
Figur 7.5. Principskitse for destillationskolonne. På venstre side af kolonnen føres en massestrøm af en
metanol/vand-blanding på væskefasen fra et trin til trinet under. På højre side af kolonnen føres en
massestrøm af en metanol/vand-blanding på gasfasen fra et trin til trinet over. Fordi metanol har et
lavere kogepunkt en vand vil denne destillationsproces føre til, at metanolkoncentrationen er højst i
toppen af kolonnen, mens vandkoncentrationen er højest i bunden af kolonnen. Se bilag 17 for et
flowsheet for alle 17 destillationstrin.
7.1.5 Antagelser i modellen
I forbindelse med modelleringen af metanolanlægget, har det været nødvendigt at
foretage en række antagelser:
• Kemisk ligevægt i forgasningsgassen fra forgasseren, i reformergassen fra
dampreformeren og i metanolgassen fra metanolreaktoren. Hvis de virkelige
komponenter designes så opholdstiden bliver lang nok og opblanding kraftig nok,
er det en god antagelse. I Viking-forgasseren på DTU er der erfaring med at
metanindholdet er højere end udregnet vha. kemisk ligevægt [Clausen et al.,
2004]. Det skyldes formentlig at de 2 omtalte kriterier ikke er opfyldt.
Hvis metanindholdet i syngassen bliver så højt at det udgør en betydelig del af
restgassen fra metanolreaktorkredsen, kan det nedbringes ved at tilføje yderligere
damp til forgasseren og/eller dampreformeren (afhængig af hvor metanet stammer
fra). Endelig kan en del af restgassen også tilbageføres til forgasseren eller
dampreformeren for at reformere metanet. Ved at sænke trykket og/eller hæve
temperaturen i forgasseren/dampreformeren kan metanindholdet naturligvis også
reduceres.
• Ingen produktion af biprodukter (hovedsagelig etanol) ved metanolkonverteringen
i metanolreaktoren. Med de moderne katalysatorer er produktionsraten af
biprodukter (i fx mol/s) omkring 1 ‰ af produktionsraten for metanol [Hansen,
1998]. Dette medfører at den efterfølgende destillationsproces, kun består i at
adskille vand fra metanol i en enkelt destillationskolonne. Destillationsprocessen
er mere kompliceret hvis biprodukter og gaskomponenter fra syngassen skal
destilleres fra. Hertil anvendes typisk 3 destillationskolonner [NZIC, 2007].
• Den eneste omkostning ved gasrensningen af forgasningsgassen er økonomisk.
Der regnes ikke med noget effektforbrug eller tryktab i forbindelse med
19

gasrensningen. I forbindelse med Viking-forgasseren på DTU regner man ikke
med at forgasningsgassen skal renses for andre komponenter end svovl, ammoniak
og evt. tjære og klor hvis gassen skal benyttes til metanolproduktion [Iversen,
2006]. Til sammenligning renses syngas fra naturgas for svovl og klor 6 vha.
katalysatorer placeret inden metanolreaktoren ved samme temperatur og tryk.
Forgasningsgassen fra Viking-forgasseren er i forvejen næsten tjærefri pga. totrins-forgasningsprocessen,
og ammoniakindholdet er ligeledes lavt efter en
afkøling af gassen [Iversen, 2006]. I forbindelse med Viking-forgasseren er der
indtil videre foretaget indledende forsøg med metanolproduktion vha. en syntetisk
forgasningsgas [Iversen, 2006].
• Trykfaldet i metanolkonverteringskredsen antages at være 5 bar og ligge over
metanolreaktoren. Det formodes at trykfaldet i realiteten hovedsageligt vil ligge
over væske/gas-separatorerne. Disse komponenter er imidlertid ikke medtaget i
modellen, men de kunne tilføjes.
• Intet kulstof i asken fra forgasseren. I realiteten vil en andel forefindes i asken.
• Varmetabet fra komponenterne til omgivelserne er negligeret, på nær for
kompressorerne.
• Tryktabet i komponenter og forbindelsesrør er negligeret.
• Effektforbruget til tryksætning og cirkulation af vand er negligeret.
7.1.6 Fastsættelse af parametre og brændselssammensætninger
anvendt i modellen
Ved modelleringen af metanolanlægget holdes en række parametre konstant. Det
gælder bl.a. temperaturer, tryk og massestrømme.
I bilag 22 er de fastholdte parametre angivet med gul farve 7 . I Tabel 7.3 er der angivet
kilde på nogle af værdierne for de fastholdte parametre.
Værdierne for de fastholdte parametre, som ikke kan vises i bilaget, kan ses i Tabel
7.2.
Hvis intet andet er anført er disse værdier for parametrene benyttet i de simuleringer,
som ligger til grund for resultaterne i afsnit 7.4.2 og i kapitel 7.5.
6
Der er også en reaktor som renser for diverse urenheder (LSK-guard) [Iversen, 2006].
7
De temperaturer efter kompressorerne som er angivet med gul holdes ikke konstant, men lig
hinanden.
20

Parameter Værdi Komponenter Evt. kilde
η 80 %
Elektrolyseanlæg [Teknologikataloget,
2005]
∆tminimum pinch point 10°C Varmevekslere
ε 90 % Varmevekslere 8
ηisentrop 90 % Kompressorer
ηmekanisk 98 % Kompressorer
m&
damp
m&
1,0 (NG)
0,2 (biogas og FG) 9
Dampreformer og forgasser
&
m recirkuleret
brændsel
m&
0,95
(metanolkonverteringskredsen)
ηmekanisk 95 % El-motor
Tabel 7.2. Værdier for en række termodynamiske parametre benyttet i modellen.
Parameter Værdi Komponenter Kilde
tligevægt 950°C Dampreformer [Wikipedia, 2007]
pligevægt 10 bar Dampreformer [Wikipedia, 2007]
tligevægt 235°C Metanolreaktor [Møller, 2006] se også bilag 14
tligevægt 144 bar Metanolreaktor [Møller, 2006]
tligevægt 800°C Forgasser [Møller, 2006]
Tabel 7.3. Værdier for en række termodynamiske parametre benyttet i modellen.
Metanolproduktionen på 205 MWLHV, som holdes konstant i modellen (se bilag 22),
svarer til 7 % af forbruget af motorbenzin til vejtransport i Danmark i 2004
[Energistyrelsen, 2004] (bilag 8). Denne metanolproduktion vil kunne blandes i
benzinen (koncentration på 7 %-energi 10 ) uden problemer for forbrændingsmotorerne
[Clausen et al., 2005].
Nedenfor er brændselssammensætningerne og brændværdierne for biogas, naturgas og
biomasse angivet.
8
Varmevekslereffektiviteten benyttes for varmevekslerne HEATEX_4 (DNA-navn, kan ses på
flowsheet).
9
Værdien er sat for at få metanindholdet i reformergassen og forgasningsgassen ned på ca. 0,5 mol-%.
Parameteren benyttes ikke for anlægskonfiguration nr. 3, idet damptilførslen styres af CO2-indholdet i
forgasningsgassen.
10
Var Elsams bud på andelen af metanol, som skulle blandes i benzinen [Clausen et al., 2005].
21

Gaskomponent Naturgas (NG) 11
[mol-%]
Biogas 12
N2 0,311
CO2 0,561 35 mol-%
CH4 91,115 65 mol-%
C2H6 5,032
C3H8 1,839
C4H10 0,473
C4H10 0,353
C5H12 0,230
C6H14 0,055
C7H16 0,003
C8H18 0,0003
C5H10 0,011
C6H12 0,002
C7H14 0,004
C6H6 0,002
C6H12 0,009
H2S 500 ppm
Tabel 7.4. Gassammensætning for kulbrinter benyttet i dampreformeren.
Naturgas (NG) 11
Biogas 12
LHV [MJ/kg] 48,5 20,2
Tabel 7.5. Nedre brændværdi for kulbrinter benyttet i dampreformeren.
Komponent Biomasse (træ)
[masse-%]
H 3,05
O 18,86
C 25,03
S 0,005
N 0,3
Ar 0,205
Aske 2,55
Vand 50
Tabel 7.6. Sammensætningen af biomassen benyttet i simuleringerne. LHV = 9,64 MJ/kg, cp = 1,35
kJ/kg [Møller, 2006].
11 Er indbygget i simuleringsværktøjet DNA.
12 Gassammensætning efter gasrensning. Fra [Teknologikataloget, 2005].
22

7.2 Anlægskonfigurationer
Den opbyggede model af et metanolanlæg benyttes til modellering af en række
forskellige anlægskonfigurationer.
Forskellene mellem anlægskonfigurationerne er på syngasproduktionsmetoden.
De anlægskonfigurationer der undersøges, består af følgende processer/kilder til
syngasproduktion:
1. Elektrolyse, forgasning af biomasse og naturgasreformering
2. Elektrolyse og forgasning af biomasse
3. Elektrolyse og forgasning af biomasse (med CO2-fjernelse)
4. Elektrolyse, naturgasreformering og CO2-tilførsel
5. Elektrolyse og biogasreformering
6. Elektrolyse og CO2-tilførsel
1. Elektrolyse, forgasning af biomasse og naturgasreformering
Denne anlægskonfiguration er standardkonfigurationen.
Dette anlæg kan producere en velegnet syngas til metanolproduktion samtidig med, at
den producerede ilt fra elektrolyseanlægget, som ikke benyttes til forgasning anvendes
til naturgasreformering.
Anlægget producerer som udgangspunkt ikke 100 % VE-metanol, men hvis
elektriciteten fremstilles ud fra vedvarende energi og naturgassen erstattes af metan
fra fx biogas kan dette lade sig gøre.
2. Elektrolyse og forgasning af biomasse
Dette anlæg kan være fordelagtigt hvis 100 % VE-metanol ønskes produceret og hvis
den overskydende ilt fra elektrolyseanlægget kan benyttes uden for anlægget.
3. Elektrolyse og forgasning af biomasse (med CO2-fjernelse)
Hvis anlægskonfiguration nr. 2 udbygges med CO2-fjernelse fra forgasningsgassen
kan elektrolyseanlæggets størrelse reduceres, således at der ikke forekommer noget
iltoverskud.
CO2’en kan enten lagres eller sendes ud til omgivelserne, da CO2’en stammer fra
biomasse. Hvis den lagres, kan den evt. benyttes til metanolproduktion sammen med
brint fra elektrolyse på et tidspunkt, hvor elektriciteten er billig.
4. Elektrolyse, naturgasreformering og CO2-tilførsel
For at kunne sammenligne ovenstående anlægskonfigurationer med et anlæg baseret
på naturgasreformering, som er den mest udbredte metode til syngasproduktion, er
dette anlæg medtaget.
5. Elektrolyse og biogasreformering
I stedet for forgasning kan biogasreformering benyttes, hvis 100 % VE-metanol
ønskes produceret.
6. Elektrolyse og CO2-tilførsel
Denne anlægskonfiguration kunne være interessant hvis 100 % VE-metanol ønskes
produceret uden benyttelse af biomasse. Et sådant anlæg vil kunne aftage betydelige
23

mængder elektricitet og kunne blive interessant, hvis andelen af ukontrollerbar elproduktion,
som sol-, vind- og vand-kraft, steg markant.
24

7.3 Økonomi
For at kunne vurdere omkostningerne ved metanolproduktion på det modellerede
anlæg er det nødvendigt at bestemme de faste og variable omkostninger.
I denne sammenhæng er komponentomkostningerne og brændsel/input-omkostninger
bestemt nedenfor.
Det er bl.a. af hensyn til den termoøkonomiske analyse at alle
komponentomkostninger fastsættes, i modsætning til at benytte en samlet
anlægsomkostning.
7.3.1 Komponentomkostninger
Nedenfor er de specifikke priser for komponenterne anvendt i modellen angivet.
For bedre at kunne relatere til komponentomkostningerne er de totale
komponentpriser for anlægskonfiguration 1 vist herefter.
Der benyttes specifikke komponentpriser for lettere at kunne sammenligne
anlægsinvesteringen for de forskellige anlægskonfigurationer. I realiteten vil de
specifikke komponentpriser afhænge af størrelsen af komponenterne, på den måde, at
større komponenter vil have en mindre specifik pris.
Komponent Specifik pris Kilde
Elektrolyseanlæg 1,5 mio. kr. / MWe [Teknologikataloget, 2005]
Damptørrer
Forgasser
4,1 mio. kr. / (kg/s)fordampet
3,8 mio. kr. / MWbiomasse
[Enerdry, 2007]
13 [Choren, 2007, side 11]
Gasrenser 0*
Dampreformer 14 1,1 mio. kr. / MWgas 15 Læs nedenfor
Metanolreaktor 121 mio. kr. / (kmol/s)syngas Læs nedenfor
Destillationskolonne 24 mio. kr. / (kg/s)feed Læs nedenfor
Varmeveksler 0,4 mio. kr. / MWoverført Læs nedenfor
Kompressor 4,5 mio. kr. / MWmek Læs nedenfor
Tabel 7.7. Specifikke priser for komponenter benyttet i modellen. * Omkostningen for gasrenseren er
indlejret i prisen for forgasseren.
Varmevekslere og kompressorer
Udgiften til varmevekslere og kompressorer er anslået ud fra [Peters, 1991]. Der er
kun anvendt én specifik pris for varmevekslere og kompressorer for at simplificere
udregningen af anlægsinvesteringen, samtidig med at disse komponenters andel af den
samlede anlægspris kun er ca. 10 %. I realiteten afhænger den specifikke pris på
varmevekslere og kompressorer fx af ved hvilken temperatur og ved hvilket tryk -
eller trykforhold - der opereres ved.
Dampreformer, metanolreaktor og destillationskolonne
Disse komponenter er prissat ud fra en samlet anlægspris på $20.000 per Barrels/dag
[Fleisch, 2002, side 4] (1.026 kr./(liter/dag)), samt en antagelse om samme pris for
alle 3 komponenter. For at kunne foretage denne prisfastsættelse, er modellen for
13
Det antages at effekten er baseret på nedre brændværdi.
14
Omkostningen i forbindelse med gasrensning af naturgas/biogas antages at være indlejret i denne
omkostning.
15
Effekten (MWnaturgas) er baseret på nedre brændværdi.
25

metanolanlægget indstillet således at syngassen kun produceres ud fra naturgas, idet
syngassen til metanolproduktion oftest produceres ud fra naturgas i kommercielle
anlæg. Det betyder mere præcist, at modellen er indstillet i det driftpunkt, hvor
forgasseren ikke benyttes og hvor elektrolyseanlægget ikke producerer mere ilt, end
der benyttes til naturgasreformeringen. Den producerede brint fra elektrolyseanlægget
benyttes ikke til syngasproduktionen (se flowsheet for anlægget i dette driftpunkt i
bilag 21).
Komponent(er) Parameter
Pris Prisandel
[mio. kr] [%]
Elektrolyseanlæg 56 MWe 86 6
Damptørrer 5,9 (kg/s)fordampet 24 2
Forgasser 121 MWbiomasse 461 32
Dampreformer 92 MWgas 96 7
Metanolreaktor 2,7 (kmol/s)syngas 327 23
Destillationskolonne 11,5 (kg/s)feed 270 19
Varmevekslere 158 MWoverført 63 4
Kompressorer 21 MWmek 96 7
Tabel 7.8. Priser for komponenter benyttet i modellen for anlægskonfiguration 1. Den samlede
anlægspris er 1580 mio. kr for denne anlægskonfiguration.
Ud fra Tabel 7.8 ses det at specielt forgasseren udgør en stor del af den samlede
anlægsomkostning. Komponenterne til metanolkonvertering og destillation udgør dog
også en betragtelig del af anlægsinvesteringen.
Parameter Værdi
Levetid 15 år
Driftstid 8000 timer/år
rD&V 2 % 16
Tabel 7.9. Værdierne for nogle centrale økonomiske driftsparametre, som er benyttet i beregningerne.
I Tabel 7.9 er nogle vigtige økonomiske driftsparametre vist. Driftstiden og rD&V er
antagede værdier, mens levetiden bygger på levetiden af elektrolyseanlægget og
forgasseren fra [Teknologikataloget, 2005] 17 .
Der regnes ikke med at anlægsinvesteringen betales med lånte penge, hvorfor
eventuelle renter af et lån skal tillægges den beregnede produktionsomkostning.
7.3.2 Brændsel/input-omkostninger
Standardpriserne for de benyttede brændsler og andre input til metanolanlægget er
som følger:
16
Andel af anlægsinvesteringen, som benyttes til drift og vedligehold per år.
17
Levetiden for et elektrolyseanlæg og en forgasser i år 2010-2015 angives til henholdsvis 15 år og 15-
20 år.
26

Input-priser Kilde
Elektricitet 18 1168 kr/MWh 324 kr/GJ [Energy Together, 2004] se bilag 3.
[GE-NET, 2007] se bilag 4
Mekanisk effekt
1192 kr/MWh 341 kr/GJ Se tabelteksten nedenfor
Biomasse (træ) 15 €/MWh 32 kr/GJ [Teknologikataloget, 2005] 19
Naturgas 20 93 kr/GJ 93 kr/GJ [Energy Together, 2004] se bilag 5.
[Naturgasafgifter, DONG Energy, 2007]
se bilag 6.
Biogas
55 kr/GJ 55 kr/GJ [Clausen et al., 2005] 21
Vand 32 kr/m 3
CO2
(fra kraftværksrøggas)
32 kr/m 3 [Københavns Energi, 2007]
se bilag 7
15 €/ton 114 kr/ton [Teknologikataloget, 2005] 22
Tabel 7.10. Standardpriser på de forskellige inputs med konventionelle enheder samt med
sammenlignelige enheder. Prisen for den mekaniske effekt (cmek) fastsættes ud fra antagelse om
c
kr
el 324 GJ
benyttelse af en el-motor med 95 % virkningsgrad: c kr
mek = = = 341 GJ .
0,
95 0,
95
El-prisen er fastsat ud fra en fremskrivning af el-prisen foretaget af Energy Together i
2004 for det frie el-marked. Prisen på 300 kr/MWh er ved ”rest peak” for 2015, for at
tage højde for at anlægget ikke er i drift når el-prisen er høj. El-prisen er herefter
tillagt afgifter og tariffer.
I resultat kapitlet (7.5.1.1) er det illustreret hvad en afgiftsfritagelse på elektricitet
betyder for den specifikke metanolomkostning, idet en hel eller delvis afgiftsfritagelse
er sandsynlig i fremtiden, for at sikre en bedre udnyttelse af specielt elektricitet fra
vindmøllerne - jævnfør afgiftslempelsen på elektricitet til fjernvarmeproduktion.
For at illustrere hvor vanskeligt det er at fastsætte en el-pris er el-priserne fra den
nordiske el-børs Nordpool 23 for 2000-2006 vist nedenfor på Figur 7.6.
Der ses tydeligt en stigende tendens, hvorfor det er svært at estimere, hvad den
gennemsnitlige el-pris bliver for et anlæg, som skal være i drift i mange år.
18
300 kr/MWh ved lidt under gennemsnitspris i 2015 (rest peak) – se første bilag angivet under ”kilde”
i tabellen.
868 kr/MWh i afgifter og tariffer for el til erhvervskunder (Årligt forbrug over 100.000 kWh), se andet
bilag angivet under ”kilde” i tabellen.
19
Afsnit 10. For år 2004-2015.
20
37 kr/GJ (gaspris + nettarif), gennemsnit for 2010-2025 – se første bilag angivet under ”kilde” i
tabellen.
CO2-afgift på 19,8 øre/m 3 og energiafgift på 204,2 øre/m 3 (LHVNG = 40 MJ/Nm 3 ) -> 56 kr./GJ – se
andet bilag angivet under ”kilde” i tabellen.
21
Biogasomkostningen er beregnet ud fra oplysninger fra [Teknologikataloget, 2005]
22
Afsnit 2, for år 2010-15.
23
El-prisen fra Nordpool er for DK-VEST [Nordpool, 2007].
27

Figur 7.6. El-priser for DK-vest fra Nordpool for 2000 til 2006 (timedata) i intervallet 0-1000 kr/MWh
(de få resterende el-priser ligger i intervallet 1000-4500 kr/MWh). Den sorte linie er
gennemsnitsprisen for alle år og den røde linie er et lineart fit til dataene.
28

7.4 Termoøkonomisk analyse
Der er udført en termoøkonomisk analyse af metanolanlægget. Analysen viser hvor
omkostningsstrømmene opstår og hvordan de føres gennem anlægget - for til sidst at
havne i produkterne fra anlægget. Ineffektiviteterne som forefindes i anlægget
kortlægges ligeledes, og det kan vurderes hvor det er mest omkostningseffektivt at
foretage forbedringer.
7.4.1 Teori 24
Thermoeconomics eller termoøkonomi handler om at kæde en exergianalyse sammen
med en økonomisk analyse. Mere specifikt tillægges alle exergistrømme i et
energisystem en økonomisk omkostningsstrøm. Fordelingen af omkostningerne på de
respektive exergistrømme bestemmes ud fra en definition af hvad der er produkter og
spild fra de enkelte komponenter.
Vha. denne analysemetode kan der dannes et overblik over omkostningsstrømmene i
et energisystem, som kan danne baggrund for en økonomisk og termodynamisk
optimering.
I analysen indgår 3 vigtige balancer, som udføres for hver komponent i systemet:
• Energibalance
• Exergibalance
• Omkostningsbalance
Efter energi- og exergibalancen er udført 25 for alle komponenter i systemet, skal hver
enkelt strøm tillægges en omkostningsstrøm. Til dette formål benyttes
omkostningsbalancer for alle komponenter i anlægget:
Ligning 7.6: Omkostningsbalance for en komponent
C&
= Z&
+ C&
,
p
i
hvor Ċp er omkostningsstrømmen [kr/s] for produkterne fra komponenten, Ż er omkostningsstrømmen
[kr/s] forbundet med D&V og afskrivninger på komponentinvesteringen og Ċi er
omkostningsstrømmen [kr/s] for inputs til komponenten.
For at kunne udføre omkostningsbalancerne skal det defineres for hver komponent
hvad der er produkter og hvad der er spild fra komponenten. I forbindelse med
definitionerne af exergivirkningsgraderne i det følgende er det beskrevet hvad der er
defineret som produkter og spild for alle komponenterne i anlægget. En strøm som
defineres som spild tillægges ingen omkostningsstrøm.
Hvis en komponent har flere produkter fordeles omkostningsstrømmen mellem
produkterne således, at de får samme specifikke omkostning per exergienhed.
I denne analyse er nogle strømme desuden defineret som neutrale. Det betyder at
strømmen har den samme omkostningsstrøm [kr/s] ind og ud af komponenten.
For at kunne sammenligne omkostningsstrømmene for produkterne i systemet
udtrykkes det enkelte produkts omkostningsstrøm (Ċp), også som en omkostning per
exergi (cex) og masse (cm).
24 Teorien bag den termoøkonomiske analyse bygger delvist på teorien fra [Clausen et al., 2005].
25 Udføres automatisk af DNA.
29

Efter disse omkostningsbalancer er udført udregnes exergivirkningsgrader for
samtlige komponenter således at sammenligning er mulig.
Exergivirkningsgraden er i udgangspunktet defineret ved:
Ligning 7.7: Standardexergivirkningsgraden for en komponent
η
ex
=
∑
∑
, hvor Ėex, p er exergistrømmene for produkterne og Ėex, i er exergistrømmene af inputtene.
Denne parameter er dermed afhængig af hvilke strømme, der defineres som produkter.
For fx varmevekslere kan denne definition være meget svær at foretage, hvis der både
ønskes en opvarmning af den ene strøm og en afkøling af den anden 26 .
I denne fremstilling er problemstillingen løst ved at definere den afkølede massestrøm
som neutral 27 og den opvarmede som produkt. Det er gjort, fordi det er den kemiske
exergi, som i dette tilfælde er interessant i den afkølede massestrøm. Den fysiske
exergi i den afkølede massestrøm har i dette anlæg ikke nogen direkte værdi.
Exergivirkningsgraden for varmevekslerne er dermed lig exergivirkningsgraden for
varmevekslere, som benyttes til opvarmning [Krane] 28 :
Ligning 7.8: Exergivirkningsgraden for en varmeveksler benyttet til opvarmning
E&
ex,
c,
o − E&
ex,
c,
i
η ex,
heatex,
op var mning =
E&
− E&
ex,
h,
i
ex,
h,
o
hvor Ėex benævner exergistrømmen, indeks c og h står for henholdsvis den kolde og den varme strøm,
og indeks i og o står for henholdsvis ind og ud. I det tilfælde hvor der sker en udkondensation af vand
og evt. metanol er Ėex, h, o inkl. den udkondenserede væskestrøm.
For kompressorer er exergivirkningsgraden defineret som:
Ligning 7.9: Exergivirkningsgraden for en kompressor
E&
ex,
o − E&
ex,
i
η ex,
komp =
,
P
komp
hvor Pkomp er den mekaniske effekt, der tilføres kompressoren.
For elektrolyseanlæg, forgasser, dampreformer og metanolreaktor er
exergivirkningsgraden defineret, som den er i udgangspunktet:
Ligning 7.10: Standardexergivirkningsgraden for en komponent
∑ E&
ex,
p
ηex
= ,
E&
∑
E &
E &
ex , p
ex , i
ex,
i
hvor Ėex, p betegner produkternes exergistrømme og Ėex, i er exergistrømmene for samtlige inputs til
komponenten.
Definitionen af produkterne fra en række komponenter findes i Tabel 7.11.
26 Damptørreren opfattes i denne sammenhæng også som en varmeveksler.
27 I tilfælde af udkondensation, opdeles omkostningsstrømmen mellem gasstrømmen og
væskestrømmen således at omkostningen per exergi er den samme.
28 side EX-83
30

Komponent Produkt(er) Spild
Elektrolyseanlæg H2, O2 og fjernvarme
Forgasser Forgasningsgas Aske
Metanolreaktor Metanolholdig gas Vanddamp
Destillationskolonne Metanol/vand-blanding på gasfase og på væskefase 29
Tabel 7.11. Definition af produkter og spild for de komponenter, som har flere output (gælder ikke
varmevekslere, se evt. side 30).
Anlæggets samlede exergivirkningsgrad er defineret på samme måde, som på
komponentbasis. Der er benyttet samme definition af produkter, som angivet ovenfor:
Ligning 7.11: Samlet exergivirkningsgrad for anlægget
∑ E&
ex,
p E&
ex,
metanol + E&
ex,
FV,
ud + E&
ex
ηex,
total = =
E&
E&
∑
ex,
i
∑
ex,
i
, ilt
+ E&
ex,
syngas
hvor Ėex, syngas er exergistrømmen for den del af syngassen som ikke omdannes til metanol eller vand og
derefter udkondenseres.
I den samlede exergi, ΣĖex, i, er medtaget samtlige exergistrømme til systemet, både
kemisk og fysisk exergi, dvs. inkl. el, FVind og brændsler.
Tilsvarende er der defineret en metanolvirkningsgrad, hvor kun metanol opfattes som
produkt:
Ligning 7.12: Metanolexergivirkningsgrad for anlægget
∑ E&
ex,
p E&
ex,
metanol
ηex,
metanol = =
E&
E&
∑
ex,
i
∑
ex,
i
Endelig er der også defineret 2 energivirkningsgrader, som har samme
produktdefinitioner, som de 2 exergivirkningsgrader ovenfor:
Ligning 7.13: Samlet energivirkningsgrad for anlægget
∑ E&
en,
p E&
en, metanol + E&
en,
FV + E&
en
ηen,
total = =
E&
E&
∑
en,
i
∑
en,
i
, syngas
Ligning 7.14: Metanolenergivirkningsgrad for anlægget
E&
en, metanol
ηen,
metanol = ,
E&
∑
en,
i
hvor Ėen, metanol er energistrømmen af metanol (nedre brændværdi), Ėen, FV er energiindholdet i
fjernvarmen (Ėen, FV, ud - Ėen, FV, ind), Ėen, syngas er energistrømmen (nedre brændværdi) for den del af
syngassen, som ikke omdannes til metanol eller vand og derefter udkondenseres og Ėen, i inkluderer
brændsler (nedre brændværdi) og el.
For at kunne lokalisere de komponenter, som har størst indflydelse på anlæggets
samlede exergivirkningsgrad udregnes hver komponents exergidestruktion:
29
Den del af metanol/vand-blandingen på væskefasen, som separeres fra efter destillationskolonnen
opfattes som spild.
,
31

Ligning 7.15: Exergidestruktion for komponent
E&
ex,
dest = ∑ E&
ex,
i − ∑ E&
ex,
p ,
hvor Ėex, i er exergistrømmene for inputtene og Ėex, p er exergistrømmene for produkterne.
Denne exergidestruktion kan udtrykkes i to pengestrømme, Ċi,dest og Ċp,dest:
Ligning 7.16: Omkostningsstrøm for komponentens exergidestruktion baseret på den gennemsnitlige
specifikke exergiomkostning for inputs til komponenten
C&
i,
dest = cex,
i ⋅ E&
ex,
dest ,
hvor cex,
i = ∑C&
i
E&
er den gennemsnitlige inputomkostning per exergi, Ċi er
∑
ex,
i
omkostningsstrømmene forbundet med inputtene til en komponent og Ėex, i er de tilhørende
exergistrømme.
Ligning 7.17: Omkostningsstrøm for komponentens exergidestruktion baseret på den gennemsnitlige
specifikke exergiomkostning for produkterne fra komponenten
C&
p,
dest = cex,
p ⋅ E&
ex,
dest ,
hvor cex,
p = ∑C&
p
E&
er den gennemsnitlige produktomkostning per exergi, Ċp er
∑
ex,
p
omkostningsstrømmene forbundet med produkterne fra en komponent og Ėex, p er de tilhørende
exergistrømme.
I forbindelse med varmevekslere er ci kun baseret på den opvarmede strøm, for at
skabe konsistens med definitionen for cp for varmevekslere.
7.4.2 Resultater
Resultaterne fra den termoøkonomiske analyse præsenteres for anlægskonfiguration
nr. 1, idet alle komponenter benyttes i denne konfiguration.
Værdierne for de termoøkonomiske parametre, defineret i teoriafsnittet ovenfor, vises
for alle komponenter og strømninger i bilag 23 30 .
I tabellerne nedenfor er nogle udvalgte værdier fra bilaget vist.
I Tabel 7.12 er værdierne for de vigtigste termoøkonomiske komponentparametre
præsenteret. Det ses tydeligt at forgasseren er den komponent med det største
exergitab, selvom komponentens exergivirkningsgrad er relativ høj. Det er naturligvis
fordi exergistrømmen gennem komponenten er stor. Omkostningen forbundet med
dette exergitab er til gengæld meget mindre end for elektrolyseanlægget, da prisen for
elektricitet er meget højere end for biomasse. Det kan herudfra tydeligt ses at det
bedst kan betale sig at mindske exergitabet i elektrolyseanlægget.
Summen af exergitabene i tabellen er 34,5 MW hvilket svarer til 11 % af
exergiinputtet til anlægget på 320 MW. Det er dermed en stor del af det samlede tab
på 20 % (jævnfør den totale exergivirkningsgrad på 80 % i Tabel 7.13). Det
resterende exergitab er næsten udelukkende et tab i fysisk exergi. Det eneste ekstra
tab i kemisk exergi er i forbindelse med metanolindholdet i spildevandet fra
destillationen.
30 Der er lidt afvigelser mellem kemisk exergi i idealgas og fluid
32

Tabet i fysisk exergi forekommer hovedsagelig i de komponenter, hvor der er
faseovergang (fordampning eller kondensation).
Komponent
ηex
[%] Ėex, dest
[MW]
Ċi, dest
[kr/s]
Ċp, dest
[kr/s]
Elektrolyseanlæg 80 11,6 3,74 4,77
Damptørrer 46 3,5 0,03 0,03
Forgasser 89 15,5 0,43 0,64
Dampreformer 93 7,6 0,66 0,74
Metanolreaktor 99,7 1,6 0,24 0,25
Destillationskolonne 73 2,3 0,38 0,39
Tabel 7.12. Termoøkonomiske parametre for de vigtigste komponenter i metanolanlægget. Til
sammenligning kan det nævnes at det samlede exergiinput til anlægget i denne konfiguration er Ėex, total
= 320 MW og den samlede omkostningsstrøm er Ċtotal = 43 kr/s.
ηex, total
80 %
ηex, metanol 72 %
ηen, total
99 %
ηen, metanol 70 %
Tabel 7.13. Exergi- og energi-virkningsgrader for det samlede metanolanlæg.
Ud fra Tabel 7.13 ses det at den totale energivirkningsgrad er på 99 %. Det er
urealistisk højt, men det skyldes at alt spildvarmen i modellen benyttes til
fjernvarmeproduktion.
Forskellen mellem de totale virkningsgrader og metanolvirkningsgraderne i Tabel
7.13 er pga. energi- og exergi-indholdet i fjernvarmevandet og i den bortseparerede
syngas.
I Tabel 7.14 er exergi- og energi-strømmene for disse 2 produkter vist og
sammenlignet med værdierne for metanol.
Produkt
Ėex Ėen Ċp cex
[MW] [MW] [kr/s] [kr/GJ]
Metanol 231 205 39,7 172
Fjernvarme 12 31 72 0,5 32
Uomsat syngas 13 11 2,2 167
Tabel 7.14. Exergi- og energi-strømme ud af metanolanlægget samt de tilhørende omkostningsstrømme
og specifikke exergiomkostninger.
Tabel 7.14 viser hvorledes investerings- og drifts-omkostninger fordeles på de 3
produkter fra anlægget. Det kan ses at den specifikke exergiomkostning ved
fjernvarmeproduktion er mindre end de øvrige produkter, hvilket skyldes at
omkostningerne forbundet med specielt elektricitetsforbruget ikke ender i
fjernvarmeproduktet, da fjernvarmen produceres ud fra spildvarme.
Ud fra en sammenligning af produkterne metanol og syngas kan det ligeledes ses at
omkostningerne ved destillationen ikke er store. Det skyldes både den relativt
begrænsede kapitalomkostning forbundet med destillationen og det begrænsede
exergitab.
31
Er defineret som exergistrømmen af fjernvarme ud af anlægget minus exergistrømmen af fjernvarme
ind i anlægget.
33

7.5 Resultater
Resultaterne opnået vha. modellen af metanolanlægget er præsenteret nedenfor.
Først præsenteres resultaterne for de 6 forskellige anlægskonfigurationer, som er
undersøgt. Dernæst foretages en parametervariation for den anlægskonfiguration, som
vurderes til at være den mest optimale.
7.5.1 Anlægskonfigurationer
Resultaterne for de 6 anlægskonfigurationer, som er beskrevet i kapitel 7.2 er vist
nedenfor.
Først beskrives resultaterne vedrørende det termodynamiske hvorefter
omkostningerne ved metanolproduktion for hver af de 6 anlægskonfigurationer
præsenteres og sammenlignes.
I bilag 24 forefindes flowsheets for alle 6 anlægskonfigurationer.
Forskellen mellem de 6 anlægskonfigurationer er på syngasproduktionsmetoden
(jævnfør kapitel 7.2), dvs. at syngassen i de 6 anlæg produceres ud fra forskellige
sammensætninger af exergikilder. På Figur 7.7 ses præcist hvordan fordelingen
mellem de 4 exergikilder er for de 6 anlæg. Exergiinputtet til anlægget går
hovedsageligt til syngasproduktionen.
34

Anlæg 1
Total: 320 MWex (292 MW)
79
145
0
96
Anlæg 4
Total: 318 MWex (308 MW)
99
0
0
219
Anlæg 2
Total: 327 MWex (293 MW)
121
0
0
205
Anlæg 5
Total: 312 MWex (300 MW)
0
96
Biogas NG Biomasse Elektricitet
216
Anlæg 3
Total: 322 MWex (280 MW)
65
0
0
256
Anlæg 6
Total: 345 MWex (345 MW)
Figur 7.7. Exergiinputfordelingen for de 6 anlægskonfigurationer. Værdien angivet i parentes er
energitilførslen (for brændsler er værdien baseret på den nedre brændværdi).
Forskellene mellem de totale exergiinputs for anlæggene angivet på figuren ovenfor,
afspejler metanolexergivirkningsgraderne angivet i Tabel 7.15, idet
metanolproduktionen er konstant.
Ud fra Tabel 7.15 ses det at virkningsgraderne for metanolanlægget er afhængig af
sammensætningen af exergikilderne til metanolproduktionen.
Det ses at de dårligste virkningsgrader opnås i anlæg nr. 6, hvilket skyldes den
dårligere virkningsgrad for elektrolyseanlægget i forhold til forgasseren og
dampreformeren (se exergivirkningsgrader i Tabel 7.12) samt den dårligere udnyttelse
af syngassen i metanolreaktoren pga. CO2 er mindre reaktionsvilligt end CO.
Forskellene mellem virkningsgraderne for de øvrige anlæg er ikke store, idet
virkningsgraden for dampreformeren kun er lidt bedre end forgasserens
virkningsgrad. Grunden til at anlægget med de højeste exergivirkningsgrader (nr. 5)
ikke også har de højeste energivirkningsgrader er at energivirkningsgraderne er
baseret på nedre brændværdi samt at forholdet mellem nedre brændværdi og kemisk
exergi er lavere for biomasse end for naturgas.
0
345
35

Anlægs-nr. ηex, metanol
[%]
ηex, total
[%]
ηen, metanol
[%]
ηen, total
[%]
1 72 80 70 99
2 71 78 70 99
3 72 78 73 102 32
4 73 82 66 94
5 74 82 68 95
6 67 77 59 88
Tabel 7.15. Exergi- og energi-virkningsgrader for de 6 forskellige anlægskonfigurationer.
Anlæggene med naturgas/biogas-tilførsel får højere exergivirkningsgrader end
anlæggene med biomassetilførsel på trods af at Tabel 7.16 viser at anlæggene med
naturgas/biogas-tilførsel har et større exergitab i form af ukonverteret syngas.
Størrelsen af exergitabet i form af ukonverteret syngas skyldes i høj grad CO/ CO2forholdet
i syngassen (se Tabel 7.16). Desto mere CO syngassen indeholder i forhold
til CO2 desto lavere bliver dette exergitab. Det skyldes som sagt at CO er mere
reaktionsvilligt end CO2.
Anlæg nr. 3 har det mindste exergitab i form af ukonverteret syngas fordi kulstoffet i
syngassen udelukkende er i form af CO. Ligeledes er CO/ CO2-forholdet også større
for de øvrige anlæg som er baseret på biomasse i forhold til anlæggene der er baseret
på naturgas/biogas.
y
Anlægs-nr.
Ėex, uomsat syngas
[MWex]
Msyngas
[-]
CO
syngas y CO2
[-]
Pkompression
[MWmek]
Q& fjernvarme
[MJ/s]
1 13 1,67 6,5 21 72
2 11 1,72 8,1 23 76
3 8 1,78 ∞ 33 24 74
4 19 1,45 1,1 21 71
5 14 1,60 3,9 18 68
6 18 1,31 0 31 84
Tabel 7.16. Exergiflow af uomsat syngas, M-faktoren for syngassen (se Ligning 7.3), CO/ CO2forholdet
for syngassen, fjernvarmeproduktionen og kompressionsarbejdet for de 6 forskellige
anlægskonfigurationer.
Ud fra Tabel 7.16 ses det at der er stor forskel på det samlede kompressionsarbejde
for de 6 anlæg, selvom alle 6 anlæg opererer ved et metanolreaktortryk på 144 bar.
Grunden til at anlæg nr. 6 har det største samlede kompressionsarbejde er at
syngasvolumenstrømmen er størst for dette anlæg, hvilket skyldes den dårligere
udnyttelse af syngassen samtidig med at kulstoffet i syngassen er i form af CO2 (der
benyttes 3 H2-molekyler til et CO2-molekyle, mens der benyttes 2 H2-molekyler til et
CO-molekyle, jævnfør reaktionsligningerne Ligning 7.4 og Ligning 7.5).
Forklaringen på at kompressionsarbejdet er mindst for anlæg 4 og 5 er at
kompressionen af naturgas og biogas ikke medregnes. For naturgas er det en fornuftig
32
Grunden til at værdien kan være højere end 100 % er at virkningsgraden er baseret på den nedre
brændværdi. Hvis den var baseret på den øvre brændværdi ville den for dette anlæg være 97 %.
33
Det antages at alt CO2 bliver vasket ud fra forgasningsgassen. I realiteten vil ikke alt CO2 blive
udvasket.
36

antagelse, da naturgasnettet er tryksat, mens det burde medregnes for biogas. Det
manglende kompressionsarbejde for biogas anslås til at være 6 MWmek 34 .
Tabel 7.16 viser desuden at der er en klar sammenhæng mellem
fjernvarmeproduktionen og det samlede kompressionsarbejde. Det er pga.
kompressormellemkølingen benyttes til fjernvarmeproduktion samtidig med at
fjernvarmeproduktionen i forbindelse med metanolkonverteringen og destilleringen -
som udgør den største andel af den samlede fjernvarmeproduktion - er næsten
konstant for alle 6 anlæg.
Anlægs-nr. xmetanol, før destillation
[mol-%]
xmetanol, efter destillation
[mol-%]
Q & destillation
[MJ/s]
1 84 99,98 38
2 89 99,98 39
3 94 99,99 41
4 63 99,89 34
5 79 99,96 37
6 50 99,51 27
Tabel 7.17. Metanolkoncentrationer før og efter destillation af vand/metanol-blandingen samt
varmeeffekten benyttet til destillationen for de 6 forskellige anlægskonfigurationer.
Metanolkoncentrationerne før og efter destillationen af vand/metanol-blandingen for
de 6 anlæg er angivet i Tabel 7.17. Hvis metanolkoncentrationen før destillationen
sammenholdes med CO/ CO2-forholdet i syngassen fra Tabel 7.16, ses det tydeligt at
metanolkoncentrationen er lavest for anlæg 6, fordi metanolen produceres ud fra CO2.
Metanolkoncentrationen på 50 % for anlæg 6 stemmer overens med
reaktionsligningen fra Ligning 7.5, idet der produceres 1 mol vand hver gang der
produceres 1 mol metanol ud fra CO2.
Grunden til at metanolkoncentrationen før destillationen for anlæg 3 ikke når 100 %,
selvom alt metanolen produceres ud fra CO, er at syngassen indeholder ca. 5 mol-%
vand. En del af denne vandmængde udkondenseres sammen med metanolen efter
metanolreaktoren (ca. 43 %), mens den resterende del omdannes vha. shiftreaktionen
(Ligning 7.18) og ender som CO2 i den uomsatte syngas.
Hvis yderligere vand ønskes fjernet fra syngassen, kan den temperatur, som syngassen
afkøles til, sænkes fra de ca. 135°C - eller reaktortrykket kan øges.
Der forventes umiddelbart ikke at være nogen forskel mellem
metanolkoncentrationerne før destillationen for anlæg 4 og 5, idet syngassen i begge
tilfælde produceres ud fra metan 35 og CO2. Forskellen er imidlertid at biogas, som
anvendes i anlæg 5, indeholder CO2, hvorfor denne CO2 gennemstrømmer
dampreformeren hvor shiftreaktionen (Ligning 7.18) kommer i ligevægt, mens CO2
tilføres efter dampreformeren i anlæg 4. CO/ CO2-forholdet i syngasserne fra Tabel
7.16 viser klart betydningen af dette.
Ligning 7.18: Shiftreaktionen
CO + H O → CO + H
2
2
2
34 Vil fx kun betyde et fald i ηex, metanol på ca. 1 %-point og en stigning i den specifikke
metanolomkostning på ca. 9 kr/GJex (se figur 7.9)
35 Naturgas indeholder også nogle højere kulbrinter
37

Metanolkoncentrationen i vand/metanol-blandingen efter destillationen afhænger
naturligvis af metanolkoncentrationen i blandingen før destillationen, men også af
varmemængden benyttet til destillationen.
Varmen til destillationen kommer hovedsageligt fra afkølingen af metanolreaktoren,
men også fra afkølingen af den metanolholdige gas efter metanolreaktoren.
Forskellen i den benyttede varmemængde til destillation for de 6 anlæg (Tabel 7.17)
skyldes forskelle i varmetabet fra metanolreaktoren.
Varmetabet ved metanolkonvertering ud fra CO er nemlig større end for CO2.
I kapitel 7.6 diskuteres hvilke krav der er til metanolkoncentrationen i vand/metanolblandingen
efter destillationen.
7.5.1.1 Økonomi
De økonomiske resultater for de 6 anlægskonfigurationer er præsenteret nedenfor.
Figur 7.8 viser hvilke udgifter der er ved metanolproduktion for hver af de 6
anlægskonfigurationer.
Figuren tydeliggør at anlæg nr. 3 er det billigste metanolanlæg mens anlæg nr. 6 er det
dyreste. Den vigtigste årsag til dette er elektricitetsforbruget af elektrolyseanlægget.
Det ses at netop disse 2 anlæg har henholdsvis det mindste og det største el-forbrug til
elektrolyse.
Dermed er fordelen ved udvaskning af CO2 fra forgasningsgas, som benyttes i anlæg
nr. 3, tydelig. Hvis anlæg 3 sammenlignes med anlæg 2, som også benytter biomasse
til syngasproduktionen, ses det at anlæg nr. 3 har opnået en stor besparelse på elforbruget
mod en lille udgift til udvaskning af CO2.
38

246
562
112
Anlæg 1
Total: 1222 mio. kr/år
123
210
Anlæg 4
Total: 1625 mio. kr/år
22
113
210
526
710
Anlæg 2
Total: 1433 mio. kr/år
158
232
323
135
Anlæg 5
Total: 1321 mio. kr/år
180
97
902
715
198
Anlæg 3
Total: 948 mio. kr/år
30
139
239
Anlæg 6
Total: 3444 mio. kr/år
312
Electricitet Mekanisk effekt NG Biogas
Biomasse CO2 CO2-fjernelse Investering og D&V
64
142
2908
Figur 7.8. Omkostningsfordelingen for de 6 anlægskonfigurationer. Den specifikke omkostning ved
CO2-fjernelse er 30,2 €/ton-CO2 [Teknologikataloget, 2005] 36 . De øvrige specifikke omkostninger,
samt oplysninger om investering og D&V, kan findes i kapitel 7.3.
Omkostningerne til investering og D&V for de 6 anlæg angivet på Figur 7.8 afspejler
anlægspriserne angivet i Tabel 7.18.
Det ses at anlæggene med forgassere (nr. 1, 2 og 3) er dyrere end de øvrige på nær
anlæg nr. 6, som specielt har en større udgift til metanolreaktoren, pga. den store
gasvolumenstrøm, som tilføres metanolreaktoren. Gasvolumenstrømmen til
metanolreaktoren er større for anlæg 6, fordi den recirkulerede gasvolumenstrøm er
større, idet CO2 er mindre reaktionsvilligt end CO. Desuden er udgiften til
elektrolyseanlægget også meget stor for anlæg 6.
Forskellen mellem anlæg 4 og 5 er også hovedsagelig pga. udgiften til
metanolreaktoren. Forklaringen på dette er den samme, som angivet ovenfor.
36 Prisen er for år 2004.
371
39

Anlægs-nr. Anlægspris
[mia. kr]
1 1,42
2 1,56
3 1,60
4 1,30
5 1,12
6 1,64
Tabel 7.18. Anlægspriser for de 6 metanolanlæg.
De samlede omkostninger, som blev angivet på Figur 7.8, er direkte proportionale
med den specifikke metanolomkostning vist på figuren nedenfor, idet
metanolproduktionen er den samme for alle 6 anlæg.
Metanolomkostning [kr/GJex]
500
450
400
350
300
250
200
150
100
50
0
Benzin
1 2 3 4 5 6
Anlægs-nr.
Figur 7.9. Den specifikke metanolomkostning for hver af de 6 anlægskonfigurationer. Til
sammenligning er prisen for benzin fra Tabel 7.19 angivet. I udregningen af den specifikke
metanolomkostning er der taget højde for indtjeningen for fjernvarmeproduktionen. Se betydningen af
dette på Figur 7.10.
40

Brændsel Pris Kilde
[kr/L] [kr/GJex] [kr/GJen]
Metanol 1,7 95 107
Metanol (kommerciel) 37 2,5 142 160 [Methanex, 2007] se bilag 12
Benzin (med afgift) 38 6,6 187 205
Råolie 39 2,2 58 61 [Bloomberg.com, 2007] se bilag 11
Etanol 40 2,4 100 111 [Ahring, 2006]
Tabel 7.19. Brændselspriser for en række relevante brændsler til sammenligning med
produktionsomkostningen for metanol for standardscenariet (angivet øverst i tabellen). Se bilag 9 for
opsplitning af benzinprisen. Afgiften angivet i bilaget er dog 4,04 kr/l i år 2002 (se bilag 10) og ikke
3,84 kr/l. Benzinprisen uden afgifter er dermed 74 kr/ GJex.
Figur 7.9 og Tabel 7.19 viser at de specifikke metanolomkostninger for mange af
anlæggene kan konkurrere med priserne for en række relevante brændsler. Det
skyldes ikke at omkostningerne til produktion af fx benzin og kommerciel metanol er
i samme størrelsesorden, som omkostningerne ved metanolproduktion i de undersøgte
anlæg, men at profitten er større på disse brændsler (samt afgift på benzin).
Udover metanol er fjernvarmen det eneste produkt fra metanolanlægget, som der
regnes med en indtjening fra. Den uomsatte syngas regnes dermed som et
spildprodukt.
Indtjeningen for fjernvarmeproduktionen for de 6 anlæg er proportionel med
fjernvarmeproduktionen (se Tabel 7.16), idet der regnes med en konstant specifik
indtjening på 150 kr/GJ.
I Danmark skal en fjernvarmeproduktion ”hvile i sig selv”, dvs. at udgifterne til
fjernvarmeproduktionen skal dækkes, men der må ikke skabes profit på
fjernvarmeproduktionen. Det vides ikke hvorledes omkostningerne til
fjernvarmeproduktionen udregnes for de 6 anlæg, men vis omkostningerne fordeles
mellem metanol og fjernvarme ud fra energiindhold opnås de specifikke
fjernvarmepriser som er angivet i Tabel 7.20.
På Figur 7.10 ses den specifikke metanolomkostnings afhængighed af den specifikke
fjernvarmeindtjening for anlæg nr. 3. Det ses, at ved en specifik fjernvarmeindtjening
på 118 kr/GJ (som angivet i Tabel 7.20) opnås en specifik metanolomkostning på 105
kr/GJex (svarende til 118 kr/GJ).
Den specifikke metanolomkostnings afhængighed af den specifikke
fjernvarmeindtjening for de øvrige anlæg er omtrent den samme (samme hældning på
graf), idet fjernvarmeproduktionen næsten er konstant for alle 6 anlæg (se Tabel 7.16).
37 €420/ton for marts 2007. Metanolprisen er steget voldsomt gennem de seneste år: I starten af 2002
var prisen derfor €125/ton. Metanol: HHV= 22,4 MJ/kg, LHV= 19,9 MJ/kg, ρ = 0,79 kg/l
38 Benzinpris på 8,2 kr/l d. 5/3-2007 fratrukket moms. Benzin: HHV= 35 MJ/l, LHV= 32 MJ/l.
39 Markedspris d. 5/3-2007: $60/bbl. Dollarkurs d. 5/3-2007: 5,8 kr/$. 1 bbl = 159 l. Råolie: HHV= 42
MJ/kg, LHV= 40 MJ/kg, ρ = 0,9 kg/l (værdierne kan variere).
40 Produktionsomkostning. Etanol: HHV= 23,4 MJ/l, LHV= 21,1 MJ/l.
41

Anlægs-nr.
Metanol og fjernvarme
[kr/GJ]
1 153
2 177
3 118
4 205
5 168
6 414
Tabel 7.20. Specifik metanol- og fjernvarme-omkostning, hvis omkostningerne fra anlæggene fordeles
på de 2 produkter efter energiindhold.
Metanolomkostning [kr/GJex]
115
110
105
100
95
90
85
80
75
Standardværdi
100 110 120 130 140 150 160 170 180 190 200
FV-indtjening [kr/GJ]
Figur 7.10. Den specifikke metanolomkostning som funktion af indtjeningen for den producerede
fjernvarme for anlæg nr. 3.
Nedenfor er den specifikke metanolomkostnings afhængighed af brændsel/inputpriserne
vist.
Det ses at el-prisen har klart den største indflydelse på den specifikke
metanolomkostning, hvilket stemmer overens med Figur 7.8.
Det vurderes, at der er mulighed for en afgiftslettelse på el-prisen til
metanolproduktion, ligesom el-afgiften for nylig blev nedsat for fjernvarmeværker,
som ønsker at producerer fjernvarme ud fra el.
Muligheden for afgiftslettelse anses for størst for de anlæg, som producerer metanol
ud fra vedvarende energi (anlæg nr. 2, 3, 5 og til dels 1 og 6).
42

Metanolomkostning [kr/GJex]
500
450
400
350
300
250
200
150
100
50
1
2
3
4
5
6
0
0 50 100 150 200
El-pris [kr/GJ]
250 300 350 400
Figur 7.11. Den specifikke metanolomkostning som funktion af el-prisen for de 6
anlægskonfigurationer. Standard-el-prisen fra Tabel 7.10 er angivet sammen med prisen uden afgifter
samt benzinprisen fra Tabel 7.19. Prisen for den mekaniske effekt antages at følge el-prisen, som
angivet ud fra ligningen under Tabel 7.10.
Metanolomkostning [kr/GJex]
500
450
400
350
300
250
200
150
100
50
0
1
2
3
4
5
6
Uden afgifter
Benzin
Uden afgifter
Benzin
Standardværdi
Standardværdi
0 30 60 90 120 150
NG-pris [kr/GJ]
Figur 7.12. Den specifikke metanolomkostning som funktion af naturgasprisen for de 6
anlægskonfigurationer. Standardnaturgasprisen fra Tabel 7.10 er angivet sammen med prisen uden
afgifter samt benzinprisen fra Tabel 7.19.
43

Metanolomkostning [kr/GJex]
500
450
400
350
300
250
200
150
100
50
1
2
3
4
5
6
0
0 10 20 30 40 50
Biomassepris [kr/GJ]
Figur 7.13. Den specifikke metanolomkostning som funktion af biomasseprisen for de 6
anlægskonfigurationer. Standardbiomasseprisen fra Tabel 7.10 er angivet sammen med benzinprisen
fra Tabel 7.19.
Metanolomkostning [kr/GJex]
500
450
400
350
300
250
200
150
100
50
0
1
2
3
4
5
6
Benzin
Benzin
Standardværdi
Standardværdi
0 10 20 30 40 50 60 70 80 90 100
Biogaspris [kr/GJ]
Figur 7.14. Den specifikke metanolomkostning som funktion af biogasprisen for de 6
anlægskonfigurationer. Standardbiogasprisen fra Tabel 7.10 er angivet sammen med benzinprisen fra
Tabel 7.19.
44

7.5.2 Parametervariation
Nedenfor er der foretaget en parametervariation for anlægskonfiguration nr. 3.
Denne anlægskonfiguration er valgt pga. den relativt høje metanolvirkningsgrad for
anlægget sammenholdt med anlæggets økonomi, som var den bedste af alle 6 anlæg,
som blev undersøgt i afsnit 7.5.1. Endelig er metanolproduktionen i anlæg 3 baseret
på vedvarende energi, i form af biomasse, hvilket tillægges stor betydning.
De parametre som er varieret nedenfor er:
• Metanolreaktortrykket
• Brint/kulstof-forholdet i syngassen
• Forgassertrykket
• Afkølingstemperaturen for den metanolholdige gas
7.5.2.1 Metanolreaktortrykket
I dette afsnit beskrives metanolreaktortrykkets påvirkning af en række parametre for
anlægskonfiguration nr. 3.
Metanolreaktortrykket er varieret fra 40-200 bar. Standardværdien er 144 bar.
Det optimale metanolreaktortryk forsøges bestemt.
I bilag 25 forefindes flowsheets for nogle af driftspunkerne 41 .
Først præsenteres påvirkningen på de termodynamiske parametre, hvorefter
påvirkningen på metanolomkostningen vises.
Metanolexergivirkningsgrad [%]
73
72
71
70
69
68
67
66
65
40 60 80 100 120
Reaktortryk [bar]
140 160 180 200
Figur 7.15. Metanolexergivirkningsgraden ηex, metanol ved varierende reaktortryk for anlæg 3.
41 40 bar, 82,7 bar og 200 bar.
45

På Figur 7.15 ses metanolreaktortrykkets påvirkning på
metanolexergivirkningsgraden (ηex, metanol). Det ses at højere reaktortryk giver bedre
virkningsgrad.
Forklaringen på dette kan ses ud fra Figur 7.16. Figur 7.16 viser at mængden af
uomsat syngas er mindst for højt metanolreaktortryk.
Figur 7.17 viser mere præcist hvorfor mængden af uomsat syngas er mindst for højt
metanolreaktortryk. Det ses at andelen af metanolstrømmen fra metanolreaktoren som
udkondenseres er størst for højt metanolreaktortryk. Størstedelen (95 %) af den
metanol som ikke udkondenseres efter metanolreaktoren recirkuleres til
metanolreaktoren, mens den resterende del havner i den uomsatte syngas, som
bortledes.
Uomsat syngas [MWex]
35
30
25
20
15
10
5
0
40 60 80 100 120
Reaktortryk [bar]
140 160 180 200
Figur 7.16. Exergistrømmen for den uomsatte syngas ved varierende reaktortryk for anlæg 3.
46

Udkondenseret metanol [%]
100
95
90
85
80
75
40 60 80 100 120
Reaktortryk [bar]
140 160 180 200
Figur 7.17. Andelen af metanolstrømmen fra metanolreaktoren som udkondenseres ved varierende
reaktortryk for anlæg 3.
Figur 7.18 og Figur 7.19 viser hvorfor andelen af metanolstrømmen fra
metanolreaktoren som udkondenseres, er størst for højt metanolreaktortryk.
Ud fra Figur 7.18 kan det ses at metanolandelen af gasstrømmen fra metanolreaktoren
er størst for højt reaktortryk, hvilket skyldes trykkets påvirkning af den kemiske
ligevægt. Det høje tryk medfører ligeledes at metanolandelen af gasstrømmen efter
afkølingen er meget lavt (Figur 7.19). Det skyldes gas/væske-ligevægten for vand og
metanol ved den temperatur som der afkøles til. Metanolpartialtrykket er imidlertid
næsten uafhængig af totaltrykket, hvorfor metanolandelen i den gas med det højeste
tryk er lavest.
47

y [mol-%]
50
45
40
35
30
25
20
15
10
5
0
40 60 80 100 120 140 160 180 200
Reaktortryk [bar]
H2
N2
CO
CO2
H2O
CH4
AR
CH3OH
Figur 7.18. Gassammensætningen i gasstrømmen fra metanolreaktoren ved varierende reaktortryk for
anlæg 3.
y [mol-%]
60
50
40
30
20
10
0
40 60 80 100 120 140 160 180 200
Reaktortryk [bar]
H2
N2
CO
CO2
H2O
CH4
AR
CH3OH
Figur 7.19. Gassammensætningen i den uomsatte syngas ved varierende reaktortryk for anlæg 3.
48

Metanolrenhed efter destillation [mol-%]
100
99.995
99.99
99.985
99.98
99.975
99.97
40 60 80 100 120 140 160 180 200
Reaktortryk [bar]
Figur 7.20. Metanolkoncentrationen efter destillationen ved varierende reaktortryk for anlæg 3.
Ved at se på reaktortrykkets påvirkning på virkningsgraden var det klart at højt
reaktortryk var optimalt, men det er også nødvendigt at se på påvirkningen af
metanolkoncentrationen efter destillationen, idet metanolkoncentrationen efter
destillationen skal være tilstrækkelig høj.
Ud fra Figur 7.20 ses det at metanolkoncentrationen efter destillationen er højest ved
højt tryk. Forklaringen på det kan ses ud fra Figur 7.21 og Figur 7.22.
Figur 7.21 viser at varmemængden til destillationen er størst for højt tryk, hvilket
skyldes forskellen i den varmemængde, som udvindes ved afkølingen af den
metanolholdige gas efter metanolreaktoren. Ved lavt tryk (mindre end ca. 80 bar) må
denne varmeveksler nemlig udkobles, idet gastemperaturen til varmeveksleren bliver
for lav i forhold til temperaturen af den metanol/vand-blanding, som skal fordampes.
Varmemængden fra metanolreaktoren, som er den anden kilde til destillationsvarme,
er imidlertid næsten uafhængig af reaktortrykket, men ved lavt tryk må en lille del af
denne varme anvendes til tørring af biomasse.
Figur 7.22 viser reaktortrykkets påvirkning på metanolkoncentrationen før
destillationen. Det ses at den højeste metanolkoncentration faktisk opnås ved lavt
reaktortryk, men pga. destillationsvarmen er lavere ved lavt tryk, opnås der en lavere
metanolkoncentration efter destillationen.
49

Destillationsvarme [MW]
Metanolrenhed før destillation [mol-%]
44
43
42
41
40
39
38
37
36
35
34
33
32
31
30
40 60 80 100 120 140 160 180 200
Reaktortryk [bar]
98
97
96
95
94
93
92
91
90
Figur 7.21. Destillationsvarmen ved varierende reaktortryk for anlæg 3.
40 60 80 100 120
Reaktortryk [bar]
140 160 180 200
Figur 7.22. Metanolkoncentrationen før destillationen ved varierende reaktortryk for anlæg 3.
Grunden til at metanolkoncentrationen før destillationen er lavest ved ca. 80 bar, kan
ses ud fra Figur 7.23 og Figur 7.24.
Figur 7.23 viser at vandkoncentrationen i syngassen er størst ved ca. 80 bar, og idet
molstrømmen af syngas næsten er uafhængig af trykket, er vandmængden i syngassen
størst ved ca. 80 bar. Vandet i syngassen stammer fra damptilførslen i forgasseren, og
denne damptilførsel følger kurven på Figur 7.24 idet mere tilført damp betyder mere
CO2 i forgasningsgassen, som derefter udvaskes i gasrenseren. Grunden til at
50

vandkoncentrationen i syngassen falder efter ca. 80 bar er, at der udkondenseres mere
vand fra syngassen i kompressionsmellemkølingen desto højere trykket bliver.
Figur 7.22 viser imidlertid at metanolkoncentrationen før destillationen er højere ved
ca. 40 bar end ved 200 bar, hvilket ikke stemmer overens med Figur 7.23.
Forklaringen på dette er at en større del af vandmængden i syngassen omdannes vha.
shiftreaktionen (Ligning 7.18) ved lavt tryk, idet der er mere CO tilgængeligt (jævnfør
Figur 7.24).
yH2O [mol-%]
M [-]
9
8
7
6
5
4
3
2
1
0
40 60 80 100 120
Reaktortryk [bar]
140 160 180 200
1.45
Figur 7.23. Vandkoncentrationen i syngassen ved varierende reaktortryk for anlæg 3.
1.9
1.85
1.8
1.75
1.7
1.65
1.6
1.55
1.5
1.4
40 60 80 100 120
Reaktortryk [bar]
140 160 180 200
Figur 7.24. Brint/kulstof-forholdet for syngassen ved varierende reaktortryk for anlæg 3. I anlæg 3 er
alt kulstof i syngassen i form af CO.
51

Specifik metanolomkostning [kr/GJex]
110
105
100
95
90
85
80
75
70
65
60
55
Reference Uden kompressionsomkostninger
50
40 60 80 100 120 140 160 180 200
Reaktortryk [bar]
Figur 7.25. Den specifikke metanolomkostning ved varierende reaktortryk for anlæg 3. Til
sammenligning er den specifikke metanolomkostning uden kompressionsomkostningerne vist.
Figur 7.25 viser, at den laveste metanolomkostning opnås ved ca. 150 bar. Grunden til
at metanolomkostningen ikke er mindre ved 200 bar er at omkostningerne til
kompressionsarbejdet stiger mere end omkostningerne til biomasse og el til
elektrolyseanlægget falder.
Det optimale reaktortryk er dermed omkring 150 bar for anlæg 3, idet virkningsgraden
næsten var konstant fra 150 bar til 200 bar. Det er dog med det forbehold at
metanolkoncentrationen efter destillationen ved 150 bar er tilstrækkelig højt.
Hvis der kommer en afgiftslettelse på el til metanolproduktion, vil det være
fordelagtigt at øge trykket til ca. 200 bar, idet el-forbruget er størst ved 200 bar.
Omkostningerne vist på Figur 7.25 er stort set uafhængige af indtjeningen fra
fjernvarmen, da fjernvarmeproduktionen næsten er uafhængig af reaktortrykket.
7.5.2.2 Brint/kulstof-forholdet i syngassen
I dette afsnit beskrives brint/kulstof-forholdets påvirkning af en række parametre for
anlægskonfiguration nr. 3.
Brint/kulstof-forholdet i syngassen varieres ved at ændre hvor meget damp der tilføres
forgasseren, idet mere damp betyder mere CO2 i forgasningsgassen, som derefter
udvaskes i gasrensningen.
Brint/kulstof-forholdet i syngassen varieres fra M=1,55 til M=2,35. Standardværdien
er M=1,78.
Det optimale brint/kulstof-forhold i syngassen forsøges bestemt.
I bilag 26 forefindes flowsheets for nogle af driftspunkerne 42 .
Først præsenteres påvirkningen på de termodynamiske parametre, hvorefter
påvirkningen på metanolomkostningen vises.
42 M=1,55 og M=2,35.
52

Metanolexergivirkningsgrad [%]
73
72
71
70
69
68
67
66
65
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.26. Metanolexergivirkningsgraden ηex, metanol ved varierende brint/kulstof-forhold for syngassen
(M) for anlæg 3.
Figur 7.26 viser at den højeste metanolexergivirkningsgrad opnås ved ca. M=1,85.
Forklaringen på det kan ses ud fra Figur 7.27, som viser at det mindste exergitab i
form af uomsat syngas opnås ved ca. M=1,85.
Ud fra teorien kunne man forvente at det mindste exergitab i form af uomsat syngas
ville opnås ved M=2, da en syngas med dette brint/kulstof-forhold i teorien kan
omdannes fuldstændigt til metanol.
Molstrømmen af uomsat syngas er dog også mindst ved M=2, men exergiindholdet i
brint er imidlertid så stort, at det mindste exergitab i form af uomsat syngas opnås ved
et lidt lavere brint/kulstof-forhold.
53

Uomsat syngas [MWex]
35
30
25
20
15
10
5
0
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.27. Exergistrømmen for den uomsatte syngas ved varierende brint/kulstof-forhold for
syngassen (M) for anlæg 3.
Figur 7.28 viser hvor meget gassammensætningen i den uomsatte syngas afhænger af
brint/kulstof-forholdet. Ved M=2 svarer andelen af brint i den uomsatte syngas til
andelen af brint i syngassen, mens andelen af brint i den uomsatte syngas for M=1,78
(30 mol-%) er meget lavere end andelen i syngassen, som er på 61 mol-%.
y [mol-%]
100
90
80
70
60
50
40
30
20
10
0
H2
N2
CO
CO2
H2O
CH4
AR
CH3OH
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.28. Gassammensætningen i den uomsatte syngas ved varierende brint/kulstof-forhold for
syngassen (M) for anlæg 3.
54

Metanolrenhed efter destillation [mol-%]
100
99.995
99.99
99.985
99.98
99.975
99.97
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.29. Metanolkoncentrationen efter destillationen ved varierende brint/kulstof-forhold for
syngassen (M) for anlæg 3.
Ved at se på brint/kulstof-forholdets påvirkning på virkningsgraden var det klart at et
forhold på M=1,85 var optimalt, men det er også nødvendigt at se på påvirkningen af
metanolkoncentrationen efter destillationen, idet metanolkoncentrationen efter
destillationen skal være tilstrækkelig høj.
Ud fra Figur 7.29 ses det at metanolkoncentrationen efter destillationen er højest ved
det laveste brint/kulstof-forhold. Forklaringen på det kan ses ud fra Figur 7.30 og
Figur 7.31.
Figur 7.30 viser at metanolkoncentrationen før destillationen, ligesom
koncentrationen efter destillationen, er højest ved det laveste brint/kulstof-forhold.
Destillationsvarmen vist på Figur 7.31 varierer dermed ikke i en sådan grad at
tendensen fra Figur 7.30 ikke kan genfindes på Figur 7.29.
Grunden til at metanolkoncentrationen før destillationen er højest ved det laveste
brint/kulstof-forhold er, at der omsættes mere vand vha. shiftreaktionen (Ligning
7.18) ved lavt brint/kulstof-forhold, idet der er mere CO tilgængeligt. Vandet
omdannes på den måde til CO2 og ender i den uomsatte syngas (Figur 7.28).
55

Metanolrenhed før destillation [mol-%]
Destillationsvarme [MW]
100
99
98
97
96
95
94
93
92
91
90
89
88
87
86
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.30. Metanolkoncentrationen før destillationen ved varierende brint/kulstof-forhold for
syngassen (M) for anlæg 3.
43
42
41
40
39
38
37
36
35
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.31. Destillationsvarmen ved varierende brint/kulstof-forhold for syngassen (M) for anlæg 3.
Variationen i destillationsvarmen, som kan ses på Figur 7.31 skyldes at varmen til
destillation opnået ved afkøling af den metanolholdige gas efter metanolreaktoren er
højest ved M=2. Forklaringen på det er at varmen benyttet til forvarmning af den
recirkulerede gas er mindst ved M=2, idet molstrømmen af den recirkulerede gas er
mindst. Samtidig er temperaturen af metanol/vand-blandingen fra
destillationskolonnen, som skal fordampes, mindst ved lavt brint/kulstof-forhold.
56

Dette betyder at den metanolholdige gas kan afkøles til en tilsvarende lavere
temperatur, som forklarer hvorfor destillationsvarmen øges fra M=1,65 til M=1,55.
Temperaturen af metanol/vand-blandingen fra destillationskolonnen, som skal
fordampes, er mindst når metanolkoncentrationen før destillationen er højest.
Varmen opnået ved afkøling af metanolreaktoren, som er den anden kilde til
destillationsvarme er næsten uafhængig af brint/kulstof-forholdet.
Specifik metanolomkostning [kr/GJex]
112
110
108
106
104
102
100
98
96
94
92
1.5 1.6 1.7 1.8 1.9 2 2.1 2.2 2.3 2.4
M [-]
Figur 7.32. Den specifikke metanolomkostning ved varierende brint/kulstof-forhold for syngassen (M)
for anlæg 3.
Figur 7.32 viser, at den laveste metanolomkostning opnås ved ca. M=1,85, hvilket
svarer til det brint/kulstof-forhold som gav den bedste virkningsgrad (Figur 7.26).
Det optimale brint/kulstof-forhold er dermed omkring M=1,85. Det er dog med det
forbehold at metanolkoncentrationen efter destillationen ved M=1,85 er tilstrækkelig
højt.
Omkostningerne vist på Figur 7.32 er stort set uafhængige af indtjeningen fra
fjernvarmen, da fjernvarmeproduktionen næsten er uafhængig af brint/kulstofforholdet.
7.5.2.3 Forgassertrykket
I dette afsnit beskrives forgassertrykkets påvirkning af en række parametre for
anlægskonfiguration nr. 3.
Tryksat forgasning ved 5 bar sammenlignes med atmosfærisk forgasning (1 bar).
Standardkonfigurationen er atmosfærisk forgasning.
I bilag 27 forefindes flowsheet’et for metanolanlægget med tryksat forgasning.
57

Atmosfærisk forgasning
(1 bar)
Tryksat forgasning
(5 bar)
cmetanol [kr/GJex] 95 89
Pkompression [MWel] 25 17
Q & fjernvarme [MJ/s] 74 66
Tabel 7.21. Forgassertrykkets påvirkning af en række parametre for anlæg nr. 3.
Ud fra Tabel 7.21 ses det, at metanolomkostningerne kan reduceres ved overgang til
tryksat forgasning. Forklaringen på det er, at kompressionsomkostningerne reduceres
ved at kompressionsarbejdet mindskes fra 25 MWel til 17 MWel. Faldet i
kompressionsarbejdet sænker dog også fjernvarmeproduktionen med samme omfang
(8 MJ/s), hvilket gør at metanolomkostningerne ikke reduceres mere end til 89
kr/GJex.
I disse beregninger er det antaget at den specifikke forgasserpris er konstant. I
realiteten vil den formentlig være større for den tryksatte forgasser. Samtidig vil der i
praksis også være et energiforbrug i forbindelse med tilførsel af biomasse til den
tryksatte forgasser. Dette mindsker samlet set fordelen ved benyttelse af tryksat
forgasning.
I modellen er effektforbruget til tryksætningen af dampen til den tryksatte forgasserer
heller ikke medregnet. Dampen vil dog med fordel kunne tryksættes inden den
fordampes, dette kræver dog et andet modeldesign omkring den tryksatte forgasser.
Forskellen mellem parametrene angivet i Tabel 7.22 skyldes modelopbygningen af
metanolanlægget, men vil i realiteten ikke afvige meget fra hinanden.
Modellen af metanolanlægget er konstrueret på en sådan måde at udvaskningen af
CO2, som benyttes i anlæg nr. 3, foregår ved at alt CO2 fjernes fra forgasningsgassen.
Det ønskede brint/kulstof-forhold opnås derfor ved at ændre mængden af damp som
tilføres forgasseren, idet mere damp betyder mere CO2 i forgasningsgassen.
Ved tryksat forgasning vil andelen af metan i forgasningsgassen imidlertid øges pga.
trykkets påvirkning af den kemiske ligevægt (se Tabel 7.22). Metanandelen kunne
sænkes ved at øge damptilførslen til forgasseren, men dette vil i modellen påvirke
brint/kulstof-forholdet pga. en øget CO2-udvaskning.
Hvis kun en del af CO2’en i forgasningsgassen blev udvasket i modellen ville
metanandelen i forgasningsgassen fra den tryksatte forgasser kunne sænkes ved at øge
damptilførslen til forgasseren uden at påvirke brint/kulstof-forholdet, hvilket ville
give en mere realistisk driftssituation.
Resultaterne angivet i Tabel 7.21 vil dog ikke være påvirket nævneværdigt af
ovenstående, idet forskellen mellem omkostningerne for anlæggene med tryksat og
atmosfærisk forgasning svarer til reduktionen i kompressionsomkostningerne.
58

Atmosfærisk forgasning
(1 bar)
Tryksat forgasning
(5 bar)
ηex, metanol [%] 72 68
Ėex, uomsat syngas [MWex] 8 32
y CH4 , uomsat syngas [mol-%] 3 32
y [mol-%] 0,15 2,23
,
CH 4
FG
xmetanol, efter destillation [mol-%] 99,992 99,974
xmetanol, før destillation [mol-%] 93,8 90,4
Q & destillation [MJ/s] 41,4 33,9
Tabel 7.22. Forgassertrykkets påvirkning af en række parametre for anlæg nr. 3. Forskellen mellem
disse parametre skyldes modelopbygningen af metanolanlægget (læs ovenfor).
7.5.2.4 Afkølingstemperaturen for den metanolholdige gas
I dette afsnit beskrives påvirkningen på en række parametre for anlægskonfiguration
nr. 3 ved variation af afkølingstemperaturen for den metanolholdige gas.
Afkølingstemperaturen for den metanolholdige gas er defineret som temperaturen i
node 605 eller 611 (se fx bilag 22). Standardtemperaturen er 60°C og der
sammenlignes med en afkølingstemperatur på 100°C.
I bilag 28 forefindes flowsheet’et for metanolanlægget ved en afkølingstemperatur på
100°C.
Tafkøling = 60°C Tafkøling = 100°C
ηex, metanol [%] 71,82 71,51
Ėex, uomsat syngas [MWex] 7,8 8,9
Udkondenseret metanol 43 [%] 98 92
y [mol-%] 0,59 2,45
CH3OH, uomsat syngas
xmetanol, efter destillation [mol-%] 99,992 99,994
xmetanol, før destillation [mol-%] 93,8 93,8
Q & destillation [MJ/s] 41,4 43,7
Q & fjernvarme [MJ/s] 73,85 74,02
cmetanol [kr/GJex] 94,5 95,1
Tabel 7.23. Afkølingstemperaturens påvirkning af en række parametre for anlæg nr. 3.
Ud fra Tabel 7.23 ses det at effekterne ved at variere afkølingstemperaturen er
begrænsede. Der ses dog et lille fald i virkningsgrad ved at øge afkølingstemperaturen
pga. et øget tab af exergi i form af uomsat syngas. Grunden til det øgede tab af exergi
i form af uomsat syngas er, at der udkondenseres mindre metanol fra gassen.
Metanolkoncentrationen i den afkølede gas bestemmes af gas/væske ligevægten for
metanol og vand ved den temperatur, som der afkøles til.
Tabel 7.23 viser også at metanolkoncentrationen efter destillationen øges ved at hæve
afkølingstemperaturen, idet destillationsvarmen øges.
43 Angiver hvor stor en del af metanolen fra metanolreaktoren som udkondenseres. Størstedelen (95 %)
af den metanol som ikke udkondenseres recirkuleres til metanolreaktoren.
59

Destillationsvarmen øges pga. destillationsvarmen udvundet ved at afkøle den
metanolholdige gas øges, idet varmen brugt til forvarmning af den recirkulerede gas
til metanolreaktoren mindskes, da temperaturen kun skal hæves fra 100°C.
Grunden til den lille stigning i metanolomkostningerne, som opstår ved at hæve
afkølingstemperaturen (se Tabel 7.23), skyldes hovedsagelig en stigning i el- og
brændsels-omkostningerne, pga. den lidt lavere virkningsgrad ved højere
afkølingstemperatur.
Den lille ændring i fjernvarmeproduktionen har ikke nogen reel betydning.
Ud fra Tabel 7.23 og Tabel 7.24 kan det også konkluderes at det ikke kan betale sig at
sænke afkølingstemperaturen yderligere, hvilket ville medføre at varmen udvundet
ved denne afkøling ikke ville kunne udnyttes til fjernvarme, medmindre
varmeveksleren blev opdelt i 2.
Afkølingsvarme til fjernvarme Afkølingsvarme ikke til fjernvarme
Q& fjernvarme [MJ/s] 73,8 68,1
cmetanol [kr/GJex] 94,5 98,2
Tabel 7.24. Fjernvarmeproduktionens og den specifikke metanolomkostnings afhængighed af om
varmen udvundet ved afkøling af den metanolholdige gas udnyttes til fjernvarme (varmeveksleren, som
er placeret efter node 643, se fx bilag 22)
60

7.6 Diskussion
I parametervariationen ovenfor blev det vist at værdierne for metanolreaktortrykket og
brint/kulstof-forholdet, som blev benyttet i simuleringerne for anlægskonfiguration nr.
3 i sammenligning med de øvrige anlægskonfigurationer, var tæt på de optimale
værdier.
De optimale værdier for de 2 parametre for de øvrige anlægskonfigurationer er
nødvendigvis ikke de samme. Det vurderes imidlertid, at det optimale reaktortryk for
de øvrige anlægskonfigurationer ikke er mindre, idet problemet med uomsat syngas
ved lavere reaktortryk, må være mere udtalt for de øvrige anlægskonfigurationer
(jævnfør Tabel 7.16 og Figur 7.16), pga. CO2 er mindre reaktionsvilligt end CO.
Uomsat syngas var hovedårsagen til at både virkningsgrad og metanolomkostning var
lavest ved et metanolreaktortryk på 150 bar eller derover.
Ligeledes vurderes det at brint/kulstof-forholdene benyttet for de øvrige
anlægskonfigurationer, som var mellem M=1,31 og M=1,72 (Tabel 7.16) var tæt på
de optimale værdier.
Det skyldes, at et højere brint/kulstof-forhold ville betyde et for stort tab af brint i den
uomsatte syngas 44 , hvilket både ville betyde lavere virkningsgrad og højere
omkostninger. Et lavere brint/kulstof-forhold ville bl.a. kræve en endnu større
metanolreaktor, idet den recirkulere volumenstrøm af uomsat syngas ville øges,
hvilket også ville øge omkostningerne.
Et lavt brint/kulstof-forhold i metanolreaktoren betyder også at produktionen af
biprodukter, som fx etanol øges [Hansen, 1998], hvilket betyder en lavere
metanolproduktion og en dyrere destillationsproces.
Det optimale metanolreaktortryk og brint/kulstof-forhold for de 6
anlægskonfigurationer afhænger også af hvad kravene til metanolkoncentrationer efter
destillation er. Kravene til metanolkoncentrationen afhænger imidlertid af hvilket
marked, som metanolen produceres til.
Kommercielt metanol har en renhed på 99,99 % 45 og 46 [NZIC,2007], men hvis
metanolen benyttes til iblanding i benzin eller diesel kan en koncentration på 99,85
% 45 [Nykomb, 1997] benyttes.
Motorforsøg med en dieselmotor viser dog, at metanol kan indeholde nogle procent
vand uden problemer for dieselmotoren [Nykomb, 1997].
Hvis den producerede metanol tænkes benyttet i DMFC brændselsceller, er vand i
metanolen heller ikke noget problem, idet brændslet til disse brændselsceller består af
vand med en lav metanolkoncentration. Biprodukterne ved metanolproduktionen, vil
imidlertid muligvis medføre at en destillation af metanolen alligevel er påkrævet.
44 Brint/kulstof-forholdet blev bestemt ved at fastholde brintandel i den uomsatte syngas på 30 mol-%.
45 Det er ikke angivet i kilden om det er mol-% eller vægt-%.
46 Værdien for metanolkoncentrationen stammer fra metanolanlæg ejet af Methanex. Methanex er også
kilden til den kommercielle metanolpris benyttet tidligere i rapporten.
61

Anlægs-nr. xmetanol, efter destillation
[mol-%]
1 99,98
2 99,98
3 99,99
4 99,89
5 99,96
6 99,51
Tabel 7.25. Metanolkoncentrationer efter destillation af vand/metanol-blandingen for de 6 forskellige
anlægskonfigurationer. Værdier fra Tabel 7.17.
Ud fra Tabel 7.25og beskrivelsen ovenfor 47 kan det konkluderes at anlæg 3 er det
eneste anlæg som kan producere kommercielt metanol, mens de øvrige anlæg 48 ved de
undersøgte driftspunkter kan producere metanol til iblanding med benzin og diesel.
Værdierne angivet i Tabel 7.25 er dog kun vejledende, idet destillationen i modellen
af metanolanlægget kun omfatter destillation af en metanol/vand-blanding, som
dermed ikke inkluderer de biprodukter, der også skal destilleres fra i et metanolanlæg.
7.6.1 Forbedring af anlægsdesign
Nedenfor er angivet nogle forslag til forbedring af anlægsdesignet for
metanolanlægget:
• Udnyttelse af uomsat syngas
• Udnyttelse af metanol fra spildvandet fra destillationsprocessen
Den uomsatte syngas fra metanolkonverteringskredsen, som i dette anlægsdesign
udgør flere MW (19 MW for anlæg nr. 4), kan anvendes til el-produktionen vha. en
gasturbine, et brændscellesystem eller ved at sende gassen til et kraftværk.
Gassen kunne også benyttes til dampproduktion, som kunne drive kompressorerne i
anlægget.
I forbindelse disse udnyttelsesmuligheder kan der også produceres varme, som fx kan
benyttes til destillationsprocessen eller fjernvarme.
Spildevandet fra destillationsprocessen, som har et metanolindhold på ca. 2,3 MWex i
det undersøgte anlægsdesign kan udnyttes til dampproduktion til dampreformeren i
stedet for rent vand. Hvis dampreformeren ikke benyttes afhænger
udnyttelsespotentialet af metanolkoncentrationen i spildevandet. Denne
metanolkoncentrationen varierer fra 1 mol-% (anlæg 6) til 13 mol-% (anlæg 3). Hvis
metanolkoncentrationen er for lav, kan det formentlig ikke betale sig at udvinde
metanolen.
Endelig kan anlægsdesignet forbedres på en sådan måde, at nogle af antagelserne
angivet i afsnit 7.1.5 kan undværes.
47
Hvis det antages at metanolkoncentrationerne angivet i [NZIC,2007] og [Nykomb, 1997] er i mol-%.
48
Metanolkoncentrationen for anlæg nr. 6 er lavere end 99,85 %, men det vides ikke hvor streng denne
grænse er.
62

7.6.2 Alternative anlægsdesign
Nedenfor er angivet nogle forslag til alternative anlægsdesign, hvis følgende krav gør
sig gældende:
• Metanolkoncentrationen efter destillationen skal øges
• Forgasningen skal foregå under tryk
Hvis metanolkoncentrationen efter destillationen skal øges, kan enten
destillationsvarmen eller metanolkoncentrationen før destillationen øges.
Destillationsvarmen kan fx øges ved at opdele forvarmningen af den uomsatte syngas
i metanolkonverteringsloopet ved at tilføje en varmeveksler mellem varmeveksleren
som producerer fjernvarme og varmeveksleren som leverer destillationsvarme. Det vil
øge destillationsvarmen, fordi temperaturen af den metanolholdige gas til
varmeveksleren, som leverer destillationsvarme, vil øges.
Destillationsvarmen kan også øges ved at sænke destillationstrykket, hvorved den
omtalte varmeveksler, som leverer destillationsvarme, kan afkøle den metanolholdige
gas til en lavere temperatur. Hvis destillationstrykket sænkes skal fjernvarmevandet
produceret ud fra spildvarmen fra destillationen dog eftervarmes. Det kan lade sig
gøre i nogle af de andre varmevekslere som producerer fjernvarme andre steder i
anlægget.
Metanolkoncentrationen før destillationen kan fx øges ved at afkøle syngassen
yderligere inden den tilføres metanolkonverteringsloopet, således at yderligere vand
udkondenseres. Varmen fra denne afkøling kan til dels benyttes til
fjernvarmeproduktion og syngassen kan efter afkølingen forvarmes med en del af
kompressormellemkølingsvarmen.
I forbindelse med anlægskonfiguration nr. 3 kan denne forbedrede tørring af
syngassen muligvis medføre, at metanolkoncentrationen før destillationen bliver så
høj, at metanolen kan benyttes som brændstof til transportsektoren - evt. ved
tilsætning til benzin eller diesel - uden destillation.
Hvis tryksat forgasning ønskes anvendt kan problematikken i forbindelse med tilførsel
af biomassen til forgasseren løses ved at forbehandle biomassen, så den gøres
flydende, hvilket muliggør at biomassen kan pumpes ind i forgasseren (entrained flow
forgasning). Det betyder naturligvis at tørring af biomassen ikke kan benyttes, hvilket
medfører, at en betydelig del af brændværdien i biomassen benyttes til fordampning af
vand.
7.6.3 Integration med andre anlæg
Hvis metanolanlægget integreres i et kraftværk, som VEnzin-visionen lægger op til,
kan der opnås en række fordele – både økonomisk og exergimæssigt.
3 oplagte muligheder for integration mellem de to anlæg er:
• Den del af varmen udvundet ved afkøling af forgasningsgassen, som i modellen
benyttes til dampproduktion til tørring af biomasse kunne i stedet benyttes til
overhedning af højtryksdamp fra et kraftværk, mod at kraftværket leverede
lavtemperaturdamp til tørringen af biomassen. Det vil samtidig kunne betyde at
kompressormellemkølingsvarmen ikke behøves at blive benyttet til tørring af
biomasse, hvilket kan medføre at gastemperaturerne inden kompressorerne kan
63

sænkes. Kompressormellemkølingsvarmen kan i stedet evt. benyttes til
fjernvarme, hvilket kun vil betyde et ca. 10 % højere kompressionsarbejde 49 .
• Den del af varmen udvundet ved afkøling af reformergassen, som i modellen
benyttes til dampproduktion til dampreformeren kunne i stedet benyttes til
overhedning af højtryks- og lavtryksdamp fra et kraftværk. Højtryksdampen skulle
benyttes i kraftværket mens lavtryksdamp (ved dampreformeringstrykket)
benyttes i dampreformeren.
• Kompressorerne i metanolanlægget kan drives dampturbiner, som får leveret
højtryksdamp fra kraftværket.
For at integrationen mellem metanolanlægget og kraftværket skal give mening, skal
elektrolyseanlægget ikke være i drift når kraftværket producerer elektricitet. Det
skyldes, at kraftværket med fordel kan producere elektricitet når el-prisen er høj, mens
elektrolyseanlægget med fordel kan være i drift når el-prisen er lav.
Ved benyttelse af det buffersystem til elektrolyseanlægget, som omtales i anden del af
rapporten (kapitel 8), er integrationen mellem de to anlæg mulig.
Ud over integration med et kraftværk lægger VEnzin-visionen også op til integration
med en etanolproduktion. Fordelene ved at integrere disse to anlæg er:
• Biomasserestproduktet fra etanolproduktionen kan benyttes i forgasseren i
metanolanlægget.
• Brinten og CO2’en, som udledes fra etanolproduktionen, kan benyttes til
syngasproduktion i metanolanlægget.
Udover disse to integrationsmuligheder, vil varme ved forskellige temperaturer,
formentlig også med fordel kunne udveksles.
49 Hvis kompressionsarbejdet sammenlignes for kompressorindgangstemperaturne 30°C og 60°C.
64

8 Benyttelse af underjordiske gaslagre til brint
og ilt i et metanolanlæg
I denne del af rapporten undersøges det, hvorvidt det er økonomisk fordelagtigt at
benytte underjordiske gaslagre til brint og ilt i et metanolanlæg, som inkluderer et
elektrolyseanlæg.
Gaslagrene tænkes benyttet i et buffersystem, således at elektrolyseanlægget
producerer brint og ilt til lagrene, samtidig med at der er et forbrug af brint og ilt fra
lagrene til metanolproduktion. På denne måde kan driften af elektrolyseanlægget
afkobles fra det øvrige metanolanlæg.
Det undersøges, om omkostningerne kan nedsættes, ved kun at have
elektrolyseanlægget i drift når el-prisen er lav, mens det resterende metanolanlæg
opererer med et maksimum af driftstimer.
Der er opstillet 2 scenarier, for at kunne undersøge dette. De gennemgås i det
følgende, efter et kapitel om underjordiske brintlagre
65

8.1 Underjordiske brintlagre
Hvis der ønskes opbevaret store mængder brint, er den klart billigste løsning et
underjordisk brintlager [Amos, 1998].
Et underjordisk brintlager kan etableres ud fra tomme olie- eller gas-felter, i salt
horste, klippe hulrum (rock caverns) eller i vandførende jordlag (aquifers) [Taylor et
al., 1986].
I litteraturen kan man finde meget forskellige priser for et underjordisk brintlager (se
Tabel 8.1), bl.a. fordi det afhænger af hvilken af de 4 lagertyper, som benyttes, og om
hulrummene er naturligt forekommende, eller de skal mineres.
Erfaringerne med underjordiske brintlagre tæller bl.a. et lager ved Beynes i Frankrig,
hvor Gaz de France har opbevaret bygas indeholdende 50 % brint i et aquifer-lager på
330 mio. Nm 3 fra 1957 til 1974 uden nogen særlige problemer overhovedet.
Et andet eksempel er Imperial Chemical Industries ved Teeside i England, som
opbevarer/opbevarede brint i en salt horst ved 50 bar [Taylor et al., 1986].
I Danmark benytter man i dag salt horste som naturgaslagre i naturgasnettet. Salt
horste, der kan benyttes til gaslagring, forefindes kun i Nordjylland i Danmark
[Jørgensen, 2007]. Hvis det ønskes at konstruere gaslagre andre steder i Danmark, kan
der fx konstrueres aquifer-lagre. Denne type gaslager benyttes som naturgaslager ved
Stenlille på Sjælland. Det kan imidlertid være et problem at få tilladelse til opførsel af
et sådant lager, bl.a. pga. en større risiko for udsivning [Jørgensen, 2007].
I en intern DONG-rapport lavet af DONG, KBB, Rambøll og MTS [DONG, 2003] er
det undersøgt, hvad et gaslager i en salt horst ved Lille Torup i Jylland vil koste.
Lageret tænkes benyttet til CAES (Compressed Air Energy Storage), og er på 500.000
m 3 . Hvis prisen for gaslageret omregnes til en energispecifik pris for et brintlager 50 ,
vil denne ligge under værdierne angivet i Tabel 8.1. Den eksakte pris er fortrolig.
Prisen angivet i [DONG, 2003] er detaljeret sammensat af delomkostninger, og må
anses for en passende kilde, idet lagerprisen er for et gaslager placeret i Danmark,
hvilket denne rapport også tager udgangspunkt i. Endeligt er lagerstørrelsen (500.000
m 3 ) også tilstrækkelig til formålet (jævnfør resultaterne senere i rapporten).
Kilde Original værdi Omregnet værdi
[kr/MJ]
[Teknologikataloget, 2005] 0,2 kr/MJ 0,2
[Amos, 1998] $2,50-$18,90/kg-H2 0,125 – 0,945
Tabel 8.1. Specifikke brintlagerpriser (cbrintlager) fra en række kilder. [Amos, 1998] er en
oversigtsrapport ligesom Teknologikataloget, hvorfor det angivede interval stammer fra 3 andre kilder
(publiceret 1986-1994).
Til denne undersøgelse anvendes prisen fra [Teknologikataloget, 2005], fordi den
anses for et fornuftigt kompromis, og samtidig delvist bygger på [Amos, 1998]. I den
høje ende af prisintervallet angivet af [Amos, 1998] er der desuden typisk medtaget
udstyr som kompressorer og lignende. Det er ikke ønskeligt i denne sammenhæng, da
lageret integreres i et metanolanlæg, som allerede indeholder det meste af dette
udstyr.
50 i omregningen til er der antaget et brintlagertryk på ca. 100 bar. LHVbrint=10,78 MJ/Nm 3
66

8.2 Scenarier
Der er undersøgt 2 scenarier i forbindelse med benyttelse af gaslagre i sammenhæng
med et elektrolyseanlæg i et metanolanlæg.
Det første scenarie undersøger, hvad der er teoretisk muligt at mindske
omkostningerne med ved benyttelse af gaslagre. Det andet scenarie undersøger, hvad
omkostningerne i realiteten kan mindskes med.
I begge scenarier antages det at metanolanlægget - eksklusiv elektrolyseanlægget – er
i drift hele året. Antallet af driftstimer for elektrolyseanlægget – og dermed også
størrelsen af elektrolyseanlægget – optimeres efter økonomi.
I tabellen nedenfor er værdierne for en række nøgleparametre, som benyttes til
simuleringerne, angivet.
Parameter Værdi Evt. kilde/kommentar
celektrolyse 1,5 mio. kr/MWe
cbrintlager 0,2 kr/MJ [Teknologikataloget, 2005]
klagerpris 1 51
ηelektrolyse 80 %
Levetid 15 år
rD&V 2 %
r 5 % Antaget kalkulationsrente
klager-max/min 5 Læs nedenfor
Tabel 8.2. Standardværdier benyttet i simuleringerne for scenarierne. Definitionen for ηelektrolyse er vist i
Ligning 7.2 på side 14. Værdierne uden kildeanvisning eller kommentar er sat efter standardværdierne
for metanolanlægget vist i Tabel 7.2 side 21, Tabel 7.7 og Tabel 7.9 side 26.
Forholdet mellem den maksimale og den minimale lagerbeholdning angivet i Tabel
8.2 (klager-max/min) svarer nogenlunde til forholdet mellem maksimal- og minimaltrykket
i gaslageret. Forholdet har betydning for den samlede pris for et gaslager, idet den
angiver, hvor stor den effektive lagerstørrelse er i forhold til den samlede
lagerstørrelse. Forskellen mellem den effektive og den samlede lagerstørrelse kaldes
”cushion gas”. Parameteren klager-max/min er typisk større end 3 [Taylor et al., 1986].
Der er foretaget nogle antagelser i forbindelse med denne undersøgelse:
• Der er ikke noget krav om en minimums operationstid, hvilket betyder, at
anlægget kan være i drift den ene time og ude af drift i den næste. Det stemmer
godt overens med elektrolyseanlæggets hurtige opstarts og reguleringstid
[Teknologikataloget, 2005].
• Der er i sammenligningen mellem metanolanlæg med og uden gaslagre ikke taget
højde for det ekstra energiforbrug til tryksætning, som formentlig vil være
forbundet med benyttelse af gaslagre i et metanolanlæg. Størrelsen af dette ekstra
forbrug afhænger meget af designet af metanolanlægget: hvis trykket i
metanolreaktoren ikke er større end brintlagertrykket, er der intet ekstra
energiforbrug til tryksætning af brint. Hvis iltlagringstrykket sættes lavt, og
51 Forhold mellem brint- og ilt-lagerprisen:
iltlageret er det samme som for brintlageret.
C
k = . Det antages, at udgiften til
iltlager
lagerpris Cbrintlager
67

ekspansionen fra iltlageret foregår vha. en turbine, kan det ekstra energiforbrug
minimeres.
• Regulerkraftmarkedet inkluderes ikke i denne undersøgelse, selvom det største
potentiale formentlig forekommer her. Det skyldes, at formålet med denne
undersøgelse kun er at sandsynliggøre, at der er bedre økonomi i et metanolanlæg
med gaslagre - end i et uden.
De el-priser som benyttes i scenarierne, er fra DK-VEST for årene 2000-2006 (se elpriserne
på Figur 7.6). Der er anført gennemsnitspriser og spredninger for disse elpriser
i tabellen nedenfor.
2000 2001 2002 2003 2004 2005 2006 2000-2006 (ref)
c el,
år
[kr/MWh]
122 177 189 250 214 277 330 223
σel, år
[kr/MWh]
93 73 119 160 50 127 99 126
Tabel 8.3. Den gennemsnitlige el-pris og spredningen på el-priserne.
For lettere at kunne forholde sig til omkostningerne forbundet med drift af et
elektrolyseanlæg med gaslagre, som præsenteres senere i rapporten, defineres en
række referenceomkostninger. Omkostningerne defineres ud fra et fiktivt år på 8760
timer med en gennemsnitlig el-pris på 223 kr/MWh (fra ”2000-2006” i Tabel 8.3).
Ligning 8.1: De specifikke reference-el-omkostninger
c = c ⋅ e ⋅ levetid = 223 kr ⋅8760
MWh ⋅15
= 29,
3
ref , el
el,
år
el
MWh
Hvor de specifikke reference-el-omkostninger er omkostningen til el for et elektrolyseanlæg på 1
MWe, som er i drift uafbrudt gennem hele levetiden ved en gennemsnits-el-pris. eel er det specifikke elforbrug
for et elektrolyseanlæg [energiforbrug / installeret effekt].
Ligning 8.2: De specifikke referenceomkostninger
c = c ⋅ ( 1+
r ⋅ levetid)
+ c
mio.
kr = 1,
5 ⋅ ( 1+
0,
02 ⋅15)
+ 29,
3
ref
elektrolyse
D&V
ref , el
MWe
MWe
mio
. kr
MWe
mio.
kr
mio.
kr = 31,
3 MWe
Hvor de specifikke referenceomkostninger, er omkostningerne til et elektrolyseanlæg på 1 MWe, som
er i drift uafbrudt, samt D&V og el for hele anlæggets levetid.
Ligning 8.3: De specifikke reference-el-omkostninger regnet i nutidsværdi
i=
levetid cel,
år
c ref , el,
nutidsværdi
= eel
⋅ ∑
i
1+
r
i=
15 223 kr
MWh
MWh
= 8760 MWe ⋅∑
i
1+
0,
05
= 20,
3
i=
1
( ) i=
1 ( )
Ligning 8.4: De specifikke referenceomkostninger regnet i nutidsværdi
i levetid rD&V
⋅ celektrolyse
c ref , nutidsværdi
= celektrolyse
+ ∑
+ c
i
ref , el,
nutidsværdi
i 1 ( 1+
r)
=
=
i 15
mio.
kr
mio. kr 0,
02 ⋅1,
5 MWe mio.
kr
mio
= 1 , 5 MWe + ∑ + 20,
3
i
MWe = 22,
1
1+
0,
05
=
i=
1
( )
For alle årene 2000-2006 er følgende parameter defineret:
. kr
MWe
mio
. kr
MWe
MWe
68

Ligning 8.5: Reference-el-omkostningerne baseret på el-priserne for et af årene fra 2000-2006
= c ⋅ E ⋅ levetid
C ref , el,
år el,
år el
hvor Eel er el-forbruget per år
Følgende 5 parametre benyttes ved fremstilling af resultaterne for simuleringerne og
til sammenligninger mellem de 2 scenarier i resultatkapitlet (8.3):
Ligning 8.6: Sparede omkostninger
=
Sparede omkostninger − C
⋅ ( 1+
r ⋅ levetid)
Csparet el ekstra anlægsomkostning
D&V
⎛ ⎛ x ⎞ ⎞
( − C ) − ⎜C
⋅ ⎜ −1⎟
+ C ⎟ ⋅ ( 1+
r ⋅ levetid)
= C ref , el,
år el
⎝
elektrolyse
⎝ Driftstimer
⎠
lagre
⎠
D&V
,
Hvor Cel er de samlede el-omkostninger gennem levetiden. Celektrolyse = celektrolyse
⋅ Pel,
ref , hvor Pel, ref
er el-effekten for referenceelektrolyseanlægget (anlægget der er i drift uafbrudt). x er antallet af timer
per år (8760 eller 8784). Clagre er omkostningen for både brint- og ilt-lager.
Ligning 8.7: Tilbagebetalingstiden
C
Tilbagebetalingstid =
Csparet
el
− C
levetid
=
C
elektrolyse
ekstra anlægsomkostning
ekstra anlægsomkostning
⎛ x ⎞
⋅ ⎜ −1⎟
+ C
⎝ Driftstimer
⎠
⋅ r
D&V
⎛ ⎛ x ⎞ ⎞
( cel,
år − cel
) ⋅ E el − ⎜C
elektrolyse
⋅⎜
−1⎟
+ Clagre
⎟ ⋅ rD&V
Hvor el
⎝
c er gennemsnits-el-prisen.
Ligning 8.8: Forrentning af investeringen
⎝ Driftstimer
1
Forrentning af investering =
Tilbagebetalingstid
=
( c − c )
el,
år
el
⋅ E
el
C
elektrolyse
lagre
⎛ ⎛ x ⎞
− ⎜C
elektrolyse
⋅⎜
−1⎟
+ C
⎝ ⎝ Driftstimer
⎠
⎛ x ⎞
⋅ ⎜ −1⎟
+ Clagre
⎝ Driftstimer
⎠
2 af parametrene ovenfor beregnes også i nutidsværdi:
⎠
⎠
Csparet
el
− C
=
levetid
C
lagre
⎞
⎟ ⋅ r
⎠
ekstra anlægsomkostning
ekstra anlægsomkostning
D&V
⋅ r
D&V
69

Ligning 8.9: Sparede omkostninger i nutidsværdi
Sparede omkostninger i nutidsværdi
⎛
⎛
⎜
⎛ x ⎞
( c − ) ⋅ − ⎜ ⋅⎜
− ⎟ +
i=
levetid el,
år cel
E el Celektrolyse
1 C
⎜
⎝ ⎝ Driftstimer
⎠
= ∑ ⎜
i
i=
1 ⎜
( 1+
r)
⎜
⎝
⎛ ⎛ x ⎞ ⎞
− ⎜C
elektrolyse
⋅ ⎜ −1⎟
+ Clagre
⎟
⎝ ⎝ Driftstimer
⎠ ⎠
Tilbagebetalingstiden regnet i nutidsværdi findes ved at sætte ”Sparede omkostninger
i nutidsværdi” = 0 og så bestemme parameteren ”levetid”, som i dette tilfælde vil
være lig ”tilbagebetalingstiden regnet i nutidsværdi”.
De specifikke referenceomkostninger på 31,3 mio. kr/MWe for det fiktive år (Ligning
8.2) benyttes til normering af de sparede omkostninger beregnet ud fra Ligning 8.6 og
Ligning 8.9 i resultatdelen, for lettere at kunne relatere til størrelserne.
For at kunne forholde sig til omkostningerne til gaslagrene defineres parameteren
klagerprisandel, som den samlede gaslagerpris delt med prisen for
referenceelektrolyseanlægget:
Ligning 8.10: Lagerprisandelen
Clagre
k lagerprisandel
=
C
elektrolyse
I forbindelse med benyttelsen af gaslagre defineres en række parametre, som benyttes
senere i rapporten:
Ligning 8.11: Energiindholdet i brintlageret
E br int lager =
k
Clagre
+ 1 ⋅ c
( lagerpris ) br int lager
Ligning 8.12: Det specifikke energiindhold i brintlageret
E br int lager
e br int lager = =
P P ⋅ k
Clagre
+ 1 ⋅ c
k
=
lagerprisandel
2 ⋅ 0,
2
el,
ref
⋅1,
5
mio
kr
MJ
. kr
MWe
el,
ref
= k
=
lagre
lagerprisandel
⎞
⎟ ⋅ r
⎠
⋅ c
D&V
⎞
⎟
⎟
⎟
⎟
⎠
elektrolyse
( lagerpris ) br int lager ( k lagerpris + 1)
⋅ c br int lager
lagerprisandel
⋅1042
MWh
MWe
Ud fra dette kan det beregnes, hvor lang tid et fyldt lager kan forsyne
metanolanlægget med gas:
k
70

Ligning 8.13: Tidskonstant for lageret
T
lager
k
=
E
=
P
br int lager,
effektiv
el,
ref
lagerprisandel
0,
8
⋅ η
elektrolyse
⋅1042
MW
MWe
E
=
MWh
MWe
⋅
br int lager
4
5
P
el,
ref
= k
k
⋅
k
lager−max/
min
⋅ η
lager−max/
min
elektrolyse
lagerprisandel
Gaslagervolumenet for et af lagrene er:
Ligning 8.14: Gaslagervolumenet for et lager
Clagre
Vlager
=
( k
p
lagerpris + 1)
⋅ c brintlager ⋅ LHVbrint
⋅
p
−1
e
=
⋅1042h
= k
Det specifikke gaslagervolumen for et af lagrene er:
Ligning 8.15: Det specifikke gaslagervolumen for et lager
Vlager
v lager =
Pel,
ref
=
P ⋅ ( k
k lagerprisandel
⋅ Celektrolyse
+ 1)
⋅ c ⋅ LHV
el,
ref
lagerpris
brintlager
Hvis lagertrykket antages at være 100 bar:
ref
brint
⋅
br int lager
k
⋅
k
η
lagerprisandel
p
p
ref
lager−max/
min
lager−max/
min
elektrolyse
⋅ 43dage
Ligning 8.16: Det specifikke gaslagervolumen for et lager på 100 bar
k c
k 1,
5 mio.
kr
lagerprisandel
⋅ elektrolyse
lagerprisandel
⋅
MWe
v lager =
=
( k 1)
c LHV
p
2 0,
2 kr 10,
78 MJ 100bar
lagerpris + ⋅ brintlager ⋅ brint ⋅
MJ
3
p
⋅ ⋅ ⋅ Nm
ref
1bar
3
= k m
lagerprisandel
⋅3479
MWe
Det betyder, at hvis referenceelektrolyseanlægget er på 1 MWe og klagerprisandel = 1, vil lagerstørrelsen
være ca. 3479 m 3 per lager.
8.2.1 Scenarie 1: Det teoretisk optimale scenarie
Scenarie 1 beskriver det teoretisk optimale scenarie for et metanolanlæg med et
elektrolyseanlæg, som benytter gaslagre til brint og ilt.
Grunden til at det er et teoretisk optimum, som beregnes, er at driftsoptimeringen for
et specifikt år, udføres på basis af el-priserne for det år - forstået på den måde, at man
ved starten af året har kendskab til el-priserne resten af året.
Ud over timedata for el-priserne benyttes dataene i Tabel 8.2 til at optimere antallet af
driftstimer - og fordelingen af driftstimerne - for elektrolyseanlægget, således at de
samlede omkostninger minimeres. De samlede omkostninger består af årlige
omkostninger til el og D&V samt investeringen i elektrolyseanlæg og gaslagre.
Proceduren bag optimeringen er: Ved et givent antal driftstimer per år for
elektrolyseanlægget, fordeles disse i første omgang således, at elektrolyseanlægget
kun er i drift ved de laveste el-priser. Dette medfører en ulige fordeling af
driftstimerne henover året (se Figur 8.2), hvilket dermed kræver en hvis størrelse
gaslagre.
−1
71

Ved at antage en fast specifik lagerpris kan det beregnes hvor stor en besparelse, der
kan opnås ved at flytte en driftstime fra område 1 til område 2 (se Figur 8.1), således
at lagerbeholdningen reduceres. Den driftstime som flyttes, er den med den højeste elpris
i område 1, og den time der udvælges som ny driftstime i område 2, er den med
den laveste el-pris.
På et tidspunkt i optimeringsprocessen er det nødvendigt at flytte mere end 1
driftstime, for at kunne reducere størrelsen på gaslagrene. På Figur 8.4 ses det, at det
er nødvendigt at flytte en driftstime fra både område 1 og 3 til område 2 og 4 for at
opnå en lagereduktion.
Når der er blevet flyttet et vist antal driftstimer, bliver lagerbeholdningen hen over
året (se fx Figur 8.1) opdateret. Det gøres for at sikre at en driftstime, som er blevet
flyttet, ikke risikerer at blive flyttet igen.
Denne optimeringsproces fortsættes, indtil der ikke længere opnås en besparelse (se
Ligning 8.17 og Figur 8.5).
Ligning 8.17: Den specifikke besparelse (besparelsen ved at flytte en times produktion på 1MWe)
c besparelse = clagerbesparelse
− cel−omkostning
k lager−max/min
= ( k lagerpris + 1)
⋅ c brintlager ⋅
⋅ ηelektrolyse
− ( cel,
1 − cel,
2 ) ⋅ levetid
k −1
lager−max/min
( c − c ) ⋅15
= 1440 kr − ( c − c ) 15
5
= 2 ⋅ 0,
2 kr 3600 MJ
MJ ⋅
MWh ⋅ ⋅ 0,
8 − el,
1 el,
2
MWh el,
1 el,
2 ⋅ ,
5 −1
hvor cel, 1 er el-prisen for den driftstime i område 1, som flyttes, og cel, 2 er el-prisen for den driftstime i
område 2, som der flyttes til.
Ud fra Ligning 8.17 kan den maksimalt tilladte forskel i el-pris udregnes (cbesparelse =
0):
Ligning 8.18: Maksimal el-prisforskel mellem de 2 områder
1440 kr
MWh
( c ) kr
el,
1 − cel,
2 = = 96
maks
MWh
15
Hvis der flyttes mere end en driftstime, er det summen af disse el-pris-differencer,
som ikke må overstige værdien angivet i Ligning 8.18.
Se Matlab-koden for denne optimeringsproces i bilag 29.
72

Brintlagerbeholdning [MWh]
3000
2500
2000
1500
1000
500
0
Område 2
Område 1 Område 2
1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.1. Lagerbeholdningen henover et år – før optimeringen (drift ved de laveste el-priser). For år
2002 ved 2000 driftstimer. Pel, ref = 1 MWe. Område 1 angiver den periode, hvor der forekommer en
stigning fra minimums- til maksimums-beholdningen. Område 2 angiver den periode, hvor der
forekommer et fald fra maksimums- til minimums-beholdningen. Se Figur 8.2 for den tilhørende
fordeling af driftstimerne henover året.
73

Driftstimer per uge [h]
160
140
120
100
80
60
40
20
0
0 5 10 15 20 25 30 35 40 45 50
Uge-nr. [-]
Figur 8.2. Fordelingen af driftstimer henover et år – før optimeringen (drift ved de laveste el-priser).
For år 2002 ved 2000 driftstimer.
Driftstimer per uge [h]
160
140
120
100
80
60
40
20
0
0 5 10 15 20 25 30 35 40 45 50
Uge-nr. [-]
Figur 8.3. Fordelingen af driftstimer henover et år – efter optimeringen. For år 2002 ved 2000
driftstimer.
74

Brintlagerbeholdning [MWh]
400
350
300
250
200
150
100
50
0
Område 2
Område 1
Område 4 Område 3
1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.4. Lagerbeholdningen henover et år – efter optimeringen. For år 2002 ved 2000 driftstimer. Pel,
ref = 1 MWe. Område 1 og 3 angiver de 2 perioder, hvor der forekommer en stigning fra minimums- til
maksimums-beholdningen. Område 2 og 4 angiver de 2 perioder, hvor der forekommer et fald fra
maksimums- til minimums-beholdningen. Se Figur 8.3 for den tilhørende fordeling af driftstimerne
henover året.
75

Omkostninger [%]
60
50
40
30
20
10
0
-10
0 10 20 30 40 50 60 70 80 90 100
Iterationsnummer [-]
El
Gaslagre
Elektrolyseanlæg
D&V
Sparede omkostninger
Figur 8.5. Udvikling gennem optimeringsprocessen ved 2000 driftstimer, hvis beregningerne foretages
på basis af el-priserne for år 2002. Omkostningerne er angivet i procent af referenceomkostningerne for
år 2002 (kan beregnes vha. Ligning 8.2). Summen af graferne giver derfor 100 %. Alle omkostninger er
beregnet for hele anlæggets levetid.
8.2.2 Scenarie 2: Det i praksis opnåelige scenarie
Scenarie 2 beskriver det praktisk opnåelige scenarie for et metanolanlæg med et
elektrolyseanlæg, som benytter gaslagre til brint og ilt.
Scenariet adskiller sig fra scenarie 1, ved at driften for et år ikke optimeres ud fra et
forhåndskendskab til el-priserne for et helt år. Det besluttes i stedet time for time, om
elektrolyseanlægget er i drift eller ej.
Det er valgt at basere driftsbeslutningen ud fra el-priserne for de forudgående 8760
timer samt lagerbeholdningerne i gaslagrene 52 .
Nedenfor er vist den simple regulator, som bestemmer, om elektrolyseanlægget skal i
drift eller ej.
Ligning 8.19: Regulatorligningen eller el-pris-funktionen
⎛ k lager-max/min
+ 1 Vlager,
nu ⎞
cel, drift = cel,
hist + ⎜
− ⎟ ⋅ cel,
lager ,
⎜ 2 k lager-max/min
V ⎟
⎝ ⋅
lager ⎠
hvor cel, drift er en drift-el-pris, som er med til at definere, hvornår elektrolyseanlægget er i drift (se
nedenfor). cel, hist er en funktion af det ønskede antal af driftstimer samt de historiske el-priser - hvor de
historiske el-priser er el-priserne for de foregående 8760 timer. Hvis n angiver det ønskede antal
driftstimer per år er cel, hist den n’de laveste af de historiske el-priser. Vlager, nu er lagerbeholdningen ved
52
Det antages at ilt- og brint-lagrene tømmes i samme takt, hvorfor den efterfølgende beskrivelse kun
omhandler brintlageret.
76

den time, hvor regulatorligningen benyttes. Vlager er lagerstørrelsen. cel, lager er en fastsat faktor - se
nedenfor for en beskrivelse af hvordan den er bestemt. Standardværdien for cel, lager = 300 kr/Mwh.
Vlager,
nu k lager-max/min
+ 1
Hvis halvdelen af lagerets effektive lagerplads er fyldt: = = 0,
6 er
c = c .
el,
drift
el,
hist
V
lager
2 ⋅ k
lager-max/min
For at sikre at gaslagrene ikke tømmes eller bliver overfuldt, er der også andre
betingelser, for hvornår elektrolyseanlægget skal være i drift. Alle betingelserne for
drift er angivet nedenfor:
Vlager
Drift hvis: c el < cel,
drift og V lager,
nu < Vlager
eller hvis V <
Der er ikke drift hvis: c el > cel,
drift og
V
lager,
nu
k
lager-max/min
lager
V lager,
nu > eller hvis V lager,
nu > Vlager
k lager-max/min
Det betyder, at elektrolyseanlægget er i drift, hvis el-prisen er mindre end el-prisfunktionen
(cel, drift), forudsat at lagrene ikke er fyldt. Elektrolyseanlægget er ligeledes
i drift, hvis lagerbeholdningen kommer under minimumslagerbeholdningen.
Ud over betingelserne for drift som er angivet ovenfor, vil der i realiteten også være et
krav om, at el-prisen ikke er så høj, at det medfører, at de variable omkostninger ved
metanolproduktionen overstiger indtjeningen ved metanolsalget.
Ligning 8.19 indeholder faktoren cel, lager, som angiver, hvor afhængig cel, drift skal være
af lagerbeholdningen. På Figur 8.6 til Figur 8.11 ses det, hvordan variationer på cel,
lager påvirker udviklingen i cel, drift og i lagerbeholdningen henover et år for en fastsat
lagerstørrelse. Figur 8.7 og Figur 8.10 viser den økonomisk optimale udvikling for det
specifikke år.
Ud fra en sammenligning af Figur 8.9 og Figur 8.10 kan det derfor konkluderes, at det
ikke er optimalt, hvis lageret er fyldt eller tomt i for lang tid af gangen. Ud fra en
sammenligning af Figur 8.11 og Figur 8.10 kan det samtidig konkluderes, at det heller
ikke er optimalt, hvis hele lagerstørrelsen ikke udnyttes. Det optimale er derfor store
udsving i lagerbeholdningen henover året.
Grunden til at det ikke er optimalt, hvis lageret er fyldt eller tomt i for lang tid af
gangen, er; at hvis lageret er fyldt, er der ikke mulighed for drift, hvis el-prisen er lav
- og hvis lageret er tomt, er der ikke mulighed for at indstille driften, hvis el-prisen er
høj.
Grunden til at det ikke er optimalt, hvis hele lagerstørrelsen ikke udnyttes, er, at
udgiften til gaslageret er større end nødvendigt. Ud fra Figur 8.8 ses det også, at en for
høj værdi af cel, lager medfører en mulighed for drift ved højere el-priser end
nødvendigt.
Det er vanskeligt at bestemme de optimale værdier for lagerstørrelsen og faktoren cel,
lager, idet de optimale værdier fundet ud fra el-priserne for et specifikt år kan være
meget forskellige fra de optimale værdier fundet ud fra el-priserne for et andet år.
Det er derfor nødvendigt, at fastsætte værdierne ud fra de historiske el-priser, samt en
fremskrivning af el-priserne. I denne undersøgelse holdes faktoren cel, lager konstant,
men den kunne reguleres automatisk ud fra spredningen på el-priserne for – fx - de
forudgående 8760 timer.
77

Det er naturligvis mest kritisk med fastsætningen af gaslagerstørrelsen, idet den ikke
er ligetil at ændre, efter gaslageret er konstrueret.
I resultatafsnittet for dette scenarie (afsnit 8.3.2) forsøges værdierne optimeret ud fra
el-priserne for år 2000-2006.
El-pris-funktionen [kr/MWh]
500
450
400
350
300
250
200
150
100
50
0
0 1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.6. Udvikling i el-pris-funktionen (cel, drift) for år 2005 ved cel, lager = 100 kr/MWh. Antallet af
driftstimer er 4000. klagerprisandel = 0,1.
78

El-pris-funktionen [kr/MWh]
500
450
400
350
300
250
200
150
100
50
0
0 1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.7. Udvikling i el-pris-funktionen (cel, drift) for år 2005 ved cel, lager = 300 kr/MWh. Antallet af
driftstimer er 4000. klagerprisandel = 0,1.
El-pris-funktionen [kr/MWh]
500
450
400
350
300
250
200
150
100
50
0
0 1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.8. Udvikling i el-pris-funktionen (cel, drift) for år 2005 ved cel, lager = 1500 kr/MWh. Antallet af
driftstimer er 4000. klagerprisandel = 0,1.
79

Brintlagerbeholdning [MWh]
100
90
80
70
60
50
40
30
20
10
0
0 1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.9. Udvikling i lagerbeholdningen for år 2005 ved cel, lager = 100 kr/MWh. Antallet af driftstimer
er 4000. klagerprisandel = 0,1. Pel, ref = 1 MWe.
Brintlagerbeholdning [MWh]
100
90
80
70
60
50
40
30
20
10
0
0 1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.10. Udvikling i lagerbeholdningen for år 2005 ved cel, lager = 300 kr/MWh. Antallet af
driftstimer er 4000. klagerprisandel = 0,1. Pel, ref = 1 MWe.
80

Brintlagerbeholdning [MWh]
100
90
80
70
60
50
40
30
20
10
0
0 1000 2000 3000 4000 5000 6000 7000 8000
Time på året [-]
Figur 8.11. Udvikling i lagerbeholdningen for år 2005 ved cel, lager = 1500 kr/MWh. Antallet af
driftstimer er 4000. klagerprisandel = 0,1. Pel, ref = 1 MWe.
Se Matlab-koden for dette scenarie i bilag 30.
81

8.3 Resultater
Resultaterne for de 2 scenarier er præsenteret nedenfor.
For at lette sammenligningen mellem de 2 scenarier er følgende parametre beregnet
for begge scenarier og præsenteret grafisk:
• Sparet omkostninger
• Sparet omkostninger (nutidsværdi)
• Forrentning
• Tilbagebetalingstid
• Tilbagebetalingstid (nutidsværdi)
Parametrene er defineret i teoriafsnittet (s. 69).
Parametrene sammenligninger resultater for det enkelte scenarie med et
referenceanlæg, som det kan læses ud fra definitionerne af parametrene.
I resultatafsnittet for scenarie 2 (afsnit 8.3.2) sammenlignes værdierne for
parametrene med de teoretisk optimale værdier, som blev præsenteret i scenarie 1.
I diskussionsafsnittet (afsnit 8.4) sammenlignes yderligere resultater fra de 2
scenarier, og resultaterne diskuteres.
8.3.1 Scenarie 1: Det teoretisk optimale scenarie
I dette afsnit præsenteres resultaterne for scenarie 1. Resultaterne tydeliggør hvad
omkostningerne i forbindelse med drift af et elektrolyseanlæg i et metanolanlæg,
teoretisk set kan reduceres med ved tilføjelse af gaslagre til brint og ilt.
82

Omkostninger [%]
100
90
80
70
60
50
40
30
20
10
0
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
El
Gaslagre
Elektrolyseanlæg
D&V
Sparede omkostninger
Figur 8.12. Omkostninger som funktion af antallet af driftstimer baseret på el-priserne for år 2005.
Omkostningerne er angivet i procent af referenceomkostningerne baseret på år 2005 (kan beregnes vha.
Ligning 8.2). Summen af graferne giver derfor 100 %. Alle omkostninger er beregnet for hele
anlæggets levetid. Ved hvert datapunkt er den teoretisk optimale fordeling af driftstimerne beregnet,
som beskrevet i teoriafsnittet (8.2.1). Det betyder samtidig, at lagerstørrelserne udregnes for hvert
punkt.
Figur 8.12 viser, hvordan omkostningerne i forbindelse med investering og drift af et
elektrolyseanlæg med gaslagre til brint og ilt afhænger af antallet af driftstimer. Hvis
anlægget kun er i drift få timer om året, får kapitalomkostningerne stor betydning,
mens el-omkostningerne reduceres, idet driftstimerne hovedsageligt fordeles efter elprisernes
størrelse. Ved et bestemt antal driftstimer kan det ikke betale sig at reducere
driftstiden yderlige, da kapitalomkostningerne stiger hurtigere, end el-omkostningerne
falder. Dette optimum kan ses ud fra grafen for sparede omkostninger.
Hvis omkostningsberegningerne baseres på el-priserne for år 2005, ses det ud fra
Figur 8.12, at det optimale antal driftstimer er ca. 4000 per år.
Det ses samtidig ud fra Figur 8.12, at omkostningerne til gaslagre ikke stiger
nævneværdigt, når antallet at driftstimer sænkes. Ud fra Figur 8.13 kan det ses, at
gaslagerstørrelserne for år 2005 faktisk mindskes, når antallet af driftstimer reduceres
fra 4500 til 3000. Det skyldes el-prisernes lidt stokastiske karakter. Det kan også
forklares ud fra et eksempel:
Hvis man antager, at en optimal fordeling af driftstimerne er fundet ved et specifikt
antal driftstimer, hvilket dermed også indbefatter en optimal gaslagerstørrelse, kan
den optimale fordeling af driftstimerne for et større antal driftstimer vise sig at værre
83

mere koncentreret i visse områder, pga. el-prisernes fordeling, hvilket medfører en
større optimal gaslagerstørrelse.
Samlet lagerpris [%]
100
90
80
70
60
50
40
30
20
10
0
2000
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.13. Den samlede lagerpris udtrykt som en procentdel af referenceelektrolyseanlægsprisen (1,5
mio. kr/MWe) for varierende antal driftstimer. Denne normering af den samlede gaslagerpris betegnes
klagerprisandel. Ved en samlet lagerpris på 100 %, kan et fyldt lager levere gas til metanolanlægget i 43
dage (se evt. Ligning 8.13). Hvis referenceelektrolyseanlægget er på 1 Mwe, betyder det endvidere, at
lagerstørrelsen er ca. 3479 m 3 per lager.
Ud fra Figur 8.13 kan det ses, at den optimale gaslagerstørrelse er meget afhængig af,
hvilket år beregningerne baseres på. Udgiften til gaslagrene udgør dog kun en lille del
af de samlede udgifter (se Figur 8.12), hvorfor lagerstørrelsen kan sættes tilstrækkelig
stor.
For hvert datapunkt på Figur 8.13 er det bl.a. også beregnet, hvor stort potentialet for
besparelser teoretisk set er. Kurven for sparede omkostninger for 2005 kunne ses på
Figur 8.12, men nedenfor er kurverne for alle 7 år samlet.
84

Sparede omkostninger [%]
30
25
20
15
10
5
0
2000
2001
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
2002
2003
2004
2005
2006
Figur 8.14. Sparede omkostninger som funktion af antallet af driftstimer. De sparede omkostninger er i
procent af referenceomkostningerne på 31,3 mio. kr/MWe (Ligning 8.2). Alle graferne vil skære xaksen,
hvor antallet af driftstimer er lig antallet af timer per år, idet referencen er et elektrolyseanlæg,
som er i drift hele året. På Figur 8.13 ses de tilhørende lagerstørrelser til hvert datapunkt.
På Figur 8.14 ses det, at besparelsespotentialet afhænger stærkt af, hvilke el-priser
beregningerne baseres på.
Det optimale antal driftstimer varierer meget fra år til år – fra ca. 2000 til ca. 6500
driftstimer.
Ud fra Tabel 8.4 ses det, at besparelsespotentialet er størst, hvis beregningerne baseres
på de el-priser, som har den største spredning. Det er kun el-priserne for år 2006, som
skiller sig lidt ud.
Maks. sparede omkostninger [%] 4 7 9 15 22 24 26
Maks. sparede omkostninger [mio. 1,3
kr/MWe]
2,2 2,8 4,7 6,9 7,5 8,1
År 2004 2001 2000 2002 2005 2006 2003
c el,
år
[kr/MWh]
214 177 122 189 277 330 250
σel, år
[kr/MWh]
50 73 93 119 127 99 160
Tabel 8.4. Den gennemsnitlige el-pris og spredningen på el-priserne for år 2000-2006 sorteret efter
maksimalt sparede omkostninger (kan aflæses på Figur 8.14).
Hvis beregningerne baseres på el-priserne fra 2002, er besparelsespotentialet ca. 4,7
mio. kr for det elektrolyseanlæg, som har 4000 driftstimer, hvis der sammenlignes
med et referenceelektrolyseanlæg på 1 MWe (referenceelektrolyseanlægget er i drift i
85

alle årets timer). Elektrolyseanlægget, som har 4000 driftstimer, er ca. dobbelt så stort
(2 MWe) som referenceelektrolyseanlægget, da der normeres efter samme
gasproduktion per år.
For at få et mere korrekt billede af besparelsespotentialet skal de sparede
omkostninger på elektricitet, som opnås hvert år, omregnes til nutidsværdi. Idet
besparelsespotentialet hovedsageligt afhænger af spredningen på el-priserne, er det
ikke nødvendigt at tage højde for el-prisstigninger i anlæggets levetid.
På figuren nedenfor er værdierne fra Figur 8.14 omregnet til nutidsværdi.
Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
2000
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.15. Sparede omkostninger i nutidsværdi som funktion af antallet af driftstimer. De sparede
omkostninger er i procent af referenceomkostningerne på 31,3 mio. kr/MWe (Ligning 8.2). Alle
graferne vil skære x-aksen, hvor antallet af driftstimer er lig antallet af timer per år, idet referencen er et
elektrolyseanlæg, som er i drift hele året. På Figur 8.13 ses de tilhørende lagerstørrelser til hvert
datapunkt.
Figur 8.15 adskiller sig bl.a. fra Figur 8.14, ved at toppunkterne for graferne er
forskudt mod højre. Det optimale antal driftstimer for de forskellige år befinder sig
dermed i intervallet fra ca. 3000 til ca. 7000 driftstimer.
Det ses desuden, at den største ændring af besparelsespotentialet forekommer ved et
lavt antal driftstimer. Det skyldes, at besparelsen på el stiger ved faldende antal
driftstimer (jævnfør Figur 8.12).
Et elektrolyseanlæg, som ikke er i drift hele året, vil som nævnt være større end
referenceelektrolyseanlægget, som er i drift hele året, idet der normeres efter et fast
output per år. Det betyder en større investering i år nul, også pga. investeringen i
gaslagre. Denne ekstra investering i forhold til referencetilfældet kan opfattes som en
86

selvstændig investering og de omkostninger, som der spares per år i forhold til
referencen, kan opfattes som en forrentning af denne investering.
Nedenfor er forrentningen, og den tilhørende tilbagebetalingstid, vist for de samme
datapunkter, som er brugt på Figur 8.13 til Figur 8.15.
Forrentning af investering [%]
50
45
40
35
30
25
20
15
10
5
0
2000
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.16. Forrentning af ekstrainvestering i forhold til referencen som funktion af antallet af
driftstimer. Definitionen af denne parameter kan læses ovenfor eller ses i Ligning 8.8. Graferne vil
være diskontinuerte ved punktet, hvor antallet af driftstimer er lig antallet af timer per år, idet der i
dette punkt hverken er nogen besparelse i forhold til referencen eller nogen ekstra investering.
Af Figur 8.16, Figur 8.17 og Figur 8.18 kan det ses, at det næsten altid kan betale sig
at benytte gaslagre, således at antallet af driftstimer kan reduceres. Figurerne antyder
dog, at den bedste økonomi opnås ved et så højt antal driftstimer som muligt - i
modsætning til graferne på Figur 8.14 og Figur 8.15. Det skyldes, at
ekstrainvesteringen, i forhold til referencen, er meget begrænset ved et højt antal
driftstimer. Samtidig med, at et højt antal driftstimer medfører en del sparede
omkostninger (se evt. Figur 8.12), pga. der undgås drift ved de højeste el-priser.
87

Tilbagebetalingstid [år]
15
10
5
0
2000
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.17. Tilbagebetalingstid for ekstrainvestering i forhold til referencen som funktion af antallet af
driftstimer. Definitionen af denne parameter kan ses i Ligning 8.7.
88

Tilbagebetalingstid (beregnet ud fra nutidsværdi) [år]
15
10
5
0
2000
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.18. Tilbagebetalingstid beregnet ud fra nutidsværdi for ekstrainvestering i forhold til referencen
som funktion af antallet af driftstimer. Definitionen af denne parameter kan ses under Ligning 8.9.
8.3.2 Scenarie 2: Det i praksis opnåelige scenarie
I dette afsnit præsenteres resultaterne for scenarie 2. Resultaterne tydeliggør hvad
omkostningerne i forbindelse med drift af et elektrolyseanlæg i et metanolanlæg, i
realiteten kan reduceres med ved tilføjelse af gaslagre til brint og ilt. Disse resultater
sammenlignes med de teoretiske værdier præsenteret i scenarie 1. For en generel
beskrivelse og forklaring af figurerne henvises til afsnit 8.3.1.
Resultaterne præsenteres for cel, lager = 300 kr/MWh og klagerprisandel = 0,1, da disse
værdier i gennemsnit medfører den største besparelse ved benyttelse af gaslagre (se
evt. bilag 31). Værdien for klagerprisandel på 0,1 betyder, at størrelsen af gaslagrene er
således, at et fyldt gaslager kan levere gas til metanolanlægget i 4,3 dage (se evt.
89

Ligning 8.13). Hvis referenceelektrolyseanlægget er på 1 Mwe, betyder det endvidere,
at lagerstørrelsen er ca. 348 m 3 per lager.
Beregningerne i det følgende er foretaget på basis af el-priserne for år 2001-2006 (elpriserne
for år 2000 benyttes som historiske el-priser for beregningen for år 2001).
Sparede omkostninger [%]
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.19. Sparede omkostninger som funktion af antallet af driftstimer. De sparede omkostninger er i
procent af referenceomkostningerne på 31,3 mio. kr/MWe (Ligning 8.2). cel, lager = 300 kr/MWh og
klagerprisandel = 0,1. Alle graferne vil skære x-aksen, hvor antallet af driftstimer er lig antallet af timer per
år, idet referencen er et elektrolyseanlæg, som er i drift hele året.
90

Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.20. Sparede omkostninger i nutidsværdi som funktion af antallet af driftstimer. De sparede
omkostninger er i procent af referenceomkostningerne på 31,3 mio. kr/MWe (Ligning 8.2). cel, lager =
300 kr/MWh og klagerprisandel = 0,1. Alle graferne vil skære x-aksen, hvor antallet af driftstimer er lig
antallet af timer per år, idet referencen er et elektrolyseanlæg, som er i drift hele året.
Figur 8.19 og Figur 8.20 viser, hvad omkostningerne kan reduceres med ved
benyttelse af gaslagre. Ved sammenligning med Figur 8.14 og Figur 8.15 fra scenarie
1 ses det, at besparelserne opnået i dette scenarie kun er lidt lavere end det teoretisk
mulige. Den største forskel mellem de omtalte figurer fra scenarie 1 og 2 ses ved et
lavt antal driftstimer.
Ud fra Figur 8.20 ses det, at det optimale antal driftstimer for de forskellige år ligger i
intervallet 3500-7000.
Nedenfor er graferne for forrentning og tilbagebetalingstid for investeringen vist.
Graferne viser en lidt lavere forrentning og en lidt længere tilbagebetalingstid end de
teoretisk mulige fra scenarie 1.
91

Forrentning af investering [%]
50
45
40
35
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.21. Forrentning af ekstrainvestering i forhold til referencen som funktion af antallet af
driftstimer. Definitionen af denne parameter kan læses ovenfor eller ses i Ligning 8.8. cel, lager = 300
kr/MWh og klagerprisandel = 0,1. Graferne vil være diskontinuerte ved punktet, hvor antallet af driftstimer
er lig antallet af timer per år, idet der i dette punkt hverken er nogen besparelse i forhold til referencen
eller nogen ekstra investering.
92

Tilbagebetalingstid [år]
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.22. Tilbagebetalingstid for ekstrainvestering i forhold til referencen som funktion af antallet af
driftstimer. Definitionen af denne parameter kan ses i Ligning 8.7. cel, lager = 300 kr/MWh og klagerprisandel
= 0,1.
93

Tilbagebetalingstid (beregnet ud fra nutidsværdi) [år]
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
Figur 8.23. Tilbagebetalingstid beregnet ud fra nutidsværdi for ekstrainvestering i forhold til referencen
som funktion af antallet af driftstimer. Definitionen af denne parameter kan ses under Ligning 8.9. cel,
lager = 300 kr/MWh og klagerprisandel = 0,1.
94

8.4 Diskussion
Resultaterne præsenteret i det foregående viste, hvad omkostningerne i teorien og i
realiteten kan reduceres med, ved benyttelse af gaslagre og et større elektrolyseanlæg i
et metanolanlæg.
Det blev vist, at besparelserne afhang meget af antallet af driftstimer for
elektrolyseanlægget, og dermed størrelsen af elektrolyseanlægget, samt hvor stor en
spredning der var på de el-priser, som beregningerne blev baseret på.
Bestemmelsen af det optimale antal driftstimer for elektrolyseanlægget afhænger
derfor af hvilket års el-priser, som er mest repræsentative for de fremtidige el-priser.
Hvis man forventer, at andelen af ukontrollerbar el-produktion vil stige, vil
spredningen på el-priserne stige, hvorfor årene 2003, 2005, 2006 vil være mest
repræsentative (se Tabel 8.3). Ukontrollerbar el-produktion indbefatter fx vindkraft,
bølgekraft og solenergi.
Hvis el-forbruget imidlertid bliver mere priselastisk, kan spredningen på el-priserne
mindskes, hvorfor årene 2000, 2001, 2004 vil være mest repræsentative (se Tabel
8.3). Det vurderes dog, at en øgning af spredningen på el-priserne vil være mest
sandsynligt, pga. en forventelig udbygning med ukontrollerbar el-produktion samtidig
med, at der skal være et større incitament, før el-forbruget bliver mere priselastisk.
Derfor vil et elektrolyseanlæg med ca. 4500 driftstimer sandsynligvis være et godt
bud på et optimalt anlæg ud fra den teoretiske analyse i scenarie 1, mens et
elektrolyseanlæg med ca. 5000 driftstimer vil være optimalt for scenarie 2. Dette
forudsætter, at en kalkulationsrente på 5 % anvendes.
I Tabel 8.5 er de sparede omkostninger for scenarie 1 og 2 sammenlignet ved 5000
driftstimer for at tydeliggøre forskellen mellem de 2 scenarier. Det ses, at resultaterne
fra scenarie 2 kommer tæt på de maksimale værdier fra scenarie 1.
Hvis der tages udgangspunkt i den gennemsnitlige besparelse på 6,1 % (Tabel 8.5) og
metanolanlægget, fra den første del af rapporten, kan der opnås en samlet besparelse
for metanolanlægget på 0,9-1,3 % 53 . Grunden til at besparelsen ikke er større, er
hovedsagelig pga. den danske el-afgift, som er medtaget i den første del af
rapporten 54 .
År 2001 2002 2003 2004 2005 2006 Gennemsnit
Scenarie 1 [%] 2,7 8,1 11,2 1,7 11,5 11,2 7,7
Scenarie 2 [%] 1,5 6,0 8,3 0,6 10,5 9,7 6,1
Tabel 8.5. Sparede omkostninger i nutidsværdi for scenarie 1 og 2 ved 5000 driftstimer. Værdierne er i
procent af referenceomkostningerne på 31,3 mio. kr/MWe (Ligning 8.2) og kan aflæses på Figur 8.15
og Figur 8.20.
Den optimale gaslagerstørrelse i scenarie 2 på klagerprisandel = 0,1 eller 348 m 3 /MWe per
lager betyder, at omkostningen til gaslagre udgør en meget lille del af de totale
omkostninger. Omkostningen for gaslagrene vil dog være mest troværdig, hvis
gaslagerstørrelsen er i nærheden af 500.000 m 3 , idet den specifikke gaslagerpris som
benyttes, bl.a. baseres på et gaslager af denne størrelse. Hvis gaslagerstørrelsen sættes
så højt, betyder det imidlertid, at metanolanlægget skal være meget stort.
53
For anlægskonfiguration 3 (0,9 %) og 6 (1,3 %).
54
Desuden er de 6,1 % baseret på nutidsværdi, hvilket der ikke regnes med i den første del af
rapporten.
95

Omkostningen til gaslagrene kan imidlertid tillades at være en del større end beregnet,
uden at det påvirker den samlede økonomi voldsomt.
Gennemsnittet af de optimale gaslagerstørrelser i scenarie 1 (jævnfør Figur 8.13) var
større end den optimale i scenarie 2 (klagerprisandel = 0,1). Det skyldes, at den simple
regulator benyttet i scenarie 2 egner sig godt til at udnytte døgnrytmen i el-prisen (se
Figur 8.25), men ikke er lige så god til at udnytte de mere stokastiske variationer i elprisen,
som kan forekomme henover et år (se evt. Figur 7.6). Det medfører, at
elektrolyseanlægget hovedsageligt er i drift i nattetimerne i scenarie 2.
Ud fra Figur 8.24 ses det, at elektrolyseanlægget også hovedsageligt er i drift i
nattetimerne i scenarie 1, men at udsvingene i driftsmønstret er lidt mindre. De mindre
udsving skyldes netop, at optimeringen i scenarie 1 også tager højde for de mere
stokastiske variationer i el-prisen, som kan forekomme henover et år.
Hvis Figur 8.24 sammenlignes med Figur 8.25, ses det, hvor klart el-prisen påvirker
driften af elektrolyseanlægget.
Antal driftstimer [timer]
350
300
250
200
150
100
50
Laveste el-priser
Scenarie 1
Scenarie 2
0
0 4 8 12
Time på døgnet [-]
16 20 24
Figur 8.24. Antallet af driftstimer for hver time på døgnet for scenarie 1 og 2 ved 5000 driftstimer per
år. Driftsmønstret for de 2 scenarier sammenlignes med hvordan driftsmønstret ville se ud, hvis der var
drift i de 5000 timer med de laveste el-priser. Grafen er produceret på baggrund af el-priserne for år
2003. cel, lager = 300 kr/MWh og klagerprisandel = 0,1 for scenarie 2.
96

El-pris [kr/Mwh]
400
350
300
250
200
150
100
50
0
0 4 8 12
Time på døgnet [-]
16 20 24
Figur 8.25. Den gennemsnitlige el-prisvariation henover døgnet for år 2000-2006.
2000
2001
2002
2003
2004
2005
2006
Der er i denne undersøgelse foretaget sammenligninger med et
referencemetanolanlæg uden gaslagre, som er i drift hele året – uanset el-prisen.
Driften på et metanolanlæg uden gaslagre vil imidlertid afbrydes, hvis de variable
omkostninger bliver større end indtjeningen fra metanolsalget.
Hvis der ses bort fra andre variable omkostninger end elektricitet (ud fra Figur 7.8 ses
det, at el-omkostningen er klart den største variable omkostning), vil metanolanlægget
indstille driften, hvis el-prisen bliver højere end en specifik værdi (drift-el-prisen).
Denne drift-el-pris vil også være relevant for metanolanlæg med gaslagre.
Elektrolyseanlægget i et sådan metanolanlæg må ligeledes indstille driften, hvis elprisen
bliver højere end drift-el-prisen, men pga. gaslagrene kan driften af
metanolanlægget fortsættes. Driften kan fortsættes så længe, der er gas i gaslagrene.
Den optimale gaslagerstørrelse, som blev bestemt i scenarie 2, må antages at være
tilstrækkelig, da el-prisen følger en døgnrytme.
Hvis der i analysen var blevet taget højde for drift-el-prisen, ville det derfor have
betydet, at referenceanlægget (uden gaslagre) ville få færre driftstimer, mens
metanolanlægget med gaslagre (ekskl. elektrolyseanlægget) stadig ville kunne være i
drift hele året.
Derfor må det konkluderes, at et metanolanlæg med gaslagre vil have bedre økonomi
end et metanolanlæg uden gaslagre.
Hvis metanolanlægget inkluderer en forgasser, kan der være en måde hvorpå et
metanolanlæg uden gaslagre, kan opnå ligeså god - eller bedre - økonomi,
sammenlignet med et anlæg med gaslagre.
Forgasningsgassen fra forgasseren vil kunne benyttes til metanolproduktion, når elprisen
er lav, og til el-produktion - fx vha. en gasturbine - når el-prisen er høj. Idet
97

forgasseren typisk vil være den dyreste komponent i et sådan anlæg, vil reduktionen i
antallet af driftstimer for de øvrige komponenter til metanolproduktion ikke påvirke
anlægsøkonomien voldsomt. Endelig behøves antallet af driftstimer for elproduktionsdelen
ikke være stort, før der kan opnås god økonomi (jævnfør et
spidslastkraftværk).
Der bliver i øjeblikket skrevet eksamensprojekt om denne anlægskombination på
MEK-DTU af Alvise Valenti.
98

9 Konklusion
I den første del af rapporten blev en model af et metanolanlæg designet ud fra optimal
energiudnyttelse og økonomi.
Anvendelsen af vedvarende energikilder til metanolproduktionen var desuden et
centralt element i anlægsdesignet.
Der blev undersøgt 6 forskellige anlægskonfigurationer, med hver sin
syngasproduktionsmetode – hver i sær baseret på en kombination af de 4 exergikilder:
elektricitet, biomasse, naturgas og biogas.
Det blev vist at den højeste metanolexergivirkningsgrad på 74 % blev opnået for
anlæg nr. 5, men kun anlæg nr. 6, som udelukkende benyttede el som exergikilde,
havde en signifikant lavere metanolexergivirkningsgrad på 67 %.
Ved at udnytte spildvarmen fra metanolanlægget til fjernvarmeproduktion blev
energiudnyttelsen øget betydeligt, samtidig med at metanolomkostningerne blev
reduceret.
Den laveste specifikke metanolomkostning på 95 kr/GJex blev opnået for anlæg nr. 3,
som benyttede forgasning af biomasse med efterfølgende udvaskning af CO2 fra
forgasningsgassen.
Den specifikke metanolomkostning for en række af anlægskonfigurationerne kunne
derfor konkurrer med den kommercielle metanolpris (142 kr/GJex) og benzinprisen
inkl. afgifter (187 kr/GJex).
Det blev desuden vist, at en afgiftslettelse på elektriciteten ville betyde en betydelig
reduktion af metanolomkostningen, idet 39-84 % af de samlede omkostninger for de 6
anlægskonfigurationer var til elektricitet.
I den anden del af rapporten blev det vist, at det var økonomisk fordelagtigt at benytte
underjordiske gaslagre til brint og ilt i et buffersystem - i forbindelse med et
elektrolyseanlæg i et metanolanlæg.
Omkostningerne blev reduceret ved kun at have elektrolyseanlægget i drift, når elprisen
var lav, mens det resterende metanolanlæg var i drift året rundt.
Ud fra simuleringer baseret på el-priserne for DK-VEST for 2000-2006 og en
kalkulationsrente på 5 % blev den største besparelse opnået ved ca. 5000 driftstimer
per år for elektrolyseanlægget. Besparelsen var op til 10,5 % og i gennemsnit 6,1 %
ved 5000 driftstimer.
Disse besparelser var tæt på det teoretisk maksimale for de undersøgte el-priser. De
teoretisk maksimale besparelser var op til 11,5 % og i gennemsnit 7,7 % ved 5000
driftstimer.
De største besparelser blev opnået for de el-priser, som havde den største spredning.
Endeligt blev det konkluderet, at der er egnede lokationer for underjordiske gaslagre
til brint og ilt i Danmark.
99

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Professor Birgitte Ahring, DTU. Udleveret faktaark om andengenerations bioetanol
fra november 2006, kopi i bilag 13.
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[Clausen et al., 2004]
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DONG, KBB, Rambøll, MTS, ”PowerStore – Feasibility study for a danish location
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101

DONG Energy A/S, Naturgasafgifter, 2007,
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102

11 Nomenklaturliste
c omkostning per enhed (se indeks for enhed) eller specifik varmekapacitet
c gennemsnitlig omkostning per exergienhed, fx [kr/GJ]
Ċ omkostningsstrøm forbundet med en exergistrøm, fx [kr/s]
Ċi, dest omkostningsstrøm for exergidestruktionen baseret på den gennemsnitlige
inputomkostning per exergi, fx [kr/s]
Ċp, dest omkostningsstrøm for exergidestruktionen baseret på den gennemsnitlige
produktomkostning per exergi, fx [kr/s]
D&V drift og vedligehold
E energi, fx [MJ]
Ė exergi- eller energi-strøm (se indeks), fx [kJ/s]
FV fjernvarme
g gibbs energi, fx [J/mol]
h enthalpi, fx [kj/mol]
LHV nedre brændværdi, fx [MJ/kg]
m& massestrøm, fx [kg/s]
M faktor for syngas (i forbindelse med produktion af flydende brændsler som
metanol) [-]
n& molstrøm, fx [kmol/s]
O omkostninger, fx [kr]
p tryk, fx [bar]
P Elektrisk eller mekanisk effekt (se indeks), fx [MW]
Q& Varmestrøm, fx [MJ/s]
r rente, fx [%]
s entropi, fx [ J
K⋅
mol ]
SO sparede omkostninger, fx [kr]
t temperatur [°C]
T absolut temperatur [K]
x væskeandel, fx [mol-%]
y gasandel, fx [mol-%]
Ż omkostningsstrøm forbundet med D&V og afskrivninger på
komponentinvesteringen, fx [kr/s]
Græske bogstaver
ε varmevekslereffektivitet
η virkningsgrad
∆ forskel eller ændring
Indeks
c kold
D&V Drift og vedligehold
dest destruktion
en energi
ex exergi
h varm
i input eller ind
komp kompressor
103

LHV nedre brændværdi, fx [MJ/kg]
m masse
mek mekanisk effekt
o ud
p produkt eller tryk
ref reference
Θ standard
104

Design og modellering
af metanolanlæg til
VEnzin-visionen
Bilag
Lasse Røngaard Clausen
Polyteknisk Eksamensprojekt
MEK-ET-EP-2007-04
Marts 2007
Danmarks
Tekniske
Universitet
Institut for
Mekanik,
Energi og
Konstruktion
MEK
Energiteknik

Bilagsoversigt
1. Damptørrer - Enerdry ApS
2. Forgasserpris - Choren
3. Elpris - Energy Together
4. El-afgifter og –tariffer GE-NET A/S
5. Naturgaspris - Energy Together
6. Naturgasafgifter – DONG Energy
7. Vandpris – Københavns Energi
8. Benzinforbrug til vejtransport
9. Benzinpris
10. Benzinafgift
11. Råoliepris
12. Metanolpris
13. Faktaark om produktion af andengenerations
bioetanol
14. Metanolproduktion, NZIC
15. Metanolproduktion, Nykomb
16. Metanolproduktion, Wikipedia
17. Destillationskolonne. Flowsheet for anlæg 3.
18. Flowsheet for et metanolanlæg (fra DONG Energy)
19. Flowsheet for et metanolanlæg (fra kurset
thermoeconomics)
20. Flowsheet for metanolanlæg – uden værdiangivelser
21. Flowsheet for metanolanlæg – til bestemmelse af
komponentpriser for dampreformer, metanolreaktor
og destillationskolonne.
22. Flowsheet for metanolanlæg – til
parameterfastsættelse
23. Flowsheets for metanolanlæg - til den
termoøkonomiske analyse.
24. Flowsheets for metanolanlæg – for de 6 forskellige
anlægskonfigurationer

25. Flowsheets for metanolanlæg – for
parametervariationen (metanolreaktortryk)
26. Flowsheets for metanolanlæg – for
parametervariationen (brint/kulstof-forholdet i
syngassen)
27. Flowsheet for metanolanlæg – for
parametervariationen (tryksat forgasning)
28. Flowsheet for metanolanlæg – for
parametervariationen (afkølingstemperaturen for
den metanolholdige gas)
29. Matlab-kode til Scenarie 1
30. Matlab-kode til Scenarie 2
31. Scenarie 2: variation af cel, lager og klagerprisandel
32. DNA-kode for metanolanlæg
33. Dokumentation for tilføjede DNA-komponenter
34. Tilføjede komponenter til DNA – Fortran-kode
35. Metanol (fluid) til DNA – Fortran-kode

1. Damptørrer - Enerdry ApS
Enerdry ApS. Firma som arbejder med damptørring.
Kopi fra: http://www.enerdry.com/index.php?id=489, d. 30/1-2007

2. Forgasserpris - Choren
Choren Industries GmbH, ”Strom und wärme aus biomasse”, (anlæg på 30 MWth),
http://www.choren.com/dl.php?file=Strom_und_Waerme_aus_Biomasse_6.pdf, kopi
fra side 11 d. 30/1-2007:

3. Elpris - Energy Together
DONG Energy, Energy Together (2004): Scenario 1 – Det frie marked,
http://www.energyserver.net/ET1/Default%20inkl%20CO2/_html/Default%20Scenari
o%201.htm#Elpriser fra d. 31/1-2007:

4. El-afgifter og –tariffer GE-NET A/S
El-afgifter og –tariffer til erhvervskunder (Årligt forbrug over 100.000 kWh), GE-
NET A/S: http://www.ge.dk/GE-Net/Priser.htm, fra d. 31/1-2007:

5. Naturgaspris - Energy Together
DONG Energy, Energy Together: Scenario 1 – Det frie marked,
http://www.energyserver.net/ET1/Default inkl CO2/Default Scenario 1.xls
fra d. 31/1-2007:

6. Naturgasafgifter – DONG Energy
Naturgasafgifter, 2007:
http://www.dongenergy.dk/erhverv/produkter/naturgas/listepris.htm

7. Vandpris – Københavns Energi
Vandpris hos Københavns Energi. 2007.
http://www.ke.dk/portal/page/portal/Erhverv/Vand/Prisen_paa_vand?page=146 fra d.
31/1-2007.

8. Benzinforbrug til vejtransport
Energistyrelsens energistatistik 2004 med variablene: Aktør/aktivitet=Vejtransport;
Energivare=Motorbenzin; Årstal=2004:
http://www.ens.dk/graphics/Energi_i_tal_og_kort/statistik/Hjemmeside/sp_frameset.h
tm (d. 1/2-2007).

9. Benzinpris
Benzinpriser fra konkurrencestyrelsen fra år 2000.
http://www.ks.dk/publikationer/konkurrence/2000/benzin-olie/bilag6/ hentet d. 5/3-
2007.

10. Benzinafgift
Benzinafgifter fra skatteministeriet fra d. 14/03-2002.
http://www.skm.dk/publikationer/udgivelser/1510/1543/ hentet d. 5/3-2007.

11. Råoliepris
Råoliepris fra Bloomberg.com fra d. 5/03-2007.
http://www.bloomberg.com/markets/commodities/energyprices.html hentet d. 5/3-
2007.

12. Metanolpris
Metanolpriser fra Methanex (verdens største metanolproducent). Månedspriser fra år
2002 frem til marts 2007:
http://www.methanex.com/products/documents/MxAvgPrice_Feb262007.pdf hentet
d. 6/3-2007. Linket ovenfor bliver ændret hver måned, i takt med at nye månedspriser
bliver tilføjet. Det aktuelle link til de historiske månedspriser kan findes på:
http://www.methanex.com/products/methanolprice.html

Methanex Monthly Average Regional Posted Contract Price History
Methanex Non-Discounted
Reference Price
Methanex European
Posted Contract Price
(MNDRP) (EPCP)
Methanex Asian Posted
Contract Price
(APCP)
Date $/gal $/MT €/MT $/MT
Jan-01 n/a n/a n/a
Feb-01 n/a n/a n/a
Mar-01 n/a n/a n/a
Apr-01 n/a n/a n/a
May-01 $0.770 $256 n/a n/a
Jun-01 $0.670 $223 n/a n/a
Jul-01 $0.570 $190 n/a n/a
Aug-01 $0.510 $170 n/a n/a
Sep-01 $0.420 $140 n/a n/a
Oct-01 $0.370 $123 n/a n/a
Nov-01 $0.400 $133 n/a n/a
Dec-01 $0.400 $133 n/a n/a
Jan-02 $0.375 $125 € 125 n/a
Feb-02 $0.360 $120 € 125 n/a
Mar-02 $0.375 $125 € 125 n/a
Apr-02 $0.420 $140 € 145 n/a
May-02 $0.500 $166 € 165 n/a
Jun-02 $0.560 $186 € 185 n/a
Jul-02 $0.620 $206 € 208 n/a
Aug-02 $0.620 $206 € 208 n/a
Sep-02 $0.620 $206 € 208 $202
Oct-02 $0.620 $206 € 208 $202
Nov-02 $0.620 $206 € 208 $202
Dec-02 $0.620 $206 € 208 $202
Jan-03 $0.690 $229 € 228 $230
Feb-03 $0.790 $263 € 228 $252
Mar-03 $0.820 $273 € 245 $270
Apr-03 $0.820 $273 € 260 $275
May-03 $0.820 $273 € 260 $275
Jun-03 $0.820 $273 € 240 $275
Jul-03 $0.775 $258 € 225 $260
Aug-03 $0.720 $239 € 225 $250
Sep-03 $0.700 $233 € 210 $241
Oct-03 $0.680 $226 € 190 $230
Nov-03 $0.680 $226 € 190 $230
Dec-03 $0.680 $226 € 190 $230
Jan-04 $0.750 $249 € 200 $250
Feb-04 $0.750 $249 € 200 $250
Mar-04 $0.750 $249 € 200 $250
Apr-04 $0.750 $249 € 200 $250
May-04 $0.750 $249 € 200 $250
Jun-04 $0.810 $269 € 200 $260
Jul-04 $0.840 $279 € 230 $272
Page 1

Methanex Non-Discounted
Reference Price
Methanex European
Posted Contract Price
(MNDRP) (EPCP)
Methanex Asian Posted
Contract Price
(APCP)
Date $/gal $/MT €/MT $/MT
Aug-04 $0.840 $279 € 230 $272
Sep-04 $0.840 $279 € 230 $272
Oct-04 $0.840 $279 € 230 $272
Nov-04 $0.900 $299 € 230 $272
Dec-04 $0.950 $316 € 230 $292
Jan-05 $0.950 $316 € 230 $302
Feb-05 $0.950 $316 € 230 $302
Mar-05 $0.950 $316 € 230 $302
Apr-05 $0.950 $316 € 230 $302
May-05 $0.950 $316 € 230 $302
Jun-05 $0.950 $316 € 230 $290
Jul-05 $0.900 $299 € 220 $280
Aug-05 $0.900 $299 € 220 $270
Sep-05 $0.900 $299 € 220 $260
Oct-05 $0.960 $319 € 235 $280
Nov-05 $0.960 $319 € 235 $280
Dec-05 $1.020 $339 € 235 $295
Jan-06 $1.020 $339 € 268 $320
Feb-06 $1.070 $356 € 268 $330
Mar-06 $1.070 $356 € 268 $330
Apr-06 $1.070 $356 € 285 $330
May-06 $1.030 $343 € 285 $310
Jun-06 $1.030 $343 € 285 $310
Jul-06 $1.000 $333 € 250 $305
Aug-06 $1.030 $343 € 250 $310
Sep-06 $1.330 $442 € 250 $420
Oct-06 $1.800 $599 € 400 $550
Nov-06 $1.800 $599 € 400 $550
Dec-06 $1.800 $599 € 400 $520
Jan-07 $1.800 $599 € 420 $520
Feb-07 $1.650 $549 € 420 $490
Mar-07
Apr-07
May-07
Jun-07
Jul-07
Aug-07
Sep-07
Oct-07
Nov-07
Dec-07
$1.550 $516 € 420 $490
Page 2

13. Faktaark om produktion af andengenerations
bioetanol

14. Metanolproduktion, NZIC
New Zealand Institute of Chemistry (NZIC),
http://www.nzic.org.nz/ChemProcesses/energy/, infomation om metanolproduktion:
http://www.nzic.org.nz/ChemProcesses/energy/7D.pdf, kopi fra d. 20/3-2007

THE PRODUCTION OF METHANOL AND GASOLINE
Methanol is made from methane (natural gas) in a series of three reactions:
Ni/800 0 C
• Steam reforming: CH4 + H2O CO + 3H2 ∆rH = +206 kJ mol -1
Ni/800 0 C
• Water shift reaction CO + H2O CO2 + H2 ∆rH = +206 kJ mol -1
• Synthesis 2H2 + CO CH3OH ∆rH = -92 kJ mol -1
Cu-Zn
Thus overall: CO2 + CO + 5H2 → 2CH3OH + H2O + heat
The methanol thus formed may be converted to gasoline by the Mobil process. First
methanol is dehydrated to give dimethyl ether:
2CH3OH CH3OCH3 + H2O
This is then further dehydrated over a zeolite catalyst, ZSM-5, to give a gasoline with 80%
C5 + hydrocarbon products.
The Methanex plant and sites in Taranaki are described.
INTRODUCTION
Methanol or methyl alcohol (CH3OH) is a colourless liquid with a boiling point of 65 o C.
Methanol will mix with a wide variety of organic liquids as well as with with water and
accordingly it is often used as a solvent for domestic and industrial applications. It is most
familiar in the home as one of the constituents of methylated spirits.
Methanol is the raw material for many chemicals, formaldehyde, dimethyl terephphalate,
methylamines and methyl halides, methyl methacrylate, acetic acid, gasoline etc.
Methanol and gasoline are produced from Kapuni and Maui natural gas (methane) by
Methanex New Zealand Ltd around Waitara and New Plymouth in North Taranaki. Methane
is steam reformed to make syngas (hydrogen and carbon monoxide), and this in turn is used
to make methanol some of which can be used in methanol to gasoline (MTG) production.
For economic reasons the MTG plant was taken out of production in late 1996, but could be
recommissioned if the economic situation warranted it.
In this article the overall layout and production steps at the Methanex plants will be
described, followed by sections on the chemistry of methanol and gasoline production.
THE METHANEX PLANTS
Methanex owns two methanol plants, the stand alone plant at Waitara Valley which came on
stream in 1983 and which can produce 1500 tonnes per day of crude methanol and distil 3000
tonnes per
VII-Energy-D-Methanol-1

Maui Gas Supply
Kapuni Gas
Supply
NGC MX
VII-Energy-D-Methanol-2
Faull Rd.
Gas mixing
station
Kapuni gas
pipeline
150 mm NB
NGC MX
Waitara Valley
Methanol production
and storage
Fuel gas pipeline
300 mm NB
Process gas pipeline
600 mm NB
Crude
methanol
pipeline
150 mm NB
Product
methanol
pipeline
150 mm NB
Motunui
Methanol and gasoline
production and storage
IPS 1
Intermediate
pumping
station one
IPS 2
Intermediate
pumping
station two
Product methanol pipeline 200 mm NB
Omata 1
Methanol storage
and transfer pumps
2 x 25,000 tonnes
Gasoline loadout line
450 mm NB
Omata 2
Gasoline storage and
ship loadout pumps
2 x 25,000 tonnes
Treated water to
Hongihongi stream
Figure 1 - Flow schematic of Methanex NZ production and storage facilities
Port
Methanol storage and
ship loadout pumps
2 x 27,000 tonnes
Product methanol
loadout line
300 mm NB
Newton King Wharf
Methanol loading arm
Gasoline loading arm
Deballast
water
transfer
pipeline
400 mm NB
Deballast
Deballast water
treatment

day of crude methanol into product methanol, and the Motunui site plant which also
produces gasoline. Here crude methanol is produced in two Davy McKee designed methanol
plants, each with a capacity to produce 2600 t/d of crude methanol. Crude methanol generally
has a water content of 18% w/w, and contains small quantities of by-products from methanol
synthesis. This crude can then be used directly in the MTG process, or piped to the Waitara
Valley site and distilled to give product grade methanol.
Production and storage facilities
The flow relationships of natural gas supply, crude methanol, product methanol, and gasoline
are shown in Figure 1.
Faull Road gas mixing station
The purpose Faull Rd gas mixing station is to carry out custody metering and control the
mixing of Maui gas (low CO2 content) and Kapuni gas (high CO2 content) as the process gas
supply for the Motuni plant with a CO2 content of 16%. The plant is operated for Methanex
by the Natural Gas Corporation NCG). Figure 2 outlines the process.
Figure 2 - Block diagram of Faull Rd gas mixing station
Motunui site
Motunui produces 5200 tonnes per day of crude methanol. This can be converted to either
gasoline by the MTG process, or product methanol with distillation. Up to 25% of the crude
methanol can be exported to Waitara Valley for distillation into product methanol. Figure 3
outlines the processes.
Figure 3 - Block diagram for the overall process at Motunui.
VII-Energy-D-Methanol-3

Gas metering and letdown
The process gas and fuel gas from Faull Rd is metered at Motunui for custody transfer and
meter checking, and then letdown to the required process pressures to be used in the plant.
Figure 4 outlines this.
Figure 4 - Gas metering and letdown
Crude methanol production
Crude methanol is produced in two Davy McKee designed methanol plants, each with a
capacity to produce 2600 t/d of crude methanol. Crude methanol generally has a water
content of 18% w/w, and contains small quantities of by-products from methanol synthesis.
Figure 5 outlines the manufacturing process at Motunui.
Figure 5 - The crude methanol manufacturing process at Motunui
Methanol ot gasoline (MTG) production
Gasoline can be produced from methanol using a process developed by Mobil, which uses
ZSM-5 Zeolite catalyst. The plant consists of five identical trains for conversion, and has a
maximum design capacity of 2200 tonnes per day of product gasoline. Figure 6 outlines the
process.
Heavy Gasoline Treatment (HGT)
The gasoline produced by the MTG process contains Durene, a substance with a high melting
point (79°C). The Durene produced by the MTG process is more than that permitted under
product gasoline specifications. The Durene content is reduced by treating the heavy gasoline
produced in MTG, in the Heavy Gasoline Treatment plants prior to blending into product
gasoline. Figure 7 outline the process.
Gasoline Blending and Storage
The separate gasoline components of light gasoline, heavy gasoline, and high vapour pressure
gasoline are all stored in intermediate storage facilities.
Gasoline of product specification is then produced by the controlled blending of these
components
VII-Energy-D-Methanol-4

Figure 6 - The gasoline manufacturing process
Figure 7 - The heavy gasoline treatment process
Figure 8 - Blending and storing gasoline
in the correct proportions. The product is then transferred by pipeline to the Omata 2 storage
facility for storage and load-out to ships. Figure 8 represents these processes.
VII-Energy-D-Methanol-5

Methanol Distillation
Crude methanol can be distilled, to remove Water and by-products formed during methanol
synthesis, into product methanol. This is done at Motunui in Distillation III and IV, which are
both rated at 2000 t/d of production. Figure 9 shows the process.
Figure 9 - The methanol distillation process
The product methanol is stored in rundown tanks initially for quality checking, and then
transferred by pipeline to Waitara Velley, for transfer to Omata 1 or the port.
Waitara Valley
The Waitara Valley methanol plant can produce 1500 t/d of crude methanol and distil 3000
t/d of crude methanol into product methanol in Distillation I and II.
The additional crude methanol to match distillation capacity is transferred from Motunui via
the
crude methanol pipeline for distillation at Waitara Valley. The overall process at Waitara
Valley is shown in Figure 10.
Figure 10 - Overall process at Waitara Valley
The methanol manufacturing process is very similar to that used at Motunui and is shown in
Figure 11.
The crude methanol is then distilled in either Distillation I or Distallation II as shown in
Figure 12. The plant distillation designs vary, with Distillation I incorporating a three tower
design, and Distillation II using a two tower design.
Pipelines
The Methanex facilities utilise a number of underground pipelines for the transfer of products
between the plants, and to the Port for shipment. See Figure 1.
VII-Energy-D-Methanol-6

Figure 11 - Methanol manufacturing process at Waitara Valley
Figure 12 - Distillation at Waitara Valley
Process Gas Pipeline (600 mm NB)
To supply mixed gas feedstock to Motunui from Faull Rd Gas Mixing Station.
Fuel Gas Pipeline (300 mm NB)
To supply Maui gas for fuel gas to Motunui from Faull Rd Gas mixing station.
Waitara Valley Kapuni Gas Pipeline (150 mm NB)
To supply Kapuni gas to Waitara Valley from Faull Rd.
Crude Methanol Pipeline (150 mm NB)
To transfer crude methanol from Motunui to Waitara Valley.
Motunui - Waitara Valley Product Methanol Pipeline (200 mm NB)
To transfer product methanol from Motunui to Waitara Valley, for storage and onward
transfer to the Port or Omata 1.
Product Methanol Pipeline (200 mm NB)
This pipeline is used to transfer all product methanol produced at Waitara Valley and
Motunui, to the Port and Omata 1. The pipeline requires the use of two intermediate pumping
stations to transfer the required volumes.
Product methanol from Omata 1 is transferred to the Port using the section of Product
Methanol Pipeline located between the two sites.
VII-Energy-D-Methanol-7

Product Gasoline Pipeline (250 mm NB)
This pipeline is used to transfer product gasoline from Motunui to Omata 2 for storage and
subsequent ship load-out.
Gasoline Load-out Line (450 mm NB)
The product gasoline is loaded onto ships by transferring the gasoline from Omata 1 directly
to the gasoline loading arm on the Port Taranaki Newton King Wharf.
Pumping stations
Intermediate Pumping Station 1 (IPS 1)
At higher flows, between 270-360 m 3 /h, in the Product methanol Pipeline, IPS 1 is required
to boost the pressure in the pipeline in order to maintain the required flowrates.
IPS 1 consists for four pumps, which operate in parallel, to increase the pressure of the
product methanol from 6 bar to 40 bar. The intermediate pumping station can be by-passed
when it is not required for use. IPS 1 is an unmanned site and is operated from Waitara
Valley
Intermediate Pumping Station 2 (IPS 2)
At maximum pipeline flowrates in the Product Methanol Pipeline (360-430 m 3 /h), IPS 2 is
required, in addition to IPS 1, in order to boost the pressure and maintain the required
flowrate. IPS 2 is an unmanned site and is operated from Waitara Valley.
Storage
Omata 1 Product Methanol Storage
Product methanol can be diverted from the 200 mm NB Product methanol pipeline to storage
at Omata 1.
Omata 1 consists of two 25,000 tonne fixed roof storage tanks and three transfer pumps. The
facility is remotely operated from the Port. The pumps are used to transfer methanol from the
Omata 1 storage tanks to the Port storage tanks, using the Product methanol pipeline.
Omata 2 Gasoline Storage
Omata 2 is used for the storage of Product gasoline prior to ship load-out.
The facility consists of two 25,000 tonne floating roof tanks and two ship load-out pumps.
One of the floating roof tanks is being converted to dual use, with a vented fixed roof and
internal floating roof, allowing it to be used for either gasoline or methanol. It is currently to
be returned to gasoline service.
The ship load-out pumps transfer the gasoline directly to the gasoline ship load-out arm on
the Port Taranaki Newton King -wharf, via the 450 mm NB Gasoline load-out line.
Port Storage and Load-out Facilities
The Port storage facility is used for the storage of product methanol prior to loading onto
ships. The facility consists of two 27,000 tonne fixed roof tanks, and four ship load-out
pumps. The load-out pumps transfer methanol to the methanol shiploading arm on the
Newton king Wharf, via the 300 mm NB load-out line.
VII-Energy-D-Methanol-8

The gasoline and Methanol ship loading arms have been included as part of the Port facilities
for the risk assessment.
Deballast Facility
The deballast facility is used to treat ballast water from ships. The ballast water contains
small quantities of oil from ship storage tanks. The deballast facility separates the oil from
the water, and then discharges the water into the nearby Hongihongi Stream. The recovered
oil is returned to crude oil storage
The facility consists of a deballast water storage tank, a small recovered oil storage tank, and
an API separator and dissolved air flotation unit.
THE METHANOL PRODUCTION PROCESS
The main process area of the plant can be divided into three sections as shown in Figure 5:
• Reforming
• Compression and Synthesis
• Distillation
In addition, a number of support utilities are required, including a conventional water
treatment plant, an ion-exchange demineralizer to produce higher quality water for boilers, a
package boiler, a cooling water system, an inert gas system, an instrument air system and an
electricity generator.
Reforming
The term "steam-hydrocarbon reforming" refers to the endothermic reaction between steam
and methane (or any other alkane) which produces carbon monoxide, carbon dioxide and
hydrogen. The reaction is carried out in a furnace at high temperatures over a nickel catalyst
inside tubes. Fired burners supply heat for the endothermic reaction:
Ni/800 0 C
CH4 + H2O CO + 3H2 ∆rH = +206 kJ mol -1
Under these conditions, the water gas shift reaction also occurs to a small extent:
Ni/800 0 C
CO + H2O CO2 + H2 ∆rH = +206 kJ mol -1
Thus the products of the reforming reaction ("synthesis gas") include carbon oxides and
hydrogen as well as unreacted methane, nitrogen, and steam. They leave the furnace at over
800 o C. Heat is recovered from this stream as it is cooled to 32 o C.
The recovered heat is used to generate high-pressure steam; heat boiler feed water, and to
supply heat to the distillation section. Some heat, which cannot be recovered, is rejected to
the atmosphere (air coolers) and the cooling water system. After cooling, steam in the
reformed gas is condensed and recycled to water treatment.
Waste flue gases leave the furnace at over 1000°C. In order to increase plant efficiency and
decrease thermal pollution, the flue gas is used to generate and superheat high pressure
VII-Energy-D-Methanol-9

steam, preheat the reactants (steam and hydrocarbons), and heat the combustion air to the
furnace. The flue gas leaves the stack at 150 o C.
Maui gas is considered almost sulphur-free but, as sulphur in only trace amounts is a poison
to the reformer catalyst, a sulphur removal system is included in the process as a
precautionary measure. Desulphurization of the hydrocarbon feedstock is carried out at
400 o C. It is mixed with a small amount of hydrogen-rich purge gas from the converter and
passed over a cobalt-molybdenum catalyst that converts any thiols, sulphides and carbonyl
sulphides to hydrogen sulphide H2S. It then passes through a zinc-oxide bed where the H2S is
absorbed by the zinc oxide.
Co-Mo-400 o C
(R-SH, R-S-R, SO2, etc) + H2 → H2S + R-H
VII-Energy-D-Methanol-10
400 0 C
H2S + ZnO → ZnS + H2O
Compression and Synthesis
The "synthesis gas" from the reformer is then compressed in a centrifugal compressor. A
turbine which draws its power from the high pressure steam system drives this compressor.
Extraction steam from the turbine is used in the reforming reaction and drives other turbines
in the process.
The compressed synthesis gas enters the converter reactor containing copper zinc and catalyst
and the synthesis reaction occurs, according to the equation:
2H2 + CO CH3OH ∆rH = -92 kJ mol -1
This reaction is highly exothermic and this excess heat is used to heat boiler feed water and
to pre-heat reactant gas.
Since the reaction is exothermic, low temperatures favour conversion to methanol. On the
other hand, the rate of reaction increases with increasing temperature. Pressure will also
affect the position of the equilibrium, with increasing pressure favouring methanol formation.
The final conditions used involve a copper oxide based catalyst at about 5 MPa (50
atmospheres) pressure and about 270 o C.
As carbon monoxide is used up in the methanol synthesis reaction the water gas shift reaction
reverses producing more carbon monoxide:
H2 + CO2 CO + H2O ∆rH = +41 kJ mol -1
These reactions combine to produce approximately 40% conversion of carbon oxides to
methanol each pass through the reactor. On leaving the reactor the gas mixture is cooled and
methanol and water condense out. The remaining gas is returned to the circulator, mixed with
incoming compressed synthesis gas and recycled through the methanol converter.

Hence, the overall reactions by which methanol is produced from synthesis gas may be
summarised into the following equation:
Cu-Zn
CO2 + CO + 5H2 → 2CH3OH + H2O + heat
A feature of the steam reforming reaction and the methanol synthesis reaction is that for
every three moles of hydrogen gas produced in the steam reformer, only two moles are used
in the recycled gas being returned to the methanol converter and the mixture must be purged
to remove this excess. At present this purge is used as fuel in the reformer, but the potential
for using hydrogen as a feedstock for other reactions (e.g. production of ammonia, reduction
of iron sands) should be noted.
It should also be noted that although the converter catalyst is highly specific in producing
methanol, some side reactions occur which produce higher alcohols (ethanol, propanol,
butanol) and alkanes. These may be summarised:
nCO + 2(n-½)H2 → CnH2nOH + (n-1)H2O
nCO + CH3OH + 2nH2 → CnH2n+3OH + nH2O
The crude methanol and water produced in the converter are reduced in pressure in a letdown
"flash" vessel. Gas from this vessel is recycled to the furnace as fuel. The crude is then
sent to "in process storage".
This crude methanol contains a large range of impurities which have to be removed to
produce methanol of chemical grade quality. The technique used for purification is
distillation.
Distillation
The distillation system consists of an extraction column, a refining column, and a recovery
column.
The first step is the removal of the volatile impurities and dissolved gases - these include
carbon dioxide, carbon monoxide, hydrogen, nitrogen, acetone, ethers, esters and volatile
alkanes up to decane - which are carried out in the extraction column. The temperature in this
column is kept as low as possible to prevent significant methanol loss by evaporation.
The bottom of the extraction column provides the feed for the reforming column. The feed is
vapourised and enters the refining column about a third of the way up the column. Methanol
is now the most volatile component and it leaves the top of the column with a purity of
99.99%. This is product methanol.
A mixture of ethanol and methanol is purged from the column (about half way up) and is sent
to the recovery column for further treatment. Propanol and other higher alcohols are purged
off (at quarter height) and pumped to the 'tails' tank. Quantities of these alcohols are so small
that it is not economic to recover them and they are added to the reformer fuel gas stream and
burned. Essentially pure water is drawn from the bottom trays and pumped to waste.
VII-Energy-D-Methanol-11

As it is very difficult to separate methanol from ethanol, a third column (the recovery
column) is completely allocated for this purpose. The feed for this column is the purge from
the refining column described above. High purity methanol leaves the top of the column,
combines with the refining column product, and is pumped to the storage tanks. From there it
is transferred by pipeline to two 27 000 tonne capacity storage tanks at Port Taranaki in New
Plymouth for subsequent export. The 'bottoms' of the recovery column are pumped to the
'tails' tank and subsequently used as fuel for the reformer.
Utilities
The main process areas require the following utilities:
• A package boiler which generates steam at intermediate pressure. This is essential for
plant start up and useful as a stream pressure controller during steady operation.
• A conventional water treatment plant to treat water abstracted from the Waitara River.
All the water is clarified and some is further treated by filtration.
• An ion-exchange demineralisation plant. This plant removes ions from filtered river
water, so that less than 0.1 mg/L of impurities remain. Returning turbine and process
condensate streams are also treated here before joining with demineralised water to
become boiler feedwater.
• A cooling water system which cools various areas in the plant and is in turn cooled by
evaporation of some of the warm water returning from the process in cooling towers.
• An inert gas (nitrogen) supply and distribution system. Nitrogen is required during the
plant start up before steam and natural gas are introduced to the reformer. It keeps
some coils in the flue gas section cool while warming up and drying out the refractory
in the reformed gas boiler. It is also used for pressure control in some areas, and is a
back-up for the instrument air system.
• An instrument air compressor and distribution system. Instrument air is required to
operate most of the control valves in the plant. It also serves as a source of air which
is used for plant maintenance.
• An electricity generator is required to maintain supply to essential process areas in the
event of failure of the main supply to the plant.
The complete process is designed to make most efficient use of resources any recycling of
waste streams is carried out wherever possible. This has the added benefit of minimising the
volumes of waste to be discharged from the plant.
The product methanol is stored in rundown tanks initially for quality checking, and then
transferred by pipeline to Waitara Valley, for transfer to Omata 1 or the Port.
METHANOL TO GASOLINE - THE MOBIL PROCESS
The Methanol to Gasoline (MTG) process was developed by Mobil in the early 1970's. In
1979, the New Zealand government decided to employ the Mobil MTG process as an
alternative in reducing the dependence on imported crude oil. A plant was built at Motunui
with a production of about 14 000 barrels per day of unleaded gasoline, having an octane
rating of 92 to 94.
The MTG plant was the first commercial synthetic gasoline plant using new technology
developed since the Second World War. The gasoline coming out from the plant can be
shipped to the Marsden Point refinery for blending into the New Zealand gasoline pool. The
VII-Energy-D-Methanol-12

methanol requirement for this process comes from the two 2,200 tonnes (water free basis) per
day methanol plants.
Catalyst
In the 1970's, Mobil synthesised a new zeolite catalyst, which became a key element in the
MTG process. Zeolites are porous, crystalline materials with three dimensional framework
composed of AlO4 and SiO4 tetrahedra.
This catalyst, known as ZSM-5 (Figure l3) can convert methanol to hydrocarbon products
which are similar to the gasoline fraction of conventional petroleum.
ZSM-5 has an intermediate pore diameter about 6Å and a unique channel structure. There
are two sets of intersecting channels present: elliptical, l0-membcred ring channels present
and near circular (sinusoidal) channels. It is this unique combination of channel shapes and
sizes that make ZSM-5 so efficient and special in MTG conversion, producing gasoline range
molecules (C4 - C10 ) with practically no hydrocarbons above Cl0. In other words, ZSM-5
ccatalyst produces the right kind of shape and size selectivity properties suitable for gasoline
synthesis. These selectivities also give ZSM-5 a reputation for high resistance to
deactivation. Hence, a novel route to gasoline from either coal or natural gas can be achieved.
Figure 13 - Representation of the ZSM-5 catalyst
VII-Energy-D-Methanol-13

Operational processes
A schematic layout for the Motunui plant is shown in Figure 6.
The natural gas is first desulphurised and saturated before entering the reformer furnace
where it reacts with steam to produce synthesis gas of hydrogen, carbon monoxide (and
carbon dioxide). The synthesis gas coming out from the reformer is cooled compressed
reheated then sent to the methanol converter. The crude methanol produced contains about
20% of water. The feed gas desulphurization facilities are included to protect the reformer
and methanol catalyst from sulphur poisoning. H2S is removed by ZnO pellets contained in a
reactor vessel
There are three stages involved in the MTG process
• Petrol synthesis
• Distillation
• Heavy Petrol treating
Catalyst regeneration is also an essential part of the MTG process
Petrol synthesis
The crude methanol is initially preheated, vapourised and then superheated to between 300-
320 0 C in a series of heat exchangers. The vapour is then sent to the dimelhy l ether (DME)
reactor containing a dehydration catalyst (alumina) where approximately 75% of the
methanol is partially dehydrated to an equilibrium mixture of DME, water and methanol.
VII-Energy-D-Methanol-14
2CH3OH CH3OCH3 + H2O
The reaction is rapid, reversible and exothermic. About 20% of the total heat produced is
liberated in this step.
The mixture (at the temperature between 400-420 o C) is then mixed witl recycle gas and
passes to thc conversion reactors Thc recycle gas, composed mainly of light hydrocarbons,
CO2 and H2 serve to absorb the heat of reaction. In the conversion reactor which contains
ZSM-5 catalyst DME is further dehydrated to give light alkenes which oligomerize (ie.
undergoing chain growth by joining two or more alkene molecules together) and cyclise to
give the final products with the liberation of the remainder of the heat.
Thc mixed effluent is cooled, by generating medium pressure steam by preheating the
methanol feed and recycle gas, by air and water. It contains approximately) 94 weight
percent (w/w %) of hydrocarbons and 56 w/w% of water, the expected stoichiometric ratio.
The conversion is essentially 100%. About 85-90% of thc hydrocarbon products can be used
as gasoline the renainder is fuel gas. Small amounts of CO, CO2 and coke are formed as byproducts.
Coke is defined (in simple terms) as the reaction product that is depositcd on the
surface and fills the pores of the catalyst. This process leads to the deactivation of the
catalyst.
The recycle gas, water and hydrocarhons then goes to the product separator. The water is
normally recycled to thc reformer saturator, the recycle gas returns to the compressor and
liquid hydrocarbons are sent to the distillation section.

Distillation
The MTG hydrocarbon is refined in three distillation columns. A portion of the lighter and
more volatile hydrocarbons dissolved gases and some water is removed by the first column.
The second column removes the remaining light hydrocarbons, which are cooled to form
LPG. It also recovers a high vapour pressure petrol blending component. The petrol is then
split into light and heavy fraction in a splicer column. The light petrol is stored. The heavy
fraction is sent to the treating facility.
Heavy Petrol treatment
Heavy petrol produced in the MTG process contains a component known as durene (1,2,4,5tetramethylbenzene)
which has a high melting point (79°C). The concentration of durene is
reduced in the heavy petrol treating section, by converting to low melting point petrol
components, e.g. isodurene (1,2,3,5-tetramethylbenzene) with melting point of -23.7°C.
H 3C
CH3
CH 3
CH 3
Product composition
The composition of the synthetic gasoline is quite similar to conventional high quality
gasoline. The products from the MTG process are summarised below:
H3C
CH3
CH3
CH3
Hydrocarbon product w/w % Gasoline composition w/w %
Light Gas 1.4 Highly branched alkanes 53
Propane 5.5 Highly branched alkenes 12
Propene 0.2 Napthenes (cycloalkanes) 7
Isobutane 8.6 Aromatics 28
n-Butane 3.3
Butenes l.1
C5 + Gasoline 79.9
Chemistry of reactions
The steam reforming process can be represented by the general equation:
CnH2n+2 + nH2O nCO + (2n+ l )H2
where CnH2n+2 is any alkane and n is a positive integer. For natural gas, which is almost
entirely methane, the above equation becomes:
CH4 + H2O CO + 3H2
Hence, synthesis gas is formed which can be used for methanol synthesis.
VII-Energy-D-Methanol-15

The reaction of the synthesis gas can give a range of products e.g.
nCO + 2nH2 → CH3(CH2)n-1OH + (n-l)H2O
nCO + (2n+1)H2 → CH3(CH2)n-2CH3 + nH2O
Hence, methanol synthesis requires proper choice of catalyst, which gives high selectivity for
methanol. From above if n=l, then:
CO + 2H2 → CH3OH
The chemistry involved in the MTG process is quite complex. A simplified reaction scheme
(proposed by Chang and Silvestri) is shown below.
-H2O -H2O
2CH3OH CH3OCH3 → C2 - C5 alkenes → alkanes, cycloalkanes, aromatics
+H2O
Figure 14 shows the product selectivity measured over a wide range of space time (contact
time). The contact time measures the time of contact between the catalyst and the reactant
molecules. At shorter contact time (in the order of 10 -3 hr), water and DME are the main
products obtained. When the contact time is increased, the yield of DME reaches a maximum
after which it decreases, since DME now has more chance to further dehydrate to give C2-C5
alkenes. With further increase in the contact time, alkanes/C6+ alkenes and aromatics are
obtained.
Figure 14 - Product time plot of products in w/w% against space time in hours
The MTG process is a selective catalytic conversion. The rate limiting step is the conversion
of DME to alkenes, a reaction step that appears to be autocatylic. The catalytic conversion of
methanol relies on the action of protonic (Bronsted acid) sites, ie. the hydroxyl groups of the
zeolitic structure. The condensation of methanol molecules to DME is thought to involve the
VII-Energy-D-Methanol-16

formation of surface methoxy group formed by the protonation and subsequently removal of
water. The second step, i.e. the oligomerization of alkene molecules probably involves
carbocation intermediates, by protonation of alkene double bonds.
Constraints of the MTG process
• The MTG process is highly exothermic. producing heat at 1740 kJ/kg of methanol
consumed. The principal problem in reactor design is thus heat removal, which is
important. The recycle gas then provides a good absorbent for the heat of reaction.
• One of the undesirable products in the MTG process is durene, which causes
carburettor "icing" because of its high melting point. The synthetic gasoline contains
higher concentration of durene (about 3-6 wt. %) than is normally present in
conventional gasoline (about 0.2-0.3 wt. %). Durene can be isomerized to give isodurene
by the process discussed above to reduce its concentration in the synthetic
gasoline. However, durene can potentially be used as a feed stock in the polymer
industry.
• Catalyst aging is an inevitable problem in catalysis. There are two types. The first is
reversible aging caused by coking. The coked catalyst, hence, requires regeneration
every three or four weeks. Coke is burned off with a heated air-nitrogen mixture.
Operation of the MTG process is kept continuous by using multliple reactors
(Figurc14). The Motunui plant uses five swing reactors, with one undergoing off-line
regeneration at any given time while the other four are run in parallel for MTG. Thc
second type is irreversible, caused by steam (a reaction product), which leads to
dealumination and loss of crystallinity. It can beminimised by operating at low
temperatures and pressures.
• In fixed-bed reactors, especially with fresh catalyst, the reaction only occurs over a
relatively narrow band of the catalyst bed. As coke deposits first deactivate the front
part of the bed, the active reaction zone move down the bed along the flow of the
reactants. This phenomenon is known as band aging, which finally allows the
reactant to break through te bed unconverted.
• The major products of the MTG process are hydrocarbon and water. Therefore, any
unconverted methanol will dissolve in the water and be lost unless a distillation step is
added to the process for recovering the methanol. Thus, essentially complete
conversion of methanol is highly preferred.
• The principal disadvantage of the Mobil process is its inability to directly produce
diesel and jet fuel. Both diesel and jet fuel are composed of linear, long chain alkanes
which the ZSM-5 catalyst does not produce. Jet fuel for example is made up of
mainly C9-C14 alkanes with maximum at about C11. Diesel is made up of mainly C10-
C16 alkanes with maximum around C14.
Advantages of the process
• The synthetic gasoline is free of sulphur and nitrogen.
• The overall energy efficiency of the MTG process including processing energy is
high, about 92-93%. The energy balance is extremely favourable, 95% of the thermal
energy of the methanol feed is preserved in the hydrocarbon product. The remaining
5% is liberating as heat of reaction. However, if one includes the thermal efficiency
for the methanol synthesis process from natural gas (~60%), then the overall energy
efficiency (natural gas to gasoline) is about 50-60%.
• The product meets or exceeds existing gasoline specifications.
• Methanol conversion is virtually complete. Gasoline yield high.
VII-Energy-D-Methanol-17

Figure 15 - Flowsheet of the MTG process section
• The feed (methanol) for the MTG process can be made from the wide variety of
sources, namely natural gas, coal, biomass etc. In fact, the MTG process will convert
most types of alcohol to gasoline, although methanol produced from either natural gas
or coal will probably continue to be the most economic feedstock.
ROLE OF THE LABORATORY
The role of the laboratory is to analyse all process streams. This involves analysis of natural
gas, process gas, cooling water, boiler feed water, waste water and methanol. It is the
laboratory's task to ensure that these streams are within their specification. On the basis of the
analytical results, process conditions can be changed and optimised
Gas streams are analysed continuously with on-line gas chromatography and at regular
intervals with the laboratory gas chromatography. For each gas stream different programs are
used to ensure complete separation and detection of the individual components
Methanol is frequently sampled at various stages of the process and undergoes a series of
physical and chemical tests
Cooling water and boiler feed water are analysed several times a day for pH, hardness,
chloride, phosphate etc. to ensure their corrosive properties are minimal
All plant waste effluents are regularly analysed and checked to see that they meet
environmental restrictions and conditions
VII-Energy-D-Methanol-18

ENVIRONMENTAL IMPLICATIONS
The production of methanol from natural gas poses only limited pressure on the environment.
Only one product is manufactured (methanol) which is a compound of relative low toxicity.
A special methanol sewer collects any methanol wastes spilled on the plant site. This waste
is burned in the reformer as fuel .
A storm pond collects rainwater from the plant and is analysed for methanol and other
contaminants prior to discharge to the river.
Rewritten by John Packer from the two articles of volume 2, compiled by P. Kooy (Petrolgas
- Waitara Valley) and Dr C M Kirk (Taranaki Polytechnic - New Plymouth) with information
supplied by Clare Wrinkes of Methanex New Zealand Ltd.
VII-Energy-D-Methanol-19

15. Metanolproduktion, Nykomb
Nykomb Synergetics, http://www.nykomb.se, svensk firma, som bl.a. arbejder med
production af metanol og andre brændsler. Paper baseret på data fra 1997:
http://www.nykomb.se/pdf/methanol.pdf, hentet d. 20/3-2007.

NYKOMB
SYNERGETICS
1. Introduction
Biomass-Derived Alcohols
for Automotive and Industrial Uses
Ecotraffic R&D AB
This paper is based on a feasibility phase project report titled Biomass-derived
Alcohols for Automotive and Industrial Uses. The report was conducted by
Ecotraffic R&D AB and Nykomb Synergetics AB and printed in September
1997. Furthermore, the report was financed by the European Union program
Altener and the Swedish National Board for Industrial and Technical
Development.
Ecotraffic R&D AB has during 1996 and 1997 made studies including
production of alcohol’s for Vattenfall AB, County Administrative Boards of
Jämtland and of Väster Norrland and for Trollhättan Municipality. Mentioned
Boards and Municipality have shown interest to go on by further studies and
could be partners in the future. In addition, Nykomb Synergetics AB has
indications of interest from their assignors Växjö Energi AB and Air Products
and Chemicals, Inc.
Thus, in the current report, technically viable routes for the conversion of
biomass to transportation fuels have been documented. The report
demonstrates that the primary interest based on present economics is to be
focused on biomass gasification followed by conversion of the syngas produced
into methanol and/or its derivatives and analogues.
With current environmental pressures and the ageing of existing systems, the
need for economically viable alternatives is crucial. Hence, advanced biomass
gasification holds the promise to change the way that biomass residues are
used in the generation of steam and power and in the production of chemicals.
With the commercialisation of such technologies involved they will thus provide
users with the opportunity to replace fossil fuels combustion processes with a
clean, efficient, and totally renewable alternative.
This documentation on technical features and conceptual economics for a
methanol production plant has been developed by Nykomb Synergetics AB and
Ecotraffic R&D AB based on information given by the main technology suppliers
Krupp Uhde GmbH, Dortmund and Haldor Topsøe A/S, Copenhagen.
Nykomb Synergetics AB is well experienced in gasification technology and
methanol production technology, as well as in business development. Ecotraffic
R&D AB is well experienced in logistics and economics of motor alcohols.
Together the two companies have a strong technical, economical and financial
capability of handling a methanol project comprising production of fuel-grade
engine methanol from raw forest biomass.
Nykomb Synergetics AB 15 April 1999 1

NYKOMB
SYNERGETICS
2. Methanol Plant Performance
The configured methanol production plant will produce 1,000 tonnes/day or
310,000 tonnes/year (390 million litres/year) of fuel-grade methanol at a plant
operation of 7,500 equivalent full load hours per year. Thus, the plant will
consume about 177 - 187 tonnes/hour or about 1.3 million tonnes/year of
unprocessed, wood biomass feedstock with a moisture content of 50 % by
weight.
Ecotraffic R&D AB
With the proposed process scheme the methanol can be produced at an
energy efficiency of 57 %. When the plant is made to produce its own electric
power needs the biomass to methanol efficiency decreases to 49 - 46 % at the
same time as the plant will produce heat suitable for district heat system
corresponding to 12 - 21 % of the fuel input.
The overall conclusion is that fuel-grade methanol can be produced from
biomass in a free-standing, self-sufficient plant at a net biomass-to-methanol
efficiency of 49 %.This efficiency can be shown in a Sankey diagram, see
Figure 1.
Biomass Feedstock
408 MW
87 - 82 %
Additional Biomass
63 - 90 MW
13 - 18 %
Methanol - PLANT
Feedstock Drying
Feeding System
HTW - Gasification
Gas Conditioning
Methanol Synthesis
Auto-Thermal
Reformer
Methanol Distillation
Power Boiler
Steam Turbine
Energy Losses
184 - 162 MW
39 - 32 %
Produced Methanol
231 MW
49 - 46 %
Available Heat
56 -105 MW
12 - 21 %
Figure 1. Sankey diagram, methanol production from biomass.
Nykomb Synergetics AB 15 April 1999 2

NYKOMB
SYNERGETICS
3. Process Configuration
Ecotraffic R&D AB
The High Temperature Winkler (HTW) fluidized-bed gasification technology
forms the basis for the synthesis gas production plant. This process, supplied
by the engineering company Krupp Uhde, Germany has attained industrial
maturity for the gasification of reactive feedstocks such as brown coal and peat
under pressure.
The methanol synthesis plant comprise a methanol synthesis unit with a purge
gas stream led to an Auto-Thermal Reformer (ATR), thus making a loop. This
process is supplied by the engineering company Haldor Topsøe, Denmark and
is commercially available. Consequently, the methanol production plant will
ensure high reliability and availability.
4. Environmental Performance
With gasification of biomass feedstock various unwanted compounds are
formed, such as sulphur compounds, ammonia, hydrogen cyanide, nitrogen
compounds and higher hydrocarbons. However, due to the gas cleaning and
gas conditioning steps within the plant, these compounds are completely
removed.
The solid residues from the gasification step will be incinerated as additional
fuels in a steam boiler in order to utilise the energy contained. During
combustion, a minor portion of the combined sulphur will be released and
exhausted to the atmosphere in the form of SO2. In conclusion, the plant will
exhibit good environmental performance with very little emissions.
5. Plant Reliability and Availability
This process plant configuration is mainly based on proven and commercially
available technologies and equipment with guaranteed performance from
competing vendors.
The simple and straight-forward process configuration with a minimum of
integration between plant units and heat exchange between process streams
contributes to an easy and reliable operation of the facility. Thus, this methanol
producing plant will exhibit good reliability and availability.
Nykomb Synergetics AB 15 April 1999 3

NYKOMB
SYNERGETICS
6. Investment Estimate
Ecotraffic R&D AB
The investment cost estimate as well as the calculated methanol production
cost are based on 1 st quarter of 1997 and were based on cost information given
by respective supplier or vendor. Some costs were assessed using in-house
information and applying accepted factoring methods as degression exponents,
scale-up factors etc.
Moreover, the capital investment cost was calculated with an interest of 8 %
and a project lifetime of 15 years, hence, an annuity of some 12 %. Thus, the
estimated investment cost for the biomass to methanol production plant is 417
MMUSD or US$1,800/kW. An investment cost break-down is illustrated below
in Figure 2.
Contingency
11%
Off-sites & Utilities
5%
Wood Preparation
& Storage Units
10%
Combined Heat
and Power Unit
9%
Methanol 8%
Synthesis Plant
57%
Figure 2. Investment cost breakdown.
Synthesis Gas Plant
Nykomb Synergetics AB 15 April 1999 4

NYKOMB
SYNERGETICS
7. Methanol Production Cost
For the production of 1,000 tonnes/day of fuel-grade methanol the calculated
production cost per year is US $0.28/litre or ECU 0.25/litre. This has been
calculated with a typical feedstock cost of ECU 9.5/MWh and 12 % annuity.
Furthermore, in the calculated cost there has been no credit taken for the
available production of heat for distant heating.
Exchange rates (PostGirot, 26 September 1997):
1 USD = 7.50 SEK
1 DEM = 4.29 SEK
1 ECU = 8.50 (set rate by Authors).
8. Commercial Demonstration
Ecotraffic R&D AB
For the commercial demonstration, the subsequent phase of efforts will clearly
focus on selecting a raw materials base, a site, a process configuration, product
slate, and a commercial investor partnership and alliances which will meet the
following criteria:
• Robust investment object in terms of product flexibility.
• Sustainable long term operation.
• Plant scale minimum to meet commercial demonstration objective.
• Transport fuel produced which will be compatible with major automotive
actors’ long range views.
• Overall economics to provide a commercial return after allowing for
compensation for small scale and short term market aberrations in pricing
of competing fossil-based fuels.
• Possibility to organise a substantial fleet demonstration for the biomass
derived fuel.
An overriding consideration is that the selection of project specifications shall
be made in such a way that a successful commercial demonstration is as far as
possible assured - i.e., a commercial return on the partnership’s risk capital
shall be likely in view of the parameters at hand.
Nykomb Synergetics AB 15 April 1999 5

NYKOMB
SYNERGETICS
9. Logistics and Site Location
Ecotraffic R&D AB
Even for a fairly modest demonstration plant, the logistic task of securing
biomass feedstock is a significant one. The ideal candidate sites for a methanol
production plant are sites where substantial volumes of forestry material is at
hand or can be transported at low costs, i.e., in conjunction with pulp mills,
preferably with integrated sawmills.
At such sites the logistic investment is largely in place and cross haul costs
would be minimised on the way from the logging/harvesting operation to the
plant. Also, the ideal site should provide a possibility of heat and utility
integration with the commercial demonstration site. Thus, on assignment of
County Administrative Boards of Jämtland and of Västernorrland and for
Trollhättan Municipality site studies have been made. Furthermore, Växjö
Energi AB has indicated interest to locate a methanol production plant.
Man power needed for operation of the plant is estimated to 60 - 70 people and
an estimated 8 trucks/hr will be needed for transport of the raw material,
provided that the plant is not to be located at a site where primary fuel is
already in place. The 1,000 tonnes/day or 1250 m 3 /day produced methanol will
have a purity of 99.85 % and will be stored in two 5000 m 3 cisterns. These will
be alternatively used for production, storage and loading.
Coastal tankers and/or tank trucks with a maximum carrying volume of 53 m 3 of
fuel will transport the methanol to central tank farm storage facilities for longtime
storage. An estimated 2 trucks/hr will be needed for transport of the fuel.
At the tank farm, fuels to be marketed (excluding methanol only fuel, which
require no further upgrading and thus can be sold direct) will be produced by
blending with diesel and/or gasoline. The fuel products will further be sold via
the present commercial distribution line of tank trucks and gas stations.
10. Engine Testing
Engine testing for a 11 litre heavy duty diesel engine with 12 vol. % methanol
(water-free) emulsified in diesel oil showed in comparison with pure diesel oil a
considerable reduction of emissions of nitrogen oxides (NOx) and particles.
However, a slight reduction (4 - 5 %) of power and torque was noted, but with
an improved efficiency (2 - 3 %).
Parallel tests with 15 vol. % ethanol (azeotrope) emulsified in diesel oil did not
produce the reduction of NOx emissions recorded for methanol, and earlier
tests elsewhere could not be reproduced.
In conclusion, alcohol-only fuels are effective in reducing emissions of NOx,
particles and poly-cyclic aromatic hydrocarbons (PAHs) and their biological
effects. In these respects, tests also show that the environmentally classified
oils in Sweden (very low contents of PAHs and sulphur) are superior to
European standard diesel oils.
Nykomb Synergetics AB 15 April 1999 6

NYKOMB
SYNERGETICS
Ecotraffic R&D AB
Alcohols used to produce stable emulsions in diesel oil need not be water-free
but may contain a few percent water, for instance the ethanol/water azeotrope
or crude methanol. However, blended fuels must be standardised on energy
content.
11. Life Cycle Analysis Considerations
It is quite obvious from reported studies that both methanol and ethanol can be
produced by conversion from wood with use of almost only renewable energy,
i.e., fuels used are by-products or part of the biomass feedstock.
Energy usage in other steps in the chain from feedstock production to end use
in vehicles (forestry, agriculture, transports) is today mainly based on fossil
resources. In the whole chain about ten times as much transport fuel energy in
form of methanol or ethanol can be obtained for each unit input of fossil energy
in a properly designed system.
This ratio can be considerably lower when fossil auxiliary fuels and electricity
are used. Such systems should not be accepted other than during transitions to
fully renewable systems.
Nykomb Synergetics AB 15 April 1999 7

16. Metanolproduktion, Wikipedia
Wikipedia, online og åben encyklopædi:
http://en.wikipedia.org/wiki/Methanol , hentet d. 21/3-2007.

17. Destillationskolonne. Flowsheet for anlæg 3.
Metanol/vandblanding
, som
skal destilleres
93,8 %
T=100,6, 10,8 kg/s
99,99 %, 31,44 kg/s
99,98 %, 31,44 kg/s
99,97 %, 31,44 kg/s
99,94 %, 31,43 kg/s
99,90 %, 31,42 kg/s
99,83 %, 31,41 kg/s
99,72 %, 31,39 kg/s
99,54 %, 31,35 kg/s
99,23 %, 31,29 kg/s
98,74 %, 31,19 kg/s
97,92 %, 31,02 kg/s
96,51 %, 41,5 kg/s
94,41 %, 40,0 kg/s
91,35 %, 39,1 kg/s
84,65 %, 37,4 kg/s
70,30 %, 33,9 kg/s
42,52 %, 27,6 kg/s
13,17 %, 22,0 kg/s
17. T=100,0
16. T=100,0
15. T=100,0
14. T=100,0
13. T=100,0
12. T=100,0
11. T=100,1
10. T=100,1
9. T=100,2
8. T=100,4
7. T=100,6
6. T=101,0
5. T=101,5
4. T=102,7
3. T=105,5
2. T=111,9
1. T=124,4
99,99 %, 41,74 kg/s
99,99 %, 41,74 kg/s
99,97 %, 41,74 kg/s
99,95 %, 41,73 kg/s
99,92 %, 41,72 kg/s
99,87 %, 41,71 kg/s
99,79 %, 41,69 kg/s
99,65 %, 41,65 kg/s
99,42 %, 41,59 kg/s
99,05 %, 41,49 kg/s
98,43 %, 41,32 kg/s
97,43 %, 41,05 kg/s
96,01 %, 39,5 kg/s
92,89 %, 38,7 kg/s
86,08 %, 36,9 kg/s
71,48 %, 33,4 kg/s
43,16 %, 27,1kg/s
13,17 %, 21,5 kg/s
Flowsheet for destillationskolonne. På venstre side af kolonnen føres en massestrøm af en
metanol/vand-blanding på væskefasen fra et trin til trinet under. På højre side af kolonnen føres en
massestrøm af en metanol/vand-blanding på gasfasen fra et trin til trinet over. Fordi metanol har et
lavere kogepunkt end vand vil denne destillationsproces føre til, at metanolkoncentrationen er højst i
toppen af kolonnen, mens vandkoncentrationen er højest i bunden af kolonnen.
Metanolkoncentrationen i mol-% er angivet for alle massestrømmene. Ligevægtstemperaturen for de
fiktive trin er også angivet (°C).

18. Flowsheet for et metanolanlæg (fra DONG
Energy)
MeOH-produktion. 435.000 t/år CO2 fra EtOH-anlæg samt en mængde lignin/xylose osv
forgasses til en syntesegas. Der spædes op med H2 fra elektrolyse (612 MW), hvorved der
produces ca 84 t/h MeOH.

19. Flowsheet for et metanolanlæg (fra kurset
thermoeconomics)
FV
Biomasse
Forgasser
Aske
FG
O2
O2
Vand
Vand
Elektrolyseanlæg
Procesdamp
Damp
FV
H2
CO2
Gasrenser
Metanolreformer
Vand
FV
O2
Syngas
Metanol
CH4
Vand
Kølevand
Metanreformer
Reformergas

20. Flowsheet for metanolanlæg – uden
værdiangivelser

Ash
Gasifier
Steam
Steam dryer
Biomass (wet)
DH condenser
Water
Water /
Methanol
GG
Biomass (dry)
DH water
Distillation
column
O 2
Steam
1
Steam
Water /
Methanol
DH water
Feed
DH cooler
DH water
Steam
DH water
DH water
Gas
Gas cleaner
Steam
Heatsink
Steam
Steam
Water
Steam
Methanol/
water
O 2
Syngas
Water
Electrolyser
Methanol
converter
Syngas
H 2
Water
DH water
Syngas
DH water
Water
O 2
Reformat
CO2
NG
Water
Electrical power
Mechanical power
Heat
Steam
Nomenclature:
Water
Steam reformer
Reformat
Water
O 2
NG

21. Flowsheet for metanolanlæg – til bestemmelse af
komponentpriser for dampreformer,
metanolreaktor og destillationskolonne.

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 6.0 -0 5.7 10.2
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 25.66 412 2
5EX 5 Component cost flow 2 6.0 kg/s 100.1 MW 201 2 5.7 kg/s 5.7 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.191 15 C SAND 100.1 0.21 850 C 294.1 5.7 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
17.24 803 4
25.5 1.0 bar
Electrolyser
33.09
4.3
0.02
0 802 2
25.5 1.0 bar DH water
0.93
Steam reformer
40.95
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.888 25.5 kg/s 5.3 0.699 0.0 0.117 0.208 25.5 kg/s 5.3 4.018
12 C
13 C/EX
SAND 1E-08 90 C
Electro-cool
3
4
1.0 bar
5.3 kg/s
2
4
1.0 bar
0.0 kg/s
50 C
Electro-cool
Comp-O2-2
1.8 MW 3
Reformat
16.7 285.4
403
2
10.0 bar
5.3 kg/s
0.0
0
Ash
0.0 2E-04
83 1.0 bar
4 0.0 kg/s
14 C/M
O2 0.002 7 4 0.002
0.90
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
0.002 5 2
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
DH water
Gas
13.57 90 C
Electrolyser
0.0 -0
6 1.0 bar
4 0.0 kg/s
2.277 90 C
Split-H2
H2 O2 13.57 401 2
5.3 1.0 bar
0.698 5.3 kg/s
90 C
SAND 1.812
14.21 402 4
0.94
14.21 5.3 10.0 bar
2.399 5.3 kg/s
431 C
431 10.0 bar
4 16.7 kg/s
40.95 950 C
NG_reformer
14.21 850 C
NG_reformer
1.9 32.21
441 10.0 bar
2 1.9 kg/s
4.622 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
3E-05
0.0
33 2
1.0 bar
Steam
32
0.0 0.009
1.0 bar
801
2
0.0 4E-05
1.0 bar
0.0 kg/s
15
4
0.0 1E-05
1.0 bar
0.0 kg/s Heatsink-H2
-0 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
4.8 82.91
10.0 bar
4.8 kg/s
2.4
14.21 0.97 Heatex-O2
SAND 11
0.001 0.0 kg/s Heatex-GG-st 4 0.0 kg/s 0 50 C 0 60 C 0.0 MW 322 2.277 0.0 MW 9 Comp-CO2 11.9 950 C
730 C SAND 7 0.00 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 2E-07 0.0 MW 7
Heatex-NG
0.89
0
Gasifier
0.0 0.115
0
0.0
0.104
Gasifier
10 GG2
0.00 0.78
1.0 bar 0.0
0.0 kg/s
800 C
0
0.0
0.104
11 2
1.0 bar
0.0 kg/s
752 C
Heatex-GG-st
0.00 0.99 0
0.0 0.0
0.099
12 2 0.00 0.74
1.0 bar 0.0
0.0 kg/s
130 C Heatex-GG-DH
0
0.0
0.099
13 2
1.0 bar
0.0 kg/s
60 C
1.00
Gas cleaner 0.0
0.0 0.099
14 1.0 bar
0.00
Heatsink 2.28
2.277 511 2
0.0 1.0 bar
0.117 0.0 kg/s
90 C
Heatsink-H2
42.73 503 4
15.6 24.0 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 24.0 bar 0.0 1.0 bar
CO2
25.65 411 2
NG5.7
10.0 bar
288 5.7 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
9.9 170.3
10.0 bar
11.6
13 25.66 0.89
0 434 Water 2
0.4 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 0.0 kg/s 267.6 15.6 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 9.9 kg/s 0.021 0.4 kg/s
2 0.0 kg/s 0.00 9 2 Heatex-GG-O2 0.0 0.004 0 21 4 0.0 60 C 280 C 300 C 15 C 24.44 950 C 107 C
0.00 120 C 0.0 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 2.28 512 2 2.289 524 4 15.6 267.8 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
5E-04 0.0 kg/s
790 C
Gasifier
2 0.0 kg/s
2E-04 120 C
Heatex-GG-st
-0 0.0 kg/s
60 C 521
Heatex-GG-DH 2
0.0 0.216
1.0 bar
0.0 kg/s
0.0
0.117
1.0 bar
0.0 kg/s
90 C
0.0
0.227
24.0 bar
0.0 kg/s
393 C
531
2
45.02
24.0 bar
15.6 kg/s
280 C
0.182 422 2
Water 5.7 10.0 bar
0.018 5.7 kg/s
23.5 Heatex-H2O
0.21 0.74 SAND 15
0 453 Water 4
Steam
811
0.0 2E-04
1.0 bar
2.28 76 C
Comp-GG-H2-1
Comp-GG-H2-1
0.0 MW 11
Mixer-GG-H2 Comp-GG-H2-2
38.9 24.06
Syngas-cool1
33 C
Heatex-H2O
0.7
0.038
10.0 bar
0.7 kg/s
4 0.0 kg/s 0.93
SAND 0.006 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 2.286 0.0 0.015 6 38.9 kg/s SAND 21 5.0 MW 5 9.2 Heatex-H2O
4.4 76.17 1.9
0.0 0.007 Heatex-GG-DH
0.0 0.221 563 1.0 bar 0.97 200 C 6.2 SAND 5.011 9.2 156.5 4.4 76.17 1.9 30.53
0.00
0.0
Steam_dryer Biomass (dry)
SAND 1
35 4 0.46 0.0 0.00 34 2
1.0 bar Steam dryer 0.00 0.0 1.0 bar
34 1.0 bar
4 0.0 kg/s
1E-04 730 C
Split-steam2
522 4.5 bar
2 0.0 kg/s
2.286 280 C
Cooler-GG-H2
2 0.0 kg/s
0.00 120 C
Cooler-GG-H2
0.0
0.00 0.85
2.29 523 2
0.0 4.5 bar
0.94
2.289
Syngas-cool1
561
2
0.962
38.9 22.01
1.0 bar
38.9 kg/s
120 C
0.96 0.86
0 541 4
0.2 24.0 bar
0.021 0.2 kg/s
136 C
Water
Reformat
42.73 462 2 42.73
15.6 24.0 bar
267.6 15.6 kg/s
40.95 461 2
0.93
15.6 10.0 bar
262.9 15.6 kg/s
452 10.0 bar
2 9.2 kg/s
24.44 109 C
Mixer-NG_ref
433 10.0 bar
2 4.4 kg/s
11.9 107 C
Mixer-NG_ref
442 10.0 bar
2 1.9 kg/s
4.622 483 C
Mixer-NG_ref
0.028 0.0 kg/s 0.03 0.0 kg/s Cooler-GG-H2 0.0 0.016 0.22 0.0 kg/s Syngas-cool1 15.3 265.4 Syngas-cool1
280 C 154 C
120 C 0.0 0.115 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 24.0 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 0.0 kg/s Comp-GG-H2-2 2 15.3 kg/s
2
0.003
0.0 kg/s
15 C
Steam
0.00 200 C
Cooler-GG-H2
0.0 MW
SAND
13
0.007
45.02 136 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
0.0 0.002
41 1.0 bar
2 0.0 kg/s
Steam
0.93
47.04
15.3 270.7
533 67.1 bar
4 15.3 kg/s
Syngas 47.04 280 C
5.7 MW
SAND
15
5.697
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
152
0
0
Total
price
[mio. kr]
198
0
0
C
[kr/s]
0.46
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
288 MW
0 MW
100 MW
117 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
11 MW
0 MW
16 MW
SAND 79 9E-05 120 C 98.5 61.02 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 0 0 0.00
DH-condenser
0.91 0.0 17.24 811 12
DH condenser 17.24 25.5 1.0 bar
581
2
2.46
1.0 bar
98.5 kg/s
200 C Steam
1.44 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
0
0
0
0
0
0.00
0.00
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
60% (with power for electrolyser)
57% (with total power)
64%
0.0 1E-04 0.889 25.5 kg/s DH-cooler DH-cooler
58.7 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 36.33 58.7 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 0 0 0.00
4 0.0 kg/s
0 95 C
DH-condenser
DH-condenser
413.3 14.44
811 1.0 bar
0.019 811 6
93.7 1.0 bar
3.273 93.7 kg/s
0.48 15.7 0 804 2
DH cooler
DH water
0.02 93.7 1.0 bar
0.767 93.7 kg/s 1.0 0.639
1.453 562 2
58.7 1.0 bar
200 C
Syngas-cool2 9.3
1.46 0.90
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
0
8
1
0
11
1
0.00
0.02
0.00 Energy
Water
2 413.3 kg/s
17.32 90 C
DH
DH water
90 C
DH-cooler
35
6
98.5 55.8
1.0 bar
98.5 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.02 225 C
Cond-steam-1
33.23 58.7 kg/s
120 C
Syngas-cool2
534
2
13.5 267
67.1 bar
13.5 kg/s
0 551 4
1.8 67.1 bar
0.177 1.8 kg/s
141 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
288
5
9
23
0
375
6
12
29
0
0.87
0.01
0.03
0.07
0.00
Input:
NG
Biomass
Power*
Total power
276 MW
0 MW
100 MW
117 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
69 MW
0 MW
14 MW
Energy content in DH water = 69 MW 2.46 120 C
DH-cooler
Steam
47.04 141 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
0
0
0
0.00
0.00
* for electrolyser
Urenhed:
0.030 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.97
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
48.39 3.8 MW 17
SAND 3.805
13.5 270.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
0
2
26
0
0
3
33
0.00
0.00
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
55% (with power for electrolyser)
52% (with total power)
73%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 4 5 0.01
0.02 120 C 2 13.5 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 17 22 0.05
Cond-steam-1
48.39 248 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 289 376 0.87 Gas composition at specific nodes (mol-%)
47.14 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 3 4 0.01
793
794
3.5 bar
10.3 kg/s 601
36.0 568.8
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4
3
5
4
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.91
4 100 C 2 36.0 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
185 40.4 907.1 Steam
0 682 4
107 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
290
0
377
0
0.87
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 63.47 58.41 40.38 43.35 49.84 53.73
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
791 3.5 bar 16.3 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 12 16 0.04 4 CO 42.73 0.00 22.49 24.73 12.85 1.39 1.49 1.72 1.85
792 40.4 kg/s 16.66 16.3 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 6 8 0.02 6 CO2 5.24 0.00 5.09 5.61 20.00 25.03 26.87 30.89 33.31
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 17 21 0.05 7 H2O-G 5.21 0.00 14.17 5.59 2.70 6.17 3.98 0.97 0.03
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.05 811 10 41.3
246.7 1.0 bar 0.05 0.70
0 806 2
DH water
246.7 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.02 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
16.3 30.6 bar
30.2 Meoh-convert
Methanol 1.00 SAND
converter 108
311
Total several DISTILLATION_STAGE's 1160 1479 3.49 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.60
0.00
0.00
5.77 7.92 8.51
0.00 0.00 0.00
0.28 19.10 15.80
9.78 10.54
0.00 0.00
6.80 0.53
8.618 246.7 kg/s
90 C
2.02 246.7 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.583 16.3 kg/s
220 C 602
36.0 554
139.0 bar 607
22.5 299.2
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
137.9
Heatsourc-DH 185
30.1 676 783
40.4 916.6 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
108
36.0 kg/s
235 C
2
59
22.5 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 40.4 kg/s 16.1 16.55 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 30.1 kg/s 4 100 C 685 30.6 bar 7.0 Preheater-sy NG 93 kr/GJ Methanol 47.1 kr/s 204 kr/GJ 230 kr/GJ 4.58 kr/kg 3.6 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 16.1 kg/s 59 606 2 59 0.84 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 19427 kr/GJ - kr/GJ 2.56 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 59 22.5 144.0 bar 32.8 496.3 DH water 0 kr/ton Syngas 3.1 kr/s 198 kr/GJ - kr/GJ 2.62 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.1 MW 19 0.90 297 22.5 kg/s 640 139.0 bar 64 10.82 3.2 55.17 Water 32 kr/ton DH water 17.3 kr/s 1200 kr/GJ 249 kr/GJ 0.04 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.138 63 C 2 32.8 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
190 0.72
Feed
16.1
3.559
30.6 bar
16.1 kg/s
220 C
Preheater-sy 97.36 189 C
Condenser-1
9.9
631 3.2 kg/s
4 189 C
Preheater-sy
Nomenclature:
Cond-steam-2 1.31 0.97 If methanol and DH share the plant costs
Condenser-1 75.9 22.75 621 631 4 (methanol and DH are the only products from the plant) -
5 705 706
19 3.5 bar
2 1.31 705 706
5 3.5 bar
6
SAND 31 26.7 378
643 139.0 bar
2 26.7 kg/s
6 139.0 bar
115 6.0 kg/s
145 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 57.1 kr/s 247 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
35 19.0 kg/s 9 4.7 kg/s Condenser 74.61 145 C Preheater-sy
DH water 10.4 kr/s 150 kr/Gjen Mass flow
135 C 135 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
47.5 1.0 bar
Reboil-meoh2 8.0
0.01 0.75
0 805 2
DH water
47.5 1.0 bar Mechanical power
10
5.242 21.1 25.96 1.659 47.5 kg/s 0.389 47.5 kg/s 1.296 4.7 5.802
707 3.5 bar Cond-steam-2 90 C 58.86 605 2 50 C 699 3.5 bar 0.25
708 21.1 kg/s SAND 393 Condenser
22.5 139.0 bar 1.2 15.63 Condenser
700 4.7 kg/s
4 135 C 296.9 22.5 kg/s 611 139.0 bar 87.0 12.65 3.1 63.79 2 135 C
Water /
Methanol
Methanol molar-% = 2.96
0 693 694
2 3.5 bar
2 2.0 kg/s
Dis_stage_1
4 3.946 695 696
14 3.5 bar
18 14.3 kg/s
2 30.0
3.982 0.68
3.982 705 706
14 3.5 bar
26 14.3 kg/s
4
46.22 625 635
12 3.5 bar
2
Methanol molar-% = 75.3
60 C
Comp-recirc
Methanol/
4 1.2 kg/s
3.098 60 C
Syngas Split-syngas
621 139.0 bar
631 3.0 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
135 C
Reboil-meoh1
135 C
Reboil-meoh1
234 12.3 kg/s
102 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

22. Flowsheet for metanolanlæg – til
parameterfastsættelse

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.4 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX
6 EX_CH * Number of decimals
5 Component cost flow
Electrolyser
2
0.076
2.4 kg/s
15 C
39.7 MW
SAND
201
39.71
2
0.00
0.0 kg/s
850 C
0.0
0.176
10.0 bar
0.0 kg/s
NG
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.369 803 4
86.9 1.0 bar
Electrolyser
13.12
1.7
0.80
0 802 2
86.9 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.906 86.9 kg/s 2.1 0.277 0.3 31.05 0.711 86.9 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 55 C
Electro-cool
3
4
1.0 bar
2.1 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.445
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.113 7 4 0.113
0.90
2.1 1.0 bar
0.277 2.1 kg/s
90 C
Comp-O2-1
0.113 5 2
2.1 1.0 bar
0.277 2.1 kg/s
90 C
Comp-O2-1
DH water
Gas
0.113 90 C
Electrolyser
0.0 -0
6 1.0 bar
4 0.0 kg/s
12.64 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.029
5.0
33 2
1.0 bar
Steam
32
18.1 23.26
1.0 bar
801
2
14.3 0.117
1.0 bar
14.3 kg/s
15
4
4.6 2.112
1.0 bar
4.6 kg/s Heatsink-H2
-0 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
6.416 5.0 kg/s Heatex-GG-st 4 18.1 kg/s 0 50 C 0 60 C 0.0 MW 322 12.64 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.11 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 4E-05 0.0 MW 7
Heatex-NG
0.89
10
Gasifier
11.7 255.5
10
18.2
234.8
Gasifier
10 GG2
0.11 0.78
1.0 bar 1.5
18.2 kg/s
800 C
10
18.2
233.7
11 2
1.0 bar
18.2 kg/s
761 C
Heatex-GG-st
0.11 0.98 10
23.1 18.2
220.5
12 2 0.00 0.74
1.0 bar 2.4
18.2 kg/s
130 C Heatex-GG-DH
10
18.2
219.9
13 2
1.0 bar
18.2 kg/s
60 C
1.00
Gas cleaner 9.6
13.6 218.8
14 1.0 bar
0.00
Heatsink
12.64
12.64 511 2
0.3 1.0 bar
31.05 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 19.8 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 19.8 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 13.6 kg/s 0.166 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 11.7 kg/s 0.11 9 2 Heatex-GG-O2 18.1 10.23 0 21 4 9.6 60 C 259 C 279 C 15 C 0.01 950 C 107 C
6.99 120 C 2.1 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 12.64 512 2 27.37 524 4 13.9 261 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.127 2.1 kg/s
790 C
Gasifier
2 18.1 kg/s
0.079 120 C
Heatex-GG-st
4E-18 0.0 kg/s
60 C 521
Heatex-GG-DH 2
13.9 249.8
1.0 bar
13.9 kg/s
0.3
31.05
1.0 bar
0.3 kg/s
90 C
13.9
260.8
19.8 bar
13.9 kg/s
305 C
531
2
27.39
19.8 bar
13.9 kg/s
304 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
14.3 0.498
1.0 bar
22.23 63 C
Comp-GG-H2-1
Comp-GG-H2-1
8.4 MW 11
Mixer-GG-H2 Comp-GG-H2-2
37.6 23.31
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 14.3 kg/s 0.93
SAND 8.391 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.2 37.6 21.3 6 37.6 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
13.1 16.84 Heatex-GG-DH
13.9 257.6 563 1.0 bar 0.17 200 C 6.0 SAND 0.002 0.0 0.094 0.0 0.046 0.0 0.018
Steam_dryer Biomass (dry)
34 1.0 bar 522 6.0 bar 2 37.6 kg/s Syngas-cool1 0.17 0.82 452 10.0 bar 433 10.0 bar 442 10.0 bar
0.45
105.4
35 4
1.0 bar
SAND 1
0.45 29.8
Steam dryer 6.99
0.45
94.9
34 2
1.0 bar
4 13.1 kg/s
0.077 730 C
Split-steam2
2 13.9 kg/s
25.2 304 C
Cooler-GG-H2
0.16 120 C
Cooler-GG-H2
6.0
0.17 0.82
25.20 523 2
13.9 6.0 bar
0.93
27.37
561
2
0.164
37.6 21.32
1.0 bar
37.6 kg/s
120 C
0 541 4
0.0 19.8 bar
6E-18 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 19.8 bar
0.16 0.0 kg/s
0.017 461 2
0.93
0.0 10.0 bar
0.158 0.0 kg/s
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
59.71 105.4 kg/s 65.17 94.9 kg/s Cooler-GG-H2 37.6 23.29 255.2 13.9 kg/s Syngas-cool1 13.9 258.6 Syngas-cool1
250 C 154 C
120 C 22.2 256.3 278 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.8 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 37.6 kg/s Comp-GG-H2-2 2 13.9 kg/s
2
6.86
22.2 kg/s
15 C
Steam
0.17 200 C
Cooler-GG-H2
6.1 MW
SAND
13
6.098
27.39 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
5.6 3.144
41 1.0 bar
2 5.6 kg/s
Steam
0.93
29.55
13.9 264.2
533 65.2 bar
4 13.9 kg/s
Syngas 29.55 304 C
6.1 MW
SAND
15
6.102
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
60
0
0
Total
price
[mio. kr]
78
0
0
C
[kr/s]
0.18
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
256 MW
40 MW
65 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
8 MW
SAND 79 0.024 120 C 52.4 32.45 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 815 1059 2.45
DH-condenser
0.73 12.9 0.41 811 12
DH condenser0.41
86.9 1.0 bar
581
2
0.24
1.0 bar
52.4 kg/s
200 C Steam
0.26 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
9
1
1
12
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
78%
5.6 0.219 3.035 86.9 kg/s DH-cooler DH-cooler
57.9 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 35.88 57.9 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 43 56 0.13
4 5.6 kg/s
0 95 C
DH-condenser
DH-condenser
439.6 15.36
811 1.0 bar
0.010 811 6
49.8 1.0 bar
1.739 49.8 kg/s
0.48 8.3 0 804 2
DH cooler
DH water
0.01 49.8 1.0 bar
0.408 49.8 kg/s 1.0 0.639
0.252 562 2
57.9 1.0 bar
200 C
Syngas-cool2 9.2
0.26 0.91
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
5
0
0
7
0
0
0.02
0.00
0.00 Energy
Water
2 439.6 kg/s
0.48 90 C
DH
DH water
90 C
DH-cooler
35
6
52.4 29.67
1.0 bar
52.4 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
32.81 57.9 kg/s
120 C
Syngas-cool2
534
2
12.4 260.7
65.2 bar
12.4 kg/s
0 551 4
1.6 65.2 bar
0.138 1.6 kg/s
135 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
214 MW
40 MW
65 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
74 MW
0 MW
7 MW
Energy content in DH water = 74 MW 0.24 120 C
DH-cooler
Steam
29.55 135 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
38
0
49
0.00
0.11
* for electrolyser
Urenhed:
0.008 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.99
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
30.82 3.6 MW 17
SAND 3.586
12.4 264.1
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
27
2
27
3
36
3
36
0.01
0.08
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
81% (with power for electrolyser)
73% (with total power)
102%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 4 5 0.01
0.00 120 C 2 12.4 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 16 21 0.05
Cond-steam-1
30.82 248 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 254 330 0.76 Gas composition at specific nodes (mol-%)
31.41 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 2 3 0.01
793
794
3.5 bar
10.3 kg/s 601
42.2 416.8
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
2
4
3
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.78
4 100 C 2 42.2 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
127.3 41.7 936.6 Steam
0 682 4
51 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
254
0
330
0
0.76
0.00
1
3
H2
N2
45.61
0.21
0.00 57.70 60.67 45.40 22.81 24.39 28.19 30.00
0.00 0.00 0.23 2.28 3.30 3.53 4.08 4.34
791 3.5 bar 17.8 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 17 0.04 4 CO 32.23 0.00 22.49 34.03 20.51 5.24 5.60 6.47 6.89
792 41.7 kg/s 18.23 17.8 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 9.40 99.97 5.09 0.03 26.44 40.34 43.14 49.87 53.07
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 17 22 0.05 7 H2O-G 12.29 0.00 14.17 4.78 2.41 1.49 0.97 0.20 0.01
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.051 811 10 42.7
254.6 1.0 bar 0.051 0.70
0 806 2
DH water
254.6 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.8 30.6 bar
33.1 Meoh-convert
Methanol 1.00 SAND
converter 51
311
Total several DISTILLATION_STAGE's 1601 2055 4.82 11
36
40
CH4
AR
CH3OH
0.15
0.10
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.16
0.11
0.00
1.58 2.30 2.46
1.09 1.58 1.69
0.29 22.94 18.23
2.84
1.96
6.39
3.02
2.08
0.59
8.895 254.6 kg/s
90 C
2.085 254.6 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.92 17.8 kg/s
220 C 602
42.2 400.7
139.0 bar 607
29.8 150.7
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
95.88
Heatsourc-DH 127.3
31.4 705.5 783
41.7 946.3 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
51
42.2 kg/s
235 C
2
20
29.8 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 41.7 kg/s 17.7 18.12 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 31.4 kg/s 4 100 C 685 30.6 bar 6.1 Preheater-sy NG 93 kr/GJ Methanol 31.4 kr/s 136 kr/GJ 153 kr/GJ 3.05 kr/kg 2.4 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.7 kg/s 20 606 2 20 0.60 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 407 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 20 29.8 144.0 bar 39.3 336.1 DH water 0 kr/ton Syngas 1.0 kr/s 132 kr/GJ - kr/GJ 0.66 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.1 MW 19 0.90 148.9 29.8 kg/s 640 139.0 bar 91 7.937 2.9 61.49 Water 32 kr/ton DH water 0.5 kr/s 31 kr/GJ 6 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.116 63 C 2 39.3 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
142 0.78
Feed
17.7
3.895
30.6 bar
17.7 kg/s
220 C
Preheater-sy 43.39 181 C
Condenser-1
8.5
631 2.9 kg/s
4 181 C
Preheater-sy
Nomenclature:
Cond-steam-2 2.95 0.50 If methanol and DH share the plant costs
Condenser-1 94.1 16.18 621 631 4 (methanol and DH are the only products from the plant) -
14 705 706
21 3.5 bar
2 2.95 705 706
4 3.5 bar
6
SAND 31 33.6 207.8
643 139.0 bar
2 33.6 kg/s
6 139.0 bar
124 5.7 kg/s
134 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 21.8 kr/s 95 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
115 21.5 kg/s 24 4.4 kg/s Condenser 27.21 134 C Preheater-sy
DH water 11.1 kr/s 150 kr/Gjen Mass flow
124 C 124 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
34.0 1.0 bar
Reboil-meoh2 5.7
0.01 0.40
0 805 2
DH water
34.0 1.0 bar Mechanical power
10
14.27 22.0 106.1 1.189 34.0 kg/s 0.279 34.0 kg/s 2.943 4.4 21.39
707 3.5 bar Cond-steam-2 90 C 19.69 605 2 50 C 699 3.5 bar 0.25
708 22.0 kg/s SAND 393 Condenser
29.8 139.0 bar 1.6 7.83 Condenser
700 4.4 kg/s
4 124 C 148.8 29.8 kg/s 611 139.0 bar 96.8 6.483 2.2 48.98 2 124 C
Water /
Methanol
Methanol molar-% = 13.17
0 693 694
0 3.5 bar
2 0.5 kg/s
Dis_stage_1
4 11.33 695 696
17 3.5 bar
82 17.0 kg/s
2 32.9
11.37 0.64
11.37 705 706
17 3.5 bar
91 17.0 kg/s
4
30.6 625 635
11 3.5 bar
2
Methanol molar-% = 94
60 C
Comp-recirc
Methanol/
4 1.6 kg/s
1.036 60 C
Syngas Split-syngas
621 139.0 bar
631 2.2 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
124 C
Reboil-meoh1
124 C
Reboil-meoh1
234 10.8 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

23. Flowsheets for metanolanlæg - til den
termoøkonomiske analyse.
Flowsheet 1/5:
Flow-parametre: P, m& , t
Komponent-parameter: ηex
Flowsheet 2/5:
Flow-parametre: m& , h, x
Komponent-parameter: Ċi, dest
Flowsheet 3/5:
Flow-parametre: eex, m, eex,ch,m, eex,ph,m
Komponent-parameter: Ċp, dest
Flowsheet 4/5:
Flow-parametre: Ėex, Ėex, ch, Ėex, ph
Komponent-parameter: Ėex, dest
Flowsheet 5/5:
Flow-parametre: Ċ, cex, cm
Komponent-parameter: Ż

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 3.4 -0 1.9 3.399
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 8.55 412 2
5EX 5 Component cost flow 2 3.4 kg/s 56.3 MW 201 2 1.9 kg/s 1.9 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.107 15 C SAND 56.34 0.07 850 C 97.97 1.9 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.381 803 4
78.5 1.0 bar
Electrolyser
18.62
2.4
0.80
0 802 2
78.5 1.0 bar DH water
0.93
Steam reformer
9.22
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.927 78.5 kg/s 3.0 0.393 0.4 44.05 0.643 78.5 kg/s 1.8 1.339
12 C
13 C/EX
SAND 1E-05 57 C
Electro-cool
3
4
1.0 bar
3.0 kg/s
2
4
1.0 bar
0.4 kg/s
50 C
Electro-cool
Comp-O2-2
0.6 MW 3
Reformat
5.6 95.09
403
2
10.0 bar
1.8 kg/s
0.0
0
Ash
0.3 0.252
83 1.0 bar
4 0.3 kg/s
14 C/M
O2 0.066 7 4 0.066
0.90
1.2 1.0 bar
0.16 1.2 kg/s
90 C
Comp-O2-1
0.066 5 2
1.2 1.0 bar
0.16 1.2 kg/s
90 C
Comp-O2-1
DH water
Gas
0.161 90 C
Electrolyser
0.0 9E-36
6 1.0 bar
4 0.0 kg/s
18.08 90 C
Electrolyser
H2 O2 0.095 401 2
1.8 1.0 bar
0.233 1.8 kg/s
90 C
SAND 0.604
0.309 402 4
0.94
0.309 1.8 10.0 bar
0.799 1.8 kg/s
431 C
431 10.0 bar
4 5.6 kg/s
9.22 950 C
NG_reformer
0.31 850 C
NG_reformer
0.6 10.73
441 10.0 bar
2 0.6 kg/s
1.041 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.009
1.3
33 2
1.0 bar
Steam
32
8.4 10.81
1.0 bar
801
2
6.8 0.056
1.0 bar
6.8 kg/s
15
4
0.0 0.016
1.0 bar
0.0 kg/s Heatsink-H2
4E-36 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
1.6 27.62
10.0 bar
1.6 kg/s
0.8
0.31 0.97 Heatex-O2
SAND 11
1.707 1.3 kg/s Heatex-GG-st 4 8.4 kg/s 0 50 C 0 60 C 0.0 MW 322 18.08 0.0 MW 9 Comp-CO2 2.678 950 C
730 C SAND 7 0.06 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 6E-05 0.0 MW 7
Heatex-NG
0.89
5
Gasifier
6.6 144.7
5
8.9
131.6
Gasifier
10 GG2
0.07 0.78
1.0 bar 0.9
8.9 kg/s
800 C
5
8.9
130.9
11 2
1.0 bar
8.9 kg/s
752 C
Heatex-GG-st
0.06 0.99 5
10.8 8.9
124.8
12 2 0.00 0.74
1.0 bar 1.1
8.9 kg/s
130 C Heatex-GG-DH
5
8.9
124.6
13 2
1.0 bar
8.9 kg/s
60 C
1.00
Gas cleaner 5.4
8.9 124.5
14 1.0 bar
0.00
Heatsink
18.08
18.08 511 2
0.4 1.0 bar
44.05 0.4 kg/s
90 C
Heatsink-H2
9.671 503 4
5.2 19.8 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 19.8 bar 0.0 1.0 bar
CO2
8.545 411 2
NG1.9
10.0 bar
95.97 1.9 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
3.3 56.74
10.0 bar
3.9
13 8.55 0.89
0 434 Water 2
0.1 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 8.9 kg/s 88.77 5.2 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 3.3 kg/s 0.007 0.1 kg/s
2 6.6 kg/s 0.07 9 2 Heatex-GG-O2 8.4 4.755 0 21 4 5.4 60 C 250 C 279 C 15 C 5.501 950 C 107 C
3.96 120 C 1.2 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 18.08 512 2 26.82 524 4 14.4 264.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.653 1.2 kg/s
790 C
Gasifier
2 8.4 kg/s
0.043 120 C
Heatex-GG-st
-0 0.0 kg/s
60 C 521
Heatex-GG-DH 2
9.2 168.4
1.0 bar
9.2 kg/s
0.4
44.05
1.0 bar
0.4 kg/s
90 C
9.2
175.7
19.8 bar
9.2 kg/s
320 C
531
2
36.49
19.8 bar
14.4 kg/s
294 C
0.061 422 2
Water 1.9 10.0 bar
0.006 1.9 kg/s
7.8 Heatex-H2O
0.07 0.74 SAND 15
0 453 Water 4
Steam
811
6.8 0.237
1.0 bar
23.50 68 C
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.2 22.42
Syngas-cool1
33 C
Heatex-H2O
0.2
0.013
10.0 bar
0.2 kg/s
4 6.8 kg/s 0.93
SAND 5.071 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.3 22.7 12.89 6 36.2 kg/s SAND 21 1.3 MW 5 3.1 Heatex-H2O
1.5 25.38 0.6
7.1 9.101 Heatex-GG-DH
9.2 173.1 563 1.0 bar 0.19 200 C 5.8 SAND 1.267 3.1 52.16 1.5 25.38 0.6 10.17
0.31
62.1
Steam_dryer Biomass (dry)
SAND 1
35 4 0.46 16.9 0.31 34 2
1.0 bar Steam dryer 3.96 56.1 1.0 bar
34 1.0 bar
4 7.1 kg/s
0.047 730 C
Split-steam2
522 5.5 bar
2 9.2 kg/s
25.3 294 C
Cooler-GG-H2
2 22.7 kg/s
0.12 120 C
Cooler-GG-H2
3.6
0.12 0.83
25.30 523 2
9.2 5.5 bar
0.93
26.82
Syngas-cool1
561
2
0.186
36.2 20.51
1.0 bar
36.2 kg/s
120 C
0.19 0.83
0 541 4
0.0 19.8 bar
-0 0.0 kg/s
130 C
Water
Reformat
9.669 462 2 9.669
5.2 19.8 bar
88.77 5.2 kg/s
9.22 461 2
0.93
5.2 10.0 bar
87.59 5.2 kg/s
452 10.0 bar
2 3.1 kg/s
5.501 109 C
Mixer-NG_ref
433 10.0 bar
2 1.5 kg/s
2.678 107 C
Mixer-NG_ref
442 10.0 bar
2 0.6 kg/s
1.041 483 C
Mixer-NG_ref
35.17 62.1 kg/s 38.2 56.1 kg/s Cooler-GG-H2 22.7 14.09 171.7 9.2 kg/s Syngas-cool1 14.4 262 Syngas-cool1
250 C 154 C
120 C 12.6 145.2 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.8 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 22.7 kg/s Comp-GG-H2-2 2 14.4 kg/s
2
3.886
12.6 kg/s
15 C
Steam
0.12 200 C
Cooler-GG-H2
4.3 MW
SAND
13
4.28
36.49 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.6 2.629
41 1.0 bar
2 4.6 kg/s
Steam
0.93
38.57
14.4 267.5
533 62.2 bar
4 14.4 kg/s
Syngas 38.57 294 C
5.9 MW
SAND
15
5.869
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
86
0
0
Total
price
[mio. kr]
111
0
0
C
[kr/s]
0.26
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
96 MW
145 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.024 120 C 53.5 33.11 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 461 600 1.39
DH-condenser
0.74 10.8 0.42 811 12
DH condenser0.42
78.5 1.0 bar
581
2
0.28
1.0 bar
53.5 kg/s
200 C Steam
0.23 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
4
0
0
6
1
0.00
0.01
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
80%
4.6 0.183 2.743 78.5 kg/s DH-cooler DH-cooler
42.5 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 26.35 42.5 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 24 32 0.07
4 4.6 kg/s
0 95 C
DH-condenser
DH-condenser
430.0 15.02
811 1.0 bar
0.010 811 6
50.8 1.0 bar
1.776 50.8 kg/s
0.48 8.5 0 804 2
DH cooler
DH water
0.01 50.8 1.0 bar
0.416 50.8 kg/s 1.0 0.639
0.219 562 2
42.5 1.0 bar
200 C
Syngas-cool2 6.8
0.23 0.87
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4
3
0
6
4
0
0.01
0.01
0.00 Energy
Water
2 430.0 kg/s
0.49 90 C
DH
DH water
90 C
DH-cooler
35
6
53.5 30.28
1.0 bar
53.5 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.01 225 C
Cond-steam-1
24.1 42.5 kg/s
120 C
Syngas-cool2
534
2
13.9 264.9
62.2 bar
13.9 kg/s
0 551 4
0.6 62.2 bar
0.049 0.6 kg/s
136 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
96
2
3
6
0
125
2
4
7
0
0.29
0.00
0.01
0.02
0.00
Input:
NG
Biomass
Power*
Total power
92 MW
121 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
11 MW
Energy content in DH water = 72 MW 0.28 120 C
DH-cooler
Steam
38.57 136 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.023 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
40.01 4.1 MW 17
SAND 4.068
13.9 268.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
19
2
26
2
25
3
34
0.00
0.06
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.01 120 C 2 13.9 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.06
Cond-steam-1
40.01 253 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 327 424 0.98 Gas composition at specific nodes (mol-%)
39.74 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
3.5 bar
10.3 kg/s 601
59.3 519.3
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.67
4 100 C 2 59.3 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
148 38.4 860.6 Steam
0 682 4
82 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
270
0
351
0
0.81
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 60.63 42.70 24.36 25.92 27.89 30.00
0.00 0.00 0.12 1.00 1.32 1.40 1.51 1.62
791 3.5 bar 17.1 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 29.16 14.45 3.27 3.47 3.74 4.02
792 38.4 kg/s 17.55 17.1 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 5.24 0.00 5.09 4.47 35.29 46.38 49.35 53.11 57.12
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 20 0.05 7 H2O-G 5.21 0.00 14.17 5.12 2.13 2.93 1.70 0.62 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.047 811 10 39.2
234.0 1.0 bar 0.047 0.70
0 806 2
DH water
234.0 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.01 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.1 30.6 bar
31.8 Meoh-convert
Methanol 1.00 SAND
converter 83
311
Total several DISTILLATION_STAGE's 1423 1826 4.28 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.44
0.06
0.00
3.62 4.77 5.08
0.48 0.63 0.67
0.33 16.33 12.39
5.47
0.73
6.94
5.88
0.78
0.56
8.175 234.0 kg/s
90 C
1.916 234.0 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.774 17.1 kg/s
220 C 602
59.3 503.9
139.0 bar 607
45.4 251
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
108.3
Heatsourc-DH 148
28.1 629.5 783
38.4 869.6 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
83
59.3 kg/s
235 C
2
42
45.4 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 38.4 kg/s 17.0 17.43 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 28.1 kg/s 4 100 C 685 30.6 bar 9.5 Preheater-sy NG 93 kr/GJ Methanol 39.7 kr/s 172 kr/GJ 194 kr/GJ 3.86 kr/kg 3.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.0 kg/s 42 606 2 42 0.77 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 410 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 42 45.4 144.0 bar 55.7 431 DH water 0 kr/ton Syngas 2.2 kr/s 167 kr/GJ - kr/GJ 0.91 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.90 248.1 45.4 kg/s 640 139.0 bar 78 11.42 3.6 69.19 Water 32 kr/ton DH water 0.5 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.176 63 C 2 55.7 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
155 0.73
Feed
17.0
3.749
30.6 bar
17.0 kg/s
220 C
Preheater-sy 71.13 170 C
Condenser-1
6.6
631 3.6 kg/s
4 170 C
Preheater-sy
Nomenclature:
Cond-steam-2 1.21 0.78 If methanol and DH share the plant costs
Condenser-1 84.1 13.67 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
19 3.5 bar
2 1.21 705 706
3 3.5 bar
6
SAND 31 51.6 346.2
643 139.0 bar
2 51.6 kg/s
4 139.0 bar
82 4.1 kg/s
142 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 31.6 kr/s 137 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
49 18.5 kg/s 9 3.2 kg/s Condenser 57.46 142 C Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Mass flow
132 C 132 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
59.9 1.0 bar
Reboil-meoh2 10.0
0.01 0.58
0 805 2
DH water
59.9 1.0 bar Mechanical power
10
6.915 19.8 40.63 2.091 59.9 kg/s 0.49 59.9 kg/s 1.2 3.2 6.628
707 3.5 bar Cond-steam-2 90 C 41.48 605 2 50 C 699 3.5 bar 0.25
708 19.7 kg/s SAND 393 Condenser
45.4 139.0 bar 2.4 13.05 Condenser
700 3.2 kg/s
4 132 C 247.9 45.4 kg/s 611 139.0 bar 91.4 13.8 3.9 82.48 2 132 C
Water /
Methanol
Methanol molar-% = 5.16
0 693 694
1 3.5 bar
2 1.2 kg/s
Dis_stage_1
4 5.716 695 696
15 3.5 bar
32 15.4 kg/s
2 31.6
5.754 0.67
5.754 705 706
15 3.5 bar
41 15.4 kg/s
4
38.88 625 635
11 3.5 bar
2
Methanol molar-% = 84.5
60 C
Comp-recirc
Methanol/
4 2.4 kg/s
2.183 60 C
Syngas Split-syngas
621 139.0 bar
631 3.9 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
132 C
Reboil-meoh1
132 C
Reboil-meoh1
234 11.5 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
2 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
3 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 4 2 3Exergy destruction cost flow - based on specific cost of input 3.4 -0 1.9 3.399
4H 8 2 4Exergy destruction cost flow - based on specific cost of output 1 3.4 kg/s Electrolyser 423 1.9 kg/s 8.55 412 2
5EX 5 Component cost flow 2 -15.91 MJ/kg 56.3 MW 201 2 -11.70 MJ/kg 1.9 1.9 kg/s
6 EX_CH * Number of decimals Electrolyser 0.107 -10.00 SAND 56.34 0.07 10.00 97.97 -2.29 MJ/kg
7 EX_PH SAND 301 Electrolyser
NG_reformer
-
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.381 803 4
78.5 78.5 kg/s
Electrolyser
18.62
2.4
3.74
0 802 2
78.5 78.5 kg/s DH water
0.66
Steam reformer
9.22
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.927 0.24 MJ/kg 3.0 0.393 0.4 44.05 0.643 0.21 MJ/kg 1.8 1.339
12 C
13 C/EX
SAND 1E-05 -10.00
Electro-cool
3
4
3.0 kg/s
0.06 MJ/kg
2
4
0.4 kg/s
0.93 MJ/kg
-10.00
Electro-cool
Comp-O2-2
0.6 MW 3
Reformat
5.6 95.09
403
2
1.8 kg/s
0.84 MJ/kg
0.0
0
Ash
0.3 0.252
83 0.3 kg/s
4 -4.31 MJ/kg
14 C/M
O2 0.066 7 4 0.066
0.00
1.2 1.2 kg/s
0.16 0.06 MJ/kg
-
Comp-O2-1
0.066 5 2
1.2 1.2 kg/s
0.16 0.06 MJ/kg
-
Comp-O2-1
DH water
Gas
0.161 -
Electrolyser
0.0 9E-36
6 0.0 kg/s
4 0.06 MJ/kg
18.08 -
Electrolyser
H2 O2 0.095 401 2
1.8 1.8 kg/s
0.233 0.06 MJ/kg
-
SAND 0.604
0.309 402 4
0.01
0.309 1.8 1.8 kg/s
0.799 0.40 MJ/kg
-
431 5.6 kg/s
4 -4.50 MJ/kg
9.22 -
NG_reformer
0.31 -
NG_reformer
0.6 10.73
441 0.6 kg/s
2 -4.50 MJ/kg
1.041 -
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 -
Gasifier
0.0
0.009
1.3
33 2
1.3 kg/s
Steam
32
8.4 10.81
8.4 kg/s
801
2
6.8 0.056
6.8 kg/s
0.21 MJ/kg
0.0 0.016
15 0.0 kg/s
4 -0.57 MJ/kg Heatsink-H2
4E-36 -
Split-O2-2
O2 0.00
Comp-H2
Comp-O2-2
Comp-O2-2
1.6 27.62
432 1.6 kg/s
2 -4.50 MJ/kg
0.8
0.31 0.01 Heatex-O2
SAND 11
1.707 -11.97 MJ/kg Heatex-GG-st 4 -11.97 MJ/kg 0 -10.00 0 - 0.0 MW 322 18.08 0.0 MW 9 Comp-CO2 2.678 -
10.00 SAND 7 0.06 10.00 Heatex-GG-DH
Cleaner SAND 0.0 SAND 6E-05 0.0 MW 7
Heatex-NG
0.43
5
Gasifier
6.6 144.7
Gasifier
5 10 GG2
0.07 0.06
8.9 8.9 kg/s 0.9
131.6 -3.44 MJ/kg
-
5 11 2
8.9 8.9 kg/s
130.9 -3.54 MJ/kg
-
Heatex-GG-st
0.06 0.00 5 12 2 0.00 0.00
10.8 8.9 8.9 kg/s 1.1
124.8 -4.75 MJ/kg
- Heatex-GG-DH
5 13 2
8.9 8.9 kg/s
124.6 -4.88 MJ/kg
-
0.00
Gas cleaner 5.4
8.9 124.5
14 8.9 kg/s
0.00
Heatsink
18.08
18.08 511 2
0.4 0.4 kg/s
44.05 0.93 MJ/kg
-
Heatsink-H2
9.671 503 4
5.2 5.2 kg/s
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.00
0.0 0.0 kg/s 0.0 0.0 kg/s
CO2
8.545 411 2
NG1.9
1.9 kg/s
95.97 -4.34 MJ/kg
-
Heatex-NG
451
Heatex-NG
SAND
3.3 56.74
3.3 kg/s
3.9
13 8.55 0.02
0 434 Water 2
0.1 0.1 kg/s
82 6.6 kg/s Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 -4.88 MJ/kg 88.77 -5.89 MJ/kg 0.007 -8.70 MJ/kg 0.005 -8.95 MJ/kg 2 -4.50 MJ/kg 0.007 -15.52 MJ/kg
2 -2.55 MJ/kg 0.07 9 2 Heatex-GG-O2 8.4 4.755 0 21 4 5.4 - - - - 5.501 - -10.00
3.96 - 1.2 1.2 kg/s SAND 5 31 8.4 kg/s 0.0 0.0 kg/s Cleaner 18.08 512 2 26.82 524 4 14.4 264.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.653 0.78 MJ/kg
-
Gasifier
2 -13.25 MJ/kg
0.043 -10.00
Heatex-GG-st
-0 -15.72 MJ/kg 9.2 168.4
-10.00 521 9.2 kg/s
Heatex-GG-DH 2 -4.65 MJ/kg
0.4
44.05
0.4 kg/s
0.93 MJ/kg
-
9.2 9.2 kg/s
175.7 -4.04 MJ/kg
-
531 14.4 kg/s
2 -4.71 MJ/kg
36.49 -
0.061 422 2
Water 1.9 1.9 kg/s
0.006 -15.83 MJ/kg
7.8 Heatex-H2O
0.07 11.89 SAND 15
0 453 Water 4
Steam
811
6.8 0.237
6.8 kg/s
23.50 -
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.2 22.42
Syngas-cool1
-10.00
Heatex-H2O
0.2 0.2 kg/s
0.013 -15.51 MJ/kg
4 0.38 MJ/kg 0.05
SAND 5.071 571 36.2 kg/s Syngas-cool1 Comp-NG_ref -10.00
0.00 -10.00 25.3 22.7 12.89 6 -13.10 MJ/kg SAND 21 1.3 MW 5 3.1 Heatex-H2O
1.5 25.38 0.6
7.1 9.101 Heatex-GG-DH
9.2 173.1 563 22.7 kg/s 0.19 -10.00 5.8 SAND 1.267 3.1 52.16 1.5 25.38 0.6 10.17
Steam_dryer Biomass (dry)
34 7.1 kg/s 522 9.2 kg/s 2 -13.25 MJ/kg Syngas-cool1 0.19 0.00 452 3.1 kg/s 433 1.5 kg/s 442 0.6 kg/s
0.31
62.1
35 4
62.1 kg/s
SAND 1
0.03 16.9
Steam dryer 3.96
0.31
56.1
34 2
56.1 kg/s
4 -11.97 MJ/kg
0.047 10.00
Split-steam2
2 -4.11 MJ/kg 0.12 -10.00
25.3 - Cooler-GG-H2
Cooler-GG-H2 3.6
0.12 0.00
25.30 523 2
9.2 9.2 kg/s
0.04
26.82
36.2 20.51
561 36.2 kg/s
2 -13.25 MJ/kg
0.186 -10.00
0 541 4
0.0 0.0 kg/s
-0 -15.42 MJ/kg
-10.00
Water
Reformat
9.669 462 2 9.669
5.2 5.2 kg/s
88.77 -5.89 MJ/kg
9.22 461 2
0.01
5.2 5.2 kg/s
87.59 -6.13 MJ/kg
2 -6.21 MJ/kg
5.501 -
Mixer-NG_ref
2 -6.10 MJ/kg
2.678 -
Mixer-NG_ref
2 -5.77 MJ/kg
1.041 -
Mixer-NG_ref
35.17 -13.25 MJ/kg 38.2 -12.95 MJ/kg Cooler-GG-H2 22.7 14.09 171.7 -4.50 MJ/kg Syngas-cool1 14.4 262 Syngas-cool1
- -
-10.00 12.6 145.2 -10.00 SAND 19 571 22.7 kg/s - Comp-GG-H2-2 532 14.4 kg/s
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 12.6 kg/s Steam_dryer
4 -13.10 MJ/kg Comp-GG-H2-2 2 -5.11 MJ/kg
2 -8.96 MJ/kg
3.886 -
Steam
0.12 -10.00
Cooler-GG-H2
4.3 MW
SAND
13
4.28
36.49 -
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.6 2.629
41 4.6 kg/s
2 -13.25 MJ/kg
Steam
0.06
38.57
14.4 267.5
533 14.4 kg/s
4 -4.71 MJ/kg
Syngas 38.57 -
5.9 MW
SAND
15
5.869
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
86
0
0
Total
price
[mio. kr]
111
0
0
C
[kr/s]
0.26
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
96 MW
145 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.024 -10.00 53.5 33.11 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 461 600 1.39
DH-condenser
0.07 10.8 0.42 811 12
DH condenser0.42
78.5 78.5 kg/s
581 53.5 kg/s
2 -13.10 MJ/kg
0.28 -10.00 Steam
0.23 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
4
0
0
6
1
0.00
0.01
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
80%
4.6 0.183 2.743 0.38 MJ/kg DH-cooler DH-cooler
42.5 42.5 kg/s Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 4.6 kg/s -10.00 SAND 25 26.35 -13.10 MJ/kg Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 24 32 0.07
4 -15.57 MJ/kg
0 -10.00
DH-condenser
DH-condenser
430.0 15.02
811 430.0 kg/s
0.010 811 6
50.8 50.8 kg/s
1.776 0.38 MJ/kg
0.01 8.5 0 804 2
DH cooler
DH water
0.01 50.8 50.8 kg/s
0.416 0.21 MJ/kg 1.0 0.639
0.219 562 2
42.5 42.5 kg/s
-10.00
Syngas-cool2 6.8
0.23 0.00
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4
3
0
6
4
0
0.01
0.01
0.00 Energy
Water
2 0.38 MJ/kg
0.49 -10.00
DH
DH water
-10.00
DH-cooler
53.5 30.28
35 53.5 kg/s
6 -13.25 MJ/kg
-10.00
DH-cooler
571 1.0 kg/s
10 -13.05 MJ/kg
0.01 -10.00
Cond-steam-1
24.1 -13.25 MJ/kg
-10.00
Syngas-cool2
13.9 264.9
534 13.9 kg/s
2 -4.77 MJ/kg
0 551 4
0.6 0.6 kg/s
0.049 -15.40 MJ/kg
-10.00
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
96
2
3
6
0
125
2
4
7
0
0.29
0.00
0.01
0.02
0.00
Input:
NG
Biomass
Power*
Total power
92 MW
121 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
11 MW
Energy content in DH water = 72 MW 0.28 -10.00
DH-cooler
Steam
38.57 -
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.023 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
1.0 kg/s
0.04
Comp-syngas2
40.01 4.1 MW 17
SAND 4.068
13.9 268.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
19
2
26
2
25
3
34
0.00
0.06
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 -13.25 MJ/kg 535 13.9 kg/s Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.01 -10.00 2 -4.49 MJ/kg Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.06
Cond-steam-1
40.01 - Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 327 424 0.98 Gas composition at specific nodes (mol-%)
39.74 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
10.3 kg/s
-7.26 MJ/kg 601
59.3 519.3
59.3 kg/s
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.67
4 0.00 2 -7.11 MJ/kg Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
148 38.4 860.6 Steam
0 682 4
82 -
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
270
0
351
0
0.81
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 60.63 42.70 24.36 25.92 27.89 30.00
0.00 0.00 0.12 1.00 1.32 1.40 1.51 1.62
791 38.4 kg/s 17.1 17.1 kg/s Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 29.16 14.45 3.27 3.47 3.74 4.02
792 -7.26 MJ/kg 17.55 2.80 MJ/kg DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 5.24 0.00 5.09 4.47 35.29 46.38 49.35 53.11 57.12
Heatsourc-DH 4 0.00 Cond-steam-1 -10.00 Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 20 0.05 7 H2O-G 5.21 0.00 14.17 5.12 2.13 2.93 1.70 0.62 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.047 811 10 39.2
234.0 234.0 kg/s 0.047 0.00
0 806 2
DH water
234.0 234.0 kg/s
0 683 2
0.1 0.1 kg/s
0.2
0.01 0.00
0 684 4
0.1 0.1 kg/s
Water
0 681 2
17.1 17.1 kg/s
31.8 Meoh-convert
Methanol 0.24 SAND
converter 83
311
Total several DISTILLATION_STAGE's 1423 1826 4.28 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.44
0.06
0.00
3.62 4.77 5.08
0.48 0.63 0.67
0.33 16.33 12.39
5.47
0.73
6.94
5.88
0.78
0.56
8.175 0.38 MJ/kg
-10.00
1.916 0.21 MJ/kg
-10.00
0.115 2.80 MJ/kg
-10.00
0.025 0.94 MJ/kg
-10.00
3.774 0.94 MJ/kg
-10.00 602
59.3 503.9
59.3 kg/s 607
45.4 251
45.4 kg/s Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
108.3
Heatsourc-DH 148
28.1 629.5 783
38.4 869.6 Heatsourc-DH
38.4 kg/s
Cond-steam-1 Cond-steam-1 Convert-cool
2 -7.64 MJ/kg
83 -
2 -7.91 MJ/kg
42 -
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 28.1 kg/s 784 -6.24 MJ/kg 17.0 17.43 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 -7.26 MJ/kg 4 1.00 685 17.0 kg/s 9.5 Preheater-sy NG 93 kr/GJ Methanol 39.7 kr/s 172 kr/GJ 194 kr/GJ 3.86 kr/kg 3.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 0.00 Dis_stage_17 2 2.80 MJ/kg 42 606 2 42 0.14 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 410 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 -10.00 Comp-recirc 42 45.4 45.4 kg/s 55.7 431 DH water 0 kr/ton Syngas 2.2 kr/s 167 kr/GJ - kr/GJ 0.91 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.00 248.1 -8.12 MJ/kg 640 55.7 kg/s 78 11.42 3.6 69.19 Water 32 kr/ton DH water 0.5 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.176 - 2 -7.78 MJ/kg 621 3.6 kg/s CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
155 0.38
Feed
17.0 17.0 kg/s
3.749 0.94 MJ/kg
-10.00
Preheater-sy 71.13 -
Condenser-1
6.6
631 -8.15 MJ/kg
4 -10.00
Preheater-sy
Nomenclature:
Cond-steam-2 1.21 0.10 If methanol and DH share the plant costs
Condenser-1 84.1 13.67 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
19 18.5 kg/s
2 1.21 705 706
3 3.2 kg/s
6
SAND 31 51.6 346.2
643 51.6 kg/s
2 -7.90 MJ/kg
4 4.1 kg/s
82 -7.90 MJ/kg
-10.00
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 31.6 kr/s 137 kr/Gjex Electrical power
Node nr
Mass flow
Transferred heat [MW]
49 -12.63 MJ/kg 9 -12.63 MJ/kg Condenser 57.46 - Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Enthalpy
1.00 1.00 SAND 33 Condenser
Quality
Dis_stage_1 0.01 811 8
59.9 59.9 kg/s
Reboil-meoh2 10.0
0.01 0.00
0 805 2
DH water
59.9 59.9 kg/s Mechanical power
10
6.915 19.8 40.63 2.091 0.38 MJ/kg 0.49 0.21 MJ/kg 1.2 3.2 6.628
707 19.7 kg/s Cond-steam-2 -10.00 41.48 605 2 -10.00 699 3.2 kg/s 0.25
708 -14.69 MJ/kg SAND 393 Condenser
45.4 45.4 kg/s 2.4 13.05 Condenser
700 -14.69 MJ/kg
4 0.00 247.9 -8.12 MJ/kg 611 2.4 kg/s 91.4 13.8 3.9 82.48 2 0.00
Water /
Methanol
Methanol molar-% = 5.16
0 693 694
1 1.2 kg/s
2 -14.69 MJ/kg
Dis_stage_1
4 5.716 695 696
15 15.4 kg/s
32 -14.69 MJ/kg
2 31.6
5.754 0.83
5.754 705 706
15 15.4 kg/s
41 -12.63 MJ/kg
4
38.88 625 635
11 11.5 kg/s
2
Methanol molar-% = 84.5
-
Comp-recirc
Methanol/
4 -8.12 MJ/kg
2.183 -
Syngas Split-syngas
621 3.9 kg/s
631 -7.79 MJ/kg
4 -10.00
Preheater-sy
Reboil-meoh2
Heat
Exergy destruction cost flow - based on specific cost of input [kr/s]
0.19
set-x-2
0.00
Reboil-meoh1
1.00
Reboil-meoh1
234 -7.94 MJ/kg
0.09
meas_flow
Methanol mass flow = 10.4 kg/s
water
NG

0
1 1
1 P
2 M
type NOD*
5 2
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
4 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 6 2 3Exergy destruction cost flow - based on specific cost of input 3.4 -0 1.9 3.399
4H 7 2 4Exergy destruction cost flow - based on specific cost of output 1 0.00 MJ/kg Electrolyser 423 1.80 MJ/kg 8.55 412 2
5EX
6 EX_CH * Number of decimals
5 Component cost flow
Electrolyser
2
0.107
0.00 MJ/kg
0.00 MJ/kg
56.3 MW
SAND
201
56.34
2
0.07
0.00 MJ/kg
1.80 MJ/kg
1.9 51.74 MJ/kg
97.97 50.38 MJ/kg
NG
7 EX_PH SAND 301 Electrolyser
NG_reformer
1.36 MJ/kg
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.381 803 4
78.5 0.01 MJ/kg
Electrolyser
18.62
2.4
4.77
0 802 2
78.5 0.01 MJ/kg DH water
0.74
Steam reformer
9.22
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.927 0.00 MJ/kg 3.0 0.393 0.4 44.05 0.643 0.00 MJ/kg 1.8 1.339
12 C
13 C/EX
SAND 1E-05 0.01 MJ/kg
Electro-cool
3
4
0.13 MJ/kg
0.12 MJ/kg
2 117.2 MJ/kg
4 117.1 MJ/kg
0.01 MJ/kg
Electro-cool
Comp-O2-2
0.6 MW 3
Reformat
5.6 95.09
403
2
0.76 MJ/kg
0.12 MJ/kg
0.0
0
Ash
0.3 0.252
83 0.78 MJ/kg
4 0.00 MJ/kg
14 C/M
O2 0.066 7 4 0.066
0.00
1.2 0.13 MJ/kg
0.16 0.12 MJ/kg
0.01 MJ/kg
Comp-O2-1
0.066 5 2
1.2 0.13 MJ/kg
0.16 0.12 MJ/kg
0.01 MJ/kg
Comp-O2-1
DH water
Gas
0.161 0.01 MJ/kg
Electrolyser
0.0 9E-36
6 0.13 MJ/kg
4 0.12 MJ/kg
18.08 0.12 MJ/kg
Electrolyser
H2 O2 0.095 401 2
1.8 0.13 MJ/kg
0.233 0.12 MJ/kg
0.01 MJ/kg
SAND 0.604
0.309 402 4
0.01
0.309 1.8 0.45 MJ/kg
0.799 0.12 MJ/kg
0.33 MJ/kg
431 17.13 MJ/kg
4 15.32 MJ/kg
9.22 1.81 MJ/kg
NG_reformer
0.31 0.63 MJ/kg
NG_reformer
0.6 10.73
441 17.13 MJ/kg
2 15.32 MJ/kg
1.041 1.81 MJ/kg
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 0.78 MJ/kg
Gasifier 0.009
0.0 1.3
33 2
1.29 MJ/kg
Steam
32
8.4 10.81
1.29 MJ/kg
801
2
6.8 0.056
0.01 MJ/kg
0.00 MJ/kg
0.0 0.016
15 23.83 MJ/kg
4 23.83 MJ/kg Heatsink-H2
4E-36 0.01 MJ/kg
Split-O2-2
O2 0.00
Comp-H2
Comp-O2-2
Comp-O2-2
1.6 27.62
432 17.13 MJ/kg
2 15.32 MJ/kg
0.8
0.31 0.00 Heatex-O2
SAND 11
1.707 0.00 MJ/kg Heatex-GG-st 4 0.00 MJ/kg 0 0.01 MJ/kg 0 0.00 MJ/kg 0.0 MW 322 18.08 0.0 MW 9 Comp-CO2 2.678 1.81 MJ/kg
1.29 MJ/kg SAND 7 0.06 1.29 MJ/kg Heatex-GG-DH
Cleaner SAND 0.0 SAND 6E-05 0.0 MW 7
Heatex-NG
0.64
5
Gasifier
6.6 144.7
Gasifier
5 10 GG2
0.07 0.01
8.9 14.87 MJ/kg 0.9
131.6 14.07 MJ/kg
0.80 MJ/kg
5 11 2
8.9 14.79 MJ/kg
130.9 14.07 MJ/kg
0.73 MJ/kg
Heatex-GG-st
0.06 0.00 5 12 2 0.00 0.00
10.8 8.9 14.10 MJ/kg 1.1
124.8 14.07 MJ/kg
0.03 MJ/kg Heatex-GG-DH
5 13 2
8.9 14.07 MJ/kg
124.6 14.07 MJ/kg
0.01 MJ/kg
0.00
Gas cleaner 5.4
8.9 124.5
14 14.07 MJ/kg
0.00
Heatsink
18.08
18.08 511 2
0.4 117.2 MJ/kg
44.05 117.1 MJ/kg
0.12 MJ/kg
Heatsink-H2
9.671 503 4
5.2 17.10 MJ/kg
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.00
0.0 0.69 MJ/kg 0.0 0.45 MJ/kg
CO2
8.545 411 2
NG1.9
50.68 MJ/kg
95.97 50.38 MJ/kg
0.31 MJ/kg
Heatex-NG
451
Heatex-NG
SAND
3.3 56.74
17.13 MJ/kg
3.9
13 8.55 0.02
0 434 Water 2
0.1 0.05 MJ/kg
82 21.83 MJ/kg Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 14.07 MJ/kg 88.77 16.36 MJ/kg 0.007 0.45 MJ/kg 0.005 0.45 MJ/kg 2 15.32 MJ/kg 0.007 0.00 MJ/kg
2 21.90 MJ/kg 0.07 9 2 Heatex-GG-O2 8.4 4.755 0 21 4 5.4 0.01 MJ/kg 0.74 MJ/kg 0.24 MJ/kg 0.00 MJ/kg 5.501 1.81 MJ/kg 0.05 MJ/kg
3.96 -0.07 MJ/kg 1.2 0.54 MJ/kg SAND 5 31 0.57 MJ/kg 0.0 0.01 MJ/kg Cleaner 18.08 512 2 26.82 524 4 14.4 264.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.653 0.12 MJ/kg
0.41 MJ/kg
Gasifier
2 0.00 MJ/kg
0.043 0.57 MJ/kg
Heatex-GG-st
-0 0.00 MJ/kg 9.2 168.4
0.01 MJ/kg 521 18.25 MJ/kg
Heatex-GG-DH 2 18.24 MJ/kg
0.4 117.2 MJ/kg
44.05 117.1 MJ/kg
0.12 MJ/kg
9.2 19.04 MJ/kg
175.7 18.24 MJ/kg
0.80 MJ/kg
531 18.33 MJ/kg
2 17.56 MJ/kg
36.49 0.77 MJ/kg
0.061 422 2
Water 1.9 0.00 MJ/kg
0.006 0.00 MJ/kg
7.8 Heatex-H2O
0.07 0.02 SAND 15
0 453 Water 4
Steam
811
6.8 0.237
0.03 MJ/kg
23.50 0.01 MJ/kg
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.2 22.42
Syngas-cool1
0.00 MJ/kg
Heatex-H2O
0.2
0.013
0.05 MJ/kg
0.00 MJ/kg
4 0.00 MJ/kg 0.05
SAND 5.071 571 0.62 MJ/kg Syngas-cool1 Comp-NG_ref 0.05 MJ/kg
0.00 0.03 MJ/kg 25.3 22.7 12.89 6 0.00 MJ/kg SAND 21 1.3 MW 5 3.1 Heatex-H2O
1.5 25.38 0.6
7.1 9.101 Heatex-GG-DH
9.2 173.1 563 0.57 MJ/kg 0.19 0.62 MJ/kg 5.8 SAND 1.267 3.1 52.16 1.5 25.38 0.6 10.17
Steam_dryer Biomass (dry)
34 1.29 MJ/kg 522 18.76 MJ/kg 2 0.00 MJ/kg Syngas-cool1 0.19 0.00 452 16.93 MJ/kg 433 17.20 MJ/kg 442 16.24 MJ/kg
0.31
62.1
35 4
0.57 MJ/kg
SAND 1
0.03 16.9
Steam dryer 3.96
0.31
56.1
34 2
0.68 MJ/kg
4 0.00 MJ/kg
0.047 1.29 MJ/kg
Split-steam2
2 18.24 MJ/kg 0.12 0.57 MJ/kg
25.3 0.52 MJ/kg Cooler-GG-H2
Cooler-GG-H2 3.6 25.30 523 2
0.12 0.00 9.2 18.61 MJ/kg
0.04
26.82
561
2
0.186
36.2 20.51
0.57 MJ/kg
0.00 MJ/kg
0.57 MJ/kg
0 541 4
0.0 0.08 MJ/kg
-0 0.00 MJ/kg
0.08 MJ/kg
Water
Reformat
9.669 462 2 9.669
5.2 17.13 MJ/kg
88.77 16.39 MJ/kg
9.22 461 2
0.01
5.2 16.90 MJ/kg
87.59 16.39 MJ/kg
2 16.45 MJ/kg
5.501 0.48 MJ/kg
Mixer-NG_ref
2 16.72 MJ/kg
2.678 0.48 MJ/kg
Mixer-NG_ref
2 15.32 MJ/kg
1.041 0.92 MJ/kg
Mixer-NG_ref
35.17 0.00 MJ/kg 38.2 0.00 MJ/kg Cooler-GG-H2 22.7 14.09 171.7 18.24 MJ/kg Syngas-cool1 14.4 262 Syngas-cool1
0.74 MJ/kg 0.51 MJ/kg
0.57 MJ/kg 12.6 145.2 0.68 MJ/kg SAND 19 571 0.62 MJ/kg 0.36 MJ/kg Comp-GG-H2-2 532 18.17 MJ/kg
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 11.53 MJ/kg Steam_dryer
4 0.00 MJ/kg Comp-GG-H2-2 2 17.56 MJ/kg
2 11.53 MJ/kg
3.886 0.00 MJ/kg
Steam
0.12 0.62 MJ/kg
Cooler-GG-H2
4.3 MW
SAND
13
4.28
36.49 0.61 MJ/kg
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.6 2.629
41 0.57 MJ/kg
2 0.00 MJ/kg
Steam
0.06
38.57
14.4 267.5
533 18.55 MJ/kg
4 17.56 MJ/kg
Syngas 38.57 0.99 MJ/kg
5.9 MW
SAND
15
5.869
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
86
0
0
Total
price
[mio. kr]
111
0
0
C
[kr/s]
0.26
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
96 MW
145 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.024 0.57 MJ/kg 53.5 33.11 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 461 600 1.39
DH-condenser
0.09 10.8 0.42 811 12
DH condenser0.42
78.5 0.03 MJ/kg
581
2
0.28
0.62 MJ/kg
0.00 MJ/kg
0.62 MJ/kg Steam
0.23 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
4
0
0
6
1
0.00
0.01
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
80%
4.6 0.183 2.743 0.00 MJ/kg DH-cooler DH-cooler
42.5 0.62 MJ/kg Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 0.04 MJ/kg 0.03 MJ/kg SAND 25 26.35 0.00 MJ/kg Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 24 32 0.07
4 0.00 MJ/kg
0 0.04 MJ/kg
DH-condenser
DH-condenser
430.0 15.02
811 0.03 MJ/kg
0.010 811 6
50.8 0.03 MJ/kg
1.776 0.00 MJ/kg
0.01 8.5 0 804 2
DH cooler
DH water
0.01 50.8 0.01 MJ/kg
0.416 0.00 MJ/kg 1.0 0.639
0.219 562 2
42.5 0.57 MJ/kg
0.62 MJ/kg
Syngas-cool2 6.8
0.23 0.00
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4
3
0
6
4
0
0.01
0.01
0.00 Energy
Water
2 0.00 MJ/kg
0.49 0.03 MJ/kg
DH
DH water
0.03 MJ/kg
DH-cooler
35
6
53.5 30.28
0.57 MJ/kg
0.00 MJ/kg
0.01 MJ/kg
DH-cooler
571 0.64 MJ/kg
10 0.00 MJ/kg
0.01 0.64 MJ/kg
Cond-steam-1
24.1 0.00 MJ/kg
0.57 MJ/kg
Syngas-cool2
13.9 264.9
534 19.10 MJ/kg
2 18.25 MJ/kg
0 551 4
0.6 0.09 MJ/kg
0.049 0.00 MJ/kg
0.09 MJ/kg
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
96
2
3
6
0
125
2
4
7
0
0.29
0.00
0.01
0.02
0.00
Input:
NG
Biomass
Power*
Total power
92 MW
121 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
11 MW
Energy content in DH water = 72 MW 0.28 0.57 MJ/kg
DH-cooler
Steam
38.57 0.85 MJ/kg
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.023 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
0.57 MJ/kg
0.04
Comp-syngas2
40.01 4.1 MW 17
SAND 4.068
13.9 268.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
19
2
26
2
25
3
34
0.00
0.06
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 0.00 MJ/kg 535 19.37 MJ/kg Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.01 0.57 MJ/kg 2 18.25 MJ/kg Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.06
Cond-steam-1
40.01 1.12 MJ/kg Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 327 424 0.98 Gas composition at specific nodes (mol-%)
39.74 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
22.44 MJ/kg
22.41 MJ/kg 601
59.3 519.3
8.76 MJ/kg
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.67
4 0.03 MJ/kg 2 8.13 MJ/kg Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
148 38.4 860.6 Steam
0 682 4
82 0.63 MJ/kg
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
270
0
351
0
0.81
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 60.63 42.70 24.36 25.92 27.89 30.00
0.00 0.00 0.12 1.00 1.32 1.40 1.51 1.62
791 22.44 MJ/kg 17.1 1.02 MJ/kg Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 29.16 14.45 3.27 3.47 3.74 4.02
792 22.41 MJ/kg 17.55 0.00 MJ/kg DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 5.24 0.00 5.09 4.47 35.29 46.38 49.35 53.11 57.12
Heatsourc-DH 4 0.03 MJ/kg Cond-steam-1 1.02 MJ/kg Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 20 0.05 7 H2O-G 5.21 0.00 14.17 5.12 2.13 2.93 1.70 0.62 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.047 811 10 39.2
234.0 0.03 MJ/kg 0.047 0.02
0 806 2
DH water
234.0 0.01 MJ/kg
0 683 2
0.1 1.02 MJ/kg
0.2
0.01 0.00
0 684 4
0.1 0.22 MJ/kg
Water
0 681 2
17.1 0.22 MJ/kg
31.8 Meoh-convert
Methanol 0.25 SAND
converter 83
311
Total several DISTILLATION_STAGE's 1423 1826 4.28 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.44
0.06
0.00
3.62 4.77 5.08
0.48 0.63 0.67
0.33 16.33 12.39
5.47
0.73
6.94
5.88
0.78
0.56
8.175 0.00 MJ/kg
0.03 MJ/kg
1.916 0.00 MJ/kg
0.01 MJ/kg
0.115 0.00 MJ/kg
1.02 MJ/kg
0.025 0.00 MJ/kg
0.22 MJ/kg
3.774 0.00 MJ/kg
0.22 MJ/kg 602
59.3 503.9
8.50 MJ/kg 607
45.4 251
5.53 MJ/kg Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
108.3
Heatsourc-DH 148 38.4 869.6 Heatsourc-DH
28.1 629.5 783 22.67 MJ/kg
Cond-steam-1 Cond-steam-1 Convert-cool
2
83
8.02 MJ/kg
0.49 MJ/kg
2
42
5.05 MJ/kg
0.48 MJ/kg
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 22.44 MJ/kg 784 22.41 MJ/kg 17.0 17.43 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 22.41 MJ/kg 4 0.26 MJ/kg 685 1.02 MJ/kg 9.5 Preheater-sy NG 93 kr/GJ Methanol 39.7 kr/s 172 kr/GJ 194 kr/GJ 3.86 kr/kg 3.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 0.03 MJ/kg Dis_stage_17 2 0.00 MJ/kg 42 606 2 42 0.14 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 410 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 1.02 MJ/kg Comp-recirc 42 45.4 5.47 MJ/kg 55.7 431 DH water 0 kr/ton Syngas 2.2 kr/s 167 kr/GJ - kr/GJ 0.91 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.00 248.1 5.05 MJ/kg 640 7.74 MJ/kg 78 11.42 3.6 69.19 Water 32 kr/ton DH water 0.5 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.176 0.42 MJ/kg 2 7.29 MJ/kg 621 19.44 MJ/kg CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
155 0.39
Feed
17.0
3.749
0.22 MJ/kg
0.00 MJ/kg
0.22 MJ/kg
Preheater-sy 71.13 0.45 MJ/kg
Condenser-1
6.6
631 19.31 MJ/kg
4 0.12 MJ/kg
Preheater-sy
Nomenclature:
Cond-steam-2 1.21 0.08 If methanol and DH share the plant costs
Condenser-1 84.1 13.67 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
19 2.65 MJ/kg
2 1.21 705 706
3 2.65 MJ/kg
6
SAND 31
643
2
51.6 346.2
6.70 MJ/kg
6.27 MJ/kg
4 20.34 MJ/kg
82 20.25 MJ/kg
0.08 MJ/kg
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 31.6 kr/s 137 kr/Gjex Electrical power
Node nr
Total exergy
Transferred heat [MW]
49 1.98 MJ/kg 9 1.98 MJ/kg Condenser 57.46 0.44 MJ/kg Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Chemical exergy
0.67 MJ/kg 0.67 MJ/kg SAND 33 Condenser
Physical exergy
Dis_stage_1 0.01 811 8
59.9 0.03 MJ/kg
Reboil-meoh2 10.0
0.01 0.01
0 805 2
DH water
59.9 0.01 MJ/kg Mechanical power
10
6.915 19.8 40.63 2.091 0.00 MJ/kg 0.49 0.00 MJ/kg 1.2 3.2 6.628
707 2.06 MJ/kg Cond-steam-2 0.03 MJ/kg 41.48 605 2 0.01 MJ/kg 699 2.06 MJ/kg 0.25
708 1.98 MJ/kg SAND 393 Condenser
45.4 5.46 MJ/kg 2.4 13.05 Condenser
700 1.98 MJ/kg
4 0.08 MJ/kg 247.9 5.05 MJ/kg 611 5.46 MJ/kg 91.4 13.8 3.9 82.48 2 0.08 MJ/kg
Water /
Methanol
Methanol molar-% = 5.16
0 693 694
1 2.05 MJ/kg
2 1.98 MJ/kg
Dis_stage_1
4 5.716 695 696
15 2.06 MJ/kg
32 1.98 MJ/kg
2 31.6
5.754 0.65
5.754 705 706
15 2.65 MJ/kg
41 1.98 MJ/kg
4
38.88 625 635
11 20.36 MJ/kg
2
Methanol molar-% = 84.5
0.41 MJ/kg
Comp-recirc
Methanol/
4 5.05 MJ/kg
2.183 0.41 MJ/kg
Syngas Split-syngas
621 21.31 MJ/kg
631 21.29 MJ/kg
4 0.03 MJ/kg
Preheater-sy
Reboil-meoh2
Heat
Exergy destruction cost flow - based on specific cost of output [kr/s]
0.07 MJ/kg
set-x-2
0.08 MJ/kg
Reboil-meoh1
0.67 MJ/kg
Reboil-meoh1
234 20.31 MJ/kg
0.05 MJ/kg
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
9 2
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
2 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 10 2 3Exergy destruction cost flow - based on specific cost of input 3.4 -0 1.9 3.399
4H 11 2 4Exergy destruction cost flow - based on specific cost of output 1 0.00 MW Electrolyser 423 3.40 MW 8.55 412 2
5EX
6 EX_CH * Number of decimals
5 Component cost flow
Electrolyser
2
0.107
0.00 MW
0.00 MW
56.3 MW
SAND
201
56.34
2
0.07
0.00 MW
3.40 MW
1.9 97.97 MW
97.97 95.39 MW
NG
7 EX_PH SAND 301 Electrolyser
NG_reformer
2.58 MW
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.381 803 4
78.5 0.93 MW
Electrolyser
18.62
2.4
11.61
0 802 2
78.5 0.64 MW DH water
7.62
Steam reformer
9.22
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.927 0.00 MW 3.0 0.393 0.4 44.05 0.643 0.00 MW 1.8 1.339
12 C
13 C/EX
SAND 1E-05 0.93 MW
Electro-cool
3
4
0.39 MW
0.37 MW
2 44.05 MW
4 44.00 MW
0.64 MW
Electro-cool
Comp-O2-2
0.6 MW 3
Reformat
5.6 95.09
403
2
1.34 MW
0.22 MW
0.0
0
Ash
0.3 0.252
83 0.25 MW
4 0.00 MW
14 C/M
O2 0.066 7 4 0.066
0.00
1.2 0.16 MW
0.16 0.15 MW
0.01 MW
Comp-O2-1
0.066 5 2
1.2 0.16 MW
0.16 0.15 MW
0.01 MW
Comp-O2-1
DH water
Gas
0.161 0.02 MW
Electrolyser
0.0 9E-36
6 0.00 MW
4 0.00 MW
18.08 0.05 MW
Electrolyser
H2 O2 0.095 401 2
1.8 0.23 MW
0.233 0.22 MW
0.01 MW
SAND 0.604
0.309 402 4
0.04
0.309 1.8 0.80 MW
0.799 0.22 MW
0.58 MW
431 95.09 MW
4 85.06 MW
9.22 10.03 MW
NG_reformer
0.31 1.12 MW
NG_reformer
0.6 10.73
441 10.73 MW
2 9.60 MW
1.041 1.13 MW
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 0.25 MW
Gasifier
0.0
0.009
1.3
33 2
1.71 MW
Steam
32
8.4 10.81
10.81 MW
801
2
6.8 0.056
0.06 MW
0.00 MW
15
4
0.0 0.016
0.02 MW
0.02 MW Heatsink-H2
4E-36 0.00 MW
Split-O2-2
O2 0.00
Comp-H2
Comp-O2-2
Comp-O2-2
1.6 27.62
432 27.62 MW
2 24.71 MW
0.8
0.31 0.02 Heatex-O2
SAND 11
1.707 0.00 MW Heatex-GG-st 4 0.00 MW 0 0.06 MW 0 0.00 MW 0.0 MW 322 18.08 0.0 MW 9 Comp-CO2 2.678 2.91 MW
1.71 MW SAND 7 0.06 10.81 MW Heatex-GG-DH
Cleaner SAND 0.0 SAND 6E-05 0.0 MW 7
Heatex-NG
15.53
5
Gasifier
6.6 144.7
Gasifier
5 10 GG2
0.07 0.14
8.9 131.5 MW 0.9
131.6 124.5 MW
7.08 MW
5 11 2
8.9 130.9 MW
130.9 124.5 MW
6.44 MW
Heatex-GG-st
0.06 0.09 5 12 2 0.00 0.06
10.8 8.9 124.8 MW 1.1
124.8 124.5 MW
0.30 MW Heatex-GG-DH
5 13 2
8.9 124.5 MW
124.6 124.5 MW
0.05 MW
0.00
Gas cleaner 5.4
8.9 124.5
14 124.5 MW
0.00
Heatsink
18.08
18.08 511 2
0.4 44.05 MW
44.05 44.00 MW
0.05 MW
Heatsink-H2
9.671 503 4
5.2 88.77 MW
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.00
0.0 0.01 MW 0.0 0.00 MW
CO2
8.545 411 2
NG1.9
95.97 MW
95.97 95.39 MW
0.58 MW
Heatex-NG
451
Heatex-NG
SAND
3.3 56.74
56.74 MW
3.9
13 8.55 0.24
0 434 Water 2
0.1 0.01 MW
82 144.7 MW Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 124.4 MW 88.77 84.95 MW 0.007 0.00 MW 0.005 0.00 MW 2 50.75 MW 0.007 0.00 MW
2 145.2 MW 0.07 9 2 Heatex-GG-O2 8.4 4.755 0 21 4 5.4 0.05 MW 3.82 MW 0.00 MW 0.00 MW 5.501 5.99 MW 0.01 MW
3.96 -0.45 MW 1.2 0.65 MW SAND 5 31 4.75 MW 0.0 0.00 MW Cleaner 18.08 512 2 26.82 524 4 14.4 264.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.653 0.15 MW
0.50 MW
Gasifier
2 0.00 MW
0.043 4.75 MW
Heatex-GG-st
-0 0.00 MW 9.2 168.4
0.00 MW 521 168.4 MW
Heatex-GG-DH 2 168.3 MW
0.4 44.05 MW
44.05 44.00 MW
0.05 MW
9.2 175.6 MW
175.7 168.3 MW
7.34 MW
531 264.3 MW
2 253.2 MW
36.49 11.14 MW
0.061 422 2
Water 1.9 0.01 MW
0.006 0.00 MW
7.8 Heatex-H2O
0.07 1.17 SAND 15
0 453 Water 4
Steam
811
6.8 0.237
0.24 MW
23.50 0.09 MW
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.2 22.42
Syngas-cool1
0.01 MW
Heatex-H2O
0.2
0.013
0.01 MW
0.00 MW
4 0.00 MW 0.36
SAND 5.071 571 22.42 MW Syngas-cool1 Comp-NG_ref 0.01 MW
0.00 0.24 MW 25.3 22.7 12.89 6 0.00 MW SAND 21 1.3 MW 5 3.1 Heatex-H2O
1.5 25.38 0.6
7.1 9.101 Heatex-GG-DH
9.2 173.1 563 12.89 MW 0.19 22.42 MW 5.8 SAND 1.267 3.1 52.16 1.5 25.38 0.6 10.17
Steam_dryer Biomass (dry)
34 9.10 MW 522 173.1 MW 2 0.00 MW Syngas-cool1 0.19 0.39 452 52.16 MW 433 25.38 MW 442 10.17 MW
0.31 35 4
62.1 35.17 MW
SAND 1
3.48 16.9
Steam dryer 3.96
0.31 34 2
56.1 38.20 MW
4 0.00 MW
0.047 9.10 MW
Split-steam2
2 168.3 MW
25.3 4.80 MW
Cooler-GG-H2
0.12 12.89 MW
Cooler-GG-H2
3.6
0.12 0.25
25.30 523 2
9.2 171.6 MW
0.29
26.82
36.2 20.51
561 20.51 MW
2 0.00 MW
0.186 20.51 MW
0 541 4
0.0 0.00 MW
-0 0.00 MW
0.00 MW
Water
Reformat
9.669 462 2 9.669
5.2 88.77 MW
88.77 84.95 MW
9.22 461 2
0.09
5.2 87.59 MW
87.59 84.95 MW
2 50.68 MW
5.501 1.47 MW
Mixer-NG_ref
2 24.67 MW
2.678 0.71 MW
Mixer-NG_ref
2 9.60 MW
1.041 0.57 MW
Mixer-NG_ref
35.17 0.00 MW 38.2 0.00 MW Cooler-GG-H2 22.7 14.09 171.7 168.3 MW Syngas-cool1 14.4 262 Syngas-cool1
3.82 MW 2.64 MW
35.17 MW 12.6 145.2 38.20 MW SAND 19 571 14.09 MW 3.36 MW Comp-GG-H2-2 532 262.0 MW
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 145.2 MW Steam_dryer
4 0.00 MW Comp-GG-H2-2 2 253.2 MW
2 145.2 MW
3.886 0.00 MW
Steam
0.12 14.09 MW
Cooler-GG-H2
4.3 MW
SAND
13
4.28
36.49 8.84 MW
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.6 2.629
41 2.63 MW
2 0.00 MW
Steam
0.41
38.57
14.4 267.5
533 267.4 MW
4 253.2 MW
Syngas 38.57 14.29 MW
5.9 MW
SAND
15
5.869
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
86
0
0
Total
price
[mio. kr]
111
0
0
C
[kr/s]
0.26
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
96 MW
145 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.024 2.63 MW 53.5 33.11 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 461 600 1.39
DH-condenser
0.63 10.8 0.42 811 12
DH condenser0.42
78.5 2.74 MW
581 33.11 MW
2 0.00 MW
0.28 33.11 MW Steam
0.23 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
4
0
0
6
1
0.00
0.01
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
80%
4.6 0.183 2.743 0.00 MW DH-cooler DH-cooler
42.5 26.35 MW Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 0.18 MW 2.74 MW SAND 25 26.35 0.00 MW Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 24 32 0.07
4 0.00 MW
0 0.18 MW
DH-condenser
DH-condenser
430.0 15.02
811 15.02 MW
0.010 811 6
50.8 1.78 MW
1.776 0.00 MW
1.47 8.5 0 804 2
DH cooler
DH water
0.01 50.8 0.42 MW
0.416 0.00 MW 1.0 0.639
0.219 562 2
42.5 24.10 MW
26.35 MW
Syngas-cool2 6.8
0.23 0.35
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4
3
0
6
4
0
0.01
0.01
0.00 Energy
Water
2 0.00 MW
0.49 15.02 MW
DH
DH water
1.78 MW
DH-cooler
53.5 30.28
35 30.28 MW
6 0.00 MW
0.42 MW
DH-cooler
571 0.64 MW
10 0.00 MW
0.01 0.64 MW
Cond-steam-1
24.1 0.00 MW
24.10 MW
Syngas-cool2
13.9 264.9
534 264.8 MW
2 253.1 MW
0 551 4
0.6 0.05 MW
0.049 0.00 MW
0.05 MW
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
96
2
3
6
0
125
2
4
7
0
0.29
0.00
0.01
0.02
0.00
Input:
NG
Biomass
Power*
Total power
92 MW
121 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
11 MW
Energy content in DH water = 72 MW 0.28 30.28 MW
DH-cooler
Steam
38.57 11.72 MW
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.023 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
0.57 MW
0.30
Comp-syngas2
40.01 4.1 MW 17
SAND 4.068
13.9 268.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
19
2
26
2
25
3
34
0.00
0.06
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 0.00 MW 535 268.6 MW Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.01 0.57 MW 2 253.1 MW Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.06
Cond-steam-1
40.01 15.49 MW Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 327 424 0.98 Gas composition at specific nodes (mol-%)
39.74 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
231.1 MW
230.8 MW 601
59.3 519.3
519.2 MW
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.67
4 0.31 MW 2 481.9 MW Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
148 38.4 860.6 Steam
0 682 4
82 37.34 MW
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
270
0
351
0
0.81
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 60.63 42.70 24.36 25.92 27.89 30.00
0.00 0.00 0.12 1.00 1.32 1.40 1.51 1.62
791 860.6 MW 17.1 17.55 MW Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 29.16 14.45 3.27 3.47 3.74 4.02
792 859.4 MW 17.55 0.00 MW DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 5.24 0.00 5.09 4.47 35.29 46.38 49.35 53.11 57.12
Heatsourc-DH 4 1.15 MW Cond-steam-1 17.55 MW Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 20 0.05 7 H2O-G 5.21 0.00 14.17 5.12 2.13 2.93 1.70 0.62 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.047 811 10 39.2
234.0 8.18 MW 0.047 2.68
0 806 2
DH water
234.0 1.92 MW
0 683 2
0.1 0.11 MW
0.2
0.01 0.02
0 684 4
0.1 0.02 MW
Water
0 681 2
17.1 3.77 MW
31.8 Meoh-convert
Methanol 1.56 SAND
converter 83
311
Total several DISTILLATION_STAGE's 1423 1826 4.28 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.44
0.06
0.00
3.62 4.77 5.08
0.48 0.63 0.67
0.33 16.33 12.39
5.47
0.73
6.94
5.88
0.78
0.56
8.175 0.00 MW
8.18 MW
1.916 0.00 MW
1.92 MW
0.115 0.00 MW
0.11 MW
0.025 0.00 MW
0.02 MW
3.774 0.00 MW
3.77 MW 602
59.3 503.9
503.9 MW 607
45.4 251
250.9 MW Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
108.3
Heatsourc-DH 148 38.4 869.6 Heatsourc-DH
28.1 629.5 783 869.5 MW
Cond-steam-1 Cond-steam-1 Convert-cool
2 475.1 MW
83 28.81 MW
2 229.1 MW
42 21.87 MW
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 629.5 MW 784 859.4 MW 17.0 17.43 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 628.6 MW 4 10.09 MW 685 17.43 MW 9.5 Preheater-sy NG 93 kr/GJ Methanol 39.7 kr/s 172 kr/GJ 194 kr/GJ 3.86 kr/kg 3.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 0.84 MW Dis_stage_17 2 0.00 MW 42 606 2 42 0.87 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 410 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 17.43 MW Comp-recirc 42 45.4 248.0 MW 55.7 431 DH water 0 kr/ton Syngas 2.2 kr/s 167 kr/GJ - kr/GJ 0.91 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.02 248.1 229.1 MW 640 431.0 MW 78 11.42 3.6 69.19 Water 32 kr/ton DH water 0.5 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.176 18.99 MW 2 406.0 MW 621 69.19 MW CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
155 2.31
Feed
17.0
3.749
3.75 MW
0.00 MW
3.75 MW
Preheater-sy 71.13 24.99 MW
Condenser-1
6.6
631 68.76 MW
4 0.43 MW
Preheater-sy
Nomenclature:
Cond-steam-2 1.21 0.53 If methanol and DH share the plant costs
Condenser-1 84.1 13.67 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
19 49.25 MW
2 1.21 705 706
3 8.54 MW
6
SAND 31 51.6 346.2
643 346.2 MW
2 323.6 MW
4 82.34 MW
82 81.99 MW
0.35 MW
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 31.6 kr/s 137 kr/Gjex Electrical power
Node nr
Total exergy flow
Transferred heat [MW]
49 36.77 MW 9 6.38 MW Condenser 57.46 22.55 MW Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Chemical exergy flow
12.48 MW 2.16 MW SAND 33 Condenser
Physical exergy flow
Dis_stage_1 0.01 811 8
59.9 2.09 MW
Reboil-meoh2 10.0
0.01 1.17
0 805 2
DH water
59.9 0.49 MW Mechanical power
10
6.915 19.8 40.63 2.091 0.00 MW 0.49 0.00 MW 1.2 3.2 6.628
707 40.63 MW Cond-steam-2 2.09 MW 41.48 605 2 0.49 MW 699 6.63 MW 0.25
708 39.11 MW SAND 393 Condenser
45.4 247.9 MW 2.4 13.05 Condenser
700 6.38 MW
4 1.52 MW 247.9 229.1 MW 611 13.05 MW 91.4 13.8 3.9 82.48 2 0.25 MW
Water /
Methanol
Methanol molar-% = 5.16
0 693 694
1 2.42 MW
2 2.33 MW
Dis_stage_1
4 5.716 695 696
15 31.58 MW
32 30.39 MW
2 31.6
5.754 4.56
5.754 705 706
15 40.71 MW
41 30.39 MW
4
38.88 625 635
11 233.7 MW
2
Methanol molar-% = 84.5
18.83 MW
Comp-recirc
Methanol/
4 12.06 MW
2.183 0.99 MW
Syngas Split-syngas
621 82.48 MW
631 82.38 MW
4 0.10 MW
Preheater-sy
Reboil-meoh2
Heat
0.08 MW
set-x-2
1.19 MW
Reboil-meoh1
10.31 MW
Reboil-meoh1
234 233.1 MW
0.62 MW
meas_flow
Methanol mass flow = 10.4 kg/s
water
Exergy destruction [MW]

0
1 1
1 P
2 M
type NOD*
12 2
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
5 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 13 2 3Exergy destruction cost flow - based on specific cost of input 3.4 -0 1.9 3.399
4H 14 2 4Exergy destruction cost flow - based on specific cost of output 1 0.11 kr/s Electrolyser 423 0.07 kr/s 8.55 412 2
5EX
6 EX_CH * Number of decimals
5 Component cost flow
Electrolyser
2
0.107
- kr/MJ
0.03 kr/kg
56.3 MW
SAND
201
56.34
2
0.07
0.02 kr/MJ
0.04 kr/kg
1.9
97.97
8.55 kr/s
0.09 kr/MJ
NG
7 EX_PH SAND 301 Electrolyser
NG_reformer
4.52 kr/kg
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.381 803 4
78.5 0.38 kr/s
Electrolyser
18.62
2.4
0.26
0 802 2
78.5 0.00 kr/s DH water
0.29
Steam reformer
9.22
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.927 0.41 kr/MJ 3.0 0.393 0.4 44.05 0.643 0.00 kr/MJ 1.8 1.339
12 C
13 C/EX
SAND 1E-05 0.00 kr/kg
Electro-cool
3
4
0.16 kr/s
0.41 kr/MJ
2 18.08 kr/s
4 0.41 kr/MJ
0.00 kr/kg
Electro-cool
Comp-O2-2
0.6 MW 3
Reformat
5.6 95.09
403
2
0.31 kr/s
0.23 kr/MJ
0.0
0
Ash
0.3 0.252
83 0.00 kr/s
4 0.00 kr/MJ
14 C/M
O2 0.066 7 4 0.066
0.00
1.2 0.07 kr/s
0.16 0.41 kr/MJ
0.05 kr/kg
Comp-O2-1
0.066 5 2
1.2 0.07 kr/s
0.16 0.41 kr/MJ
0.05 kr/kg
Comp-O2-1
DH water
Gas
0.161 0.05 kr/kg
Electrolyser
0.0 9E-36
6 0.00 kr/s
4 0.41 kr/MJ
18.08 48.11 kr/kg
Electrolyser
H2 O2 0.095 401 2
1.8 0.10 kr/s
0.233 0.41 kr/MJ
0.05 kr/kg
SAND 0.604
0.309 402 4
0.01
0.309 1.8 0.31 kr/s
0.799 0.39 kr/MJ
0.18 kr/kg
431 9.22 kr/s
4 0.10 kr/MJ
9.22 1.66 kr/kg
NG_reformer
0.31 0.18 kr/kg
NG_reformer
0.6 10.73
441 1.04 kr/s
2 0.10 kr/MJ
1.041 1.66 kr/kg
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 0.00 kr/kg
Gasifier
0.0
0.009
1.3
33 2
0.01 kr/s
Steam
32
8.4 10.81
0.06 kr/s
801
2
6.8 0.056
0.00 kr/s
0.00 kr/MJ
15
4
0.0 0.016
0.00 kr/s
0.00 kr/MJ Heatsink-H2
4E-36 0.05 kr/kg
Split-O2-2
O2 0.00
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
1.6 27.62
2.68 kr/s
0.10 kr/MJ
0.8
0.31 0.00 Heatex-O2
SAND 11
1.707 0.01 kr/MJ Heatex-GG-st 4 0.01 kr/MJ 0 0.00 kr/kg 0 0.00 kr/kg 0.0 MW 322 18.08 0.0 MW 9 Comp-CO2 2.678 1.66 kr/kg
0.01 kr/kg SAND 7 0.06 0.01 kr/kg Heatex-GG-DH
Cleaner SAND 0.0 SAND 6E-05 0.0 MW 7
Heatex-NG
1.39
5
Gasifier
6.6 144.7
5
8.9
131.6
Gasifier
10 GG2
0.07 0.00
5.42 kr/s 0.9
0.04 kr/MJ
0.61 kr/kg
5
8.9
130.9
11 2
5.42 kr/s
0.04 kr/MJ
0.61 kr/kg
Heatex-GG-st
0.06 0.01 5
10.8 8.9
124.8
12 2 0.00 0.00
5.42 kr/s 1.1
0.04 kr/MJ
0.61 kr/kg Heatex-GG-DH
5
8.9
124.6
13 2
5.42 kr/s
0.04 kr/MJ
0.61 kr/kg
0.00
Gas cleaner 5.4
8.9 124.5
14 5.42 kr/s
0.00
Heatsink
18.08
18.08 511 2
0.4 18.08 kr/s
44.05 0.41 kr/MJ
48.11 kr/kg
Heatsink-H2
9.671 503 4
5.2 9.67 kr/s
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.00
0.0 0.00 kr/s 0.0 0.00 kr/s
CO2
8.545 411 2
NG1.9
8.55 kr/s
95.97 0.09 kr/MJ
4.51 kr/kg
Heatex-NG
451
Heatex-NG
SAND
3.3 56.74
5.50 kr/s
3.9
13 8.55 0.00
0 434 Water 2
0.1 0.00 kr/s
82 3.96 kr/s Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 0.04 kr/MJ 88.77 0.11 kr/MJ 0.007 0.30 kr/MJ 0.005 0.25 kr/MJ 2 0.10 kr/MJ 0.007 0.00 kr/MJ
2 0.03 kr/MJ 0.07 9 2 Heatex-GG-O2 8.4 4.755 0 21 4 5.4 0.61 kr/kg 1.86 kr/kg 0.20 kr/kg 0.11 kr/kg 5.501 1.66 kr/kg 0.00 kr/kg
3.96 0.60 kr/kg 1.2 0.07 kr/s SAND 5 31 0.04 kr/s 0.0 0.00 kr/s Cleaner 18.08 512 2 26.82 524 4 14.4 264.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.653 0.10 kr/MJ
0.05 kr/kg
Gasifier
2 0.01 kr/MJ
0.043 0.01 kr/kg
Heatex-GG-st
-0 0.00 kr/MJ 9.2 168.4
0.00 kr/kg 521 23.50 kr/s
Heatex-GG-DH 2 0.14 kr/MJ
0.4 18.08 kr/s
44.05 0.41 kr/MJ
48.11 kr/kg
9.2 26.82 kr/s
175.7 0.15 kr/MJ
2.91 kr/kg
531 36.49 kr/s
2 0.14 kr/MJ
36.49 2.53 kr/kg
0.061 422 2
Water 1.9 0.06 kr/s
0.006 10.14 kr/MJ
7.8 Heatex-H2O
0.07 0.01 SAND 15
0 453 Water 4
Steam
811
6.8 0.237
0.00 kr/s
23.50 2.55 kr/kg
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.2 22.42
Syngas-cool1
0.03 kr/kg
Heatex-H2O
0.2
0.013
0.00 kr/s
0.00 kr/MJ
4 0.01 kr/MJ 0.07
SAND 5.071 571 0.19 kr/s Syngas-cool1 Comp-NG_ref 0.00 kr/kg
0.00 0.00 kr/kg 25.3 22.7 12.89 6 0.01 kr/MJ SAND 21 1.3 MW 5 3.1 Heatex-H2O
1.5 25.38 0.6
7.1 9.101 Heatex-GG-DH
9.2 173.1 563 0.12 kr/s 0.19 0.01 kr/kg 5.8 SAND 1.267 3.1 52.16 1.5 25.38 0.6 10.17
Steam_dryer Biomass (dry)
34 0.05 kr/s 522 25.30 kr/s 2 0.01 kr/MJ Syngas-cool1 0.19 0.01 452 5.50 kr/s 433 2.68 kr/s 442 1.04 kr/s
0.31
62.1
35 4
0.31 kr/s
SAND 1
0.07 16.9
Steam dryer 3.96
0.31
56.1
34 2
0.31 kr/s
4 0.01 kr/MJ
0.047 0.01 kr/kg
Split-steam2
2 0.15 kr/MJ 0.12 0.01 kr/kg
25.3 2.74 kr/kg Cooler-GG-H2
Cooler-GG-H2 3.6
0.12 0.00
25.30 523 2
9.2 25.30 kr/s
0.06
26.82
561
2
0.186
36.2 20.51
0.19 kr/s
0.01 kr/MJ
0.01 kr/kg
0 541 4
0.0 0.00 kr/s
-0 0.00 kr/MJ
0.00 kr/kg
Water
Reformat
9.669 462 2 9.669
5.2 9.67 kr/s
88.77 0.11 kr/MJ
9.22 461 2
0.02
5.2 9.22 kr/s
87.59 0.11 kr/MJ
2 0.11 kr/MJ
5.501 1.79 kr/kg
Mixer-NG_ref
2 0.11 kr/MJ
2.678 1.82 kr/kg
Mixer-NG_ref
2 0.10 kr/MJ
1.041 1.66 kr/kg
Mixer-NG_ref
35.17 0.01 kr/MJ 38.2 0.01 kr/MJ Cooler-GG-H2 22.7 14.09 171.7 0.15 kr/MJ Syngas-cool1 14.4 262 Syngas-cool1
1.87 kr/kg 1.78 kr/kg
0.00 kr/kg 12.6 145.2 0.01 kr/kg SAND 19 571 0.12 kr/s 2.74 kr/kg Comp-GG-H2-2 532 36.49 kr/s
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 3.89 kr/s Steam_dryer
4 0.01 kr/MJ Comp-GG-H2-2 2 0.14 kr/MJ
2
3.886
0.03 kr/MJ
0.31 kr/kg
Steam
0.12 0.01 kr/kg
Cooler-GG-H2
4.3 MW
SAND
13
4.28
36.49 2.53 kr/kg
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.6 2.629
41 0.02 kr/s
2 0.01 kr/MJ
Steam
0.08
38.57
14.4 267.5
533 38.57 kr/s
4 0.14 kr/MJ
Syngas 38.57 2.67 kr/kg
5.9 MW
SAND
15
5.869
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
86
0
0
Total
price
[mio. kr]
111
0
0
C
[kr/s]
0.26
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
96 MW
145 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.024 0.01 kr/kg 53.5 33.11 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 461 600 1.39
DH-condenser
0.01 10.8 0.42 811 12
DH condenser0.42
78.5 0.42 kr/s
581
2
0.28
0.28 kr/s
0.01 kr/MJ
0.01 kr/kg Steam
0.23 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
4
0
0
6
1
0.00
0.01
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
80%
4.6 0.183 2.743 0.15 kr/MJ DH-cooler DH-cooler
42.5 0.23 kr/s Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 0.00 kr/s 0.01 kr/kg SAND 25 26.35 0.01 kr/MJ Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 24 32 0.07
4 0.00 kr/MJ
0 0.00 kr/kg
DH-condenser
DH-condenser
430.0 15.02
811 0.49 kr/s
0.010 811 6
50.8 0.01 kr/s
1.776 0.01 kr/MJ
0.01 8.5 0 804 2
DH cooler
DH water
0.01 50.8 0.00 kr/s
0.416 0.00 kr/MJ 1.0 0.639
0.219 562 2
42.5 0.22 kr/s
0.01 kr/kg
Syngas-cool2 6.8
0.23 0.01
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4
3
0
6
4
0
0.01
0.01
0.00 Energy
Water
2 0.03 kr/MJ
0.49 0.00 kr/kg
DH
DH water
0.00 kr/kg
DH-cooler
35
6
53.5 30.28
0.28 kr/s
0.01 kr/MJ
0.00 kr/kg
DH-cooler
571 0.01 kr/s
10 0.01 kr/MJ
0.01 0.01 kr/kg
Cond-steam-1
24.1 0.01 kr/MJ
0.01 kr/kg
Syngas-cool2
13.9 264.9
534 38.57 kr/s
2 0.15 kr/MJ
0 551 4
0.6 0.00 kr/s
0.049 0.00 kr/MJ
0.00 kr/kg
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
96
2
3
6
0
125
2
4
7
0
0.29
0.00
0.01
0.02
0.00
Input:
NG
Biomass
Power*
Total power
92 MW
121 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
11 MW
Energy content in DH water = 72 MW 0.28 0.01 kr/kg
DH-cooler
Steam
38.57 2.78 kr/kg
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.023 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
0.01 kr/s
0.06
Comp-syngas2
40.01 4.1 MW 17
SAND 4.068
13.9 268.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
19
2
26
2
25
3
34
0.00
0.06
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 0.01 kr/MJ 535 40.01 kr/s Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.01 0.01 kr/kg 2 0.15 kr/MJ Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.06
Cond-steam-1
40.01 2.88 kr/kg Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 327 424 0.98 Gas composition at specific nodes (mol-%)
39.74 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
39.74 kr/s
0.17 kr/MJ 601
59.3 519.3
81.56 kr/s
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.67
4 3.86 kr/kg 2 0.16 kr/MJ Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
148 38.4 860.6 Steam
0 682 4
82 1.38 kr/kg
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
270
0
351
0
0.81
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 60.63 42.70 24.36 25.92 27.89 30.00
0.00 0.00 0.12 1.00 1.32 1.40 1.51 1.62
791 147.9 kr/s 17.1 0.00 kr/s Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 29.16 14.45 3.27 3.47 3.74 4.02
792 0.17 kr/MJ 17.55 0.00 kr/MJ DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 5.24 0.00 5.09 4.47 35.29 46.38 49.35 53.11 57.12
Heatsourc-DH 4 3.86 kr/kg Cond-steam-1 0.00 kr/kg Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 20 0.05 7 H2O-G 5.21 0.00 14.17 5.12 2.13 2.93 1.70 0.62 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.047 811 10 39.2
234.0 0.05 kr/s 0.047 0.05
0 806 2
DH water
234.0 0.00 kr/s
0 683 2
0.1 0.00 kr/s
0.2
0.01 0.00
0 684 4
0.1 0.00 kr/s
Water
0 681 2
17.1 0.00 kr/s
31.8 Meoh-convert
Methanol 0.98 SAND
converter 83
311
Total several DISTILLATION_STAGE's 1423 1826 4.28 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.44
0.06
0.00
3.62 4.77 5.08
0.48 0.63 0.67
0.33 16.33 12.39
5.47
0.73
6.94
5.88
0.78
0.56
8.175 0.01 kr/MJ
0.00 kr/kg
1.916 0.00 kr/MJ
0.00 kr/kg
0.115 0.00 kr/MJ
0.00 kr/kg
0.025 0.00 kr/MJ
0.00 kr/kg
3.774 0.00 kr/MJ
0.00 kr/kg 602
59.3 503.9
82.55 kr/s 607
45.4 251
41.55 kr/s Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
108.3
Heatsourc-DH 148 38.4 869.6 Heatsourc-DH
28.1 629.5 783 147.9 kr/s
Cond-steam-1 Cond-steam-1 Convert-cool
2
83
0.16 kr/MJ
1.39 kr/kg
2
42
0.17 kr/MJ
0.92 kr/kg
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 108.2 kr/s 784 0.17 kr/MJ 17.0 17.43 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 0.17 kr/MJ 4 3.86 kr/kg 685 0.00 kr/s 9.5 Preheater-sy NG 93 kr/GJ Methanol 39.7 kr/s 172 kr/GJ 194 kr/GJ 3.86 kr/kg 3.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 3.86 kr/kg Dis_stage_17 2 0.00 kr/MJ 42 606 2 42 0.01 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 410 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 0.00 kr/kg Comp-recirc 42 45.4 41.54 kr/s 55.7 431 DH water 0 kr/ton Syngas 2.2 kr/s 167 kr/GJ - kr/GJ 0.91 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.00 248.1 0.17 kr/MJ 640 71.13 kr/s 78 11.42 3.6 69.19 Water 32 kr/ton DH water 0.5 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.176 0.92 kr/kg 2 0.17 kr/MJ 621 11.42 kr/s CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
155 0.81
Feed
17.0
3.749
0.00 kr/s
0.00 kr/MJ
0.00 kr/kg
Preheater-sy 71.13 1.28 kr/kg
Condenser-1
6.6
631 0.17 kr/MJ
4 3.21 kr/kg
Preheater-sy
Nomenclature:
Cond-steam-2 1.21 0.01 If methanol and DH share the plant costs
Condenser-1 84.1 13.67 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
19 6.96 kr/s
2 1.21 705 706
3 1.21 kr/s
6
SAND 31 51.6 346.2
643 57.46 kr/s
2 0.17 kr/MJ
4 13.67 kr/s
82 0.17 kr/MJ
3.38 kr/kg
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 31.6 kr/s 137 kr/Gjex Electrical power
Node nr
Cost flow
Transferred heat [MW]
49 0.14 kr/MJ 9 0.14 kr/MJ Condenser 57.46 1.11 kr/kg Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Specific exergy cost
0.37 kr/kg 0.37 kr/kg SAND 33 Condenser
Specific mass cost
Dis_stage_1 0.01 811 8
59.9 0.01 kr/s
Reboil-meoh2 10.0
0.01 0.01
0 805 2
DH water
59.9 0.00 kr/s Mechanical power
10
6.915 19.8 40.63 2.091 0.01 kr/MJ 0.49 0.00 kr/MJ 1.2 3.2 6.628
707 6.92 kr/s Cond-steam-2 0.00 kr/kg 41.48 605 2 0.00 kr/kg 699 1.20 kr/s 0.25
708 0.17 kr/MJ SAND 393 Condenser
45.4 41.48 kr/s 2.4 13.05 Condenser
700 0.18 kr/MJ
4 0.35 kr/kg 247.9 0.17 kr/MJ 611 2.18 kr/s 91.4 13.8 3.9 82.48 2 0.37 kr/kg
Water /
Methanol
Methanol molar-% = 5.16
0 693 694
1 0.00 kr/s
2 0.00 kr/MJ
Dis_stage_1
4 5.716 695 696
15 5.72 kr/s
32 0.18 kr/MJ
2 31.6
5.754 0.04
5.754 705 706
15 5.75 kr/s
41 0.14 kr/MJ
4
38.88 625 635
11 38.88 kr/s
2
Methanol molar-% = 84.5
0.91 kr/kg
Comp-recirc
Methanol/
4 0.17 kr/MJ
2.183 0.91 kr/kg
Syngas Split-syngas
621 13.80 kr/s
631 0.17 kr/MJ
4 3.57 kr/kg
Preheater-sy
Reboil-meoh2
Heat
Component cost flow [kr/s]
0.00 kr/kg
set-x-2
0.37 kr/kg
Reboil-meoh1
0.37 kr/kg
Reboil-meoh1
234 0.17 kr/MJ
3.39 kr/kg
meas_flow
Methanol mass flow = 10.4 kg/s
water

24. Flowsheets for metanolanlæg – for de 6
forskellige anlægskonfigurationer
Flowsheets sorteret efter anlægsnummer - anlæg 1 først.

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 3.4 -0 1.9 3.399
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 8.55 412 2
5EX 5 Component cost flow 2 3.4 kg/s 56.3 MW 201 2 1.9 kg/s 1.9 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.107 15 C SAND 56.34 0.07 850 C 97.97 1.9 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.381 803 4
78.5 1.0 bar
Electrolyser
18.62
2.4
0.80
0 802 2
78.5 1.0 bar DH water
0.93
Steam reformer
9.22
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.927 78.5 kg/s 3.0 0.393 0.4 44.05 0.643 78.5 kg/s 1.8 1.339
12 C
13 C/EX
SAND 1E-05 57 C
Electro-cool
3
4
1.0 bar
3.0 kg/s
2
4
1.0 bar
0.4 kg/s
50 C
Electro-cool
Comp-O2-2
0.6 MW 3
Reformat
5.6 95.09
403
2
10.0 bar
1.8 kg/s
0.0
0
Ash
0.3 0.252
83 1.0 bar
4 0.3 kg/s
14 C/M
O2 0.066 7 4 0.066
0.90
1.2 1.0 bar
0.16 1.2 kg/s
90 C
Comp-O2-1
0.066 5 2
1.2 1.0 bar
0.16 1.2 kg/s
90 C
Comp-O2-1
DH water
Gas
0.161 90 C
Electrolyser
0.0 9E-36
6 1.0 bar
4 0.0 kg/s
18.08 90 C
Electrolyser
H2 O2 0.095 401 2
1.8 1.0 bar
0.233 1.8 kg/s
90 C
SAND 0.604
0.309 402 4
0.94
0.309 1.8 10.0 bar
0.799 1.8 kg/s
431 C
431 10.0 bar
4 5.6 kg/s
9.22 950 C
NG_reformer
0.31 850 C
NG_reformer
0.6 10.73
441 10.0 bar
2 0.6 kg/s
1.041 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.009
1.3
33 2
1.0 bar
Steam
32
8.4 10.81
1.0 bar
801
2
6.8 0.056
1.0 bar
6.8 kg/s
15
4
0.0 0.016
1.0 bar
0.0 kg/s Heatsink-H2
4E-36 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
1.6 27.62
10.0 bar
1.6 kg/s
0.8
0.31 0.97 Heatex-O2
SAND 11
1.707 1.3 kg/s Heatex-GG-st 4 8.4 kg/s 0 50 C 0 60 C 0.0 MW 322 18.08 0.0 MW 9 Comp-CO2 2.678 950 C
730 C SAND 7 0.06 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 6E-05 0.0 MW 7
Heatex-NG
0.89
5
Gasifier
6.6 144.7
5
8.9
131.6
Gasifier
10 GG2
0.07 0.78
1.0 bar 0.9
8.9 kg/s
800 C
5
8.9
130.9
11 2
1.0 bar
8.9 kg/s
752 C
Heatex-GG-st
0.06 0.99 5
10.8 8.9
124.8
12 2 0.00 0.74
1.0 bar 1.1
8.9 kg/s
130 C Heatex-GG-DH
5
8.9
124.6
13 2
1.0 bar
8.9 kg/s
60 C
1.00
Gas cleaner 5.4
8.9 124.5
14 1.0 bar
0.00
Heatsink
18.08
18.08 511 2
0.4 1.0 bar
44.05 0.4 kg/s
90 C
Heatsink-H2
9.671 503 4
5.2 19.8 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 19.8 bar 0.0 1.0 bar
CO2
8.545 411 2
NG1.9
10.0 bar
95.97 1.9 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
3.3 56.74
10.0 bar
3.9
13 8.55 0.89
0 434 Water 2
0.1 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 8.9 kg/s 88.77 5.2 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 3.3 kg/s 0.007 0.1 kg/s
2 6.6 kg/s 0.07 9 2 Heatex-GG-O2 8.4 4.755 0 21 4 5.4 60 C 250 C 279 C 15 C 5.501 950 C 107 C
3.96 120 C 1.2 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 18.08 512 2 26.82 524 4 14.4 264.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.653 1.2 kg/s
790 C
Gasifier
2 8.4 kg/s
0.043 120 C
Heatex-GG-st
-0 0.0 kg/s
60 C 521
Heatex-GG-DH 2
9.2 168.4
1.0 bar
9.2 kg/s
0.4
44.05
1.0 bar
0.4 kg/s
90 C
9.2
175.7
19.8 bar
9.2 kg/s
320 C
531
2
36.49
19.8 bar
14.4 kg/s
294 C
0.061 422 2
Water 1.9 10.0 bar
0.006 1.9 kg/s
7.8 Heatex-H2O
0.07 0.74 SAND 15
0 453 Water 4
Steam
811
6.8 0.237
1.0 bar
23.50 68 C
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.2 22.42
Syngas-cool1
33 C
Heatex-H2O
0.2
0.013
10.0 bar
0.2 kg/s
4 6.8 kg/s 0.93
SAND 5.071 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.3 22.7 12.89 6 36.2 kg/s SAND 21 1.3 MW 5 3.1 Heatex-H2O
1.5 25.38 0.6
7.1 9.101 Heatex-GG-DH
9.2 173.1 563 1.0 bar 0.19 200 C 5.8 SAND 1.267 3.1 52.16 1.5 25.38 0.6 10.17
0.31
62.1
Steam_dryer Biomass (dry)
SAND 1
35 4 0.46 16.9 0.31 34 2
1.0 bar Steam dryer 3.96 56.1 1.0 bar
34 1.0 bar
4 7.1 kg/s
0.047 730 C
Split-steam2
522 5.5 bar
2 9.2 kg/s
25.3 294 C
Cooler-GG-H2
2 22.7 kg/s
0.12 120 C
Cooler-GG-H2
3.6
0.12 0.83
25.30 523 2
9.2 5.5 bar
0.93
26.82
Syngas-cool1
561
2
0.186
36.2 20.51
1.0 bar
36.2 kg/s
120 C
0.19 0.83
0 541 4
0.0 19.8 bar
-0 0.0 kg/s
130 C
Water
Reformat
9.669 462 2 9.669
5.2 19.8 bar
88.77 5.2 kg/s
9.22 461 2
0.93
5.2 10.0 bar
87.59 5.2 kg/s
452 10.0 bar
2 3.1 kg/s
5.501 109 C
Mixer-NG_ref
433 10.0 bar
2 1.5 kg/s
2.678 107 C
Mixer-NG_ref
442 10.0 bar
2 0.6 kg/s
1.041 483 C
Mixer-NG_ref
35.17 62.1 kg/s 38.2 56.1 kg/s Cooler-GG-H2 22.7 14.09 171.7 9.2 kg/s Syngas-cool1 14.4 262 Syngas-cool1
250 C 154 C
120 C 12.6 145.2 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.8 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 22.7 kg/s Comp-GG-H2-2 2 14.4 kg/s
2
3.886
12.6 kg/s
15 C
Steam
0.12 200 C
Cooler-GG-H2
4.3 MW
SAND
13
4.28
36.49 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.6 2.629
41 1.0 bar
2 4.6 kg/s
Steam
0.93
38.57
14.4 267.5
533 62.2 bar
4 14.4 kg/s
Syngas 38.57 294 C
5.9 MW
SAND
15
5.869
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
86
0
0
Total
price
[mio. kr]
111
0
0
C
[kr/s]
0.26
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
96 MW
145 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.024 120 C 53.5 33.11 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 461 600 1.39
DH-condenser
0.74 10.8 0.42 811 12
DH condenser0.42
78.5 1.0 bar
581
2
0.28
1.0 bar
53.5 kg/s
200 C Steam
0.23 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
4
0
0
6
1
0.00
0.01
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
80%
4.6 0.183 2.743 78.5 kg/s DH-cooler DH-cooler
42.5 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 26.35 42.5 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 24 32 0.07
4 4.6 kg/s
0 95 C
DH-condenser
DH-condenser
430.0 15.02
811 1.0 bar
0.010 811 6
50.8 1.0 bar
1.776 50.8 kg/s
0.48 8.5 0 804 2
DH cooler
DH water
0.01 50.8 1.0 bar
0.416 50.8 kg/s 1.0 0.639
0.219 562 2
42.5 1.0 bar
200 C
Syngas-cool2 6.8
0.23 0.87
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4
3
0
6
4
0
0.01
0.01
0.00 Energy
Water
2 430.0 kg/s
0.49 90 C
DH
DH water
90 C
DH-cooler
35
6
53.5 30.28
1.0 bar
53.5 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.01 225 C
Cond-steam-1
24.1 42.5 kg/s
120 C
Syngas-cool2
534
2
13.9 264.9
62.2 bar
13.9 kg/s
0 551 4
0.6 62.2 bar
0.049 0.6 kg/s
136 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
96
2
3
6
0
125
2
4
7
0
0.29
0.00
0.01
0.02
0.00
Input:
NG
Biomass
Power*
Total power
92 MW
121 MW
56 MW
79 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
11 MW
Energy content in DH water = 72 MW 0.28 120 C
DH-cooler
Steam
38.57 136 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.023 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
40.01 4.1 MW 17
SAND 4.068
13.9 268.6
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
19
2
26
2
25
3
34
0.00
0.06
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.01 120 C 2 13.9 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.06
Cond-steam-1
40.01 253 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 327 424 0.98 Gas composition at specific nodes (mol-%)
39.74 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
3.5 bar
10.3 kg/s 601
59.3 519.3
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.67
4 100 C 2 59.3 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
148 38.4 860.6 Steam
0 682 4
82 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
270
0
351
0
0.81
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 60.63 42.70 24.36 25.92 27.89 30.00
0.00 0.00 0.12 1.00 1.32 1.40 1.51 1.62
791 3.5 bar 17.1 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 29.16 14.45 3.27 3.47 3.74 4.02
792 38.4 kg/s 17.55 17.1 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 5.24 0.00 5.09 4.47 35.29 46.38 49.35 53.11 57.12
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 20 0.05 7 H2O-G 5.21 0.00 14.17 5.12 2.13 2.93 1.70 0.62 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.047 811 10 39.2
234.0 1.0 bar 0.047 0.70
0 806 2
DH water
234.0 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.01 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.1 30.6 bar
31.8 Meoh-convert
Methanol 1.00 SAND
converter 83
311
Total several DISTILLATION_STAGE's 1423 1826 4.28 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.44
0.06
0.00
3.62 4.77 5.08
0.48 0.63 0.67
0.33 16.33 12.39
5.47
0.73
6.94
5.88
0.78
0.56
8.175 234.0 kg/s
90 C
1.916 234.0 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.774 17.1 kg/s
220 C 602
59.3 503.9
139.0 bar 607
45.4 251
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
108.3
Heatsourc-DH 148
28.1 629.5 783
38.4 869.6 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
83
59.3 kg/s
235 C
2
42
45.4 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 38.4 kg/s 17.0 17.43 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 28.1 kg/s 4 100 C 685 30.6 bar 9.5 Preheater-sy NG 93 kr/GJ Methanol 39.7 kr/s 172 kr/GJ 194 kr/GJ 3.86 kr/kg 3.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.0 kg/s 42 606 2 42 0.77 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 410 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 42 45.4 144.0 bar 55.7 431 DH water 0 kr/ton Syngas 2.2 kr/s 167 kr/GJ - kr/GJ 0.91 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.90 248.1 45.4 kg/s 640 139.0 bar 78 11.42 3.6 69.19 Water 32 kr/ton DH water 0.5 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.176 63 C 2 55.7 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
155 0.73
Feed
17.0
3.749
30.6 bar
17.0 kg/s
220 C
Preheater-sy 71.13 170 C
Condenser-1
6.6
631 3.6 kg/s
4 170 C
Preheater-sy
Nomenclature:
Cond-steam-2 1.21 0.78 If methanol and DH share the plant costs
Condenser-1 84.1 13.67 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
19 3.5 bar
2 1.21 705 706
3 3.5 bar
6
SAND 31 51.6 346.2
643 139.0 bar
2 51.6 kg/s
4 139.0 bar
82 4.1 kg/s
142 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 31.6 kr/s 137 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
49 18.5 kg/s 9 3.2 kg/s Condenser 57.46 142 C Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Mass flow
132 C 132 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
59.9 1.0 bar
Reboil-meoh2 10.0
0.01 0.58
0 805 2
DH water
59.9 1.0 bar Mechanical power
10
6.915 19.8 40.63 2.091 59.9 kg/s 0.49 59.9 kg/s 1.2 3.2 6.628
707 3.5 bar Cond-steam-2 90 C 41.48 605 2 50 C 699 3.5 bar 0.25
708 19.7 kg/s SAND 393 Condenser
45.4 139.0 bar 2.4 13.05 Condenser
700 3.2 kg/s
4 132 C 247.9 45.4 kg/s 611 139.0 bar 91.4 13.8 3.9 82.48 2 132 C
Water /
Methanol
Methanol molar-% = 5.16
0 693 694
1 3.5 bar
2 1.2 kg/s
Dis_stage_1
4 5.716 695 696
15 3.5 bar
32 15.4 kg/s
2 31.6
5.754 0.67
5.754 705 706
15 3.5 bar
41 15.4 kg/s
4
38.88 625 635
11 3.5 bar
2
Methanol molar-% = 84.5
60 C
Comp-recirc
Methanol/
4 2.4 kg/s
2.183 60 C
Syngas Split-syngas
621 139.0 bar
631 3.9 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
132 C
Reboil-meoh1
132 C
Reboil-meoh1
234 11.5 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 5.8 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 5.8 kg/s 96.7 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.184 15 C SAND 96.65 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.592 803 4
115.3 1.0 bar
Electrolyser
31.94
4.1
0.80
0 802 2
115.3 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 1.439 115.3 kg/s 5.1 0.674 0.6 75.57 0.944 115.3 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 59 C
Electro-cool
3
4
1.0 bar
5.1 kg/s
2
4
1.0 bar
0.6 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.5 0.357
83 1.0 bar
4 0.5 kg/s
14 C/M
O2 0.093 7 4 0.093
0.90
1.7 1.0 bar
0.227 1.7 kg/s
90 C
Comp-O2-1
0.093 5 2
1.7 1.0 bar
0.227 1.7 kg/s
90 C
Comp-O2-1
DH water
Gas
0.277 90 C
Electrolyser
3.4 0.447
6 1.0 bar
4 3.4 kg/s
31.07 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.011
1.9
33 2
1.0 bar
Steam
32
11.9 15.28
1.0 bar
801
2
9.6 0.079
1.0 bar
9.6 kg/s
15
4
0.0 0.023
1.0 bar
0.0 kg/s Heatsink-H2
0.184 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
2.414 1.9 kg/s Heatex-GG-st 4 11.9 kg/s 0 50 C 0 60 C 0.0 MW 322 31.07 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.07 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 1E-04 0.0 MW 7
Heatex-NG
0.89
8
Gasifier
9.4 204.7
8
12.5
186.1
Gasifier
10 GG2
0.09 0.78
1.0 bar 1.2
12.5 kg/s
800 C
8
12.5
185.2
11 2
1.0 bar
12.5 kg/s
752 C
Heatex-GG-st
0.07 0.99 8
15.2 12.5
176.5
12 2 0.00 0.74
1.0 bar 1.6
12.5 kg/s
130 C Heatex-GG-DH
8
12.5
176.1
13 2
1.0 bar
12.5 kg/s
60 C
1.00
Gas cleaner 7.7
12.5 176.1
14 1.0 bar
0.00
Heatsink
31.07
31.07 511 2
0.6 1.0 bar
75.57 0.6 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 18.5 bar
SAND 0.002
0.002 502 4 0.002 0.001 501 2
0.93
0.0 18.5 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 12.5 kg/s 0.165 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 9.4 kg/s 0.09 9 2 Heatex-GG-O2 11.9 6.724 0 21 4 7.7 60 C 250 C 272 C 15 C 0.01 950 C 107 C
5.60 120 C 1.7 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 31.07 512 2 43.56 524 4 13.2 261.9 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
0.924 1.7 kg/s
790 C
Gasifier
2 11.9 kg/s
0.051 120 C
Heatex-GG-st
5E-20 0.0 kg/s
60 C 521
Heatex-GG-DH 2
13.2 251.4
1.0 bar
13.2 kg/s
0.6
75.57
1.0 bar
0.6 kg/s
90 C
13.2
261.7
18.5 bar
13.2 kg/s
303 C
531
2
43.58
18.5 bar
13.2 kg/s
303 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
9.6 0.336
1.0 bar
38.74 69 C
Comp-GG-H2-1
Comp-GG-H2-1
7.8 MW 11
Mixer-GG-H2 Comp-GG-H2-2
35.7 22.12
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 9.6 kg/s 0.93
SAND 7.805 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 41.51 35.7 20.21 6 35.7 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
10.0 12.87 Heatex-GG-DH
13.2 258.7 563 1.0 bar 0.16 200 C 5.7 SAND 0.002 0.0 0.094 0.0 0.046 0.0 0.018
0.37
87.8
Steam_dryer Biomass (dry)
SAND 1
35 4 0.46 23.9 0.37 34 2
1.0 bar Steam dryer 5.60 79.4 1.0 bar
34 1.0 bar
4 10.0 kg/s
0.058 730 C
Split-steam2
522 5.7 bar
2 13.2 kg/s
41.51 303 C
Cooler-GG-H2
2 35.7 kg/s
0.15 120 C
Cooler-GG-H2
5.7
0.16 0.82
41.51 523 2
13.2 5.7 bar
0.93
43.56
Syngas-cool1
561
2
0.153
35.7 20.23
1.0 bar
35.7 kg/s
120 C
0.16 0.82
0 541 4
0.0 18.5 bar
7E-18 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 18.5 bar
0.16 0.0 kg/s
0.017 461 2
0.92
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
49.74 87.8 kg/s 54.02 79.4 kg/s Cooler-GG-H2 35.7 22.09 256.4 13.2 kg/s Syngas-cool1 13.2 259.6 Syngas-cool1
240 C 154 C
120 C 17.8 205.3 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 18.5 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 35.7 kg/s Comp-GG-H2-2 2 13.2 kg/s
2
5.495
17.8 kg/s
15 C
Steam
0.16 200 C
Cooler-GG-H2
5.8 MW
SAND
13
5.785
43.58 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
6.6 3.718
41 1.0 bar
2 6.6 kg/s
Steam
0.93
45.63
13.2 265
533 60.6 bar
4 13.2 kg/s
Syngas 45.63 303 C
5.8 MW
SAND
15
5.789
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
147
0
0
Total
price
[mio. kr]
191
0
0
C
[kr/s]
0.44
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
205 MW
97 MW
121 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
11 MW
SAND 79 0.028 120 C 38.7 23.99 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 653 848 1.96
DH-condenser
0.75 15.2 0.64 811 12
DH condenser0.64
115.3 1.0 bar
581
2
0.17
1.0 bar
38.7 kg/s
200 C Steam
0.16 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
6
1
1
8
1
0.00
0.02
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
71% (with total power)
78%
6.6 0.259 4.029 115.3 kg/s DH-cooler DH-cooler
35.7 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 22.12 35.7 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 35 45 0.10
4 6.6 kg/s
0 95 C
DH-condenser
DH-condenser
450.0 15.72
811 1.0 bar
0.007 811 6
36.8 1.0 bar
1.286 36.8 kg/s
0.48 6.2 0 804 2
DH cooler
DH water
0.01 36.8 1.0 bar
0.301 36.8 kg/s 1.0 0.639
0.153 562 2
35.7 1.0 bar
200 C
Syngas-cool2 5.7
0.16 0.82
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
6
0
0
8
0
0
0.02
0.00
0.00 Energy
Water
2 450.0 kg/s
0.71 90 C
DH
DH water
90 C
DH-cooler
35
6
38.7 21.94
1.0 bar
38.7 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
20.23 35.7 kg/s
120 C
Syngas-cool2
534
2
13.2 262.7
60.6 bar
13.2 kg/s
0 551 4
0.0 60.6 bar
-0 0.0 kg/s
130 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
172 MW
97 MW
121 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
76 MW
0 MW
9 MW
Energy content in DH water = 76 MW 0.17 120 C
DH-cooler
Steam
45.63 130 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
35
0
46
0.00
0.11
* for electrolyser
Urenhed:
0.016 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.98
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
47.07 4.0 MW 17
SAND 4.039
13.2 266.4
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
26
2
26
3
34
3
34
0.01
0.08
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
70% (with total power)
99%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 2 3 0.01
0.00 120 C 2 13.2 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 24 0.05
Cond-steam-1
47.07 251 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 295 384 0.89 Gas composition at specific nodes (mol-%)
46.69 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 3 4 0.01
793
794
3.5 bar
10.3 kg/s 601
51.9 478.1
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
3
4
4
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.72
4 100 C 2 51.9 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
177.7 39.2 879.7 Steam
0 682 4
88 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
262
0
341
0
0.79
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 61.87 44.20 23.87 25.43 27.98 30.00
0.00 0.00 0.18 1.56 2.13 2.27 2.50 2.68
791 3.5 bar 17.2 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 16 0.04 4 CO 42.73 0.00 22.49 30.14 16.13 3.88 4.13 4.54 4.87
792 39.2 kg/s 17.58 17.2 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 2 3 0.01 6 CO2 5.24 0.00 5.09 3.72 32.37 44.09 46.98 51.68 55.41
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 16 21 0.05 7 H2O-G 5.21 0.00 14.17 3.68 1.65 2.30 1.39 0.42 0.01
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.048 811 10 40.1
239.2 1.0 bar 0.048 0.70
0 806 2
DH water
239.2 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.2 30.6 bar
31.9 Meoh-convert
Methanol 1.00 SAND
converter 89
311
Total several DISTILLATION_STAGE's 1559 2002 4.69 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.34
0.08
0.00
3.01 4.10 4.37
0.75 1.03 1.09
0.32 18.61 14.33
4.81
1.20
6.88
5.16
1.29
0.57
8.356 239.2 kg/s
90 C
1.958 239.2 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.78 17.2 kg/s
220 C 602
51.9 462.6
139.0 bar 607
38.7 210.9
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
131
Heatsourc-DH 177.7
28.9 648.6 783
39.2 888.8 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
89
51.9 kg/s
235 C
2
41
38.7 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 39.2 kg/s 17.0 17.47 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 28.9 kg/s 4 100 C 685 30.6 bar 8.1 Preheater-sy NG 93 kr/GJ Methanol 46.7 kr/s 202 kr/GJ 228 kr/GJ 4.53 kr/kg 3.6 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.0 kg/s 41 606 2 41 0.70 SAND 29 Biomass 32 kr/GJ Oxygen 0.2 kr/s 411 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 41 38.7 144.0 bar 48.6 392.4 DH water 0 kr/ton Syngas 2.2 kr/s 198 kr/GJ - kr/GJ 1.06 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.90 208.5 38.7 kg/s 640 139.0 bar 84 12.96 3.3 66.71 Water 32 kr/ton DH water 0.7 kr/s 45 kr/GJ 9 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.151 63 C 2 48.6 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
189 0.75
Feed
17.0
3.756
30.6 bar
17.0 kg/s
220 C
Preheater-sy 76.24 173 C
Condenser-1
7.3
631 3.3 kg/s
4 173 C
Preheater-sy
Nomenclature:
Cond-steam-2 2.15 0.65 If methanol and DH share the plant costs
Condenser-1 88.8 19.14 621 631 4 (methanol and DH are the only products from the plant) -
11 705 706
19 3.5 bar
2 2.15 705 706
4 3.5 bar
6
SAND 31 44.0 291.5
643 139.0 bar
2 44.0 kg/s
5 139.0 bar
98 4.6 kg/s
139 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 38.4 kr/s 166 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
66 19.3 kg/s 12 3.6 kg/s Condenser 57.09 139 C Preheater-sy
DH water 11.3 kr/s 150 kr/Gjen Mass flow
129 C 129 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
49.1 1.0 bar
Reboil-meoh2 8.2
0.01 0.50
0 805 2
DH water
49.1 1.0 bar Mechanical power
10
11.45 20.1 57.25 1.714 49.1 kg/s 0.402 49.1 kg/s 2.145 3.6 10.28
707 3.5 bar Cond-steam-2 90 C 41.18 605 2 50 C 699 3.5 bar 0.25
708 20.1 kg/s SAND 393 Condenser
38.7 139.0 bar 2.0 10.97 Condenser
700 3.6 kg/s
4 129 C 208.4 38.7 kg/s 611 139.0 bar 94.0 13.75 3.2 69.56 2 129 C
Water /
Methanol
Methanol molar-% = 7.35
0 693 694
1 3.5 bar
2 0.8 kg/s
Dis_stage_1
4 9.301 695 696
16 3.5 bar
45 15.6 kg/s
2 31.7
9.339 0.66
9.339 705 706
16 3.5 bar
54 15.6 kg/s
4
45.85 625 635
11 3.5 bar
2
Methanol molar-% = 88.8
60 C
Comp-recirc
Methanol/
4 2.0 kg/s
2.167 60 C
Syngas Split-syngas
621 139.0 bar
631 3.2 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
129 C
Reboil-meoh1
129 C
Reboil-meoh1
234 11.1 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.4 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.4 kg/s 39.7 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.076 15 C SAND 39.71 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.369 803 4
86.9 1.0 bar
Electrolyser
13.12
1.7
0.80
0 802 2
86.9 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.906 86.9 kg/s 2.1 0.277 0.3 31.05 0.711 86.9 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 55 C
Electro-cool
3
4
1.0 bar
2.1 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.445
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.113 7 4 0.113
0.90
2.1 1.0 bar
0.277 2.1 kg/s
90 C
Comp-O2-1
0.113 5 2
2.1 1.0 bar
0.277 2.1 kg/s
90 C
Comp-O2-1
DH water
Gas
0.113 90 C
Electrolyser
0.0 -0
6 1.0 bar
4 0.0 kg/s
12.64 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.029
5.0
33 2
1.0 bar
Steam
32
18.1 23.26
1.0 bar
801
2
14.3 0.117
1.0 bar
14.3 kg/s
15
4
4.6 2.112
1.0 bar
4.6 kg/s Heatsink-H2
-0 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
6.416 5.0 kg/s Heatex-GG-st 4 18.1 kg/s 0 50 C 0 60 C 0.0 MW 322 12.64 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.11 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 4E-05 0.0 MW 7
Heatex-NG
0.89
10
Gasifier
11.7 255.5
10
18.2
234.8
Gasifier
10 GG2
0.11 0.78
1.0 bar 1.5
18.2 kg/s
800 C
10
18.2
233.7
11 2
1.0 bar
18.2 kg/s
761 C
Heatex-GG-st
0.11 0.98 10
23.1 18.2
220.5
12 2 0.00 0.74
1.0 bar 2.4
18.2 kg/s
130 C Heatex-GG-DH
10
18.2
219.9
13 2
1.0 bar
18.2 kg/s
60 C
1.00
Gas cleaner 9.6
13.6 218.8
14 1.0 bar
0.00
Heatsink
12.64
12.64 511 2
0.3 1.0 bar
31.05 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 19.8 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 19.8 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 13.6 kg/s 0.166 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 11.7 kg/s 0.11 9 2 Heatex-GG-O2 18.1 10.23 0 21 4 9.6 60 C 259 C 279 C 15 C 0.01 950 C 107 C
6.99 120 C 2.1 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 12.64 512 2 27.37 524 4 13.9 261 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.127 2.1 kg/s
790 C
Gasifier
2 18.1 kg/s
0.079 120 C
Heatex-GG-st
4E-18 0.0 kg/s
60 C 521
Heatex-GG-DH 2
13.9 249.8
1.0 bar
13.9 kg/s
0.3
31.05
1.0 bar
0.3 kg/s
90 C
13.9
260.8
19.8 bar
13.9 kg/s
305 C
531
2
27.39
19.8 bar
13.9 kg/s
304 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
14.3 0.498
1.0 bar
22.23 63 C
Comp-GG-H2-1
Comp-GG-H2-1
8.4 MW 11
Mixer-GG-H2 Comp-GG-H2-2
37.6 23.31
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 14.3 kg/s 0.93
SAND 8.391 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.2 37.6 21.3 6 37.6 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
13.1 16.84 Heatex-GG-DH
13.9 257.6 563 1.0 bar 0.17 200 C 6.0 SAND 0.002 0.0 0.094 0.0 0.046 0.0 0.018
0.45
105.4
Steam_dryer Biomass (dry)
SAND 1
35 4 0.45 29.8 0.45 34 2
1.0 bar Steam dryer 6.99 94.9 1.0 bar
34 1.0 bar
4 13.1 kg/s
0.077 730 C
Split-steam2
522 6.0 bar
2 13.9 kg/s
25.2 304 C
Cooler-GG-H2
2 37.6 kg/s
0.16 120 C
Cooler-GG-H2
6.0
0.17 0.82
25.20 523 2
13.9 6.0 bar
0.93
27.37
Syngas-cool1
561
2
0.164
37.6 21.32
1.0 bar
37.6 kg/s
120 C
0.17 0.82
0 541 4
0.0 19.8 bar
6E-18 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 19.8 bar
0.16 0.0 kg/s
0.017 461 2
0.93
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
59.71 105.4 kg/s 65.17 94.9 kg/s Cooler-GG-H2 37.6 23.29 255.2 13.9 kg/s Syngas-cool1 13.9 258.6 Syngas-cool1
250 C 154 C
120 C 22.2 256.3 278 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.8 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 37.6 kg/s Comp-GG-H2-2 2 13.9 kg/s
2
6.86
22.2 kg/s
15 C
Steam
0.17 200 C
Cooler-GG-H2
6.1 MW
SAND
13
6.098
27.39 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
5.6 3.144
41 1.0 bar
2 5.6 kg/s
Steam
0.93
29.55
13.9 264.2
533 65.2 bar
4 13.9 kg/s
Syngas 29.55 304 C
6.1 MW
SAND
15
6.102
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
60
0
0
Total
price
[mio. kr]
78
0
0
C
[kr/s]
0.18
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
256 MW
40 MW
65 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
8 MW
SAND 79 0.024 120 C 52.4 32.45 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 815 1059 2.45
DH-condenser
0.73 12.9 0.41 811 12
DH condenser0.41
86.9 1.0 bar
581
2
0.24
1.0 bar
52.4 kg/s
200 C Steam
0.26 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
9
1
1
12
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
78%
5.6 0.219 3.035 86.9 kg/s DH-cooler DH-cooler
57.9 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 35.88 57.9 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 43 56 0.13
4 5.6 kg/s
0 95 C
DH-condenser
DH-condenser
439.6 15.36
811 1.0 bar
0.010 811 6
49.8 1.0 bar
1.739 49.8 kg/s
0.48 8.3 0 804 2
DH cooler
DH water
0.01 49.8 1.0 bar
0.408 49.8 kg/s 1.0 0.639
0.252 562 2
57.9 1.0 bar
200 C
Syngas-cool2 9.2
0.26 0.91
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
5
0
0
7
0
0
0.02
0.00
0.00 Energy
Water
2 439.6 kg/s
0.48 90 C
DH
DH water
90 C
DH-cooler
35
6
52.4 29.67
1.0 bar
52.4 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
32.81 57.9 kg/s
120 C
Syngas-cool2
534
2
12.4 260.7
65.2 bar
12.4 kg/s
0 551 4
1.6 65.2 bar
0.138 1.6 kg/s
135 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
214 MW
40 MW
65 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
74 MW
0 MW
7 MW
Energy content in DH water = 74 MW 0.24 120 C
DH-cooler
Steam
29.55 135 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
38
0
49
0.00
0.11
* for electrolyser
Urenhed:
0.008 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.99
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
30.82 3.6 MW 17
SAND 3.586
12.4 264.1
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
27
2
27
3
36
3
36
0.01
0.08
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
81% (with power for electrolyser)
73% (with total power)
102%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 4 5 0.01
0.00 120 C 2 12.4 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 16 21 0.05
Cond-steam-1
30.82 248 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 254 330 0.76 Gas composition at specific nodes (mol-%)
31.41 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 2 3 0.01
793
794
3.5 bar
10.3 kg/s 601
42.2 416.8
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
2
4
3
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.78
4 100 C 2 42.2 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
127.3 41.7 936.6 Steam
0 682 4
51 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
254
0
330
0
0.76
0.00
1
3
H2
N2
45.61
0.21
0.00 57.70 60.67 45.40 22.81 24.39 28.19 30.00
0.00 0.00 0.23 2.28 3.30 3.53 4.08 4.34
791 3.5 bar 17.8 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 17 0.04 4 CO 32.23 0.00 22.49 34.03 20.51 5.24 5.60 6.47 6.89
792 41.7 kg/s 18.23 17.8 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 9.40 99.97 5.09 0.03 26.44 40.34 43.14 49.87 53.07
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 17 22 0.05 7 H2O-G 12.29 0.00 14.17 4.78 2.41 1.49 0.97 0.20 0.01
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.051 811 10 42.7
254.6 1.0 bar 0.051 0.70
0 806 2
DH water
254.6 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.8 30.6 bar
33.1 Meoh-convert
Methanol 1.00 SAND
converter 51
311
Total several DISTILLATION_STAGE's 1601 2055 4.82 11
36
40
CH4
AR
CH3OH
0.15
0.10
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.16
0.11
0.00
1.58 2.30 2.46
1.09 1.58 1.69
0.29 22.94 18.23
2.84
1.96
6.39
3.02
2.08
0.59
8.895 254.6 kg/s
90 C
2.085 254.6 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.92 17.8 kg/s
220 C 602
42.2 400.7
139.0 bar 607
29.8 150.7
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
95.88
Heatsourc-DH 127.3
31.4 705.5 783
41.7 946.3 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
51
42.2 kg/s
235 C
2
20
29.8 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 41.7 kg/s 17.7 18.12 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 31.4 kg/s 4 100 C 685 30.6 bar 6.1 Preheater-sy NG 93 kr/GJ Methanol 31.4 kr/s 136 kr/GJ 153 kr/GJ 3.05 kr/kg 2.4 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.7 kg/s 20 606 2 20 0.60 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 407 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 20 29.8 144.0 bar 39.3 336.1 DH water 0 kr/ton Syngas 1.0 kr/s 132 kr/GJ - kr/GJ 0.66 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.1 MW 19 0.90 148.9 29.8 kg/s 640 139.0 bar 91 7.937 2.9 61.49 Water 32 kr/ton DH water 0.5 kr/s 31 kr/GJ 6 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.116 63 C 2 39.3 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
142 0.78
Feed
17.7
3.895
30.6 bar
17.7 kg/s
220 C
Preheater-sy 43.39 181 C
Condenser-1
8.5
631 2.9 kg/s
4 181 C
Preheater-sy
Nomenclature:
Cond-steam-2 2.95 0.50 If methanol and DH share the plant costs
Condenser-1 94.1 16.18 621 631 4 (methanol and DH are the only products from the plant) -
14 705 706
21 3.5 bar
2 2.95 705 706
4 3.5 bar
6
SAND 31 33.6 207.8
643 139.0 bar
2 33.6 kg/s
6 139.0 bar
124 5.7 kg/s
134 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 21.8 kr/s 95 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
115 21.5 kg/s 24 4.4 kg/s Condenser 27.21 134 C Preheater-sy
DH water 11.1 kr/s 150 kr/Gjen Mass flow
124 C 124 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
34.0 1.0 bar
Reboil-meoh2 5.7
0.01 0.40
0 805 2
DH water
34.0 1.0 bar Mechanical power
10
14.27 22.0 106.1 1.189 34.0 kg/s 0.279 34.0 kg/s 2.943 4.4 21.39
707 3.5 bar Cond-steam-2 90 C 19.69 605 2 50 C 699 3.5 bar 0.25
708 22.0 kg/s SAND 393 Condenser
29.8 139.0 bar 1.6 7.83 Condenser
700 4.4 kg/s
4 124 C 148.8 29.8 kg/s 611 139.0 bar 96.8 6.483 2.2 48.98 2 124 C
Water /
Methanol
Methanol molar-% = 13.17
0 693 694
0 3.5 bar
2 0.5 kg/s
Dis_stage_1
4 11.33 695 696
17 3.5 bar
82 17.0 kg/s
2 32.9
11.37 0.64
11.37 705 706
17 3.5 bar
91 17.0 kg/s
4
30.6 625 635
11 3.5 bar
2
Methanol molar-% = 93.8
60 C
Comp-recirc
Methanol/
4 1.6 kg/s
1.036 60 C
Syngas Split-syngas
621 139.0 bar
631 2.2 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
124 C
Reboil-meoh1
124 C
Reboil-meoh1
234 10.8 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 4.5 -0 4.3 7.757
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 19.51 412 2
5EX 5 Component cost flow 2 4.5 kg/s 76.1 MW 201 2 4.3 kg/s 4.3 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.145 15 C SAND 76.14 0.16 850 C 223.6 4.3 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.28 803 4
19.4 1.0 bar
Electrolyser
25.16
3.2
0.80
0 802 2
19.4 1.0 bar DH water
0.93
Steam reformer
21.04
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.675 19.4 kg/s 4.0 0.531 0.5 59.53 0.159 19.4 kg/s 4.0 3.055
12 C
13 C/EX
SAND 1E-08 90 C
Electro-cool
3
4
1.0 bar
4.0 kg/s
2
4
1.0 bar
0.5 kg/s
50 C
Electro-cool
Comp-O2-2
1.4 MW 3
Reformat
12.7 217
403
2
10.0 bar
4.0 kg/s
0.0
0
Ash
0.0 2E-04
83 1.0 bar
4 0.0 kg/s
14 C/M
O2 5E-05 7 4 5E-05
0.90
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
5E-05 5 2
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
DH water
Gas
0.22 90 C
Electrolyser
0.0 1E-37
6 1.0 bar
4 0.0 kg/s
24.66 90 C
Electrolyser
H2 O2 0.22 401 2
4.0 1.0 bar
0.531 4.0 kg/s
90 C
SAND 1.377
0.708 402 4
0.94
0.708 4.0 10.0 bar
1.824 4.0 kg/s
431 C
431 10.0 bar
4 12.7 kg/s
21.04 950 C
NG_reformer
0.71 850 C
NG_reformer
1.4 24.49
441 10.0 bar
2 1.4 kg/s
2.375 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
5E-05
0.0
33 2
1.0 bar
Steam
32
0.0 0.009
1.0 bar
801
2
0.0 4E-05
1.0 bar
0.0 kg/s
15
4
0.0 1E-05
1.0 bar
0.0 kg/s Heatsink-H2
6E-38 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
3.7 63.04
10.0 bar
3.7 kg/s
1.8
0.71 0.97 Heatex-O2
SAND 11
0.001 0.0 kg/s Heatex-GG-st 4 0.0 kg/s 0 50 C 0 60 C 0.0 MW 322 24.66 0.0 MW 9 Comp-CO2 6.113 950 C
730 C SAND 7 0.00 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 9E-05 1.7 MW 7
Heatex-NG
0.89
0
Gasifier
0.0 0.115
0
0.0
0.104
Gasifier
10 GG2
0.00 0.78
1.0 bar 0.0
0.0 kg/s
800 C
0
0.0
0.104
11 2
1.0 bar
0.0 kg/s
752 C
Heatex-GG-st
0.00 0.99 0
0.0 0.0
0.099
12 2 0.00 0.74
1.0 bar 0.0
0.0 kg/s
130 C Heatex-GG-DH
0
0.0
0.099
13 2
1.0 bar
0.0 kg/s
60 C
1.00
Gas cleaner 0.0
0.0 0.099
14 1.0 bar
0.00
Heatsink
24.66
24.66 511 2
0.5 1.0 bar
59.53 0.5 kg/s
90 C
Heatsink-H2
23.43 503 4
18.5 19.7 bar
SAND 1.703
1.364 502 4 1.364 0.76 501 2
0.93
6.7 19.7 bar 6.7 1.0 bar
CO2
19.5 411 2
NG4.3
10.0 bar
219 4.3 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
7.6 129.5
10.0 bar
8.8
13 19.51 0.89
0 434 Water 2
0.3 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 0.0 kg/s 206.4 18.5 kg/s 4.589 6.7 kg/s 3.009 6.7 kg/s 2 7.6 kg/s 0.016 0.3 kg/s
2 0.0 kg/s 0.00 9 2 Heatex-GG-O2 0.0 0.004 0 21 4 0.0 60 C 255 C 279 C 15 C 12.56 950 C 107 C
0.00 120 C 0.0 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 24.66 512 2 25.88 524 4 19.0 268.3 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
5E-04 0.0 kg/s
790 C
Gasifier
2 0.0 kg/s
3E-04 120 C
Heatex-GG-st
2E-22 0.0 kg/s
60 C 521
Heatex-GG-DH 2
0.5 59.63
1.0 bar
0.5 kg/s
0.5
59.53
1.0 bar
0.5 kg/s
90 C
0.5
62.38
19.7 bar
0.5 kg/s
395 C
531
2
49.3
19.7 bar
19.0 kg/s
278 C
0.138 422 2
Water 4.3 10.0 bar
0.014 4.3 kg/s
17.9 Heatex-H2O
0.16 0.74 SAND 15
0 453 Water 4
Steam
811
0.0 2E-04
1.0 bar
24.67 90 C
Comp-GG-H2-1
Comp-GG-H2-1
1.4 MW 11
Mixer-GG-H2 Comp-GG-H2-2
40.8 25.27
Syngas-cool1
33 C
Heatex-H2O
0.5
0.029
10.0 bar
0.5 kg/s
4 0.0 kg/s 0.93
SAND 1.416 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.17 6.9 3.9 6 40.8 kg/s SAND 21 2.9 MW 5 7.0 Heatex-H2O
3.4 57.92 1.4
0.0 0.007 Heatex-GG-DH
0.5 60.94 563 1.0 bar 2.02 200 C 6.5 SAND 2.878 7.0 119 3.4 57.92 1.4 23.22
0.00
0.0
Steam_dryer Biomass (dry)
SAND 1
35 4 0.46 0.0 0.00 34 2
1.0 bar Steam dryer 0.00 0.0 1.0 bar
34 1.0 bar
4 0.0 kg/s
3E-04 730 C
Split-steam2
522 3.8 bar
2 0.5 kg/s
25.17 278 C
Cooler-GG-H2
2 6.9 kg/s
0.34 120 C
Cooler-GG-H2
1.1
0.34 0.85
25.17 523 2
0.5 3.8 bar
0.94
25.88
Syngas-cool1
561
2
2.021
40.8 23.12
1.0 bar
40.8 kg/s
120 C
2.03 0.85
0 541 4
0.0 19.7 bar
1E-17 0.0 kg/s
130 C
Water
Reformat
22.06 462 2 22.06
11.8 19.7 bar
202.6 11.8 kg/s
21.04 461 2
0.93
11.8 10.0 bar
199.9 11.8 kg/s
452 10.0 bar
2 7.0 kg/s
12.56 109 C
Mixer-NG_ref
433 10.0 bar
2 3.4 kg/s
6.113 107 C
Mixer-NG_ref
442 10.0 bar
2 1.4 kg/s
2.375 483 C
Mixer-NG_ref
0.028 0.0 kg/s 0.03 0.0 kg/s Cooler-GG-H2 6.9 4.264 60.51 0.5 kg/s Syngas-cool1 19.0 265.8 Syngas-cool1
249 C 154 C
120 C 0.0 0.115 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.7 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 6.9 kg/s Comp-GG-H2-2 2 19.0 kg/s
2
0.003
0.0 kg/s
15 C
Steam
0.34 200 C
Cooler-GG-H2
2.0 MW
SAND
13
1.998
49.3 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
0.0 0.002
41 1.0 bar
2 0.0 kg/s
Steam
0.93
51.65
19.0 271.9
533 59.4 bar
4 19.0 kg/s
Syngas 51.65 278 C
6.6 MW
SAND
15
6.616
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
116
0
0
Total
price
[mio. kr]
150
0
0
C
[kr/s]
0.35
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
219 MW
0 MW
76 MW
99 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
11 MW
0 MW
19 MW
SAND 79 2E-04 120 C 100.2 62.05 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 0 0 0.00
DH-condenser
0.91 0.0 0.28 811 12
DH condenser0.28
19.4 1.0 bar
581 1.0 bar
2 100.2 kg/s
4.97 200 C Steam
2.56 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
0
0
0
0
0
0.00
0.00
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
73% (with total power)
82%
0.0 1E-04 0.677 19.4 kg/s DH-cooler DH-cooler
51.5 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 31.9 51.5 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 0 0 0.00
4 0.0 kg/s
0 95 C
DH-condenser
DH-condenser
421.9 14.74
811 1.0 bar
0.019 811 6
95.3 1.0 bar
3.328 95.3 kg/s
0.48 16.0
DH cooler 0.02
0 804 2
DH water
95.3 1.0 bar
0.78 95.3 kg/s 1.0 0.639
2.551 562 2
51.5 1.0 bar
200 C
Syngas-cool2 8.2
2.56 0.88
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
0
6
1
0
8
1
0.00
0.02
0.00 Energy
Water
2 421.9 kg/s
0.36 90 C
DH
DH water
90 C
DH-cooler
100.2 56.74
35 1.0 bar
6 100.2 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.05 225 C
Cond-steam-1
29.18 51.5 kg/s
120 C
Syngas-cool2
534
2
18.0 268.8
59.4 bar
18.0 kg/s
0 551 4
1.0 59.4 bar
0.095 1.0 kg/s
141 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
219
4
7
13
8
285
5
9
17
10
0.66
0.01
0.02
0.04
0.02
Input:
NG
Biomass
Power*
Total power
210 MW
0 MW
76 MW
99 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
71 MW
0 MW
15 MW
Energy content in DH water = 71 MW 4.97 120 C
DH-cooler
Steam
51.65 141 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
6
0
8
0.00
0.02
* for electrolyser
Urenhed:
0.105 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.89
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
53.45 5.1 MW 17
SAND 5.075
18.0 273.5
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
9
3
30
1
12
3
39
0.00
0.03
0.01
0.09
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
72% (with power for electrolyser)
66% (with total power)
94%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.05 120 C 2 18.0 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 23 30 0.07
Cond-steam-1
53.45 260 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 475 618 1.43 Gas composition at specific nodes (mol-%)
51.97 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 6 8 0.02
793
794
3.5 bar
10.3 kg/s 601
96.3 629.5
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
7
3
9
0.01
0.02
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.45
4 100 C 2 96.3 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 2 0.00
Species
Split-meoh1
168.7 33.5 750.2 Steam
0 682 4
131 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
327
0
425
0
0.98
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 61.60 40.52 25.25 26.87 27.93 30.00
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
791 3.5 bar 14.8 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 11 14 0.03 4 CO 42.73 0.00 22.49 16.51 7.02 1.92 2.04 2.12 2.28
792 33.4 kg/s 15.14 14.8 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 6 8 0.02 6 CO2 5.24 0.00 5.09 15.32 47.39 53.36 56.77 59.02 63.39
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 14 18 0.04 7 H2O-G 5.21 0.00 14.17 6.18 2.09 5.95 3.06 1.57 0.05
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.041 811 10 34.2
204.2 1.0 bar 0.041 0.70
0 806 2
DH water
204.2 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.05 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
14.8 30.6 bar
27.5 Meoh-convert
Methanol 1.00 SAND
converter 132
311
Total several DISTILLATION_STAGE's 1298 1662 3.91 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.40
0.00
0.00
2.67 3.19
0.00 0.00
0.32 10.32
3.40
0.00
7.86
3.53
0.00
5.82
3.80
0.00
0.48
7.133 204.2 kg/s
90 C
1.672 204.2 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.256 14.8 kg/s
220 C 602
96.3 616.3
139.0 bar 607
78.3 357.5
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
116.7
Heatsourc-DH 168.7
23.1 519 783
33.5 757.9 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
132
96.3 kg/s
235 C
2
77
78.3 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 33.4 kg/s 14.7 15.03 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 23.1 kg/s 4 100 C 685 30.6 bar 16.0 Preheater-sy NG 93 kr/GJ Methanol 52.0 kr/s 225 kr/GJ 254 kr/GJ 5.05 kr/kg 4.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 14.7 kg/s 77 606 2 77 0.86 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 414 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 77 78.3 144.0 bar 91.5 541 DH water 0 kr/ton Syngas 4.1 kr/s 219 kr/GJ - kr/GJ 0.98 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.3 MW 19 0.90 352.6 78.3 kg/s 640 139.0 bar 49 15.06 4.9 69.64 Water 32 kr/ton DH water 0.4 kr/s 24 kr/GJ 5 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.292 63 C 2 91.5 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
172 0.69
Feed
14.7
3.232
30.6 bar
14.7 kg/s
220 C
Preheater-sy
117 166 C
Condenser-1
6.4
631 4.9 kg/s
4 166 C
Preheater-sy
Nomenclature:
Cond-steam-2 0.61 1.03 If methanol and DH share the plant costs
Condenser-1 59.3 10.87 621 631 4 (methanol and DH are the only products from the plant) -
3 705 706
16 3.5 bar
2 0.61 705 706
3 3.5 bar
6
SAND 31 88.4 489
643 139.0 bar
2 88.4 kg/s
3 139.0 bar
50 3.1 kg/s
146 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 45.8 kr/s 198 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
22 15.9 kg/s 4 3.0 kg/s Condenser 106.1 146 C Preheater-sy
DH water 10.6 kr/s 150 kr/Gjen Mass flow
136 C 136 C SAND 33 Condenser
Temperature
Dis_stage_1 0.02 811 8
103.1 1.0 bar
Reboil-meoh2 17.3
0.02 0.74
0 805 2
DH water
103.1 1.0 bar Mechanical power
10
3.185 19.5 14.31 3.601 103.1 kg/s 0.844 103.1 kg/s 0.605 3.0 2.217
707 3.5 bar Cond-steam-2 90 C 77.04 605 2 50 C 699 3.5 bar 0.25
708 19.5 kg/s SAND 393 Condenser
78.3 139.0 bar 4.1 18.54 Condenser
700 3.0 kg/s
4 136 C 352.4 78.3 kg/s 611 139.0 bar 77.9 25.02 5.9 114.4 2 136 C
Water /
Methanol
Methanol molar-% = 1.65
0 693 694
4 3.5 bar
3 3.6 kg/s
Dis_stage_1
4 2.58 695 696
13 3.5 bar
9 12.9 kg/s
2 27.3
2.613 0.69
2.613 705 706
13 3.5 bar
18 12.9 kg/s
4
50.95 625 635
14 3.5 bar
2
Methanol molar-% = 62.7
60 C
Comp-recirc
Methanol/
4 4.1 kg/s
4.055 60 C
Syngas Split-syngas
621 139.0 bar
631 5.9 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
136 C
Reboil-meoh1
136 C
Reboil-meoh1
234 13.9 kg/s
104 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 4.6 0.228 2.0 3.73
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 11.24 412 2
5EX 5 Component cost flow 2 4.6 kg/s 76.6 MW 201 2 2.0 kg/s 10.1 10.0 bar Biogas
6 EX_CH * Number of decimals Electrolyser 0.146 15 C SAND 76.58 0.07 850 C 226.6 10.1 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
891 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.281 803 4
19.5 1.0 bar
Electrolyser
25.31
3.3
0.79
0 802 2
19.5 1.0 bar DH water
0.93
Steam reformer
12.66
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.679 19.5 kg/s 4.1 0.534 0.5 59.87 0.16 19.5 kg/s 3.9 2.985
12 C
13 C/EX
SAND 1E-08 90 C
Electro-cool
3
4
1.0 bar
4.1 kg/s
2
4
1.0 bar
0.5 kg/s
50 C
Electro-cool
Comp-O2-2
1.3 MW 3
Reformat
16.1 217
403
2
10.0 bar
3.9 kg/s
0.0
0
Ash
0.0 2E-04
83 1.0 bar
4 0.0 kg/s
14 C/M
O2 5E-05 7 4 5E-05
0.90
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
5E-05 5 2
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
DH water
Gas
0.221 90 C
Electrolyser
0.1 0.015
6 1.0 bar
4 0.1 kg/s
24.8 90 C
Electrolyser
H2 O2 0.215 401 2
3.9 1.0 bar
0.519 3.9 kg/s
90 C
SAND 1.346
0.692 402 4
0.94
0.692 3.9 10.0 bar
1.782 3.9 kg/s
431 C
431 10.0 bar
4 16.1 kg/s
12.66 950 C
NG_reformer
0.69 850 C
NG_reformer
1.7 23.44
441 10.0 bar
2 1.7 kg/s
1.367 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
5E-05
0.0
33 2
1.0 bar
Steam
32
0.0 0.009
1.0 bar
801
2
0.0 4E-05
1.0 bar
0.0 kg/s
15
4
0.0 1E-05
1.0 bar
0.0 kg/s Heatsink-H2
0.006 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
9.9 134
10.0 bar
9.9 kg/s
1.8
0.69 0.97 Heatex-O2
SAND 11
0.001 0.0 kg/s Heatex-GG-st 4 0.0 kg/s 0 50 C 0 60 C 0.0 MW 322 24.8 0.0 MW 9 Comp-CO2 7.818 950 C
730 C SAND 7 0.00 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 9E-05 0.0 MW 7
Heatex-NG
0.89
0
Gasifier
0.0 0.115
0
0.0
0.104
Gasifier
10 GG2
0.00 0.78
1.0 bar 0.0
0.0 kg/s
800 C
0
0.0
0.104
11 2
1.0 bar
0.0 kg/s
752 C
Heatex-GG-st
0.00 0.99 0
0.0 0.0
0.099
12 2 0.00 0.74
1.0 bar 0.0
0.0 kg/s
130 C Heatex-GG-DH
0
0.0
0.099
13 2
1.0 bar
0.0 kg/s
60 C
1.00
Gas cleaner 0.0
0.0 0.099
14 1.0 bar
0.00
Heatsink
24.80
24.8 511 2
0.5 1.0 bar
59.87 0.5 kg/s
90 C
Heatsink-H2
13.79 503 4
15.4 21.2 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 21.2 bar 0.0 1.0 bar
CO2
11.22 411 2
Biogas 10.1 10.0 bar
215.8 10.1 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
4.4 59.5
10.0 bar
18.6
13 11.24 0.99
0 434 Water 2
0.5 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 0.0 kg/s 202.6 15.4 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 4.4 kg/s 0.047 0.5 kg/s
2 0.0 kg/s 0.00 9 2 Heatex-GG-O2 0.0 0.004 0 21 4 0.0 60 C 254 C 286 C 15 C 3.471 950 C 107 C
0.00 120 C 0.0 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 24.80 512 2 26.06 524 4 15.9 265 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
5E-04 0.0 kg/s
790 C
Gasifier
2 0.0 kg/s
3E-04 120 C
Heatex-GG-st
-0 0.0 kg/s
60 C 521
Heatex-GG-DH 2
0.5 59.97
1.0 bar
0.5 kg/s
0.5
59.87
1.0 bar
0.5 kg/s
90 C
0.5
62.82
21.2 bar
0.5 kg/s
403 C
531
2
39.86
21.2 bar
15.9 kg/s
283 C
0.065 422 2
Water 2.0 10.0 bar
0.115 2.0 kg/s
8.3 Heatex-H2O
0.07 0.75 SAND 15
0 453 Water 4
Steam
811
0.0 2E-04
1.0 bar
24.81 90 C
Comp-GG-H2-1
Comp-GG-H2-1
1.5 MW 11
Mixer-GG-H2 Comp-GG-H2-2
36.5 24.44
Syngas-cool1
45 C
Heatex-H2O
0.2
0.02
10.0 bar
0.2 kg/s
4 0.0 kg/s 0.93
SAND 1.463 571 1.0 bar Syngas-cool1 Comp-NG_ref 107 C
0.00 90 C 25.33 7.2 4.415 6 36.5 kg/s SAND 21 3.2 MW 5 4.2 Heatex-H2O
9.5 123.1 1.7
0.0 0.008 Heatex-GG-DH
0.5 61.33 563 1.0 bar 1.59 200 C 5.8 SAND 3.205 4.2 54.64 9.5 123.1 1.7 22.19
0.00
0.0
Steam_dryer Biomass (dry)
SAND 1
35 4 0.50 0.0 0.00 34 2
1.0 bar Steam dryer 0.00 0.0 1.0 bar
34 1.0 bar
4 0.0 kg/s
2E-04 730 C
Split-steam2
522 4.0 bar
2 0.5 kg/s
25.33 283 C
Cooler-GG-H2
2 7.2 kg/s
0.31 120 C
Cooler-GG-H2
1.1
0.31 0.84
25.33 523 2
0.5 4.0 bar
0.94
26.06
Syngas-cool1
561
2
1.589
36.5 22.51
1.0 bar
36.5 kg/s
120 C
1.59 0.84
0 541 4
0.0 21.2 bar
-0 0.0 kg/s
130 C
Water
Reformat
13.79 462 2 13.79
15.4 21.2 bar
202.6 15.4 kg/s
12.66 461 2
0.93
15.4 10.0 bar
199.6 15.4 kg/s
452 10.0 bar
2 4.2 kg/s
3.471 107 C
Mixer-NG_ref
433 10.0 bar
2 9.5 kg/s
7.818 107 C
Mixer-NG_ref
442 10.0 bar
2 1.7 kg/s
1.367 483 C
Mixer-NG_ref
0.03 0.0 kg/s 0.033 0.0 kg/s Cooler-GG-H2 7.2 4.793 60.88 0.5 kg/s Syngas-cool1 15.9 262.7 Syngas-cool1
254 C 151 C
120 C 0.0 0.115 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 21.2 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 7.2 kg/s Comp-GG-H2-2 2 15.9 kg/s
2
0.003
0.0 kg/s
15 C
Steam
0.31 200 C
Cooler-GG-H2
2.1 MW
SAND
13
2.072
39.86 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
0.0 0.002
41 1.0 bar
2 0.0 kg/s
Steam
0.93
41.96
15.9 268.2
533 63.3 bar
4 15.9 kg/s
Syngas 41.96 283 C
5.9 MW
SAND
15
5.921
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
116
0
0
Total
price
[mio. kr]
151
0
0
C
[kr/s]
0.35
0.00
0.00
Input:
Biogas
Biomass
Power*
Total power
* for electrolyser
216 MW
0 MW
77 MW
96 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
11 MW
0 MW
14 MW
SAND 79 2E-04 120 C 94.1 62.97 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 0 0 0.00
DH-condenser
0.91 0.0 0.28 811 12
DH condenser0.28
19.5 1.0 bar
581
2
4.10
1.0 bar
94.1 kg/s
200 C Steam
2.16 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
0
0
0
0
0
0.00
0.00
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
79% (with power for electrolyser)
74% (with total power)
82%
0.0 3E-04 0.681 19.5 kg/s DH-cooler DH-cooler
49.4 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 33.07 49.4 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 0 0 0.00
4 0.0 kg/s
0 95 C
DH-condenser
DH-condenser
407.0 14.22
811 1.0 bar
0.018 811 6
89.5 1.0 bar
3.126 89.5 kg/s
0.48 15.0 0 804 2
DH cooler
DH water
0.02 89.5 1.0 bar
0.733 89.5 kg/s 1.0 0.689
2.15 562 2
49.4 1.0 bar
200 C
Syngas-cool2 7.9
2.16 0.90
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
0
6
1
0
8
1
0.00
0.02
0.00 Energy
Water
2 407.0 kg/s
0.36 90 C
DH
DH water
90 C
DH-cooler
35
6
94.1 57.98
1.0 bar
94.1 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.04 225 C
Cond-steam-1
30.46 49.4 kg/s
120 C
Syngas-cool2
534
2
14.8 265.1
63.3 bar
14.8 kg/s
0 551 4
1.1 63.3 bar
0.165 1.1 kg/s
141 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
213
7
3
14
0
277
10
4
19
0
0.64
0.02
0.01
0.04
0.00
Input:
Biogas
Biomass
Power*
Total power
204 MW
0 MW
77 MW
96 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
68 MW
0 MW
12 MW
Energy content in DH water = 68 MW 4.10 120 C
DH-cooler
Steam
41.96 141 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
7
0
9
0.00
0.02
* for electrolyser
Urenhed:
0.035 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.96
Water /
671
1.0 0.616
1.0 bar
0.93
43.43
14.8
Comp-syngas2
4.2 MW 17
SAND 4.157
269
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
9
2
27
1
12
3
35
0.00
0.03
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
73% (with power for electrolyser)
68% (with total power)
95%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.04 120 C 2 14.8 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 19 24 0.06
Cond-steam-1
43.43 255 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 361 469 1.08 Gas composition at specific nodes (mol-%)
43.01 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 6 0.01
793
794
3.5 bar
10.3 kg/s 601
68.5 531.9
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
5
3
6
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.60
4 100 C 2 68.5 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
155.3 37.2 834.4 Steam
0 682 4
91 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
282
0
366
0
0.85
0.00
1
3
H2
N2
45.98
0.25
0.00 46.10 60.37 41.82 24.69 26.26 27.85 30.00
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
791 3.5 bar 16.8 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 12 16 0.04 4 CO 42.73 0.00 31.87 26.62 12.44 2.80 2.98 3.16 3.41
792 37.2 kg/s 17.17 16.8 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 6 8 0.02 6 CO2 5.24 0.00 8.15 6.82 40.23 50.62 53.85 57.11 61.51
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 15 20 0.05 7 H2O-G 5.21 0.00 13.43 5.81 2.28 3.78 2.10 0.88 0.03
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.046 811 10 38.0
226.9 1.0 bar 0.046 0.70
0 806 2
DH water
226.9 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.04 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
16.8 30.6 bar
31.1 Meoh-convert
Methanol 1.00 SAND
converter 92
311
Total several DISTILLATION_STAGE's 1118 1426 3.36 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.45
0.00
0.00
0.37
0.00
0.00
2.90 3.71 3.95
0.00 0.00 0.00
0.33 14.40 10.85
4.19
0.00
6.80
4.51
0.00
0.54
7.927 226.9 kg/s
90 C
1.858 226.9 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.691 16.8 kg/s
220 C 602
68.5 517
139.0 bar 607
53.7 264.5
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
112.3
Heatsourc-DH 155.3
26.9 603.3 783
37.2 843.1 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
92
68.5 kg/s
235 C
2
47
53.7 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 37.2 kg/s 16.6 17.05 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 26.9 kg/s 4 100 C 685 30.6 bar 11.1 Preheater-sy Biogas 55 kr/GJ Methanol 43.0 kr/s 186 kr/GJ 210 kr/GJ 4.18 kr/kg 3.3 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 16.6 kg/s 47 606 2 47 0.87 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 414 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 47 53.7 144.0 bar 64.6 442.4 DH water 0 kr/ton Syngas 2.5 kr/s 181 kr/GJ - kr/GJ 0.88 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.90 261.2 53.7 kg/s 640 139.0 bar 70 12.66 3.9 70.75 Water 32 kr/ton DH water 0.4 kr/s 25 kr/GJ 5 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.203 63 C 2 64.6 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
161 0.71
Feed
16.6
3.667
30.6 bar
16.6 kg/s
220 C
Preheater-sy 79.14 168 C
Condenser-1
6.3
631 3.9 kg/s
4 168 C
Preheater-sy
Nomenclature:
Cond-steam-2 0.93 1.03 If methanol and DH share the plant costs
Condenser-1 77.8 12.57 621 631 4 (methanol and DH are the only products from the plant) -
5 705 706
18 3.5 bar
2 0.93 705 706
3 3.5 bar
6
SAND 31 61.0 370.6
643 139.0 bar
2 61.0 kg/s
4 139.0 bar
70 3.6 kg/s
144 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 35.6 kr/s 154 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
38 17.8 kg/s 6 3.0 kg/s Condenser 66.57 144 C Preheater-sy
DH water 10.3 kr/s 150 kr/Gjen Mass flow
134 C 134 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
71.2 1.0 bar
Reboil-meoh2 11.9
0.01 0.75
0 805 2
DH water
71.2 1.0 bar Mechanical power
10
5.455 19.5 29.62 2.487 71.2 kg/s 0.583 71.2 kg/s 0.919 3.0 4.559
707 3.5 bar Cond-steam-2 90 C 47.2 605 2 50 C 699 3.5 bar 0.25
708 19.5 kg/s SAND 393 Condenser
53.7 139.0 bar 2.8 13.74 Condenser
700 3.0 kg/s
4 134 C 261 53.7 kg/s 611 139.0 bar 88.0 16.89 4.5 93.4 2 134 C
Water /
Methanol
Methanol molar-% = 3.59
0 693 694
2 3.5 bar
3 1.7 kg/s
Dis_stage_1
4 4.537 695 696
15 3.5 bar
23 14.8 kg/s
2 30.9
4.574 0.67
4.574 705 706
15 3.5 bar
32 14.8 kg/s
4
42.12 625 635
12 3.5 bar
2
Methanol molar-% = 78.8
60 C
Comp-recirc
Methanol/
4 2.8 kg/s
2.484 60 C
Syngas Split-syngas
621 139.0 bar
631 4.5 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
134 C
Reboil-meoh1
134 C
Reboil-meoh1
234 12.0 kg/s
102 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 18.6 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 18.6 kg/s 311.6 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.594 15 C SAND 311.6 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
1.144 803 4
79.1 1.0 bar
Electrolyser
103
13.2
0.80
0 802 2
79.1 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 2.762 79.1 kg/s 16.5 2.174 2.1 243.6 0.648 79.1 kg/s 0.0 0.002
12 C
13 C/EX
SAND 1E-08 90 C
Electro-cool
3
4
1.0 bar
16.5 kg/s
2
4
1.0 bar
2.1 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.0 2E-04
83 1.0 bar
4 0.0 kg/s
14 C/M
O2 5E-05 7 4 5E-05
0.90
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
5E-05 5 2
0.0 1.0 bar
1E-04 0.0 kg/s
90 C
Comp-O2-1
DH water
Gas
0.901 90 C
Electrolyser
16.5 2.173
6 1.0 bar
4 16.5 kg/s
100.9 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
3E-05
0.0
33 2
1.0 bar
Steam
32
0.0 0.009
1.0 bar
801
2
0.0 4E-05
1.0 bar
0.0 kg/s
15
4
0.0 1E-05
1.0 bar
0.0 kg/s Heatsink-H2
0.9 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
0.001 0.0 kg/s Heatex-GG-st 4 0.0 kg/s 0 50 C 0 60 C 0.0 MW 322 100.9 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.00 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 4E-04 4.4 MW 7
Heatex-NG
0.89
0
Gasifier
0.0 0.115
0
0.0
0.104
Gasifier
10 GG2
0.00 0.78
1.0 bar 0.0
0.0 kg/s
800 C
0
0.0
0.104
11 2
1.0 bar
0.0 kg/s
752 C
Heatex-GG-st
0.00 0.99 0
0.0 0.0
0.099
12 2 0.00 0.74
1.0 bar 0.0
0.0 kg/s
130 C Heatex-GG-DH
0
0.0
0.099
13 2
1.0 bar
0.0 kg/s
60 C
1.00
Gas cleaner 0.0
0.0 0.099
14 1.0 bar
0.00
Heatsink
#####
100.9 511 2
2.1 1.0 bar
243.6 2.1 kg/s
90 C
Heatsink-H2
3.806 503 4
19.6 14.6 bar
SAND 4.373
3.789 502 4 3.789 2.238 501 2
0.92
19.6 14.6 bar 19.6 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 0.0 kg/s 13.05 19.6 kg/s 12.91 19.6 kg/s 8.864 19.6 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 0.0 kg/s 0.00 9 2 Heatex-GG-O2 0.0 0.004 0 21 4 0.0 60 C 248 C 248 C 15 C 0.01 950 C 107 C
0.00 120 C 0.0 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner ##### 512 2 105.2 524 4 21.7 263.9 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
5E-04 0.0 kg/s
790 C
Gasifier
2 0.0 kg/s
2E-04 120 C
Heatex-GG-st
1E-22 0.0 kg/s
60 C 521
Heatex-GG-DH 2
2.1 243.7
1.0 bar
2.1 kg/s
2.1
243.6
1.0 bar
2.1 kg/s
90 C
2.1
253.1
14.6 bar
2.1 kg/s
322 C
531
2
109
14.6 bar
21.7 kg/s
292 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
0.0 2E-04
1.0 bar
##### 90 C
Comp-GG-H2-1
Comp-GG-H2-1
6.2 MW 11
Mixer-GG-H2 Comp-GG-H2-2
50.9 31.51
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 0.0 kg/s 0.93
SAND 6.215 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 103.1 30.8 17.44 6 50.9 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
0.0 0.007 Heatex-GG-DH
2.1 249.5 563 1.0 bar 1.32 200 C 8.1 SAND 0.001 0.0 0.094 0.0 0.046 0.0 0.018
0.00
0.0
Steam_dryer Biomass (dry)
SAND 1
35 4 0.46 0.0 0.00 34 2
1.0 bar Steam dryer 0.00 0.0 1.0 bar
34 1.0 bar
4 0.0 kg/s
1E-04 730 C
Split-steam2
522 4.2 bar
2 2.1 kg/s
103.1 292 C
Cooler-GG-H2
2 30.8 kg/s
0.80 120 C
Cooler-GG-H2
4.9
0.81 0.83
##### 523 2
2.1 4.2 bar
0.93
105.2
Syngas-cool1
561
2
1.322
50.9 28.82
1.0 bar
50.9 kg/s
120 C
1.33 0.83
0 541 4
0.0 14.6 bar
7E-21 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 14.6 bar
0.159 0.0 kg/s
0.017 461 2
0.92
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
0.028 0.0 kg/s 0.03 0.0 kg/s Cooler-GG-H2 30.8 19.06 247.5 2.1 kg/s Syngas-cool1 21.7 260.7 Syngas-cool1
206 C 154 C
120 C 0.0 0.115 271 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 14.6 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 30.8 kg/s Comp-GG-H2-2 2 21.7 kg/s
2
0.003
0.0 kg/s
15 C
Steam
0.81 200 C
Cooler-GG-H2
5.9 MW
SAND
13
5.922
109 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
0.0 0.002
41 1.0 bar
2 0.0 kg/s
Steam
0.93
112
21.7 268.4
533 51.1 bar
4 21.7 kg/s
Syngas112
292 C
8.2 MW
SAND
15
8.248
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
474
0
0
Total
price
[mio. kr]
616
0
0
C
[kr/s]
1.43
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
0 MW
312 MW
345 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
13 MW
2 MW
18 MW
SAND 79 1E-04 120 C 133.5 82.69 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 0 0 0.00
DH-condenser
0.91 0.0 1.14 811 12
DH condenser1.14
79.1 1.0 bar
581 1.0 bar
2 133.5 kg/s
3.48 200 C Steam
1.33 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
0
0
0
0
0
0.00
0.00
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
74% (with power for electrolyser)
67% (with total power)
77%
0.0 1E-04 2.764 79.1 kg/s DH-cooler DH-cooler
50.9 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 31.51 50.9 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 0 0 0.00
4 0.0 kg/s
0 95 C
DH-condenser
DH-condenser
500.0 17.47
811 1.0 bar
0.026 811 6
126.9 1.0 bar
4.432 126.9 kg/s
0.48 21.3 0 804 2
DH cooler
DH water
0.03 126.9 1.0 bar
1.039 126.9 kg/s 1.0 0.639
1.322 562 2
50.9 1.0 bar
200 C
Syngas-cool2 8.1
1.33 0.83
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
0
0
0
0
0
0
0.00
0.00
0.00 Energy
Water
2 500.0 kg/s
1.23 90 C
DH
DH water
90 C
DH-cooler
133.5 75.62
35 1.0 bar
6 133.5 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.03 225 C
Cond-steam-1
28.82 50.9 kg/s
120 C
Syngas-cool2
534
2
21.7 265.1
51.1 bar
21.7 kg/s
0 551 4
0.0 51.1 bar
-0 0.0 kg/s
130 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
20
0
0
0
0
26
0.00
0.00
0.00
0.00
0.06
Input:
NG
Biomass
Power*
Total power
0MW
0 MW
312 MW
345 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
84 MW
0 MW
14 MW
Energy content in DH water = 84 MW 3.48 120 C
DH-cooler
Steam
112 130 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
28
0
36
0.00
0.08
* for electrolyser
Urenhed:
0.493 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.51
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
114.3 6.6 MW 17
SAND 6.637
21.7 271.3
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
27
3
37
3
35
4
48
0.01
0.08
0.01
0.11
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
66% (with power for electrolyser)
59% (with total power)
88%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 4 0.01
0.03 120 C 2 21.7 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 30 39 0.09
Cond-steam-1
114.3 261 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 580 754 1.74 Gas composition at specific nodes (mol-%)
109.1 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 8 11 0.02
793
794
3.5 bar
10.3 kg/s 601
124.5 616.7
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
9
5
11
0.01
0.03
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.31
4 100 C 2 124.5 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 2 2 0.00
Species
Split-meoh1
288.4 27.3 610.7 Steam
0 682 4
272 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
384
0
499
0
1.16
0.00
1
3
H2
N2
45.98
0.25
0.00 57.70 69.78 42.28 25.26 26.98 28.07 30.00
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
791 3.5 bar 10.2 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 7 10 0.02 4 CO 42.73 0.00 22.49 0.02 1.26 1.53 1.63 1.70 1.82
792 27.3 kg/s 10.43 10.2 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 9 11 0.03 6 CO2 5.24 0.00 5.09 30.18 56.10 57.00 60.87 63.33 67.68
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 11 14 0.03 7 H2O-G 5.21 0.00 14.17 0.01 0.04 7.99 4.02 2.00 0.06
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 ##### 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.033 811 10 27.8
167.0 1.0 bar 0.033 0.70
0 806 2
DH water
167.0 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.03 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
10.2 30.6 bar
18.9 Meoh-convert
Methanol 1.00 SAND
converter 274
311
Total several DISTILLATION_STAGE's 1636 2102 4.92 11
36
40
CH4
AR
CH3OH
0.48
0.12
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.30
0.00
0.00
8.22
0.00
0.00
6.48
0.00
0.00
4.90
0.00
0.00
0.44
5.835 167.0 kg/s
90 C
1.368 167.0 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
2.242 10.2 kg/s
220 C 602
124.5 606.5
139.0 bar 607
102.8 346.2
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
179.2
Heatsourc-DH 288.4
17.0 379.6 783
27.3 617 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2 124.5 kg/s
274 235 C
2 102.8 kg/s
158 225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 27.3 kg/s 10.1 10.31 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 16.9 kg/s 4 100 C 685 30.6 bar 20.3 Preheater-sy NG 93 kr/GJ Methanol 109.1 kr/s 472 kr/GJ 532 kr/GJ 10.60 kr/kg 8.3 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 10.1 kg/s 158 606 2 158 0.84 SAND 29 Biomass 32 kr/GJ Oxygen 0.9 kr/s 414 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 158 102.8 144.0 bar 118.5 534.7 DH water 0 kr/ton Syngas 8.3 kr/s 463 kr/GJ - kr/GJ 1.53 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.4 MW 19 0.90 340.1 102.8 kg/s 640 139.0 bar 34 29.5 6.0 64.61 Water 32 kr/ton DH water 1.2 kr/s 70 kr/GJ 15 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.369 63 C 2 118.5 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
293 0.64
Feed
10.1
2.217
30.6 bar
10.1 kg/s
220 C
Preheater-sy 244.1 169 C
Condenser-1
8.7
631 5.9 kg/s
4 169 C
Preheater-sy
Nomenclature:
Cond-steam-2 1.33 1.00 If methanol and DH share the plant costs
Condenser-1 45.7 22.79 621 631 4 (methanol and DH are the only products from the plant) -
4 705 706
13 3.5 bar
2 1.33 705 706
4 3.5 bar
6
SAND 31 114.8 482.4
643 139.0 bar
2 114.8 kg/s
4 139.0 bar
50 3.7 kg/s
147 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 106.9 kr/s 463 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
14 12.8 kg/s 5 4.1 kg/s Condenser 221.3 147 C Preheater-sy
DH water 12.6 kr/s 150 kr/Gjen Mass flow
137 C 137 C SAND 33 Condenser
Temperature
Dis_stage_1 0.03 811 8
127.0 1.0 bar
Reboil-meoh2 21.3
0.03 0.74
0 805 2
DH water
127.0 1.0 bar Mechanical power
10
4.182 18.8 8.949 4.437 127.0 kg/s 1.04 127.0 kg/s 1.324 4.1 1.933
707 3.5 bar Cond-steam-2 90 C 157.4 605 2 50 C 699 3.5 bar 0.25
708 18.8 kg/s SAND 393 Condenser
102.8 139.0 bar 5.4 17.88 Condenser
700 4.1 kg/s
4 137 C 339.8 102.8 kg/s 611 139.0 bar 69.8 55.66 6.7 120.2 2 137 C
Water /
Methanol
Methanol molar-% = 0.98
0 693 694
6 3.5 bar
3 6.0 kg/s
Dis_stage_1
4 2.858 695 696
9 3.5 bar
4 8.8 kg/s
2 18.7
2.881 0.69
2.881 705 706
9 3.5 bar
10 8.8 kg/s
4
107.9 625 635
16 3.5 bar
2
Methanol molar-% = 49.7
60 C
Comp-recirc
Methanol/
4 5.4 kg/s
8.283 60 C
Syngas Split-syngas
621 139.0 bar
631 6.7 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
137 C
Reboil-meoh1
137 C
Reboil-meoh1
234 16.3 kg/s
107 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

25. Flowsheets for metanolanlæg – for
parametervariationen (metanolreaktortryk)
Flowsheets for metanolreaktortryk på 40 bar, 82,7 bar og 200 bar.
Sorteret efter metanolreaktortryk – anlægget på 40 bar først.

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.7 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 3.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.7 kg/s 44.8 MW 201 2 0.0 kg/s 0.0 3.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.085 15 C SAND 44.77 0.00 850 C 0.175 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
656 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.515 803 4
129.3 1.0 bar
Electrolyser
14.8
1.9
0.80
0 802 2
129.3 1.0 bar DH water
0.92
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 1.275 129.3 kg/s 2.4 0.312 0.3 35.01 1.058 129.3 kg/s 0.0 0.002
12 C
13 C/EX
SAND 3E-05 54 C
Electro-cool
3
4
1.0 bar
2.4 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.168
403
2
3.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.492
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.126 7 4 0.126
0.90
2.4 1.0 bar
0.312 2.4 kg/s
90 C
Comp-O2-1
0.126 5 2
2.4 1.0 bar
0.312 2.4 kg/s
90 C
Comp-O2-1
DH water
Gas
0.126 90 C
Electrolyser
0.0 -0
6 1.0 bar
4 0.0 kg/s
14.15 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 4E-04
3E-04 402 4
0.92
3E-04 0.0 3.0 bar
8E-04 0.0 kg/s
231 C
431 3.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.02
441 3.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.014
3.1
33 2
1.0 bar
Steam
32
17.0 21.92
1.0 bar
801
2
13.7 0.112
1.0 bar
13.7 kg/s
15
4
3.0 1.377
1.0 bar
3.0 kg/s Heatsink-H2
-0 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.048
3.0 bar
0.0 kg/s
0.0
0.00 0.95 Heatex-O2
SAND 11
4.007 3.1 kg/s Heatex-GG-st 4 17.0 kg/s 0 50 C 0 60 C 0.0 MW 322 14.15 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.07 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 5E-05 0.0 MW 7
Heatex-NG
0.89
11
Gasifier
12.9 282.2
11
17.8
257
Gasifier
10 GG2
0.13 0.78
1.0 bar 1.7
17.8 kg/s
800 C
11
17.8
255.8
11 2
1.0 bar
17.8 kg/s
754 C
Heatex-GG-st
0.07 0.98 11
21.8 17.8
243.3
12 2 0.00 0.74
1.0 bar 2.3
17.8 kg/s
130 C Heatex-GG-DH
11
17.8
242.8
13 2
1.0 bar
17.8 kg/s
60 C
1.00
Gas cleaner 10.6
14.8 242.2
14 1.0 bar
0.00
Heatsink
14.15
14.15 511 2
0.3 1.0 bar
35.01 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 7.5 bar
SAND 0.002
0.002 502 4 0.002 0.001 501 2
0.92
0.0 7.5 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
3.0 bar
0.171 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.1
3.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 3.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 14.8 kg/s 0.162 0.0 kg/s 0.006 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 4E-06 0.0 kg/s
2 12.9 kg/s 0.13 9 2 Heatex-GG-O2 17.0 9.643 0 21 4 10.6 60 C 213 C 182 C 15 C 0.01 950 C 79 C
7.72 120 C 2.4 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 14.15 512 2 28.02 524 4 15.1 284.6 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.271 2.4 kg/s
790 C
Gasifier
2 17.0 kg/s
0.049 120 C
Heatex-GG-st
2E-19 0.0 kg/s
60 C 521
Heatex-GG-DH 2
15.1 277
1.0 bar
15.1 kg/s
0.3
35.01
1.0 bar
0.3 kg/s
90 C
15.1
284.4
7.5 bar
15.1 kg/s
228 C
531
2
28.04
7.5 bar
15.1 kg/s
228 C
1E-04 422 2
Water 0.0 3.0 bar
2E-06 0.0 kg/s
0.0 Heatex-H2O
0.00 0.68 SAND 15
0 453 Water 4
Steam
811
13.7 0.479
1.0 bar
24.72 64 C
Comp-GG-H2-1
Comp-GG-H2-1
5.8 MW 11
Mixer-GG-H2 Comp-GG-H2-2
57.1 33.33
Syngas-cool1
23 C
Heatex-H2O
0.0
7E-06
3.0 bar
0.0 kg/s
4 13.7 kg/s 0.92
SAND 5.817 571 1.0 bar Syngas-cool1 Comp-NG_ref 79 C
0.00 90 C 26.79 57.0 32.29 6 57.1 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.044 0.0
13.9 17.91 Heatex-GG-DH
15.1 282.4 563 1.0 bar 0.17 150 C 3.4 SAND 0.003 0.0 0.092 0.0 0.044 0.0 0.019
0.63
219.1
Steam_dryer Biomass (dry)
SAND 1
35 4 0.52 32.9 0.63 34 2
1.0 bar Steam dryer 7.72 207.5 1.0 bar
34 1.0 bar
4 13.9 kg/s
0.061 730 C
Split-steam2
522 3.7 bar
2 15.1 kg/s
26.79 228 C
Cooler-GG-H2
2 57.0 kg/s
0.16 120 C
Cooler-GG-H2
3.4
0.17 0.81
26.79 523 2
15.1 3.7 bar
0.92
28.02
Syngas-cool1
561
2
0.163
57.1 32.32
1.0 bar
57.1 kg/s
120 C
0.17 0.81
0 541 4
0.0 7.5 bar
3E-18 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 7.5 bar
0.157 0.0 kg/s
0.016 461 2
0.92
0.0 3.0 bar
0.154 0.0 kg/s
452 3.0 bar
2 0.0 kg/s
0.01 79 C
Mixer-NG_ref
433 3.0 bar
2 0.0 kg/s
0.005 79 C
Mixer-NG_ref
442 3.0 bar
2 0.0 kg/s
0.002 303 C
Mixer-NG_ref
124.1 219.1 kg/s 128.5 207.5 kg/s Cooler-GG-H2 57.0 33.29 281.2 15.1 kg/s Syngas-cool1 15.1 283.3 Syngas-cool1
226 C 108 C
120 C 24.6 283.1 200 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 7.5 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 57.0 kg/s Comp-GG-H2-2 2 15.1 kg/s
2
7.577
24.6 kg/s
15 C
Steam
0.17 150 C
Cooler-GG-H2
3.5 MW
SAND
13
3.49
28.04 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
8.5 4.827
41 1.0 bar
2 8.5 kg/s
Steam
0.92
29.28
15.1 286.5
533 15.2 bar
4 15.1 kg/s
Syngas 29.28 228 C
3.5 MW
SAND
15
3.493
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
68
0
0
Total
price
[mio. kr]
88
0
0
C
[kr/s]
0.20
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
283 MW
45 MW
65 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
11 MW
0 MW
35 MW
SAND 79 0.024 120 C 1.0 0.59 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 900 1170 2.71
DH-condenser
0.72 19.8 0.56 811 12
DH condenser0.56
129.3 1.0 bar
581
2
0.00
1.0 bar
1.0 kg/s
159 C Steam
0.17 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
9
1
1
11
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
70% (with power for electrolyser)
66% (with total power)
80%
8.5 0.336 4.516 129.3 kg/s DH-cooler DH-cooler
57.1 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 33.33 57.1 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 48 62 0.14
4 8.5 kg/s
0 95 C
DH-condenser
DH-condenser
428.0 14.95
811 1.0 bar
0.000 811 6
0.5 1.0 bar
0.016 0.5 kg/s
0.53 0.1 0 804 2
DH cooler
DH water
0.00 0.5 1.0 bar
0.004 0.5 kg/s 23.4 14.99
0.163 562 2
57.1 1.0 bar
150 C
Syngas-cool2 3.4
0.17 0.81
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
8
0
0
10
0
0
0.02
0.00
0.00 Energy
Water
2 428.0 kg/s
0.62 90 C
DH
DH water
90 C
DH-cooler
35
6
1.0 0.566
1.0 bar
1.0 kg/s
50 C
DH-cooler
571 1.0 bar
10 23.4 kg/s
0.07 225 C
Cond-steam-1
32.32 57.1 kg/s
120 C
Syngas-cool2
534
2
15.1 285.3
15.2 bar
15.1 kg/s
0 551 4
0.0 15.2 bar
-0 0.0 kg/s
130 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
237 MW
45 MW
65 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
33 MW
Energy content in DH water = 72 MW 0.00 120 C
DH-cooler
Steam
29.28 130 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
26
0
34
0.00
0.08
* for electrolyser
Urenhed:
0.026 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.97
Water /
671
23.4 13.28
1.0 bar
0.93
Comp-syngas2
31.04 5.0 MW 17
SAND 4.957
15.1 289.9
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
16
1
16
2
20
2
20
0.00
0.05
0.00
0.05
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
73% (with power for electrolyser)
68% (with total power)
103%
Methanol
2 23.4 kg/s 535 40.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 1 2 0.00
0.06 120 C 2 15.1 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 22 29 0.07
Cond-steam-1
31.04 269 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 550 715 1.65 Gas composition at specific nodes (mol-%)
29.63 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 7 9 0.02
793
794
3.5 bar
10.3 kg/s 601
101.6 969.3
40.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
8
0
10
0.00
0.02
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.47
4 100 C 2 101.6 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 6 8 0.02
Species
Split-meoh1
80.83 28.1 630.4 Steam
0 682 4
115 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
249
2
324
3
0.75
0.01
1
3
H2
N2
46.08
0.24
0.00 57.09 55.57 36.59 27.41 27.41 27.41 30.00
0.00 0.00 0.22 1.16 1.36 1.36 1.36 1.48
791 3.5 bar 18.7 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 12 16 0.04 4 CO 40.49 0.00 22.34 37.67 30.98 26.18 26.18 26.18 28.65
792 28.1 kg/s 19.14 18.7 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 0 0 0.00 6 CO2 6.19 99.94 4.97 0.02 25.64 31.56 31.56 31.56 34.54
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 11 15 0.03 7 H2O-G 6.51 0.00 15.55 6.07 1.58 0.28 0.28 0.28 0.03
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.035 811 10 28.7
171.4 1.0 bar 0.035 0.70
0 806 2
DH water
171.4 1.0 bar
0 683 2
2.6 30.6 bar
4.9
0.07 0.81
0 684 4
2.6 30.6 bar
Water
0 681 2
18.7 30.6 bar
34.7 Meoh-convert
Methanol 1.00 SAND
converter 116
311
Total several DISTILLATION_STAGE's 1963 2537 5.91 11
36
40
CH4
AR
CH3OH
0.36
0.12
0.00
0.00
0.00
0.00
0.05
0.00
0.00
0.34
0.11
0.00
1.75 2.05 2.05 2.05
0.56 0.65 0.65 0.65
1.74 10.51 10.51 10.51
2.24
0.71
2.35
5.989 171.4 kg/s
90 C
1.404 171.4 kg/s
50 C
2.691 2.6 kg/s
235 C
0.579 2.6 kg/s
220 C
4.116 18.7 kg/s
220 C 602
101.6 952.6
35.0 bar 607
86.4 679.7
40.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
51.2
Heatsourc-DH 80.83
17.8 399.3 783
28.1 637 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2 101.6 kg/s
116 235 C
2
84
86.4 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 28.1 kg/s 16.1 16.45 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 17.8 kg/s 4 100 C 685 30.6 bar 17.7 Preheater-sy NG 93 kr/GJ Methanol 29.6 kr/s 128 kr/GJ 145 kr/GJ 2.88 kr/kg 2.3 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 16.1 kg/s 84 606 2 84 0.89 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 404 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 84 86.4 40.0 bar 101.6 946.4 DH water 0 kr/ton Syngas 4.4 kr/s 124 kr/GJ - kr/GJ 0.96 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 1.4 MW 19 0.90 674.2 86.4 kg/s 640 35.0 bar 1 2E-28 0.0 2E-27 Water 32 kr/ton DH water 0.6 kr/s 42 kr/GJ 9 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 1.437 73 C 2 101.6 kg/s 621 35.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
99 0.80
Feed
16.1
3.537
30.6 bar
16.1 kg/s
220 C
Preheater-sy 116.4 110 C
Condenser-1
0.1
631 0.0 kg/s
4 110 C
Preheater-sy
Nomenclature:
Cond-steam-2 0.08 1.06 If methanol and DH share the plant costs
Condenser-1 0.0 -0 621 631 4 (methanol and DH are the only products from the plant) -
18 705 706
17 3.5 bar
2 0.08 705 706
0 3.5 bar
6
SAND 31 101.6 946.3
643 35.0 bar
2 101.6 kg/s
0
0
35.0 bar
0.0 kg/s
109 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 23.8 kr/s 103 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
151 17.1 kg/s 1 0.0 kg/s Condenser 116.4 109 C Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Mass flow
118 C 118 C SAND 33 Condenser
Temperature
Dis_stage_1 0.02 811 8
113.1 1.0 bar
Reboil-meoh2 19.0
0.02 0.64
0 805 2
DH water
113.1 1.0 bar Mechanical power
10
18.44 17.4 145.3 3.951 113.1 kg/s 0.926 113.1 kg/s 0.084 0.1 0.652
707 3.5 bar Cond-steam-2 90 C 83.21 605 2 50 C 699 3.5 bar 0.25
708 17.4 kg/s SAND 393 Condenser
86.4 35.0 bar 4.5 35.41 Condenser
700 0.0 kg/s
4 118 C 672.9 86.4 kg/s 611 35.0 bar 97.0 28.85 10.6 233.3 2 118 C
Water /
Methanol
Methanol molar-% = 24.82
0 693 694
0 3.5 bar
2 0.3 kg/s
Dis_stage_1
4 18.35 695 696
17 3.5 bar
142 17.0 kg/s
2 29.9
18.39 0.61
18.39 705 706
17 3.5 bar
150 17.0 kg/s
4
28.85 625 635
11 3.5 bar
2
Methanol molar-% = 97.0
60 C
Comp-recirc
Methanol/
4 4.5 kg/s
4.379 60 C
Syngas Split-syngas
621 35.0 bar
631 10.6 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
118 C
Reboil-meoh1
118 C
Reboil-meoh1
233 10.6 kg/s
61 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.5 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.5 kg/s 41.4 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.079 15 C SAND 41.44 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.444 803 4
109.3 1.0 bar
Electrolyser
13.69
1.8
0.80
0 802 2
109.3 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 1.096 109.3 kg/s 2.2 0.289 0.3 32.4 0.895 109.3 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 54 C
Electro-cool
3
4
1.0 bar
2.2 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.458
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.117 7 4 0.117
0.90
2.2 1.0 bar
0.289 2.2 kg/s
90 C
Comp-O2-1
0.117 5 2
2.2 1.0 bar
0.289 2.2 kg/s
90 C
Comp-O2-1
DH water
Gas
0.117 90 C
Electrolyser
0.0 -0
6 1.0 bar
4 0.0 kg/s
13.13 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.018
3.7
33 2
1.0 bar
Steam
32
16.8 21.69
1.0 bar
801
2
13.5 0.11
1.0 bar
13.5 kg/s
15
4
3.5 1.625
1.0 bar
3.5 kg/s Heatsink-H2
-0 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
4.763 3.7 kg/s Heatex-GG-st 4 16.8 kg/s 0 50 C 0 60 C 0.0 MW 322 13.13 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.08 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 5E-05 0.0 MW 7
Heatex-NG
0.89
10
Gasifier
12.0 262.9
10
17.3
240.2
Gasifier
10 GG2
0.12 0.78
1.0 bar 1.6
17.3 kg/s
800 C
10
17.3
239
11 2
1.0 bar
17.3 kg/s
757 C
Heatex-GG-st
0.08 0.98 10
21.6 17.3
226.7
12 2 0.00 0.74
1.0 bar 2.3
17.3 kg/s
130 C Heatex-GG-DH
10
17.3
226.2
13 2
1.0 bar
17.3 kg/s
60 C
1.00
Gas cleaner 9.9
13.8 225.4
14 1.0 bar
0.00
Heatsink
13.13
13.13 511 2
0.3 1.0 bar
32.4 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 12.7 bar
SAND 0.002
0.002 502 4 0.002 0.001 501 2
0.92
0.0 12.7 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 13.8 kg/s 0.164 0.0 kg/s 0.006 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 12.0 kg/s 0.12 9 2 Heatex-GG-O2 16.8 9.543 0 21 4 9.9 60 C 200 C 233 C 15 C 0.01 950 C 107 C
7.19 120 C 2.2 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 13.13 512 2 27.14 524 4 14.1 266.9 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.176 2.2 kg/s
790 C
Gasifier
2 16.8 kg/s
0.058 120 C
Heatex-GG-st
2E-18 0.0 kg/s
60 C 521
Heatex-GG-DH 2
14.1 257.7
1.0 bar
14.1 kg/s
0.3
32.4
1.0 bar
0.3 kg/s
90 C
14.1
266.7
12.7 bar
14.1 kg/s
269 C
531
2
27.16
12.7 bar
14.1 kg/s
269 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
13.5 0.47
1.0 bar
22.98 64 C
Comp-GG-H2-1
Comp-GG-H2-1
7.0 MW 11
Mixer-GG-H2 Comp-GG-H2-2
29.3 18.13
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 13.5 kg/s 0.93
SAND 6.976 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.46 29.2 16.56 6 29.3 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
13.1 16.93 Heatex-GG-DH
14.1 264.1 563 1.0 bar 0.11 200 C 4.6 SAND 7E-04 0.0 0.094 0.0 0.046 0.0 0.018
0.38
110.5
Steam_dryer Biomass (dry)
SAND 1
35 4 0.45 30.6 0.38 34 2
1.0 bar Steam dryer 7.19 99.7 1.0 bar
34 1.0 bar
4 13.1 kg/s
0.066 730 C
Split-steam2
522 4.8 bar
2 14.1 kg/s
25.46 269 C
Cooler-GG-H2
2 29.2 kg/s
0.10 120 C
Cooler-GG-H2
4.6
0.11 0.86
25.46 523 2
14.1 4.8 bar
0.93
27.14
Syngas-cool1
561
2
0.101
29.3 16.58
1.0 bar
29.3 kg/s
120 C
0.11 0.86
0 541 4
0.0 12.7 bar
1E-17 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 12.7 bar
0.158 0.0 kg/s
0.017 461 2
0.92
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
62.6 110.5 kg/s 68.17 99.7 kg/s Cooler-GG-H2 29.2 18.11 262.3 14.1 kg/s Syngas-cool1 14.1 265.1 Syngas-cool1
186 C 154 C
120 C 22.9 263.7 275 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 12.7 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 29.2 kg/s Comp-GG-H2-2 2 14.1 kg/s
2
7.057
22.9 kg/s
15 C
Steam
0.11 200 C
Cooler-GG-H2
4.7 MW
SAND
13
4.742
27.16 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
7.1 4.043
41 1.0 bar
2 7.1 kg/s
Steam
0.93
28.84
14.1 269.5
533 33.5 bar
4 14.1 kg/s
Syngas 28.84 269 C
4.7 MW
SAND
15
4.745
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
63
0
0
Total
price
[mio. kr]
82
0
0
C
[kr/s]
0.19
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
264 MW
41 MW
64 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
16 MW
SAND 79 0.025 120 C 2.3 1.434 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 838 1089 2.52
DH-condenser
0.72 16.5 0.49 811 12
DH condenser0.49
109.3 1.0 bar
581
2
0.01
1.0 bar
2.3 kg/s
200 C Steam
0.11 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
9
1
1
11
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
76% (with power for electrolyser)
71% (with total power)
79%
7.1 0.281 3.817 109.3 kg/s DH-cooler DH-cooler
29.3 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 18.17 29.3 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 44 58 0.13
4 7.1 kg/s
0 95 C
DH-condenser
DH-condenser
430.0 15.02
811 1.0 bar
0.000 811 6
2.2 1.0 bar
0.077 2.2 kg/s
0.48 0.4 0 804 2
DH cooler
DH water
0.00 2.2 1.0 bar
0.018 2.2 kg/s 1.0 0.639
0.101 562 2
29.3 1.0 bar
200 C
Syngas-cool2 4.7
0.11 0.86
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
7
0
0
9
0
0
0.02
0.00
0.00 Energy
Water
2 430.0 kg/s
0.55 90 C
DH
DH water
90 C
DH-cooler
35
6
2.3 1.311
1.0 bar
2.3 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
16.62 29.3 kg/s
120 C
Syngas-cool2
534
2
14.1 267.7
33.5 bar
14.1 kg/s
0 551 4
0.0 33.5 bar
8E-04 0.0 kg/s
130 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
221 MW
41 MW
64 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
72 MW
0 MW
14 MW
Energy content in DH water = 72 MW 0.01 120 C
DH-cooler
Steam
28.84 130 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
31
0
41
0.00
0.09
* for electrolyser
Urenhed:
0.027 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.97
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
30.39 4.4 MW 17
SAND 4.371
14.1 271.7
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
21
2
21
2
28
2
28
0.01
0.06
0.01
0.06
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
102%
Methanol
2 1.0 kg/s 535 82.7 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 2 2 0.01
0.00 120 C 2 14.1 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 20 26 0.06
Cond-steam-1
30.39 259 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 386 502 1.16 Gas composition at specific nodes (mol-%)
30.53 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 5 6 0.01
793
794
3.5 bar
10.3 kg/s 601
73.6 574.2
82.7 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
7
0
9
0.00
0.02
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.58
4 100 C 2 73.6 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 2 2 0.01
Species
Split-meoh1
97.81 33.0 740.6 Steam
0 682 4
69 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
258
0
336
0
0.78
0.00
1
3
H2
N2
46.05
0.23
0.00 57.70 55.98 39.11 25.78 26.50 26.59 30.00
0.00 0.00 0.22 1.54 1.93 1.99 1.99 2.25
791 3.5 bar 18.5 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 14 18 0.04 4 CO 37.19 0.00 22.49 35.29 18.28 7.82 8.04 8.07 9.10
792 33.0 kg/s 18.92 18.5 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 0 0 0.00 6 CO2 7.54 99.96 5.09 0.02 35.12 46.46 47.76 47.92 54.07
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 13 18 0.04 7 H2O-G 8.62 0.00 14.17 8.14 2.87 1.30 0.93 0.89 0.03
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.041 811 10 33.7
201.4 1.0 bar 0.041 0.70
0 806 2
DH water
201.4 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
18.5 30.6 bar
34.3 Meoh-convert
Methanol 1.00 SAND
converter 70
311
Total several DISTILLATION_STAGE's 1747 2254 5.26 11
36
40
CH4
AR
CH3OH
0.25
0.11
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.24
0.11
0.00
1.68 2.11 2.17 2.18
0.74 0.93 0.95 0.96
0.66 13.67 11.66 11.41
2.46
1.08
1.01
7.035 201.4 kg/s
90 C
1.649 201.4 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
4.069 18.5 kg/s
220 C 602
73.6 558
77.7 bar 607
59.5 302.6
82.7 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
67.29
Heatsourc-DH 97.81
22.7 509.4 783
33.0 748.2 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
70
73.6 kg/s
235 C
2
38
59.5 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 33.0 kg/s 18.4 18.81 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 22.7 kg/s 4 100 C 685 30.6 bar 12.1 Preheater-sy NG 93 kr/GJ Methanol 30.5 kr/s 132 kr/GJ 149 kr/GJ 2.96 kr/kg 2.3 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 18.4 kg/s 38 606 2 38 0.80 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 405 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 38 59.5 82.7 bar 71.5 510.9 DH water 0 kr/ton Syngas 2.0 kr/s 128 kr/GJ - kr/GJ 0.64 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.4 MW 19 0.90 298.9 59.5 kg/s 640 77.7 bar 86 5.367 2.1 42.56 Water 32 kr/ton DH water 0.6 kr/s 37 kr/GJ 8 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.409 66 C 2 71.5 kg/s 621 77.7 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
106 0.75
Feed
18.4
4.045
30.6 bar
18.4 kg/s
220 C
Preheater-sy 64.42 139 C
Condenser-1
0.4
631 2.1 kg/s
4 139 C
Preheater-sy
Nomenclature:
Cond-steam-2 0.09 0.74 If methanol and DH share the plant costs
Condenser-1 85.9 0.655 621 631 4 (methanol and DH are the only products from the plant) -
8 705 706
17 3.5 bar
2 0.09 705 706
0 3.5 bar
6
SAND 31
643
2
71.3 505.5
77.7 bar
71.3 kg/s
0
5
77.7 bar
0.2 kg/s
138 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 22.2 kr/s 96.3 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
70 17.3 kg/s 1 0.2 kg/s Condenser 63.76 138 C Preheater-sy
DH water 10.8 kr/s 150 kr/Gjen Mass flow
128 C 128 C SAND 33 Condenser
Temperature
Dis_stage_1 0.02 811 8
103.7 1.0 bar
Reboil-meoh2 17.4
0.02 0.50
0 805 2
DH water
103.7 1.0 bar Mechanical power
10
8.191 18.0 62.66 3.624 103.7 kg/s 0.849 103.7 kg/s 0.089 0.2 0.655
707 3.5 bar Cond-steam-2 90 C 38.07 605 2 50 C 699 3.5 bar 0.25
708 18.0 kg/s SAND 393 Condenser
59.5 77.7 bar 3.1 15.71 Condenser
700 0.2 kg/s
4 128 C 298.5 59.5 kg/s 611 77.7 bar 92.4 23.69 8.7 185.7 2 128 C
Water /
Methanol
Methanol molar-% = 9.16
0 693 694
1 3.5 bar
2 0.7 kg/s
Dis_stage_1
4 8.102 695 696
17 3.5 bar
60 17.1 kg/s
2 34.1
8.143 0.65
8.143 705 706
17 3.5 bar
69 17.1 kg/s
4
29.71 625 635
11 3.5 bar
2
Methanol molar-% = 91.0
60 C
Comp-recirc
Methanol/
4 3.1 kg/s
2.004 60 C
Syngas Split-syngas
621 77.7 bar
631 8.7 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
128 C
Reboil-meoh1
128 C
Reboil-meoh1
233 11.0 kg/s
81 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.3 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.3 kg/s 39.1 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.075 15 C SAND 39.13 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.339 803 4
78.0 1.0 bar
Electrolyser
12.93
1.7
0.80
0 802 2
78.0 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.831 78.0 kg/s 2.1 0.273 0.3 30.59 0.638 78.0 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 55 C
Electro-cool
3
4
1.0 bar
2.1 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.441
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.111 7 4 0.111
0.90
2.1 1.0 bar
0.273 2.1 kg/s
90 C
Comp-O2-1
0.111 5 2
2.1 1.0 bar
0.273 2.1 kg/s
90 C
Comp-O2-1
DH water
Gas
0.111 90 C
Electrolyser
0.0 7E-39
6 1.0 bar
4 0.0 kg/s
12.48 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.035
5.5
33 2
1.0 bar
Steam
32
18.6 23.96
1.0 bar
801
2
14.6 0.12
1.0 bar
14.6 kg/s
15
4
5.0 2.298
1.0 bar
5.0 kg/s Heatsink-H2
3E-39 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
7.113 5.5 kg/s Heatex-GG-st 4 18.6 kg/s 0 50 C 0 60 C 0.0 MW 322 12.48 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.12 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 4E-05 0.0 MW 7
Heatex-NG
0.89
10
Gasifier
11.6 253.3
10
18.6
233.4
Gasifier
10 GG2
0.11 0.78
1.0 bar 1.5
18.6 kg/s
800 C
10
18.6
232.3
11 2
1.0 bar
18.6 kg/s
763 C
Heatex-GG-st
0.12 0.98 10
23.8 18.6
218.6
12 2 0.00 0.74
1.0 bar 2.5
18.6 kg/s
130 C Heatex-GG-DH
10
18.6
218.1
13 2
1.0 bar
18.6 kg/s
60 C
1.00
Gas cleaner 9.5
13.6 216.9
14 1.0 bar
0.00
Heatsink
12.48
12.48 511 2
0.3 1.0 bar
30.59 0.3 kg/s
90 C
Heatsink-H2
0.02 503 4
0.0 25.3 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 25.3 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 13.6 kg/s 0.167 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 11.6 kg/s 0.11 9 2 Heatex-GG-O2 18.6 10.54 0 21 4 9.5 60 C 294 C 305 C 15 C 0.01 950 C 107 C
6.93 120 C 2.1 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 12.48 512 2 27.7 524 4 13.9 259.7 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.111 2.1 kg/s
790 C
Gasifier
2 18.6 kg/s
0.088 120 C
Heatex-GG-st
-0 0.0 kg/s
60 C 521
Heatex-GG-DH 2
13.9 247.4
1.0 bar
13.9 kg/s
0.3
30.59
1.0 bar
0.3 kg/s
90 C
13.9
259.6
25.3 bar
13.9 kg/s
325 C
531
2
27.72
25.3 bar
13.9 kg/s
325 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
14.6 0.511
1.0 bar
21.99 63 C
Comp-GG-H2-1
Comp-GG-H2-1
9.2 MW 11
Mixer-GG-H2 Comp-GG-H2-2
45.6 28.21
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 14.6 kg/s 0.93
SAND 9.225 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.26 42.5 24.1 6 45.6 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
13.1 16.85 Heatex-GG-DH
13.9 256 563 1.0 bar 0.22 200 C 7.2 SAND 0.003 0.0 0.094 0.0 0.046 0.0 0.018
0.48
103.7
Steam_dryer Biomass (dry)
SAND 1
35 4 0.45 29.5 0.48 34 2
1.0 bar Steam dryer 6.93 93.2 1.0 bar
34 1.0 bar
4 13.1 kg/s
0.082 730 C
Split-steam2
522 6.8 bar
2 13.9 kg/s
25.26 325 C
Cooler-GG-H2
2 42.5 kg/s
0.20 120 C
Cooler-GG-H2
6.8
0.21 0.80
25.26 523 2
13.9 6.8 bar
0.93
27.7
Syngas-cool1
561
2
0.215
45.6 25.8
1.0 bar
45.6 kg/s
120 C
0.22 0.82
0 541 4
0.3 25.3 bar
0.025 0.3 kg/s
135 C
Water
Reformat
0.018 462 2 0.018
0.0 25.3 bar
0.161 0.0 kg/s
0.017 461 2
0.93
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
58.72 103.7 kg/s 64.17 93.2 kg/s Cooler-GG-H2 42.5 26.34 253.1 13.9 kg/s Syngas-cool1 13.6 256.8 Syngas-cool1
288 C 154 C
120 C 22.0 254.1 279 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 25.3 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 42.5 kg/s Comp-GG-H2-2 2 13.6 kg/s
2
6.801
22.0 kg/s
15 C
Steam
0.21 200 C
Cooler-GG-H2
6.9 MW
SAND
13
6.897
27.72 135 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
4.9 2.786
41 1.0 bar
2 4.9 kg/s
Steam
0.93
30.07
13.6 262.9
533 89.8 bar
4 13.6 kg/s
Syngas 30.07 325 C
6.6 MW
SAND
15
6.618
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
59
0
0
Total
price
[mio. kr]
77
0
0
C
[kr/s]
0.18
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
254 MW
39 MW
67 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
5 MW
SAND 79 0.023 120 C 78.0 48.32 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 808 1050 2.43
DH-condenser
0.73 11.4 0.38 811 12
DH condenser0.38
78.0 1.0 bar
581
2
0.38
1.0 bar
78.0 kg/s
200 C Steam
0.34 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
10
1
1
12
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
79% (with power for electrolyser)
72% (with total power)
77%
4.9 0.194 2.724 78.0 kg/s DH-cooler DH-cooler
69.1 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 42.77 69.1 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 43 56 0.13
4 4.9 kg/s
0 95 C
DH-condenser
DH-condenser
448.5 15.67
811 1.0 bar
0.015 811 6
74.1 1.0 bar
2.589 74.1 kg/s
0.48 12.4 0 804 2
DH cooler
DH water
0.01 74.1 1.0 bar
0.607 74.1 kg/s 1.0 0.639
0.327 562 2
69.1 1.0 bar
200 C
Syngas-cool2 11.0
0.34 0.90
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
5
0
0
6
0
0
0.01
0.00
0.00 Energy
Water
2 448.5 kg/s
0.45 90 C
DH
DH water
90 C
DH-cooler
35
6
78.0 44.19
1.0 bar
78.0 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
39.12 69.1 kg/s
120 C
Syngas-cool2
534
2
11.6 258.7
89.8 bar
11.6 kg/s
0 551 4
2.0 89.8 bar
0.168 2.0 kg/s
130 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
213 MW
39 MW
67 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
75 MW
0 MW
4 MW
Energy content in DH water = 75 MW 0.38 120 C
DH-cooler
Steam
30.07 130 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
42
0
54
0.00
0.12
* for electrolyser
Urenhed:
0.005 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.99
Water /
671
1.0 0.566
1.0 bar
0.92
Comp-syngas2
31.31 3.5 MW 17
SAND 3.497
11.6 261.9
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
3
31
3
30
4
40
4
39
0.01
0.09
0.01
0.09
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
81% (with power for electrolyser)
73% (with total power)
102%
Methanol
2 1.0 kg/s 535 200.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 4 6 0.01
0.00 120 C 2 11.6 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 16 20 0.05
Cond-steam-1
31.31 243 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 206 268 0.62 Gas composition at specific nodes (mol-%)
32.03 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 2 2 0.00
793
794
3.5 bar
10.3 kg/s 601
30.7 369.3
200.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4
1
5
2
0.01
0.00
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.86
4 100 C 2 30.7 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 0 0 0.00
Species
Split-meoh1
134.9 43.4 973 Steam
0 682 4
45 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
250
0
326
0
0.75
0.00
1
3
H2
N2
45.32
0.21
0.00 57.70 62.82 49.72 20.37 22.59 28.84 30.00
0.00 0.00 0.23 2.77 4.48 4.97 6.34 6.60
791 3.5 bar 17.5 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 17 0.04 4 CO 30.41 0.00 22.49 33.66 22.88 4.52 5.01 6.40 6.65
792 43.4 kg/s 17.97 17.5 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 5 6 0.01 6 CO2 10.03 99.97 5.09 0.03 19.67 33.45 37.09 47.34 49.25
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 18 23 0.05 7 H2O-G 13.81 0.00 14.17 3.01 1.81 1.28 0.82 0.08 0.00
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.053 811 10 44.3
264.5 1.0 bar 0.053 0.70
0 806 2
DH water
264.5 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.5 30.6 bar
32.6 Meoh-convert
Methanol 0.99 SAND
converter 46
311
Total several DISTILLATION_STAGE's 1553 1990 4.67 11
36
40
CH4
AR
CH3OH
0.12
0.10
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.14
0.11
0.00
1.64 2.65 2.94
1.33 2.15 2.39
0.17 31.10 24.19
3.75
3.04
4.22
3.90
3.17
0.43
9.241 264.5 kg/s
90 C
2.166 264.5 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.864 17.5 kg/s
220 C 602
30.7 352.9
195.0 bar 607
19.1 103.6
200.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
102.8
Heatsourc-DH 134.9
33.1 741.9 783
43.4 983.1 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
46
30.7 kg/s
235 C
2
14
19.1 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 43.4 kg/s 17.4 17.85 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 33.1 kg/s 4 100 C 685 30.6 bar 4.0 Preheater-sy NG 93 kr/GJ Methanol 32.0 kr/s 139 kr/GJ 156 kr/GJ 3.11 kr/kg 2.4 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.4 kg/s 14 606 2 14 0.44 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 408 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 14 19.1 200.0 bar 27.5 279.3 DH water 0 kr/ton Syngas 0.7 kr/s 136 kr/GJ - kr/GJ 0.73 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.1 MW 19 0.90 102.4 19.1 kg/s 640 195.0 bar 94 9.277 3.2 70.89 Water 32 kr/ton DH water 0.5 kr/s 29 kr/GJ 6 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.054 62 C 2 27.5 kg/s 621 195.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
157 0.81
Feed
17.4
3.839
30.6 bar
17.4 kg/s
220 C
Preheater-sy 36.55 212 C
Condenser-1
10.0
631 3.2 kg/s
4 212 C
Preheater-sy
Nomenclature:
Cond-steam-2 5.16 0.39 If methanol and DH share the plant costs
Condenser-1 96.5 19.19 621 631 4 (methanol and DH are the only products from the plant) -
22 705 706
23 3.5 bar
2 5.16 705 706
5 3.5 bar
6
SAND 31 21.0 129.4
643 195.0 bar
2 21.0 kg/s
6 195.0 bar
143 6.5 kg/s
130 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 21.9 kr/s 94.8 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
169 23.2 kg/s 40 5.4 kg/s Condenser 17.36 130 C Preheater-sy
DH water 11.3 kr/s 150 kr/Gjen Mass flow
120 C 120 C SAND 33 Condenser
Temperature
Dis_stage_1 0.00 811 8
17.3 1.0 bar
Reboil-meoh2 2.9
0.00 0.36
0 805 2
DH water
17.3 1.0 bar Mechanical power
10
21.9 23.5 159.7 0.605 17.3 kg/s 0.142 17.3 kg/s 5.149 5.4 36.98
707 3.5 bar Cond-steam-2 90 C 13.87 605 2 50 C 699 3.5 bar 0.25
708 23.5 kg/s SAND 393 Condenser
19.1 195.0 bar 1.0 5.386 Condenser
700 5.4 kg/s
4 120 C 102.3 19.1 kg/s 611 195.0 bar 98.1 2.762 0.9 20.38 2 120 C
Water /
Methanol
Methanol molar-% = 19.46
0 693 694
0 3.5 bar
2 0.3 kg/s
Dis_stage_1
4 16.76 695 696
18 3.5 bar
120 17.7 kg/s
2 32.4
16.79 0.62
16.79 705 706
18 3.5 bar
129 17.7 kg/s
4
31.23 625 635
11 3.5 bar
2
Methanol molar-% = 96.0
60 C
Comp-recirc
Methanol/
4 1.0 kg/s
0.73 60 C
Syngas Split-syngas
621 195.0 bar
631 0.9 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
120 C
Reboil-meoh1
120 C
Reboil-meoh1
234 10.6 kg/s
100 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

26. Flowsheets for metanolanlæg – for
parametervariationen (brint/kulstof-forholdet i
syngassen)
Flowsheets for brint/kulstof-forhold på M=1,55 og M=2,35.
Sorteret efter brint/kulstof-forhold – anlægget på M=1,55 først.

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.4 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.4 kg/s 41.0 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.078 15 C SAND 41 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.45 803 4
111.3 1.0 bar
Electrolyser
13.55
1.7
0.80
0 802 2
111.3 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 1.11 111.3 kg/s 2.2 0.286 0.3 32.06 0.912 111.3 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 54 C
Electro-cool
3
4
1.0 bar
2.2 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.452
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.116 7 4 0.116
0.90
2.2 1.0 bar
0.286 2.2 kg/s
90 C
Comp-O2-1
0.116 5 2
2.2 1.0 bar
0.286 2.2 kg/s
90 C
Comp-O2-1
DH water
Gas
0.116 90 C
Electrolyser
0.0 -0
6 1.0 bar
4 0.0 kg/s
12.99 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.019
3.4
33 2
1.0 bar
Steam
32
16.3 21.02
1.0 bar
801
2
13.1 0.107
1.0 bar
13.1 kg/s
15
4
3.2 1.501
1.0 bar
3.2 kg/s Heatsink-H2
-0 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
4.384 3.4 kg/s Heatex-GG-st 4 16.3 kg/s 0 50 C 0 60 C 0.0 MW 322 12.99 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.09 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 5E-05 0.0 MW 7
Heatex-NG
0.89
10
Gasifier
11.9 259.5
10
16.9
236.9
Gasifier
10 GG2
0.12 0.78
1.0 bar 1.6
16.9 kg/s
800 C
10
16.9
235.7
11 2
1.0 bar
16.9 kg/s
756 C
Heatex-GG-st
0.09 0.98 10
20.9 16.9
223.8
12 2 0.00 0.74
1.0 bar 2.2
16.9 kg/s
130 C Heatex-GG-DH
10
16.9
223.3
13 2
1.0 bar
16.9 kg/s
60 C
1.00
Gas cleaner 9.7
13.6 222.6
14 1.0 bar
0.00
Heatsink
12.99
12.99 511 2
0.3 1.0 bar
32.06 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 19.1 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 19.1 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 13.6 kg/s 0.166 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 11.9 kg/s 0.12 9 2 Heatex-GG-O2 16.3 9.249 0 21 4 9.7 60 C 254 C 275 C 15 C 0.01 950 C 107 C
7.10 120 C 2.2 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 12.99 512 2 27.6 524 4 13.9 265.2 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.164 2.2 kg/s
790 C
Gasifier
2 16.3 kg/s
0.064 120 C
Heatex-GG-st
2E-18 0.0 kg/s
60 C 521
Heatex-GG-DH 2
13.9 254.5
1.0 bar
13.9 kg/s
0.3
32.06
1.0 bar
0.3 kg/s
90 C
13.9
265
19.1 bar
13.9 kg/s
304 C
531
2
27.62
19.1 bar
13.9 kg/s
304 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
13.1 0.457
1.0 bar
22.71 64 C
Comp-GG-H2-1
Comp-GG-H2-1
8.0 MW 11
Mixer-GG-H2 Comp-GG-H2-2
35.8 22.16
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 13.1 kg/s 0.93
SAND 7.98 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.54 35.7 20.25 6 35.8 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
12.9 16.64 Heatex-GG-DH
13.9 261.9 563 1.0 bar 0.15 200 C 5.7 SAND 0.002 0.0 0.094 0.0 0.046 0.0 0.018
0.42
109.6
Steam_dryer Biomass (dry)
SAND 1
35 4 0.45 30.3 0.42 34 2
1.0 bar Steam dryer 7.10 98.9 1.0 bar
34 1.0 bar
4 12.9 kg/s
0.071 730 C
Split-steam2
522 5.9 bar
2 13.9 kg/s
25.54 304 C
Cooler-GG-H2
2 35.7 kg/s
0.14 120 C
Cooler-GG-H2
5.7
0.15 0.82
25.54 523 2
13.9 5.9 bar
0.93
27.6
Syngas-cool1
561
2
0.14
35.8 20.27
1.0 bar
35.8 kg/s
120 C
0.15 0.82
0 541 4
0.0 19.1 bar
-0 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 19.1 bar
0.16 0.0 kg/s
0.017 461 2
0.92
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
62.07 109.6 kg/s 67.55 98.9 kg/s Cooler-GG-H2 35.7 22.13 259.6 13.9 kg/s Syngas-cool1 13.9 262.9 Syngas-cool1
245 C 154 C
120 C 22.6 260.4 274 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.1 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 35.7 kg/s Comp-GG-H2-2 2 13.9 kg/s
2
6.968
22.6 kg/s
15 C
Steam
0.15 200 C
Cooler-GG-H2
5.8 MW
SAND
13
5.796
27.62 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
7.3 4.131
41 1.0 bar
2 7.3 kg/s
Steam
0.93
29.67
13.9 268.3
533 62.0 bar
4 13.9 kg/s
Syngas 29.67 304 C
5.8 MW
SAND
15
5.8
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
62
0
0
Total
price
[mio. kr]
81
0
0
C
[kr/s]
0.19
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
260 MW
41 MW
66 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
13 MW
SAND 79 0.029 120 C 28.6 17.72 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 827 1076 2.49
DH-condenser
0.72 16.9 0.50 811 12
DH condenser0.50
111.3 1.0 bar
581
2
0.12
1.0 bar
28.6 kg/s
200 C Steam
0.17 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
8
1
1
11
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
77% (with power for electrolyser)
71% (with total power)
78%
7.3 0.287 3.889 111.3 kg/s DH-cooler DH-cooler
42.1 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 26.04 42.1 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 44 57 0.13
4 7.3 kg/s
0 95 C
DH-condenser
DH-condenser
443.8 15.5
811 1.0 bar
0.006 811 6
27.2 1.0 bar
0.95 27.2 kg/s
0.48 4.6 0 804 2
DH cooler
DH water
0.01 27.2 1.0 bar
0.223 27.2 kg/s 1.0 0.639
0.165 562 2
42.1 1.0 bar
200 C
Syngas-cool2 6.7
0.17 0.86
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
7
0
0
9
0
0
0.02
0.00
0.00 Energy
Water
2 443.8 kg/s
0.57 90 C
DH
DH water
90 C
DH-cooler
35
6
28.6 16.21
1.0 bar
28.6 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
23.82 42.1 kg/s
120 C
Syngas-cool2
534
2
13.4 265.6
62.0 bar
13.4 kg/s
0 551 4
0.5 62.0 bar
0.046 0.5 kg/s
135 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
218 MW
41 MW
66 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
75 MW
0 MW
11 MW
Energy content in DH water = 75 MW 0.12 120 C
DH-cooler
Steam
29.67 135 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
36
0
47
0.00
0.11
* for electrolyser
Urenhed:
0.003 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = #####
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
31.05 3.9 MW 17
SAND 3.891
13.4 269.2
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
26
2
26
3
34
3
34
0.01
0.08
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
79% (with power for electrolyser)
72% (with total power)
102%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 3 3 0.01
0.00 120 C 2 13.4 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 23 0.05
Cond-steam-1
31.05 255 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 328 427 0.99 Gas composition at specific nodes (mol-%)
31.24 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
3.5 bar
10.3 kg/s 601
69.0 513.8
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
3
3
4
4
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.55
4 100 C 2 69.0 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
125.1 41.2 925.5 Steam
0 682 4
63 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
247
0
320
0
0.74
0.00
1
3
H2
N2
46.08
0.23
0.00 57.70 57.39 29.76
0.00 0.00 0.23 1.78
9.95 10.49 11.34 11.84
2.35 2.47 2.68 2.79
791 3.5 bar 18.2 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 18 0.04 4 CO 38.18 0.00 22.49 36.99 28.62 19.50 20.55 22.23 23.20
792 41.2 kg/s 18.68 18.2 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 2 2 0.01 6 CO2 7.14 99.95 5.09 0.02 34.50 47.77 50.34 54.45 56.85
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 17 22 0.05 7 H2O-G 7.96 0.00 14.17 4.99 1.96 0.21 0.12 0.03 0.00
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.051 811 10 42.2
251.6 1.0 bar 0.051 0.70
0 806 2
DH water
251.6 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
18.2 30.6 bar
33.9 Meoh-convert
Methanol 1.00 SAND
converter 64
311
Total several DISTILLATION_STAGE's 1681 2161 5.06 11
36
40
CH4
AR
CH3OH
0.28
0.11
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.27
0.11
0.00
2.15 2.82 2.98
0.86 1.13 1.19
0.37 16.27 11.87
3.22
1.29
4.77
3.36
1.34
0.61
8.789 251.6 kg/s
90 C
2.06 251.6 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
4.017 18.2 kg/s
220 C 602
69.0 497.4
139.0 bar 607
55.6 244.4
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
93.87
Heatsourc-DH 125.1
30.9 694.4 783
41.2 935.1 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
64
69.0 kg/s
235 C
2
32
55.6 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 41.2 kg/s 18.1 18.57 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 30.9 kg/s 4 100 C 685 30.6 bar 9.8 Preheater-sy NG 93 kr/GJ Methanol 31.2 kr/s 135 kr/GJ 152 kr/GJ 3.03 kr/kg 2.4 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 18.1 kg/s 32 606 2 32 0.70 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 405 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 32 55.6 144.0 bar 65.7 418.8 DH water 0 kr/ton Syngas 1.7 kr/s 131 kr/GJ - kr/GJ 0.57 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.90 241.4 55.6 kg/s 640 139.0 bar 98 9.615 3.3 74.35 Water 32 kr/ton DH water 0.6 kr/s 36 kr/GJ 8 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.183 63 C 2 65.7 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
173 0.88
Feed
18.1
3.992
30.6 bar
18.1 kg/s
220 C
Preheater-sy 54.16 158 C
Condenser-1
7.7
631 3.3 kg/s
4 158 C
Preheater-sy
Nomenclature:
Cond-steam-2 8.90 0.58 If methanol and DH share the plant costs
Condenser-1 98.8 13.7 621 631 4 (methanol and DH are the only products from the plant) -
48 705 706
27 3.5 bar
2 8.90 705 706
5 3.5 bar
6
SAND 31 61.0 310.4
643 139.0 bar
2 61.0 kg/s
5 139.0 bar
105 4.7 kg/s
122 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 22.3 kr/s 96.4 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
366 27.4 kg/s 68 5.0 kg/s Condenser 40.46 122 C Preheater-sy
DH water 11.2 kr/s 150 kr/Gjen Mass flow
112 C 112 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
40.6 1.0 bar
Reboil-meoh2 6.8
0.01 0.54
0 805 2
DH water
40.6 1.0 bar Mechanical power
10
47.86 27.5 357.7 1.419 40.6 kg/s 0.332 40.6 kg/s 8.895 5.1 66.05
707 3.5 bar Cond-steam-2 90 C 31.66 605 2 50 C 699 3.5 bar 0.25
708 27.5 kg/s SAND 393 Condenser
55.6 139.0 bar 2.9 12.7 Condenser
700 5.0 kg/s
4 112 C 241.3 55.6 kg/s 611 139.0 bar 99.3 7.137 2.4 54.4 2 112 C
Water /
Methanol
Methanol molar-% = 43.46
0 693 694
0 3.5 bar
2 0.2 kg/s
Dis_stage_1
4 38.96 695 696
22 3.5 bar
289 22.3 kg/s
2 33.7
39.01 0.58
39.01 705 706
22 3.5 bar
298 22.3 kg/s
4
30.45 625 635
10 3.5 bar
2
Methanol molar-% = 98.7
60 C
Comp-recirc
Methanol/
4 2.9 kg/s
1.666 60 C
Syngas Split-syngas
621 139.0 bar
631 2.4 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
112 C
Reboil-meoh1
112 C
Reboil-meoh1
234 10.5 kg/s
100 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.5 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.5 kg/s 41.9 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.08 15 C SAND 41.88 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.206 803 4
33.7 1.0 bar
Electrolyser
13.84
1.8
0.80
0 802 2
33.7 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.5 33.7 kg/s 2.2 0.292 0.3 32.75 0.276 33.7 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 63 C
Electro-cool
3
4
1.0 bar
2.2 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.487
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.12 7 4
2.2 1.0 bar
0.292 2.2 kg/s
90 C
Comp-O2-1
0.12
0.90
0.12 5 2
2.2 1.0 bar
0.292 2.2 kg/s
90 C
Comp-O2-1
DH water
Gas
0.121 90 C
Electrolyser
0.0 4E-36
6 1.0 bar
4 0.0 kg/s
13.51 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.067
9.9
33 2
1.0 bar
Steam
32
25.0 32.21
1.0 bar
801
2
19.7 0.161
1.0 bar
19.7 kg/s
15
4
7.9 3.639
1.0 bar
7.9 kg/s Heatsink-H2
2E-36 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
12.7 9.9 kg/s Heatex-GG-st 4 25.0 kg/s 0 50 C 0 62 C 0.0 MW 322 13.51 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.17 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 5E-05 0.0 MW 7
Heatex-NG
0.89
11
Gasifier
12.8 279.7
11
24.3
261.7
Gasifier
10 GG2
0.12 0.78
1.0 bar 1.6
24.3 kg/s
800 C
11
24.3
260.6
11 2
1.0 bar
24.3 kg/s
770 C
Heatex-GG-st
0.17 0.98 11
32.1 24.3
242.1
12 2 0.00 0.75
1.0 bar 3.3
24.3 kg/s
130 C Heatex-GG-DH
11
24.2
241.4
13 2
1.0 bar
24.2 kg/s
62 C
1.00
Gas cleaner 10.5
16.3 239.3
14 1.0 bar
0.00
Heatsink
13.51
13.51 511 2
0.3 1.0 bar
32.75 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 20.2 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 20.2 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 16.3 kg/s 0.166 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 12.8 kg/s 0.12 9 2 Heatex-GG-O2 25.0 14.17 0 21 4 10.5 62 C 262 C 281 C 15 C 0.01 950 C 107 C
7.65 120 C 2.2 1.0 bar SAND 5 31 1.0 bar 0.1 1.0 bar Cleaner 13.51 512 2 30.48 524 4 16.6 285.9 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.189 2.2 kg/s
790 C
Gasifier
2 25.0 kg/s
0.133 120 C
Heatex-GG-st
0.001 0.1 kg/s
62 C 521
Heatex-GG-DH 2
16.5 271.9
1.0 bar
16.5 kg/s
0.3
32.75
1.0 bar
0.3 kg/s
90 C
16.5
285.8
20.2 bar
16.5 kg/s
303 C
531
2
30.5
20.2 bar
16.6 kg/s
303 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
19.7 0.689
1.0 bar
24.04 65 C
Comp-GG-H2-1
Comp-GG-H2-1
10.5 MW 11
Mixer-GG-H2 Comp-GG-H2-2
55.0 34.04
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 19.7 kg/s 0.93
SAND 10.51 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 27.76 47.2 26.75 6 55.0 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
15.2 19.51 Heatex-GG-DH
16.5 281.7 563 1.0 bar 0.30 200 C 8.7 SAND 0.002 0.0 0.094 0.0 0.046 0.0 0.018
0.56
109.5
Steam_dryer Biomass (dry)
SAND 1
35 4 0.45 32.6 0.56 34 2
1.0 bar Steam dryer 7.65 98.0 1.0 bar
34 1.0 bar
4 15.2 kg/s
0.104 730 C
Split-steam2
522 6.1 bar
2 16.5 kg/s
27.76 303 C
Cooler-GG-H2
2 47.2 kg/s
0.25 120 C
Cooler-GG-H2
7.5
0.26 0.82
27.76 523 2
16.5 6.1 bar
0.93
30.48
Syngas-cool1
561
2
0.291
55.0 31.14
1.0 bar
55.0 kg/s
120 C
0.30 0.86
0 541 4
0.8 20.2 bar
0.08 0.8 kg/s
144 C
Water
Reformat
0.017 462 2 0.017
0.0 20.2 bar
0.16 0.0 kg/s
0.017 461 2
0.93
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
62.04 109.5 kg/s 68.2 98.0 kg/s Cooler-GG-H2 47.2 29.24 278.6 16.5 kg/s Syngas-cool1 15.7 282.5 Syngas-cool1
253 C 154 C
120 C 24.3 280.5 287 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 20.2 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 47.2 kg/s Comp-GG-H2-2 2 15.7 kg/s
2
7.508
24.3 kg/s
15 C
Steam
0.26 200 C
Cooler-GG-H2
7.7 MW
SAND
13
7.657
30.5 144 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
1.7 0.943
41 1.0 bar
2 1.7 kg/s
Steam
0.93
32.91
15.7 288.8
533 59.9 bar
4 15.7 kg/s
Syngas 32.91 303 C
6.8 MW
SAND
15
6.796
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
64
0
0
Total
price
[mio. kr]
83
0
0
C
[kr/s]
0.19
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
281 MW
42 MW
73 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
34 MW
SAND 79 0.009 120 C 120.4 74.57 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 892 1159 2.68
DH-condenser
0.77 3.9 0.22 811 12
DH condenser0.22
33.7 1.0 bar
581 1.0 bar
2 120.4 kg/s
0.66 200 C Steam
0.55 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
13
1
1
17
2
0.00
0.04
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
72% (with power for electrolyser)
65% (with total power)
78%
1.7 0.066 1.176 33.7 kg/s DH-cooler DH-cooler
100.0 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 61.96 100.0 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 47 62 0.14
4 1.7 kg/s
0 95 C
DH-condenser
DH-condenser
461.8 16.13
811 1.0 bar
0.023 811 6
114.3 1.0 bar
3.994 114.3 kg/s
0.48 19.2 0 804 2
DH cooler
DH water
0.02 114.3 1.0 bar
0.936 114.3 kg/s 1.0 0.639
0.53 562 2
100.0 1.0 bar
200 C
Syngas-cool2 15.9
0.55 0.95
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
2
0
0
2
0
0
0.00
0.00
0.00 Energy
Water
2 461.8 kg/s
0.31 90 C
DH
DH water
90 C
DH-cooler
120.4 68.2
35 1.0 bar
6 120.4 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.01 225 C
Cond-steam-1
56.67 100.0 kg/s
120 C
Syngas-cool2
534
2
11.8 282.9
59.9 bar
11.8 kg/s
0 551 4
3.9 59.9 bar
0.325 3.9 kg/s
130 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
235 MW
42 MW
73 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
78 MW
0 MW
29 MW
Energy content in DH water = 78 MW 0.66 120 C
DH-cooler
Steam
32.91 130 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
47
0
61
0.00
0.14
* for electrolyser
Urenhed:
0.029 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.97
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
34.45 4.4 MW 17
SAND 4.352
11.8 286.9
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
3
34
3
31
4
45
5
40
0.01
0.10
0.01
0.09
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
74% (with power for electrolyser)
67% (with total power)
101%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 6 8 0.02
0.01 120 C 2 11.8 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 20 25 0.06
Cond-steam-1
34.45 255 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 424 552 1.28 Gas composition at specific nodes (mol-%)
32.19 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 6 0.01
793
794
3.5 bar
10.3 kg/s 601
20.0 905.9
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
2
5
2
7
0.00
0.02
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
2.35
4 100 C 2 20.0 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 2 0.00
Species
Split-meoh1
110.2 35.3 791 Steam
0 682 4
120 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
266
0
346
0
0.80
0.00
1
3
H2
N2
43.02
0.18
0.00 57.70 66.71 85.60 82.33 85.67 88.36 94.86
0.00 0.00 0.23 1.49 1.83 1.91 1.97 2.11
791 3.5 bar 17.2 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 17 0.04 4 CO 22.32 0.00 22.49 28.36 9.49 0.21 0.22 0.22 0.24
792 35.3 kg/s 17.63 17.2 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 8 10 0.02 6 CO2 12.35 99.98 5.09 0.02 0.43 0.54 0.57 0.58 0.63
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 14 19 0.04 7 H2O-G 22.00 0.00 14.17 4.51 1.50 1.82 1.08 0.61 0.02
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.043 811 10 36.0
215.1 1.0 bar 0.043 0.70
0 806 2
DH water
215.1 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.01 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.2 30.6 bar
32.0 Meoh-convert
Methanol 1.00 SAND
converter 121
311
Total several DISTILLATION_STAGE's 1902 2444 5.72 11
36
40
CH4
AR
CH3OH
0.05
0.09
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.06
0.11
0.00
0.41 0.50
0.71 0.88
0.37 11.89
0.52
0.91
9.13
0.54
0.94
6.77
0.58
1.01
0.56
7.514 215.1 kg/s
90 C
1.761 215.1 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.791 17.2 kg/s
220 C 602
20.0 889
139.0 bar 607
8.3 649.2
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
77.97
Heatsourc-DH 110.2
25.0 559.9 783
35.3 799.2 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
121
20.0 kg/s
235 C
2
85
8.3 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 35.3 kg/s 17.1 17.51 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 25.0 kg/s 4 100 C 685 30.6 bar 11.1 Preheater-sy NG 93 kr/GJ Methanol 32.2 kr/s 139 kr/GJ 157 kr/GJ 3.12 kr/kg 2.5 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.1 kg/s 85 606 2 85 -4.10 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 413 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 85 8.3 144.0 bar 16.8 825.8 DH water 0 kr/ton Syngas 4.5 kr/s 132 kr/GJ - kr/GJ 10.32 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.3 MW 19 0.90 645.9 8.3 kg/s 640 139.0 bar 80 8.728 3.2 64.07 Water 32 kr/ton DH water 0.3 kr/s 19 kr/GJ 4 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.262 64 C 2 16.8 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
116 0.72
Feed
17.1
3.766
30.6 bar
17.1 kg/s
220 C
Preheater-sy 112.5 155 C
Condenser-1
4.0
631 3.2 kg/s
4 155 C
Preheater-sy
Nomenclature:
Cond-steam-2 0.67 -0.29 If methanol and DH share the plant costs
Condenser-1 83.9 6.851 621 631 4 (methanol and DH are the only products from the plant) -
6 705 706
17 3.5 bar
2 0.67 705 706
2 3.5 bar
6
SAND 31 14.3 779.2
643 139.0 bar
2 14.3 kg/s
2 139.0 bar
51 2.4 kg/s
141 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 25.3 kr/s 110 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
51 17.5 kg/s 6 2.0 kg/s Condenser 105.6 141 C Preheater-sy
DH water 11.6 kr/s 150 kr/Gjen Mass flow
131 C 131 C SAND 33 Condenser
Temperature
Dis_stage_1 0.02 811 8
79.0 1.0 bar
Reboil-meoh2 13.2
0.02 -0.11
0 805 2
DH water
79.0 1.0 bar Mechanical power
10
5.983 18.5 43.4 2.761 79.0 kg/s 0.647 79.0 kg/s 0.669 2.0 4.586
707 3.5 bar Cond-steam-2 90 C 85.38 605 2 50 C 699 3.5 bar 0.25
708 18.5 kg/s SAND 393 Condenser
8.3 139.0 bar 0.4 33.98 Condenser
700 2.0 kg/s
4 131 C 645.7 8.3 kg/s 611 139.0 bar 91.3 15.76 5.6 119.2 2 131 C
Water /
Methanol
Methanol molar-% = 5.95
0 693 694
1 3.5 bar
2 1.0 kg/s
Dis_stage_1
4 5.313 695 696
16 3.5 bar
36 15.6 kg/s
2 31.8
5.352 0.66
5.352 705 706
16 3.5 bar
46 15.6 kg/s
4
31.34 625 635
11 3.5 bar
2
Methanol molar-% = 86.3
60 C
Comp-recirc
Methanol/
4 0.4 kg/s
4.493 60 C
Syngas Split-syngas
621 139.0 bar
631 5.6 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
131 C
Reboil-meoh1
131 C
Reboil-meoh1
234 11.3 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

27. Flowsheet for metanolanlæg – for
parametervariationen (tryksat forgasning)

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.2 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.2 kg/s 36.5 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.07 15 C SAND 36.5 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.344 803 4
81.3 1.0 bar
Electrolyser
12.06
1.6
0.80
0 802 2
81.3 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.4 MW 1 0.844 81.3 kg/s 1.9 0.255 0.2 28.54 0.666 81.3 kg/s 0.0 0.002
12 C
13 C/EX
SAND 0.417 55 C
Electro-cool
3
4
1.0 bar
1.9 kg/s
2
4
1.0 bar
0.2 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.495
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.251 7 4 0.251
0.93
1.9 5.0 bar
0.642 1.9 kg/s
310 C
Comp-O2-1
0.103 5 2
1.9 1.0 bar
0.254 1.9 kg/s
90 C
Comp-O2-1
DH water
Gas
0.104 90 C
Electrolyser
0.0 3E-43
6 1.0 bar
4 0.0 kg/s
11.62 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.026
6.5
33 2
5.0 bar
Steam
32
21.4 27.54
1.0 bar
801
2
43.8 0.359
1.0 bar
43.8 kg/s
15
4
5.9 3.255
5.0 bar
5.9 kg/s Heatsink-H2
1E-43 90 C
Split-O2-2
O2 0.93
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
9.783 6.5 kg/s Heatex-GG-st 4 21.4 kg/s 0 50 C 0 70 C 0.9 MW 322 11.92 0.8 MW 9 Comp-CO2 0.005 950 C
731 C SAND 7 0.09 730 C Heatex-GG-DH
Cleaner SAND 0.9 SAND 0.844 0.0 MW 7
Heatex-NG
0.91
11
Gasifier
13.0 284.4
11
20.8
268.4
Gasifier
10 GG2
0.25 0.88
5.0 bar 1.0
20.8 kg/s
800 C
11
20.8
267.7
11 2
5.0 bar
20.8 kg/s
779 C
Heatex-GG-st
0.09 0.97 11
27.4 20.8
251.8
12 2 0.01 0.85
5.0 bar 7.3
20.8 kg/s
130 C Heatex-GG-DH
11
18.7
250.4
13 2
5.0 bar
18.7 kg/s
70 C
1.00
Gas cleaner 10.8
12.8 248.5
14 5.0 bar
0.00
Heatsink
11.91
11.92 511 2
0.2 5.0 bar
29.33 0.2 kg/s
325 C
Heatsink-H2
0.02 503 4
0.0 32.6 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 32.6 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 12.8 kg/s 0.168 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 13.0 kg/s 0.25 9 2 Heatex-GG-O2 21.4 12.12 0 21 4 10.8 70 C 332 C 334 C 15 C 0.01 950 C 107 C
7.78 120 C 1.9 5.0 bar SAND 5 31 1.0 bar 2.1 5.0 bar Cleaner 11.91 512 2 25.61 524 4 13.0 284 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.268 1.9 kg/s
790 C
Gasifier
2 21.4 kg/s
0.053 120 C
Heatex-GG-st
0.042 2.1 kg/s
70 C 521
Heatex-GG-DH 2
13.0 277.4
5.0 bar
13.0 kg/s
0.2
28.99
5.0 bar
0.2 kg/s
60 C
13.0
283.9
32.6 bar
13.0 kg/s
221 C
531
2
25.63
32.6 bar
13.0 kg/s
221 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
43.8 1.53
1.0 bar
22.70 69 C
Comp-GG-H2-1
Comp-GG-H2-1
5.1 MW 11
Mixer-GG-H2 Comp-GG-H2-2
19.0 11.74
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 43.8 kg/s 0.92
SAND 5.126 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.01 90 C 24.52 18.9 10.73 6 19.0 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
14.9 19.16 Heatex-GG-DH
13.0 282.1 563 1.0 bar 0.05 200 C 3.0 SAND 0.004 0.0 0.094 0.0 0.046 0.0 0.018
0.27
107.7
Steam_dryer Biomass (dry)
SAND 1
35 4 0.44 33.2 0.27 34 2
1.0 bar Steam dryer 7.78 96.0 1.0 bar
34 1.0 bar
4 14.9 kg/s
0.06 730 C
Split-steam2
522 16.8 bar
2 13.0 kg/s
24.52 221 C
Cooler-GG-H2
2 18.9 kg/s
0.05 120 C
Cooler-GG-H2
3.0
0.05 0.94
24.52 523 2
13.0 16.8 bar
0.92
25.61
Syngas-cool1
561
2
0.047
19.0 10.74
1.0 bar
19.0 kg/s
120 C
0.05 0.94
0 541 4
0.0 32.6 bar
5E-18 0.0 kg/s
130 C
Water
Reformat
0.018 462 2 0.018
0.0 32.6 bar
0.162 0.0 kg/s
0.017 461 2
0.93
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
60.99 107.7 kg/s 67.38 96.0 kg/s Cooler-GG-H2 18.9 11.73 281 13.0 kg/s Syngas-cool1 13.0 283 Syngas-cool1
331 C 154 C
120 C 24.8 285.3 294 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 32.6 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 18.9 kg/s Comp-GG-H2-2 2 13.0 kg/s
2
7.635
24.8 kg/s
15 C
Steam
0.05 200 C
Cooler-GG-H2
3.1 MW
SAND
13
3.066
25.63 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
5.2 2.95
41 1.0 bar
2 5.2 kg/s
Steam
0.92
26.72
13.0 285.8
533 63.6 bar
4 13.0 kg/s
Syngas 26.72 221 C
3.1 MW
SAND
15
3.073
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
55
4
2
Total
price
[mio. kr]
72
5
2
C
[kr/s]
0.17
0.01
0.01
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
285 MW
37 MW
54 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
10 MW
0 MW
32 MW
SAND 79 0.013 120 C 1.0 0.625 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 907 1179 2.73
DH-condenser
0.73 12.1 0.37 811 12
DH condenser0.37
81.3 1.0 bar
581
2
0.00
1.0 bar
1.0 kg/s
208 C Steam
0.05 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0
11
3
1
14
4
0.00
0.03
0.01
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
72% (with power for electrolyser)
68% (with total power)
81%
5.2 0.205 2.841 81.3 kg/s DH-cooler DH-cooler
19.5 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 12.05 19.5 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 48 63 0.14
4 5.2 kg/s
0 95 C
DH-condenser
DH-condenser
391.0 13.66
811 1.0 bar
0.000 811 6
1.0 1.0 bar
0.036 1.0 kg/s
0.47 0.2 0 804 2
DH cooler
DH water
0.00 1.0 1.0 bar
0.008 1.0 kg/s 24.7 15.81
0.048 562 2
19.5 1.0 bar
200 C
Syngas-cool2 3.1
0.05 0.95
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
5
0
0
6
0
0
0.01
0.00
0.00 Energy
Water
2 391.0 kg/s
0.43 90 C
DH
DH water
90 C
DH-cooler
35
6
1.0 0.566
1.0 bar
1.0 kg/s
50 C
DH-cooler
571 1.0 bar
10 24.7 kg/s
0.06 225 C
Cond-steam-1
11.02 19.5 kg/s
120 C
Syngas-cool2
534
2
12.9 284.7
63.6 bar
12.9 kg/s
0 551 4
0.2 63.6 bar
0.015 0.2 kg/s
138 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
239 MW
37 MW
54 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
66 MW
0 MW
30 MW
Energy content in DH water = 66 MW 0.00 120 C
DH-cooler
Steam
26.72 138 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
23
0
30
0.00
0.07
* for electrolyser
Urenhed:
0.026 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.97
Water /
671
24.7 14.01
1.0 bar
0.93
Comp-syngas2
28.1 3.9 MW 17
SAND 3.903
12.9 288.3
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
1
14
1
14
2
18
2
18
0.00
0.04
0.00
0.04
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
74% (with power for electrolyser)
70% (with total power)
103%
Methanol
2 24.7 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 1 2 0.00
0.05 120 C 2 12.9 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 18 23 0.05
Cond-steam-1
28.1 254 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 332 431 1.00 Gas composition at specific nodes (mol-%)
26.43 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 4 5 0.01
793
794
3.5 bar
10.3 kg/s 601
47.8 906.7
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
2
4
3
5
0.01
0.01
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.84
4 100 C 2 47.8 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
86.99 33.9 760.5 Steam
0 682 4
96 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
259
2
337
3
0.78
0.01
1
3
H2
N2
42.86
0.21
0.00 57.70 59.43 41.77 24.84 26.28 28.03 30.00
0.00 0.00 0.24 1.94 2.54 2.69 2.86 3.06
791 3.5 bar 17.7 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 11 14 0.03 4 CO 28.56 0.00 22.49 32.25 15.14 3.08 3.26 3.48 3.72
792 33.9 kg/s 18.16 17.7 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 0 0 0.00 6 CO2 10.91 99.97 5.09 0.02 17.57 24.24 25.65 27.35 29.27
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 14 18 0.04 7 H2O-G 15.12 0.00 14.17 5.43 2.18 1.66 0.96 0.36 0.01
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.042 811 10 34.6
206.8 1.0 bar 0.042 0.70
0 806 2
DH water
206.8 1.0 bar
0 683 2
2.8 30.6 bar
5.2
0.06 0.81
0 684 4
2.8 30.6 bar
Water
0 681 2
17.7 30.6 bar
32.9 Meoh-convert
Methanol 1.00 SAND
converter 97
311
Total several DISTILLATION_STAGE's 1736 2239 5.22 11
36
40
CH4
AR
CH3OH
2.23
0.10
0.00
0.00
0.00
0.00
0.55
0.00
0.00
2.52 20.13 26.40 27.93 29.79 31.88
0.12 0.93 1.22 1.29 1.37 1.47
0.00 0.35 16.02 11.94 6.74 0.58
7.225 206.8 kg/s
90 C
1.693 206.8 kg/s
50 C
2.839 2.8 kg/s
235 C
0.61 2.8 kg/s
220 C
3.904 17.7 kg/s
220 C 602
47.8 890.7
139.0 bar 607
35.0 619.2
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
60.56
Heatsourc-DH 86.99
23.6 529.4 783
33.9 768.4 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
97
47.8 kg/s
235 C
2
68
35.0 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 33.9 kg/s 14.9 15.32 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 23.6 kg/s 4 100 C 685 30.6 bar 9.8 Preheater-sy NG 93 kr/GJ Methanol 26.4 kr/s 114 kr/GJ 129 kr/GJ 2.57 kr/kg 2.0 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 14.9 kg/s 68 606 2 68 0.81 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 407 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 68 35.0 144.0 bar 44.4 815.6 DH water 0 kr/ton Syngas 3.6 kr/s 110 kr/GJ - kr/GJ 1.94 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.2 MW 19 0.90 616.3 35.0 kg/s 640 139.0 bar 86 7.796 3.5 71.4 Water 32 kr/ton DH water 0.4 kr/s 32 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.183 63 C 2 44.4 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
94 0.75
Feed
14.9
3.294
30.6 bar
14.9 kg/s
220 C
Preheater-sy 89.04 164 C
Condenser-1
6.1
631 3.5 kg/s
4 164 C
Preheater-sy
Nomenclature:
Cond-steam-2 1.19 0.84 If methanol and DH share the plant costs
Condenser-1 90.1 8.751 621 631 4 (methanol and DH are the only products from the plant) -
7 705 706
17 3.5 bar
2 1.19 705 706
3 3.5 bar
6
SAND 31 40.6 733.6
643 139.0 bar
2 40.6 kg/s
4 139.0 bar
80 3.8 kg/s
138 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 20.6 kr/s 89 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
65 16.9 kg/s 12 3.0 kg/s Condenser 80.29 138 C Preheater-sy
DH water 9.9 kr/s 150 kr/Gjen Mass flow
128 C 128 C SAND 33 Condenser
Temperature
Dis_stage_1 0.01 811 8
58.0 1.0 bar
Reboil-meoh2 9.7
0.01 0.62
0 805 2
DH water
58.0 1.0 bar Mechanical power
10
6.588 17.6 58.2 2.027 58.0 kg/s 0.475 58.0 kg/s 1.178 3.0 9.981
707 3.5 bar Cond-steam-2 90 C 67.66 605 2 50 C 699 3.5 bar 0.25
708 17.6 kg/s SAND 393 Condenser
35.0 139.0 bar 1.8 32.43 Condenser
700 3.0 kg/s
4 128 C 616.1 35.0 kg/s 611 139.0 bar 94.7 9.068 3.8 82.57 2 128 C
Water /
Methanol
Methanol molar-% = 8.64
0 693 694
1 3.5 bar
2 0.7 kg/s
Dis_stage_1
4 5.41 695 696
14 3.5 bar
46 13.9 kg/s
2 27.8
5.444 0.65
5.444 705 706
14 3.5 bar
54 13.9 kg/s
4
25.61 625 635
11 3.5 bar
2
Methanol molar-% = 90.4
60 C
Comp-recirc
Methanol/
4 1.8 kg/s
3.561 60 C
Syngas Split-syngas
621 139.0 bar
631 3.8 kg/s
4 60 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
128 C
Reboil-meoh1
128 C
Reboil-meoh1
234 11.0 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

28. Flowsheet for metanolanlæg – for
parametervariationen (afkølingstemperaturen for
den metanolholdige gas)

0
1 1
1 P
2 M
type NOD*
1 1
type NOD*
1 1
1 Energy flow
2 Cost flow
type NOD*
1 2
1 Exergy efficiency
2 Exergy destruction
Water
Steam
3T 2 1 3Exergy destruction cost flow - based on specific cost of input 2.4 -0 0.0 0.006
4H 3 0 4Exergy destruction cost flow - based on specific cost of output 1 1.0 bar Electrolyser 423 10.0 bar 0.02 412 2
5EX 5 Component cost flow 2 2.4 kg/s 39.9 MW 201 2 0.0 kg/s 0.0 10.0 bar NG
6 EX_CH * Number of decimals Electrolyser 0.076 15 C SAND 39.89 0.00 850 C 0.176 0.0 kg/s
7 EX_PH SAND 301 Electrolyser
NG_reformer
667 C
8X
9 EX*M
10 EX_CH*M Comp-O2-1
DH water
0.371 803 4
87.5 1.0 bar
Electrolyser
13.18
1.7
0.80
0 802 2
87.5 1.0 bar DH water
0.93
Steam reformer
0.02
NG_reformer
O2 11 EX_PH*M 0.0 MW 1 0.911 87.5 kg/s 2.1 0.278 0.3 31.19 0.716 87.5 kg/s 0.0 0.002
12 C
13 C/EX
SAND 2E-05 55 C
Electro-cool
3
4
1.0 bar
2.1 kg/s
2
4
1.0 bar
0.3 kg/s
50 C
Electro-cool
Comp-O2-2
0.0 MW 3
Reformat
0.0 0.171
403
2
10.0 bar
0.0 kg/s
0.0
0
Ash
0.6 0.447
83 1.0 bar
4 0.6 kg/s
14 C/M
O2 0.113 7 4 0.113
0.90
2.1 1.0 bar
0.278 2.1 kg/s
90 C
Comp-O2-1
0.113 5 2
2.1 1.0 bar
0.278 2.1 kg/s
90 C
Comp-O2-1
DH water
Gas
0.113 90 C
Electrolyser
0.0 9E-41
6 1.0 bar
4 0.0 kg/s
12.7 90 C
Electrolyser
H2 O2 2E-04 401 2
0.0 1.0 bar
4E-04 0.0 kg/s
90 C
SAND 0.001
6E-04 402 4
0.94
6E-04 0.0 10.0 bar
0.001 0.0 kg/s
431 C
431 10.0 bar
4 0.0 kg/s
0.02 950 C
NG_reformer
0.00 850 C
NG_reformer
0.0 0.019
441 10.0 bar
2 0.0 kg/s
0.002 950 C
Heatex-O2
Gasifier
304 0.0 MW
SAND
0 800 C
Gasifier
0.0
0.029
5.0
33 2
1.0 bar
Steam
32
18.1 23.33
1.0 bar
801
2
14.3 0.117
1.0 bar
14.3 kg/s
15
4
4.6 2.116
1.0 bar
4.6 kg/s Heatsink-H2
4E-41 90 C
Split-O2-2
O2 0.90
Comp-H2
Comp-O2-2
Comp-O2-2
432
2
0.0 0.05
10.0 bar
0.0 kg/s
0.0
0.00 0.97 Heatex-O2
SAND 11
6.423 5.0 kg/s Heatex-GG-st 4 18.1 kg/s 0 50 C 0 60 C 0.0 MW 322 12.7 0.0 MW 9 Comp-CO2 0.005 950 C
730 C SAND 7 0.11 730 C Heatex-GG-DH
Cleaner SAND 0.0 SAND 5E-05 0.0 MW 7
Heatex-NG
0.89
10
Gasifier
11.8 256.6
10
18.3
235.8
Gasifier
10 GG2
0.11 0.78
1.0 bar 1.5
18.3 kg/s
800 C
10
18.3
234.7
11 2
1.0 bar
18.3 kg/s
761 C
Heatex-GG-st
0.11 0.98 10
23.2 18.3
221.4
12 2 0.00 0.74
1.0 bar 2.4
18.3 kg/s
130 C Heatex-GG-DH
10
18.3
220.9
13 2
1.0 bar
18.3 kg/s
60 C
1.00
Gas cleaner 9.6
13.7 219.8
14 1.0 bar
0.00
Heatsink
12.70
12.7 511 2
0.3 1.0 bar
31.19 0.3 kg/s
90 C
Heatsink-H2
0.019 503 4
0.0 19.8 bar
SAND 0.003
0.002 502 4 0.002 0.001 501 2
0.93
0.0 19.8 bar 0.0 1.0 bar
CO2
0.015 411 2
NG0.0
10.0 bar
0.173 0.0 kg/s
25 C
Heatex-NG
451
Heatex-NG
SAND
0.0 0.102
10.0 bar
0.0
13 0.02 0.89
0 434 Water 2
0.0 10.0 bar
82 1.0 bar Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH SAND 9 Cleaner
4 13.7 kg/s 0.166 0.0 kg/s 0.007 0.0 kg/s 0.005 0.0 kg/s 2 0.0 kg/s 1E-05 0.0 kg/s
2 11.8 kg/s 0.11 9 2 Heatex-GG-O2 18.1 10.27 0 21 4 9.6 60 C 259 C 279 C 15 C 0.01 950 C 107 C
7.02 120 C 2.1 1.0 bar SAND 5 31 1.0 bar 0.0 1.0 bar Cleaner 12.70 512 2 27.48 524 4 14.0 262.1 Mixer-CO2-NG
Comp-CO2 Comp-CO2
Heatex-H2O Pres-sep-3
Gasifier
H2O [mass-%] = 0.05
Dry-wood
1.132 2.1 kg/s
790 C
Gasifier
2 18.1 kg/s
0.079 120 C
Heatex-GG-st
-0 0.0 kg/s
60 C 521
Heatex-GG-DH 2
13.9 250.8
1.0 bar
13.9 kg/s
0.3
31.19
1.0 bar
0.3 kg/s
90 C
13.9
261.9
19.8 bar
13.9 kg/s
304 C
531
2
27.5
19.8 bar
14.0 kg/s
304 C
1E-04 422 2
Water 0.0 10.0 bar
1E-05 0.0 kg/s
0.0 Heatex-H2O
0.00 0.74 SAND 15
0 453 Water 4
Steam
811
14.3 0.5
1.0 bar
22.32 63 C
Comp-GG-H2-1
Comp-GG-H2-1
8.4 MW 11
Mixer-GG-H2 Comp-GG-H2-2
37.8 23.38
Syngas-cool1
33 C
Heatex-H2O
0.0
2E-05
10.0 bar
0.0 kg/s
4 14.3 kg/s 0.93
SAND 8.418 571 1.0 bar Syngas-cool1 Comp-NG_ref 109 C
0.00 90 C 25.31 37.7 21.36 6 37.8 kg/s SAND 21 0.0 MW 5 0.0 Heatex-H2O
0.0 0.046 0.0
13.1 16.91 Heatex-GG-DH
13.9 258.7 563 1.0 bar 0.17 200 C 6.0 SAND 0.002 0.0 0.094 0.0 0.046 0.0 0.018
0.45
105.9
Steam_dryer Biomass (dry)
SAND 1
35 4 0.45 29.9 0.45 34 2
1.0 bar Steam dryer 7.02 95.3 1.0 bar
34 1.0 bar
4 13.1 kg/s
0.077 730 C
Split-steam2
522 6.0 bar
2 13.9 kg/s
25.31 304 C
Cooler-GG-H2
2 37.7 kg/s
0.16 120 C
Cooler-GG-H2
6.0
0.17 0.82
25.31 523 2
13.9 6.0 bar
0.93
27.48
Syngas-cool1
561
2
0.164
37.8 21.38
1.0 bar
37.8 kg/s
120 C
0.17 0.82
0 541 4
0.0 19.8 bar
-0 0.0 kg/s
130 C
Water
Reformat
0.017 462 2 0.017
0.0 19.8 bar
0.16 0.0 kg/s
0.017 461 2
0.93
0.0 10.0 bar
0.158 0.0 kg/s
452 10.0 bar
2 0.0 kg/s
0.01 109 C
Mixer-NG_ref
433 10.0 bar
2 0.0 kg/s
0.005 107 C
Mixer-NG_ref
442 10.0 bar
2 0.0 kg/s
0.002 483 C
Mixer-NG_ref
59.97 105.9 kg/s 65.46 95.3 kg/s Cooler-GG-H2 37.7 23.36 256.2 13.9 kg/s Syngas-cool1 14.0 259.7 Syngas-cool1
250 C 154 C
120 C 22.3 257.4 278 C SAND 19 571 1.0 bar 130 C Comp-GG-H2-2 532 19.8 bar
Mixer-CO2-NG
Comp-NG_ref
Steam_dryer
81 1.0 bar Steam_dryer
4 37.7 kg/s Comp-GG-H2-2 2 14.0 kg/s
2
6.889
22.3 kg/s
15 C
Steam
0.17 200 C
Cooler-GG-H2
6.1 MW
SAND
13
6.116
27.5 130 C
Comp-syngas1 Comp-syngas1 Component information
Technical lifetime =
O&M =
15 years
0.02 of the componentprice per year
Operating hours = 8000
Exergy
Steam
DH-condenser
Steam_dryer
Biomass (wet)
5.6 3.166
41 1.0 bar
2 5.6 kg/s
Steam
0.93
29.67
14.0 265.3
533 65.1 bar
4 14.0 kg/s
Syngas 29.67 304 C
6.1 MW
SAND
15
6.12
Electrolyser
Comp-H2
Comp-O2-1
Node before
component
1
2
5
Component
type
Electrolyser
Compressor
Compressor
DNA name
ELECTROLYSER
COMPRE_1
COMPRE_1
Specific price
1.52 mio. kr/MWe
4.50 mio. kr/MW
4.50 mio. kr/MW
Price
[mio. kr]
61
0
0
Total
price
[mio. kr]
79
0
0
C
[kr/s]
0.18
0.00
0.00
Input:
NG
Biomass
Power*
Total power
* for electrolyser
0 MW
257 MW
40 MW
66 MW
Output:
Methanol
DH
Oxygen
Syngas
231 MW
12 MW
0 MW
9 MW
SAND 79 0.024 120 C 52.1 32.3 set_temp-2
Gasifier
9 Gasifier
GASIFI_3 3.80 mio. kr/MW-biomass 818 1064 2.46
DH-condenser
0.73 13.0 0.41 811 12
DH condenser0.41
87.5 1.0 bar
581
2
0.24
1.0 bar
52.1 kg/s
200 C Steam
0.26 571 8
Heatex-GG-O2
Heatex-GG-st
Heatex-GG-DH
10
11
12
Heat exchanger
Heat exchanger
Heat exchanger
HEATEX_2
HEATEX_2
GASCOOL2
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
1
9
1
1
12
1
0.00
0.03
0.00
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
78% (with power for electrolyser)
72% (with total power)
78%
5.6 0.22 3.055 87.5 kg/s DH-cooler DH-cooler
57.8 1.0 bar Cleaner 13 Gas cleaner GASCLE_2 0.00 mio. kr/(kg/s)-gas 0 0 0.00
42 1.0 bar 90 C SAND 25 35.82 57.8 kg/s Steam_dryer
34 Steam dryer DRYER_04 4.10 mio. kr/(kg/s)-evaporated 43 56 0.13
4 5.6 kg/s
0 95 C
DH-condenser
DH-condenser
440.6 15.39
811 1.0 bar
0.010 811 6
49.5 1.0 bar
1.731 49.5 kg/s
0.48 8.3 0 804 2
DH cooler
DH water
0.01 49.5 1.0 bar
0.406 49.5 kg/s 1.0 0.639
0.251 562 2
57.8 1.0 bar
200 C
Syngas-cool2 9.2
0.26 0.91
Syngas-cool2
SAND 23
DH-condenser
Comp-O2-2
Heatex-O2
41
401
402
Heat exchanger
Compressor
Heat exchanger
HEATEX_1
COMPRE_1
HEATEX_4
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
5
0
0
7
0
0
0.02
0.00
0.00 Energy
Water
2 440.6 kg/s
0.48 90 C
DH
DH water
90 C
DH-cooler
35
6
52.1 29.53
1.0 bar
52.1 kg/s
50 C
DH-cooler
571 1.0 bar
10 1.0 kg/s
0.00 225 C
Cond-steam-1
32.76 57.8 kg/s
120 C
Syngas-cool2
534
2
12.4 261.9
65.1 bar
12.4 kg/s
0 551 4
1.5 65.1 bar
0.137 1.5 kg/s
135 C
NG_reformer
Heatex-NG
Water
Heatex-H2O
Comp-NG_ref
Comp-CO2
403
411
422
461
501
NG reformer
Heat exchanger
Heat exchanger
Compressor
Compressor
STEAM_REFORMER
GASCOOL2
GASCOOL2
COMPRE_1
COMPRE_1
1.05 mio. kr/MW-NG
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
4.50 mio. kr/MW
0
0
0
0
0
0
0
0
0
0
0.00
0.00
0.00
0.00
0.00
Input:
NG
Biomass
Power*
Total power
0MW
215 MW
40 MW
66 MW
Output:
Methanol
DH
Oxygen
Syngas
205 MW
74 MW
0 MW
7 MW
Energy content in DH water = 74 MW 0.24 120 C
DH-cooler
Steam
29.67 135 C
Comp-syngas2
Syngas-cool2 Heatsink-H2
Comp-GG-H2-1
511
521
Heat exchanger
Compressor
HEATSNK0
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0
38
0
49
0.00
0.11
* for electrolyser
Urenhed:
0.006 %
Methanol loss in distillation [%] = 1.0
Methanol molar-% = 99.99
Water /
671
1.0 0.566
1.0 bar
0.93
Comp-syngas2
30.95 3.6 MW 17
SAND 3.617
12.4 265.2
Cooler-GG-H2
Comp-GG-H2-2
Syngas-cool1
Comp-syngas1
522
523
531
532
Heat exchanger
Compressor
Heat exchanger
Compressor
GASCOOL2
COMPRE_1
GASCOOL2
COMPRE_1
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
0.40 mio. kr/MW-transferred
4.50 mio. kr/MW
2
28
2
28
3
36
3
36
0.01
0.08
0.01
0.08
Methanol-efficiency 1:
Methanol-efficiency 2:
Total efficiency:
80% (with power for electrolyser)
73% (with total power)
102%
Methanol
2 1.0 kg/s 535 144.0 bar Syngas-cool2 533 Heat exchanger GASCOOL2 0.40 mio. kr/MW-transferred 4 5 0.01
0.00 120 C 2 12.4 kg/s Comp-syngas2
534 Compressor COMPRE_1 4.50 mio. kr/MW 16 21 0.05
Cond-steam-1
30.95 248 C Meoh-convert
601 Meoh converter MEOH_CONVERTER ##### mio. kr/(kmol/s-syngas) 260 338 0.78 Gas composition at specific nodes (mol-%)
31.43 10.3 231.1 set-M
Preheater-sy 602 Heat exchanger GASCOOL4 0.40 mio. kr/MW-transferred 2 3 0.01
793
794
3.5 bar
10.3 kg/s 601
43.5 438.2
144.0 bar
Condenser-1
Syngas Condenser
640
643
Heat exchanger
Heat exchanger
GASCOOL4
GASCOOL4
0.40 mio. kr/MW-transferred
0.40 mio. kr/MW-transferred
4
1
6
2
0.01
0.00
Node 10
3
15 431 534 601 602 640 643 605
15 23 33 35 41 43 39 37
M-factor
1.78
4 100 C 2 43.5 kg/s Comp-recirc
605 Compressor COMPRE_1 4.50 mio. kr/MW 1 1 0.00
Species
Split-meoh1
135 44.2 992.6 Steam
0 682 4
53 235 C
Meoh-convert
feed_Water
Cond-steam-1
625
671
Distillation column
Heat exchanger
DISTILLATION_STAGE*
HEATEX_1
23.52 mio. kr/(kg/s-feed)
0.40 mio. kr/MW-transferred
254
0
330
0
0.76
0.00
1
3
H2
N2
45.61
0.21
0.00 57.70 60.62 45.05 23.06 24.07 28.74 30.00
0.00 0.00 0.23 2.23 3.20 3.34 3.99 4.16
791 3.5 bar 17.9 30.6 bar Cond-steam-2
685 Heat exchanger HEATSNK0 0.40 mio. kr/MW-transferred 13 17 0.04 4 CO 32.28 0.00 22.49 34.04 20.22 5.27 5.50 6.56 6.85
792 44.2 kg/s 18.3 17.9 kg/s DH-cooler
804 Heat exchanger HEATEX_1 0.40 mio. kr/MW-transferred 3 4 0.01 6 CO2 9.39 99.97 5.09 0.03 26.24 39.65 41.40 49.42 51.59
Heatsourc-DH 4 100 C Cond-steam-1 235 C Heatsourc-DH
806 Heat exchanger HEATSRC0 0.40 mio. kr/MW-transferred 18 24 0.05 7 H2O-G 12.25 0.00 14.17 4.82 2.39 1.47 1.13 0.20 0.04
SAND 390 Cond-meoh SAND 35 Convert-cool * The distillation column is composed of 9 H2S 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.054 811 10 45.2
269.8 1.0 bar 0.054 0.70
0 806 2
DH water
269.8 1.0 bar
0 683 2
0.1 30.6 bar
0.2
0.00 0.81
0 684 4
0.1 30.6 bar
Water
0 681 2
17.9 30.6 bar
33.2 Meoh-convert
Methanol 1.00 SAND
converter 54
311
Total several DISTILLATION_STAGE's 1613 2069 4.85 11
36
40
CH4
AR
CH3OH
0.15
0.10
0.00
0.00
0.00
0.00
0.55
0.00
0.00
0.16
0.11
0.00
1.56 2.24 2.33
1.07 1.54 1.60
1.25 23.59 20.62
2.79
1.91
6.39
2.91
2.00
2.45
9.427 269.8 kg/s
90 C
2.209 269.8 kg/s
50 C
0.115 0.1 kg/s
235 C
0.025 0.1 kg/s
220 C
3.935 17.9 kg/s
220 C 602
43.5 422.2
139.0 bar 607
31.1 171.2
144.0 bar Input prices
GG
H2S
NG_ref-cool Syngas-loop1 Syngas-meoh- Syngas-loop2
Syngas-3 Syngas-meoh Syngas-loop3
103.5
Heatsourc-DH 135
33.9 761.5 783
44.2 1003 Heatsourc-DH
3.5 bar
Cond-steam-1 Cond-steam-1 Convert-cool
2
54
43.5 kg/s
235 C
2
22
31.1 kg/s
225 C
Input
Electric power
Price
324 kr/GJ Output cost
Comparable fuel prices
781 3.5 bar 784 44.2 kg/s 17.7 18.19 Preheater-sy
Mixer-syn_re
Mechanical power 341 kr/GJ Output Cost flow Cost (exergy) Cost (energy) Cost (mass) Cost (volume) Fuel Price (exergy) Price (volume)
782 33.9 kg/s 4 100 C 685 30.6 bar 4.9 Preheater-sy NG 93 kr/GJ Methanol 31.4 kr/s 136 kr/GJ 153 kr/GJ 3.05 kr/kg 2.4 kr/l Methanol (commercial) 142 kr/GJ 2.5 kr/l
2 100 C Dis_stage_17 2 17.7 kg/s 22 606 2 22 0.70 SAND 29 Biomass 32 kr/GJ Oxygen 0.0 kr/s 407 kr/GJ - kr/GJ 0.05 kr/kg - kr/l Petrol 187 kr/GJ 6.6 kr/l
Dis_stage_17 0 235 C Comp-recirc 22 31.1 144.0 bar 41.6 378.3 DH water 0 kr/ton Syngas 1.2 kr/s 132 kr/GJ - kr/GJ 0.72 kr/kg - kr/l Crude oil 58 kr/GJ 2.2 kr/l
Cond-steam-2 0.1 MW 19 0.90 169.6 31.1 kg/s 640 139.0 bar 91 5.347 1.9 41.46 Water 32 kr/ton DH water 0.5 kr/s 31 kr/GJ 7 kr/GJ 0.00 kr/kg - kr/l Ethanol 100 kr/GJ 2.4 kr/l
0 681 4 SAND 0.136 103 C 2 41.6 kg/s 621 139.0 bar CO2 114 kr/ton Water 0 kr/s - kr/GJ - kr/GJ - kr/kg - kr/l
Distillation
column
150 0.79
Feed
17.7
3.91
30.6 bar
17.7 kg/s
220 C
Preheater-sy 48.79 187 C
Condenser-1
10.7
631 1.9 kg/s
4 187 C
Preheater-sy
Nomenclature:
Cond-steam-2 3.70 0.50 If methanol and DH share the plant costs
Condenser-1 94.1 20.65 621 631 4 (methanol and DH are the only products from the plant) -
15 705 706
23 3.5 bar
2 3.70 705 706
6 3.5 bar
6
SAND 31 34.3 214.8
643 139.0 bar
2 34.3 kg/s
7 139.0 bar
158 7.2 kg/s
134 C
and the DH cost is fixed corresponding to the DH price:
Output Cost flow Cost
Methanol 22.0 kr/s 95.1 kr/Gjex Electrical power
Node nr
Pressure
Transferred heat [MW]
121 22.7 kg/s 30 5.6 kg/s Condenser 28.14 134 C Preheater-sy
DH water 11.1 kr/s 150 kr/Gjen Mass flow
124 C 124 C SAND 33 Condenser
Temperature
Dis_stage_1 0.00 811 8
19.5 1.0 bar
Reboil-meoh2 3.3
0.00 0.35
0 805 2
DH water
19.5 1.0 bar Mechanical power
10
15.01 23.2 111.5 0.68 19.5 kg/s 0.159 19.5 kg/s 3.685 5.6 26.8
707 3.5 bar Cond-steam-2 90 C 22.36 605 2 50 C 699 3.5 bar 0.25
708 23.2 kg/s SAND 393 Condenser
31.1 139.0 bar 1.6 8.918 Condenser
700 5.6 kg/s
4 124 C 169.4 31.1 kg/s 611 139.0 bar 96.2 4.613 1.6 34.97 2 124 C
Water /
Methanol
Methanol molar-% = 13.12
0 693 694
0 3.5 bar
2 0.5 kg/s
Dis_stage_1
4 11.32 695 696
17 3.5 bar
82 17.1 kg/s
2 33.0
11.36 0.64
11.36 705 706
17 3.5 bar
91 17.1 kg/s
4
30.61 625 635
11 3.5 bar
2
Methanol molar-% = 93.8
100 C
Comp-recirc
Methanol/
4 1.6 kg/s
1.177 100 C
Syngas Split-syngas
621 139.0 bar
631 1.6 kg/s
4 100 C
Preheater-sy
Reboil-meoh2
Heat
Exergy efficiency [-]
64 C
set-x-2
124 C
Reboil-meoh1
124 C
Reboil-meoh1
234 10.8 kg/s
101 C
meas_flow
Methanol mass flow = 10.4 kg/s
water

29. Matlab-kode til Scenarie 1

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 1 of 12
1 clear all
2 clc
3 format compact
4
5 stregfarve_{1}='-yp' ;
6 farve_{1}= 'y';
7 stregfarve_{2}='-k+' ;
8 farve_{2}= 'k';
9 stregfarve_{3}='-ro' ;
10 farve_{3}= 'r';
11 stregfarve_{4}='-g*' ;
12 farve_{4}= 'g';
13 stregfarve_{5}='-bx' ;
14 farve_{5}= 'b';
15 stregfarve_{6}='-cs' ;
16 farve_{6}= 'c';
17 stregfarve_{7}='-md' ;
18 farve_{7}= 'm';
19
20 fil{1}='El-priser2000.txt' ;
21 fil{2}='El-priser2001.txt' ;
22 fil{3}='El-priser2002.txt' ;
23 fil{4}='El-priser2003.txt' ;
24 fil{5}='El-priser2004.txt' ;
25 fil{6}='El-priser2005.txt' ;
26 fil{7}='El-priser2006.txt' ;
27
28 elpris_gennemsnit_ref=223; % [kr/MWh]
29
30 kkk=1;
31 while kkk

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 2 of 12
53 lagerpris=lagerpris*3600; % [kr/MWh]
54 forhold_lager=5; % forholdet mellem max- og min-indhold i brint- og iltlager
55 lagerprisforhold=1; % forhold mellem brint- og iltlagerprisen (hvis mindre end 1
er iltlageret billigst - det er ikke den specifikke pris)
56 kalkulationsrente=0.05
57 LHV_brint=10.78 % [MJ/Nm^3]
58 maxLagertryk=100 % [bar]
59 DogV=0.02;
60
61 % Referenceudgifterne:
62 ref_eludgift=elektrolyseeffekt*time(end)/antal_aar*elpris_gennemsnit/1E6*levetid
63 ref_eludgift_ref=elektrolyseeffekt*time(end)
/antal_aar*elpris_gennemsnit_ref/1E6*levetid
64 ref_anlagsudgift=elektrolyseanlagspris*euro*elektrolyseeffekt
65 ref_DogV=ref_anlagsudgift*DogV*levetid
66 ref_omkostninger=ref_anlagsudgift+ref_DogV+ref_eludgift_ref
67 ref_omkostninger_aar=ref_anlagsudgift+ref_DogV+ref_eludgift
68
69 Driftstimer=5000*antal_aar; % Driftstimer af elektrolyseanlæg
70 k=1;
71
72 % Undersøger hvilket antal Driftstimer der er optimalt for
73 % elektrolyseanlægget
74 while Driftstimer >= 900*antal_aar & k

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 3 of 12
101 for ii=1:24
102 driftstatus_doegn_foer(ii,k)=0;
103 end
104 end
105 while i

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 4 of 12
k))*DogV*levetid;
151 DogV_samlet2(k)=DogV_samlet(iterationer,k);
152 sparet(iterationer,k)=sparet_el(iterationer,k)-(ekstraanlagsudgift(k)
+Lagerprisen(iterationer,k))*(1+DogV*levetid);
153 sparet2(k)=sparet(iterationer,k);
154 andel_sparet(k)=sparet(iterationer,k)/ref_omkostninger;
155 lagerpris_andel(k)=Lagerprisen2(k)/ref_anlagsudgift;
156 tilbagebetalingstid_aar(k)=(ekstraanlagsudgift(k)+Lagerprisen2(k))/
(sparet_el2(k)/levetid-(ekstraanlagsudgift(k)+Lagerprisen2(k))*DogV);
157 forrentning(k)=1/tilbagebetalingstid_aar(k);
158
159 sparet_sum_nutidsvardi(k)=0;
160 stop_nutidsvardi=0;
161 for i=1:50
162 sparet_aarligt=(sparet_el2(k)/levetid-(ekstraanlagsudgift(k)
+Lagerprisen2(k))*DogV)/(1+kalkulationsrente)^i;
163 sparet_sum_nutidsvardi(k)=sparet_sum_nutidsvardi(k)+sparet_aarligt;
164 if sparet_sum_nutidsvardi(k) >= ekstraanlagsudgift(k)+Lagerprisen2(k);
165 andel_af_aar=(sparet_sum_nutidsvardi(k)-(ekstraanlagsudgift(k)
+Lagerprisen2(k)))/sparet_aarligt;
166 tilbagebetalingstid2_aar(k)=i-andel_af_aar;
167 stop_nutidsvardi=1;
168 break
169 end
170 i=i+1;
171 end
172 if stop_nutidsvardi == 0
173 tilbagebetalingstid2_aar(k)=99;
174 end
175 sparet_sum_nutidsvardi(k)=0;
176 for i=1:levetid
177 sparet_sum_nutidsvardi(k)=sparet_sum_nutidsvardi(k)+(sparet_el2(k)
/levetid-(ekstraanlagsudgift(k)+Lagerprisen2(k))*DogV)/(1+kalkulationsrente)^i;
178 end
179 sparet_nutidsvardi(k)=sparet_sum_nutidsvardi(k)-ekstraanlagsudgift(k)-
Lagerprisen2(k);
180 andel_sparet_nutidsvardi(k)=sparet_nutidsvardi(k)/ref_omkostninger;
181
182 % Lokaliserer "peak"- og "off-peak"-områder i lagerbeholdningen henover
alle
183 % timerne. Et "peak"-område er et område hvor der forekommer en stigning i
lagerbeholdningen fra minimumbeholdningen til maksimumbeholdningen.
184 % Omvendt er et "off-peak"-område et område hvor der forekommer et fald i
lagerbeholdningen fra maksimumbeholdningen til minimumbeholdningen.
185 [minlager,minnr]=min(lager(:,k));
186 [maxlager,maxnr]=max(lager(:,k));
187 i=1;
188 s=1;
189 f=1;
190 lagerhistorie=1;
191 while i maxlager-lagerreduktion2*3
193 if lagerhistorie == 0
194 stigning(s,2)=i;
195 s=s+1;
196 elseif lagerhistorie == 1

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 5 of 12
197 start=i;
198 startstatus=2;
199 end
200 fald(f,1)=i;
201 lagerhistorie=2;
202 elseif lager(i,k) < minlager+lagerreduktion2*3
203 if lagerhistorie == 2
204 fald(f,2)=i;
205 f=f+1;
206 elseif lagerhistorie == 1
207 start=i;
208 startstatus=0;
209 end
210 stigning(s,1)=i;
211 lagerhistorie=0;
212 end
213 i=i+1;
214 end
215 if lagerhistorie == 2 & startstatus == 0
216 fald(f,2)=start;
217 f=f+1;
218 elseif lagerhistorie == 0 & startstatus == 2
219 stigning(s,2)=start;
220 s=s+1;
221 end
222 f=f-1;
223 s=s-1;
224 if f ~= s
225 stop=1
226 iterationer
227 warning('f forskellig fra s')
228 break
229 end
230
231 % Flytter Driftstimer fra "peak"-områder til "off-peak"-områder, indtil det
ikke længere er økonomisk
232 % fordelagtigt, eller til lagerbeholdningen skal opdateres
233 antal_flyt=0;
234 while iterer == 0
235
236 % Lokaliserer hvilke Driftstimer, som foregår i "peak"-områder, som
skal flyttes til "off-peak"-områder
237 i=1;
238 while i

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 6 of 12
248 if elpris_ind_1 = elpris_ud_2
266 elpris_ud = elpris_ud_1;
267 time_ud(i) = time_ud_1;
268 else
269 elpris_ud = elpris_ud_2;
270 time_ud(i) = time_ud_2;
271 end
272 end
273 i=i+1;
274 end
275 if time_ud(s) < time_ud(1) & s ~= 1
276 time_ud=sort(time_ud);
277 end
278 if time_ind(s) < time_ind(1) & s ~= 1
279 time_ind=sort(time_ind);
280 end
281
282 % Finder minimumlagerbeholdningerne for de områder hvor der
283 % forekommer en reduktion i lagerbeholningen pga flytningerne
284 % af Driftstimer fra "peak"-områder til "off-peak"-områder. Samt
285 % maksimumlagerbeholdningerne for de områder hvor der
286 % forekommer en tilvækst i lagerbeholningen pga flytningerne
287 % af Driftstimer fra "peak"-områder til "off-peak"-områder.
288 i=1;
289 while i i
294 [maxlager_interval(i),maxnr_interval]=max(lager(time_ind
(i):time_ud(i+1)-1,k));
295 maxnr_interval=maxnr_interval+time_ind(i)-1;
296 else
297 if time_ud(1) == 1
298 [maxlager_interval(i),maxnr_interval]=max(lager
(time_ind(i):end,k));

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 7 of 12
299 maxnr_interval=maxnr_interval+time_ind(i)-1;
300 else
301 [maxlager_interval_1,maxnr_interval_1]=max(lager
(time_ind(i):end,k));
302 maxnr_interval_1=maxnr_interval_1+time_ind(i)-1;
303 [maxlager_interval_2,maxnr_interval_2]=max(lager(1:
time_ud(1)-1,k));
304 if maxlager_interval_1 > maxlager_interval_2
305 maxlager_interval(i)=maxlager_interval_1;
306 maxnr_interval=maxnr_interval_1;
307 else
308 maxlager_interval(i)=maxlager_interval_2;
309 maxnr_interval=maxnr_interval_2;
310 end
311 end
312 end
313 else
314 [maxlager_interval(i),maxnr_interval]=max(lager(time_ind(i):
time_ud(i)-1,k));
315 maxnr_interval=maxnr_interval+time_ind(i)-1;
316 if s > i
317 [minlager_interval(i),minnr_interval]=min(lager(time_ud(i):
time_ind(i+1)-1,k));
318 minnr_interval=minnr_interval+time_ud(i)-1;
319 else
320 if time_ind(1) == 1
321 [minlager_interval(i),minnr_interval]=min(lager(time_ud
(i):end,k));
322 minnr_interval=minnr_interval+time_ud(i)-1;
323 else
324 [minlager_interval_1,minnr_interval_1]=min(lager
(time_ud(i):end,k));
325 minnr_interval_1=minnr_interval_1+time_ud(i)-1;
326 [minlager_interval_2,minnr_interval_2]=min(lager(1:
time_ind(1)-1,k));
327 if minlager_interval_1 < minlager_interval_2
328 minlager_interval(i)=minlager_interval_1;
329 minnr_interval=minnr_interval_1;
330 else
331 minlager_interval(i)=minlager_interval_2;
332 minnr_interval=minnr_interval_2;
333 end
334 end
335 end
336 end
337 i=i+1;
338 end
339 i=1;
340 diff=0;
341 while i diff_elpris
346 sidste=1
347 diff

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 8 of 12
348 break
349 end
350 if max(maxlager_interval) < maxlager-lagerreduktion2*(antal_flyt+1) &
min(minlager_interval)-lagerreduktion2*(antal_flyt+1) > minlager
351 i=1;
352 while i

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 9 of 12
401 time_doegn=time_doegn+1;
402 if time_doegn == 25
403 time_doegn = 1;
404 end
405 i=i+1;
406 end
407 lagerfejl=min(lager(:,k));
408 iii=iii+1;
409 end
410 timer_i_drift_=timer_i_drift(end,k)
411 Driftstimer
412 iterationer
413 sparet_=sparet2(k)
414 lagerfejl_start_stop=lager(end,k)-lager(1,k)
415
416 iterationer=iterationer-1;
417 iterationer_list(k)=iterationer;
418 andel_list(k)=andel;
419 Driftstimer_list(k)=Driftstimer;
420 Driftstimer=Driftstimer-timestep;
421 k=k+1;
422 end
423 [maxxx,kk]=max(sparet2)
424
425 figure(3);
426 bar(uge_drift(:,kk))
427 axis([0 53*antal_aar 0 24*7])
428 %title('Driftsfordeling på ugebasis')
429 ylabel('Driftstimer per uge [h]' )
430 xlabel('Uge-nr. [-]' )
431
432 figure(4);
433 plot(lager(:,kk))
434 axis tight
435 %title('Variationen i lagerbeholdningen henover året')
436 ylabel('Brintlagerbeholdning [MWh]' )
437 xlabel('Time på året [-]' )
438
439 figure(19);
440 plot(driftstatus_doegn_foer(:,kk),'k' )
441 hold on
442 plot(driftstatus_doegn_efter(:,kk),'b')
443 ylabel('Antal timer [-]' )
444 hold off
445 legend('før' ,'efter' ,1);
446
447 figure(7);
448 plot((ref_eludgift-sparet_el(1:iterationer_list(kk),kk))
/ref_omkostninger_aar*100,'-k' )
449 hold on
450 plot(Lagerprisen(1:iterationer_list(kk),kk)/ref_omkostninger_aar*100, '--r')
451 plot(anlagsudgift2(1:iterationer_list(kk),kk)/ref_omkostninger_aar*100,':g')
452 plot(DogV_samlet(1:iterationer_list(kk),kk)/ref_omkostninger_aar*100, ':b')
453 plot(sparet(1:iterationer_list(kk),kk)/ref_omkostninger_aar*100,'-.c' )
454 hold off
455 legend('El' ,'Gaslagre','Elektrolyseanlæg' ,'D&V','Sparede omkostninger' ,1);

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 10 of 12
456 %title('Udvikling gennem optimeringen for år 2002 ved 2000 Driftstimer')
457 ylabel('Omkostninger [%]' )
458 xlabel('Iterationsnummer [-]' )
459
460 figure(8);
461 plot(Driftstimer_list,(ref_eludgift-sparet_el2)/ref_omkostninger_aar*100,'k+','LineWidth'
,2,...
462 'MarkerEdgeColor' ,'k',...
463 'MarkerFaceColor' ,'k',...
464 'MarkerSize' ,10)
465 hold on
466 plot(Driftstimer_list,Lagerprisen2/ref_omkostninger_aar*100, '-ro','LineWidth' ,2,...
467 'MarkerEdgeColor' ,'r',...
468 'MarkerFaceColor' ,'r',...
469 'MarkerSize' ,10)
470 plot(Driftstimer_list,anlagsudgift/ref_omkostninger_aar*100, '-g*','LineWidth' ,2,...
471 'MarkerEdgeColor' ,'g',...
472 'MarkerFaceColor' ,'g',...
473 'MarkerSize' ,10)
474 plot(Driftstimer_list,DogV_samlet2/ref_omkostninger_aar*100, '-bx','LineWidth' ,2,...
475 'MarkerEdgeColor' ,'b',...
476 'MarkerFaceColor' ,'b',...
477 'MarkerSize' ,10)
478 plot(Driftstimer_list,sparet2/ref_omkostninger_aar*100,'-cs' ,'LineWidth',2, ...
479 'MarkerEdgeColor' ,'c',...
480 'MarkerFaceColor' ,'c',...
481 'MarkerSize' ,10)
482 axis([500 time(end) 0 100])
483 %title('Omkostninger')
484 ylabel('Omkostninger [%]' )
485 xlabel('Driftstimer [timer]' )
486 legend('El' ,'Gaslagre','Elektrolyseanlæg' ,'D&V','Sparede omkostninger' ,1);
487 hold off
488
489 figure(9);
490 hold on
491 plot(Driftstimer_list,andel_sparet*100,stregfarve,'LineWidth' ,2,...
492 'MarkerEdgeColor' ,farve,...
493 'MarkerFaceColor' ,farve,...
494 'MarkerSize' ,10)
495 axis([500 time(end) 0 30])
496 %title('Sparede omkostninger')
497 ylabel('Sparede omkostninger [%]' )
498 xlabel('Driftstimer [timer]' )
499 legend('2000','2001' ,'2002','2003','2004','2005','2006',1);
500 hold off
501
502 figure(10);
503 hold on
504 plot(Driftstimer_list,andel_sparet_nutidsvardi*100,stregfarve, 'LineWidth',2, ...
505 'MarkerEdgeColor' ,farve,...
506 'MarkerFaceColor' ,farve,...
507 'MarkerSize' ,10)
508 axis([500 time(end) 0 30])
509 %title('Sparede omkostninger i nutidsværdi')
510 ylabel('Sparede omkostninger i nutidsværdi [%]' )

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 11 of 12
511 xlabel('Driftstimer [timer]' )
512 legend('2000','2001' ,'2002','2003','2004','2005','2006',1);
513 hold off
514
515 figure(11);
516 hold on
517 plot(Driftstimer_list,lagerpris_andel*100,stregfarve, 'LineWidth',2, ...
518 'MarkerEdgeColor' ,farve,...
519 'MarkerFaceColor' ,farve,...
520 'MarkerSize' ,10)
521 axis([500 time(end) 0 100])
522 %title('Lagerprisen')
523 ylabel('Samlet lagerpris [%]' )
524 xlabel('Driftstimer [timer]' )
525 legend('2000','2001' ,'2002','2003','2004','2005','2006',1);
526 hold off
527
528 figure(12);
529 hold on
530 plot(Driftstimer_list,forrentning*100,stregfarve,'LineWidth' ,2,...
531 'MarkerEdgeColor' ,farve,...
532 'MarkerFaceColor' ,farve,...
533 'MarkerSize' ,10)
534 axis([500 8500 0 50])
535 %title('Forrentning af investering')
536 ylabel('Forrentning af investering [%]' )
537 xlabel('Driftstimer [timer]' )
538 legend('2000','2001' ,'2002','2003','2004','2005','2006',1);
539 hold off
540
541 figure(13);
542 hold on
543 plot(Driftstimer_list,tilbagebetalingstid_aar,stregfarve,'LineWidth' ,2,...
544 'MarkerEdgeColor' ,farve,...
545 'MarkerFaceColor' ,farve,...
546 'MarkerSize' ,10)
547 axis([500 8500 0 levetid])
548 %title('Tilbagebetalingstider')
549 ylabel('Tilbagebetalingstid [år]' )
550 xlabel('Driftstimer [timer]' )
551 legend('2000','2001' ,'2002','2003','2004','2005','2006',1);
552 hold off
553
554 figure(14);
555 hold on
556 plot(Driftstimer_list,tilbagebetalingstid2_aar,stregfarve,'LineWidth' ,2,...
557 'MarkerEdgeColor' ,farve,...
558 'MarkerFaceColor' ,farve,...
559 'MarkerSize' ,10)
560 axis([500 8500 0 levetid])
561 %title('Tilbagebetalingstider regnet i nutidsværdi')
562 ylabel('Tilbagebetalingstid (beregnet ud fra nutidsværdi) [år]' )
563 xlabel('Driftstimer [timer]' )
564 legend('2000','2001' ,'2002','2003','2004','2005','2006',1);
565 hold off
566

18-03-07 23:10 D:\DTU\Eksamensprojekt\bilag\elektrolysedrift.m 12 of 12
567 end

30. Matlab-kode til Scenarie 2

19-03-07 19:26 D:\DTU\Eksamensprojekt\bilag\elektrolysedriftreal.m 1 of 5
1 clear all
2 clc
3 format compact
4
5 stregfarve_{1}='-yp' ;
6 farve_{1}= 'y';
7 stregfarve_{2}='-k+' ;
8 farve_{2}= 'k';
9 stregfarve_{3}='-ro' ;
10 farve_{3}= 'r';
11 stregfarve_{4}='-g*' ;
12 farve_{4}= 'g';
13 stregfarve_{5}='-bx' ;
14 farve_{5}= 'b';
15 stregfarve_{6}='-cs' ;
16 farve_{6}= 'c';
17 stregfarve_{7}='-md' ;
18 farve_{7}= 'm';
19
20 fil{1}='El-priser2000.txt' ;
21 fil{2}='El-priser2001.txt' ;
22 fil{3}='El-priser2002.txt' ;
23 fil{4}='El-priser2003.txt' ;
24 fil{5}='El-priser2004.txt' ;
25 fil{6}='El-priser2005.txt' ;
26 fil{7}='El-priser2006.txt' ;
27
28 elpris_gennemsnit_ref=223; % [kr/MWh]
29
30 kkk=1;
31 while kkk

19-03-07 19:26 D:\DTU\Eksamensprojekt\bilag\elektrolysedriftreal.m 2 of 5
teknologikataloget (ENS)
55 lagerpris=lagerpris*3600; % [kr/MWh]
56 forhold_lager=5; % forholdet mellem max- og min-indhold i brint- og iltlager
57 lagerprisforhold=1; % forhold mellem brint- og iltlagerprisen (hvis mindre end 1
er iltlageret billigst - det er ikke den specifikke pris)
58 faktor=300
59 faktorstep=50
60 lagerpris_andel=0.1 % 1/44 er en dags forbrug
61
62 ref_eludgift=elektrolyseeffekt*time(end)*elpris_gennemsnit/1E6*levetid
63 ref_eludgift_ref=elektrolyseeffekt*time(end)*elpris_gennemsnit_ref/1E6*levetid
64 ref_anlagsudgift=elektrolyseanlagspris*euro*elektrolyseeffekt
65 ref_DogV=ref_anlagsudgift*DogV*levetid
66 ref_omkostninger=ref_anlagsudgift+ref_DogV+ref_eludgift_ref
67
68 lagerprisen=ref_anlagsudgift*lagerpris_andel; % mio. kr
69 lagerbeholdning=lagerprisen*1E6/(lagerpris*(lagerprisforhold+1)) % MWh
70 lagerbeholdning_effektiv=lagerbeholdning*(forhold_lager-1)/forhold_lager % MWh
71 andel_af_aarslager=lagerbeholdning_effektiv/(time(end)*elektrolyseeffekt*virk);
72 antal_dages_forbrug=andel_af_aarslager*time(end)/24;
73 lagerpris_andel=lagerprisen/ref_anlagsudgift;
74
75 elpris_funk=@(elpris_Driftstimer,lager,faktor)elpris_Driftstimer+((forhold_lager+1)
/(2*forhold_lager)-lager/lagerbeholdning)*faktor;
76
77 Driftstimer=5000;
78
79 k=1;
80 lagerstatus=lagerbeholdning/2;
81 while Driftstimer >= 900 & faktor

19-03-07 19:26 D:\DTU\Eksamensprojekt\bilag\elektrolysedriftreal.m 3 of 5
106 end
107 time_doegn=time_doegn+1;
108 if time_doegn == 25
109 time_doegn = 1;
110 end
111 elpris_hist(i)=elpris(i);
112 lagerstatus=lager(i,aar,k);
113 if i > 500*antal
114 elpris_hist_sort=sort(elpris_hist);
115 elpris_Driftstimer=elpris_hist_sort(Driftstimer);
116 antal=antal+1;
117 end
118 end
119 lagerstatus=lager(i,aar,k);
120 drift_=drift(aar)
121 if drift(aar) == Driftstimer
122 if abs(lager(1,aar,k)-lager(i,aar,k)) > 300
123 warning('lagerstart forskellig fra lagerslut' )
124 return
125 end
126 break
127 end
128 end
129 if drift(aar) ~= Driftstimer
130 warning('drift forskellig fra Driftstimer' )
131 return
132 end
133 sum=aarsum(aar);
134 elpris_snit(k)=sum/(elektrolyseeffekt*andel*drift(aar));
135 sparet_el(k)=ref_eludgift-sum*levetid/1E6;
136 anlagsudgift(k)=ref_anlagsudgift*andel;
137 ekstraanlagsudgift(k)=anlagsudgift(k)-ref_anlagsudgift;
138 sparet(k)=sparet_el(k)-(ekstraanlagsudgift(k)+lagerprisen)*(1+levetid*DogV);
139 andel_sparet(k)=sparet(k)/ref_omkostninger;
140 tilbagebetalingstid_aar(k)=(ekstraanlagsudgift(k)+lagerprisen)/(sparet_el(k)
/levetid-(ekstraanlagsudgift(k)+lagerprisen)*DogV);
141 if tilbagebetalingstid_aar(k) < 0
142 tilbagebetalingstid_aar(k)=99;
143 end
144 forrentning(k)=1/tilbagebetalingstid_aar(k);
145
146 sparet_sum_nutidsvardi(k)=0;
147 stop_nutidsvardi=0;
148 for i=1:50
149 sparet_aarligt=(sparet_el(k)/levetid-(ekstraanlagsudgift(k)+lagerprisen)
*DogV)/(1+kalkulationsrente)^i;
150 sparet_sum_nutidsvardi(k)=sparet_sum_nutidsvardi(k)+sparet_aarligt;
151 if sparet_sum_nutidsvardi(k) >= ekstraanlagsudgift(k)+lagerprisen
152 andel_af_aar=(sparet_sum_nutidsvardi(k)-(ekstraanlagsudgift(k)
+lagerprisen))/sparet_aarligt;
153 tilbagebetalingstid2_aar(k)=i-andel_af_aar;
154 stop_nutidsvardi=1;
155 break
156 end
157 i=i+1;
158 end

19-03-07 19:26 D:\DTU\Eksamensprojekt\bilag\elektrolysedriftreal.m 4 of 5
159 if stop_nutidsvardi == 0
160 tilbagebetalingstid2_aar(k)=99;
161 end
162 sparet_sum_nutidsvardi(k)=0;
163 for i=1:levetid
164 sparet_sum_nutidsvardi(k)=sparet_sum_nutidsvardi(k)+(sparet_el(k)/levetid-
(ekstraanlagsudgift(k)+lagerprisen)*DogV)/(1+kalkulationsrente)^i;
165 end
166 sparet_nutidsvardi(k)=sparet_sum_nutidsvardi(k)-ekstraanlagsudgift(k)lagerprisen;
167 andel_sparet_nutidsvardi(k)=sparet_nutidsvardi(k)/ref_omkostninger;
168
169 Driftstimer_list(k)=Driftstimer;
170 faktor_list(k)=faktor;
171 Driftstimer=Driftstimer-timestep;
172 %faktor=faktor+faktorstep;
173 k=k+1;
174 end
175 [maxxx,kk]=max(sparet);
176
177 %faktor_optimum=faktor_list(kk)
178
179 figure(1);
180 plot(elpris_funktion(:,kk))
181 %title('Udvikling i el-pris-funktionen henover året')
182 ylabel('El-pris-funktionen [kr/MWh]' )
183 xlabel('Time på året [-]' )
184 axis([0 time(end) 0 500])
185
186 figure(2);
187 plot(lager(:,aar,kk))
188 %title('Udviklingen i lagerbeholdningen henover året')
189 ylabel('Brintlagerbeholdning [MWh]' )
190 xlabel('Time på året [-]' )
191 axis([0 time(end) 0 lagerbeholdning])
192
193 figure(3);
194 hold on ;
195 plot(Driftstimer_list,andel_sparet*100,stregfarve,'LineWidth' ,2,...
196 'MarkerEdgeColor' ,farve,...
197 'MarkerFaceColor' ,farve,...
198 'MarkerSize' ,10);
199 axis([500 8500 0 30]);
200 %title('Sparede omkostninger')
201 ylabel('Sparede omkostninger [%]' );
202 xlabel('Driftstimer [timer]' );
203 legend('2001','2002' ,'2003','2004','2005','2006',1);
204 hold off ;
205
206 figure(4);
207 hold on ;
208 plot(Driftstimer_list,andel_sparet_nutidsvardi*100,stregfarve, 'LineWidth',2, ...
209 'MarkerEdgeColor' ,farve,...
210 'MarkerFaceColor' ,farve,...
211 'MarkerSize' ,10);
212 axis([500 8500 0 30]);

19-03-07 19:26 D:\DTU\Eksamensprojekt\bilag\elektrolysedriftreal.m 5 of 5
213 %title('Sparede omkostninger i nutidsværdi')
214 ylabel('Sparede omkostninger i nutidsværdi [%]' );
215 xlabel('Driftstimer [timer]' );
216 legend('2001','2002' ,'2003','2004','2005','2006',1);
217 hold off ;
218
219 figure(7);
220 hold on ;
221 plot(Driftstimer_list,forrentning*100,stregfarve,'LineWidth' ,2,...
222 'MarkerEdgeColor' ,farve,...
223 'MarkerFaceColor' ,farve,...
224 'MarkerSize' ,10);
225 axis([500 8500 0 50]);
226 %title('Forrentning af investering')
227 ylabel('Forrentning af investering [%]' );
228 xlabel('Driftstimer [timer]' );
229 legend('2001','2002' ,'2003','2004','2005','2006',1);
230 hold off ;
231
232 figure(9);
233 hold on ;
234 plot(Driftstimer_list,tilbagebetalingstid_aar,stregfarve,'LineWidth' ,2,...
235 'MarkerEdgeColor' ,farve,...
236 'MarkerFaceColor' ,farve,...
237 'MarkerSize' ,10);
238 axis([500 8500 0 levetid]);
239 %title('Tilbagebetalingstider')
240 ylabel('Tilbagebetalingstid [år]' );
241 xlabel('Driftstimer [timer]' );
242 legend('2001','2002' ,'2003','2004','2005','2006',1);
243 hold off ;
244
245 figure(10);
246 hold on ;
247 plot(Driftstimer_list,tilbagebetalingstid2_aar,stregfarve,'LineWidth' ,2,...
248 'MarkerEdgeColor' ,farve,...
249 'MarkerFaceColor' ,farve,...
250 'MarkerSize' ,10);
251 axis([500 8500 0 levetid]);
252 %title('Tilbagebetalingstider regnet i nutidsværdi')
253 ylabel('Tilbagebetalingstid (beregnet ud fra nutidsværdi) [år]' );
254 xlabel('Driftstimer [timer]' );
255 legend('2001','2002' ,'2003','2004','2005','2006',1);
256 hold off ;
257
258 figure(19);
259 hold on
260 plot(driftstatus_doegn(:,kk), 'r')
261 ylabel('Antal driftstimer [timer]' )
262 xlabel('Time på døgnet [-]' )
263 hold off
264 legend('Laveste el-priser' ,'Scenarie 1','Scenarie 2' ,1);
265
266 end

31. Scenarie 2: variation af cel, lager og klagerprisandel
Sparede omkostninger i nutidsværdi [%]
Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 100 kr/MWh og klagerprisandel = 0,1.
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 300 kr/MWh og klagerprisandel = 0,1.

Sparede omkostninger i nutidsværdi [%]
Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 600 kr/MWh og klagerprisandel = 0,1.
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 100 kr/MWh og klagerprisandel = 1.

Sparede omkostninger i nutidsværdi [%]
Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 300 kr/MWh og klagerprisandel = 1.
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 600 kr/MWh og klagerprisandel = 1.

Sparede omkostninger i nutidsværdi [%]
Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 100 kr/MWh og klagerprisandel = 1/43.
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 300 kr/MWh og klagerprisandel = 1/43.

Sparede omkostninger i nutidsværdi [%]
30
25
20
15
10
5
0
2001
2002
2003
2004
2005
2006
1000 2000 3000 4000 5000 6000 7000 8000
Driftstimer [timer]
cel, lager = 600 kr/MWh og klagerprisandel = 1/43.

32. DNA-kode for metanolanlæg

metanolanlaeg.dna
d:/DTU/Eksamensprojekt/dna/
TITLE Methanol plant
c Vigtige addco’s
addco ZC 900 0.30
addco m NG_reformer 431 −0.01
addco m Comp−CO2 501 0.01
addco m Split−O2−2 6 0
addco m Cond−steam−1 671 1
addco m set_flow 794 10.3
addco p 601 144
addco t Condenser 604 60
c −−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C *****************************************************
C ELECTROLYSIS
C *****************************************************
struc Electrolyser ELECTROLYSER 1 2 3 201 301 90 0.8
media 2 H2 3 O2
addco p 1 1 t Electrolyser 1 15
struc Split−O2−1 splitter 3 4 401
struc Split−O2−2 splitter 4 5 6
C *****************************************************
C GASIFICATION
C *****************************************************
struc Comp−O2−1 compre_1 5 7 302 101 0.9 0.98
struc Heatsink−O2 heatsnk0 7 8 329 0
addco q Heatsink−O2 329 0
struc Steam_dryer DRYER_04 81 34 82 35 328 0.05 0
media 81 Wood 82 Dry−wood
SOLID Wood H .0305 O .1886 H2O−L .5 C .2503 S .00005
+ N 0.003 36 0.00205 ASH .0255
+ LHV 21722 CP 1.35
addco t Steam_dryer 81 15 t Steam_dryer 82 120 p 81 1 P 82 1
addco t Steam_dryer 35 120
addco q Steam_dryer 328 0
struc Split−steam1 splitter2 7 35 41 561 562 563 31 671
struc Gasifier GASIFI_3_VENZIN 8 82 33 9 10 83 304 905 1 3 4 6 7 9 11 36 /
1.0001 800 0 1.0 0
media 10 GG 83 Ash
addco P 83 1 T Gasifier 10 800
addco Q Gasifier 304 0
struc Heatex−GG−O2 heatex_2 10 11 8 9 321 10 0 0
addco q Heatex−GG−O2 321 0
struc Heatex−GG−st heatex_2 11 12 31 32 306 10 0 0
addco q Heatex−GG−st 306 0
addco t Heatex−GG−st 32 730
struc Split−steam2 splitter2 3 32 34 33
struc Heatex−GG−DH GASCOOL2 12 13 21 801 811 0 0 10
addco t Heatex−GG−DH 801 50 t Heatex−GG−DH 811 90
media 13 GG−dry
struc Cleaner GASCLE_2 8 13 14 15 308 0 6 8 9 10 31 32 38 39
media 14 GG−clean 15 H2S
addco Q Cleaner 308 0
C *****************************************************
C NATURAL GAS REFORMING
C *****************************************************
struc Comp−O2−2 compre_1 401 402 312 101 0.9 0.98
struc Heatex−O2 heatex_4 441 442 402 403 315 0.9 0 0
addco q Heatex−O2 315 0
addco t Heatex−O2 403 850
1/5
18−03−2007

metanolanlaeg.dna
d:/DTU/Eksamensprojekt/dna/
struc Heatex−NG GASCOOL2 432 433 434 411 412 0 0 10
addco t Heatex−NG 411 25
struc Heatex−H2O GASCOOL2 451 452 453 422 423 0 0 10
addco t Heatex−H2O 423 850
struc Pres−sep−3 PRES_SEP 434 422
struc Pres−sep−2 PRES_SEP 453 422
struc Water_supply ADDANODE 421 422
addco t Water_supply 421 15
struc NG_reformer STEAM_REFORMER 412 403 423 431 313 1
media 412 NATURAL_GAS 431 NG_reformat
addco t NG_reformer 431 950
addco p 403 10
addco q NG_reformer 313 0
struc Split−NG_ref splitter2 4 431 432 441 451
struc Mixer−NG_ref mixer_03 4 433 442 452 461
media 433 NG_ref−cold1 452 NG_ref−cold2 461 NG_ref−cool
struc Comp−NG_ref compre_1 461 462 318 101 0.9 0.98
C *****************************************************
C GAS MIXING AND PRESSURIZATION
C *****************************************************
struc Comp−CO2 compre_1 501 502 310 101 0.9 0.98
addco p 501 1 t Comp−CO2 501 15
struc Mixer−CO2−NG mixer_01 502 462 503
media 503 NG_ref−CO2 502 CO2
fluid CO2 CO2 1
struc Comp−H2 compre_1 2 511 303 101 0.9 0.98
struc Heatsink−H2 heatsnk0 511 512 322 0
addco t Heatsink−H2 512 90
struc Mixer−GG−H2 mixer_01 14 512 521
media 521 GG−H2
struc Comp−GG−H2−1 compre_1 521 591 335 101 0.9 0.98
struc set_temp−1 SET_TEMP 591 522 971
struc Cooler−GG−H2 GASCOOL2 522 523 525 563 571 0 0 10
media 523 GG−H2−2
addco t Cooler−GG−H2 571 200
struc Comp−GG−H2−2 compre_1 523 524 320 101 0.9 0.98
struc Mixer−syngas mixer_01 524 503 593
media 531 Syngas−1
struc set_temp−3 SET_TEMP 593 531 971
struc Syngas−cool1 GASCOOL2 531 532 541 561 571 0 0 10
media 532 Syngas−2
addco t Syngas−cool1 571 200
struc Comp−syngas1 compre_1 532 592 309 101 0.9 0.98
struc set_temp−2 SET_TEMP 592 533 971
struc Syngas−cool2 GASCOOL2 533 534 551 562 571 0 0 10
media 534 Syngas−3
addco t Syngas−cool2 571 200
struc Split−steam3 splitter2 3 571 34 581
struc DH−cooler heatex_1 581 35 804 811 337 0 0
addco q DH−cooler 337 0
addco t DH−cooler 804 50 t DH−cooler 811 90
2/5
18−03−2007

metanolanlaeg.dna
d:/DTU/Eksamensprojekt/dna/
addco t DH−cooler 35 120
struc Comp−syngas2 compre_1 534 535 334 101 0.9 0.98
struc set−M SET_M 535 536 980
C *****************************************************
C METHANOL CONVERSION
C *****************************************************
struc Mixer−syn_re mixer_01 536 607 601
media 601 Syngas−loop1
struc Meoh−convert MEOH_CONVERTER 601 602 311 5
media 602 Syngas−meoh
addco t Meoh−convert 601 235
addco t Meoh−convert 602 235
STRUC Preheater−sy GASCOOL4 602 603 621 631 606 607 902 0 0 10
media 603 Syngas−meoh−
struc set_temp−6 SET_TEMP2 603 640 974 975
STRUC Condenser−1 GASCOOL4 640 641 621 631 663 664 902 0 0 10
media 663 STANDARD_AIR 643 Syngas−loop3
addco t Condenser−1 663 90 p 663 1
struc set_temp−5 SET_TEMP 641 642 974
struc set_temp−4 SET_TEMP2 642 643 907 973
addco ZC 973 10
STRUC Condenser GASCOOL4 643 604 621 631 805 811 903 0 0 10
media 604 Syngas−loop2
addco t Condenser 805 50 t Condenser 811 90
addco ZC 902 10
struc Split−syngas splitter3 604 605 611 0.95
struc set−X_H2 SET_X 611 612 900 1
struc set−X_CH4 SET_X 612 613 901 40
struc measure−pres SET_PRES 613 614 904
struc Comp−recirc compre_1 605 606 325 101 0.9 0.98
struc Convert−cool heatsrc0 681 682 311 0
media 681 STEAM
addco tsat 681 235
addco t Convert−cool 681 220 x Convert−cool 682 1
struc Split−steam4 splitter2 3 682 683 685
struc Cond−steam−1 heatex_1 683 684 671 571 327 0 0
addco q Cond−steam−1 327 0
addco t Cond−steam−1 571 225
addco p 671 1
struc Cond−steam−2 heatsnk0 685 681 393 0
addco t Cond−steam−2 681 220
struc Pres−sep−1 PRES_SEP 684 681
struc set−pres−1 SET_PRES 621 622 904
struc set−pres−2 SET_PRES 631 632 904
struc Water−meoh−t MIXING_TANK 622 624 632 634 330 0 0
addco q Water−meoh−t 330 0
struc Pres−sep−6 PRES_SEP 634 635
struc Pres−sep−7 PRES_SEP 624 625
struc Heatsink−re heatsnk0 664 665 394 0
addco t Heatsink−re 665 90
3/5
18−03−2007

metanolanlaeg.dna
d:/DTU/Eksamensprojekt/dna/
C *****************************************************
C METHANOL DISTILLATION
C *****************************************************
struc Reboil−meoh1 heatsrc0 696 706 393 0
addco x Reboil−meoh1 706 1
struc Reboil−meoh2 heatsrc0 700 706 394 0
addco x Reboil−meoh2 706 1
struc Split−meoh2 splitter2 4 708 696 698 692
struc Reboil−wat1 heatsrc0 695 705 393 0
addco x Reboil−wat1 705 1
struc Reboil−wat2 heatsrc0 699 705 394 0
addco x Reboil−wat2 705 1
struc Split−water2 splitter2 4 707 695 697 691
struc set−x−2 SET_X_REALFLUID 691 693 692 694 908 0 0
addco p 693 1 p 694 1
struc set−x−3 SET_X_REALFLUID 697 699 698 700 908 0 0
struc Dis_stage_1 DISTILLATION_STAGE 701 707 705 703 702 708 706 704 343 906 /
907 908 909 0 0
MEDIA 701 STEAM−HF 702 METHANOL
addco q Dis_stage_1 343 0
struc Dis_stage_2 DISTILLATION_STAGE 717 701 703 715 718 702 704 716 344 906 /
910 911 912 0 0
addco q Dis_stage_2 344 0
struc Dis_stage_3 DISTILLATION_STAGE 711 717 715 713 712 718 716 714 345 906 /
913 914 915 0 0
addco q Dis_stage_3 345 0
struc Dis_stage_4 DISTILLATION_STAGE 727 711 713 725 728 712 714 726 346 906 /
916 917 918 0 0
addco q Dis_stage_4 346 0
struc Dis_stage_5 DISTILLATION_STAGE 721 727 725 723 722 728 726 724 347 906 /
919 920 921 0 0
addco q Dis_stage_5 347 0
struc Dis_stage_6 DISTILLATION_STAGE 737 721 723 735 738 722 724 736 348 906 /
922 923 924 0 0
addco q Dis_stage_6 348 0
struc Dis_stage_7 DISTILLATION_STAGE 731 737 735 733 732 738 736 734 349 906 /
925 926 927 0 0
addco q Dis_stage_7 349 0
struc Dis_stage_8 DISTILLATION_STAGE 747 731 733 745 748 732 734 746 350 906 /
928 929 930 0 0
addco q Dis_stage_8 350 0
struc Dis_stage_9 DISTILLATION_STAGE 741 747 745 743 742 748 746 744 351 906 /
931 932 933 0 0
addco q Dis_stage_9 351 0
struc Dis_stage_10 DISTILLATION_STAGE 757 741 743 755 758 742 744 756 352 906 /
934 935 936 0 0
addco q Dis_stage_10 352 0
struc Dis_stage_11 DISTILLATION_STAGE 751 757 755 753 752 758 756 754 353 906 /
937 938 939 0 0
addco q Dis_stage_11 353 0
struc Dis_stage_12 DISTILLATION_STAGE 767 751 753 765 768 752 754 766 354 906 /
940 941 942 0 0
addco q Dis_stage_12 354 0
struc Dis_stage_13 DISTILLATION_STAGE 761 767 765 763 762 768 766 764 355 906 /
943 944 945 0 0
addco q Dis_stage_13 355 0
4/5
18−03−2007

metanolanlaeg.dna
d:/DTU/Eksamensprojekt/dna/
struc Dis_stage_14 DISTILLATION_STAGE 777 761 763 775 778 762 764 776 356 906 /
946 947 948 0 0
addco q Dis_stage_14 356 0
struc Dis_stage_15 DISTILLATION_STAGE 771 777 775 773 772 778 776 774 357 906 /
949 950 951 0 0
addco q Dis_stage_15 357 0
struc Dis_stage_16 DISTILLATION_STAGE 787 771 773 785 788 772 774 786 358 906 /
952 953 954 0 0
addco q Dis_stage_16 358 0
struc Dis_stage_17 DISTILLATION_STAGE 781 787 785 783 782 788 786 784 359 906 /
955 956 957 0 0
addco q Dis_stage_17 359 0
addco ZC 955 100
struc Cond−meoh heatsnk0 784 792 390 0
addco x Cond−meoh 792 0
struc Split−meoh1 splitter 792 794 782
struc set_flow SET_FLOW 794 796 990 991
addco ZC 991 0.99
struc Cond−water heatsnk0 783 791 390 0
addco x Cond−water 791 0
struc Split−water1 splitter 791 793 781
struc set−x−1 SET_X_REALFLUID 793 795 796 798 957 0 0
struc feed_Water ADDANODE 625 737
struc feed_MeOH ADDANODE 636 738
struc meas_flow MEASURE_FLOW 635 636 990
struc Heatsourc−DH heatsrc0 806 811 390 0
MEDIA 806 STEAM
addco t Heatsourc−DH 806 50 t Heatsourc−DH 811 90
C *****************************************************
C DISTRICT HEATING AND MOTOR
C *****************************************************
struc Electro−cool heatsrc0 802 803 301 0
media 802 STEAM
addco t Electro−cool 802 50 p 802 1
struc DH−condenser heatex_1 41 42 803 811 331 0 0
addco t DH−condenser 811 90 t DH−condenser 42 95
addco q DH−condenser 331 0
struc DH heatsnk0 811 812 338 0
addco t DH 812 50
struc El−motor EL−MOTOR 203 319 101 0.95
XERGY t 15 p 1
5/5
18−03−2007

33. Dokumentation for tilføjede DNA-komponenter

17.121 ELECTROLYSER
Water elektrolysis with efficiency.
17.121.1 Nodes
Number of nodes: 5
1. Water in (Internal Number: 97) : water for gas app (C)
2. H2 out (Internal Number: -4) : any gas (I/V)
3. O2 out (Internal Number: -4) : any gas (I/V)
4. Power in (Internal Number: 200) : electrical power
5. Heat loss (Internal Number: 300) : heat
17.121.2 Parameters
Number of parameters: 2
1. Temperature: Temp [C]
2. Efficiency of elektrolysis: η [–]
17.121.3 Equations
Number of equations: 8
1. Only H2 in node 2: yj(H2, medie(2)) = 1
2. Only O2 in node 3: yj(O2, medie(3)) = 1
3. Mol balance: − ˙m2 = ˙m1Mmol(H2)/Mmol(H2O)
4. Equal pressures: p1 = p2
5. Equal pressures: p1 = p3
6. Temperature of outlet gas: T emp = T2
7. Equal temperature of outlet gases: T3 = T2
8. Efficiency of elektrolysis: ˙ Eη = − ˙m2LHVH2
436

17.121.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 < 0
˙Q < 0
˙E > 0
17.121.5 Example
struc Elyse ELECTROLYSER 1 2 3 201 301 90 0.8
media 2 H2 3 O2
addco p 1 1 m Elyse 1 1 t Elyse 1 15
start m Elyse 2 -1 m Elyse 3 -1
start t Elyse 2 90 t Elyse 3 90
start e Elyse 201 100
start y_j H2 H2 1 y_j O2 O2 1
start p 2 1 p 3 1 q Elyse 301 -10
437

17.122 DRYER_04
Steam dryer for solid fuels (Steam is a real fluid).
17.122.1 Nodes
Number of nodes: 5
1. Solid in (Internal Number: -5) : any solid (I/V)
2. Steam in (Internal Number: 97) : water for gas app (C)
3. Dry solid out (Internal Number: -5) : any solid (I/V)
4. Steam out (Internal Number: 97) : water for gas app (C)
5. Heat loss (Internal Number: 300) : heat
17.122.2 Parameters
Number of parameters: 2
1. Moisture content of dried fuel
2. Pressure loss: ∆p [bar]
17.122.3 Equations
Number of equations: 41
1. –
2. –
3. –
4. –
5. –
6. –
7. –
8. –
438

9. –
10. –
11. –
12. –
13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
29. –
30. –
31. –
32. –
33. –
439

34. –
35. –
36. –
37. –
38. –
39. –
40. –
41. –
17.122.4 Conditions
˙m1 > 0
˙m2 > 0
˙m3 < 0
˙m4 < 0
T1 < T3
T2 > T4
Q < 0
x1,H2O > x3,H2O
17.122.5 Example
struc dryer DRYER_04 1 2 3 4 300 0.05 0
media 1 Wood 3 dry-wood
SOLID Wood H .0305 O .1886 H2O-L .5 C .2503 S .00005 ASH .0255
+ N 0.003 36 0.00205
+ LHV 21750 CP 1.35
addco m dryer 1 2.05 t dryer 1 15 p 1 1
addco t dryer 2 322 t dryer 3 150 t dryer 4 150
addco p 2 1 p 3 1
addco q dryer 300 0
START M dryer 2 8.3 M dryer 3 -1
START X_J dry-wood H2 0.057 X_J dry-wood O2 0.35
START X_J dry-wood C 0.47 X_J dry-wood H2O-L 0.05
440

17.123 GASIFI_3_VENZIN
Gasifier with water/steam. 1 identifier: Calculated compounds. The difference
between GASIFI 3 and this component is that the water to fuel ratio is
defined as a control variable.
17.123.1 Nodes
Number of nodes: 7
1. Fuel in (Internal Number: -5) : any solid (I/V)
2. Steam in (Internal Number: 97) : water for gas app (C)
3. Air in (Internal Number: -4) : any gas (I/V)
4. Product gas out (Internal Number: -4) : any gas (I/V)
5. Ash out (Internal Number: -5) : any solid (I/V)
6. Heat loss (Internal Number: 300) : heat
7. water to fuel ratio (DMVC) (Internal Number: 999) : control
17.123.2 Parameters
Number of parameters: 20
1. Gasifier pressure: PGAS
2. Gasifier temperature: TGAS
3. Pressure loss: DELP
4. Carbon conversion ratio
5. Non-equilibrium methane
6. –
7. –
8. –
9. –
10. –
441

11. –
12. –
13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
17.123.3 Equations
Number of equations: 30
1. –
2. –
3. –
4. –
5. –
6. –
7. –
8. –
9. –
10. –
11. –
12. –
442

13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
29. –
30. –
17.123.4 Conditions
m1 ˙ > 0
m2 ˙ > 0
m3 ˙ > 0
m4 ˙ < 0
m5 ˙ < 0
˙Q < 0
443

17.123.5 Example
STRUC Gasifier GASIFI_3_VENZIN 8 2 34 25 3 4 302 900 /
1 3 4 6 7 9 11 36 2 750 0 1.0 0.0
MEDIA 2 Wood 25 O2 3 FlueGas 4 Ash
fluid O2 O2 1
SOLID Wood H .057 O .4085 H2O-L .05 C .4750 S .0001 ASH .0092
+ N 0.0001 36 0.0001
+ LHV 19000 CP 1.35
ADDCO Q Gasifier 302 0 P 4 1 M Gasifier 2 1.2 T Gasifier 3 700
addco T Gasifier 2 150 T Gasifier 34 600 T Gasifier 25 600
addco p 2 1 ZC 900 0.35
START M Gasifier 34 0.0 M Gasifier 25 1.8 M Gasifier 4 -0.01
START Y_J FlueGas H2 0.21 Y_J FlueGas N2 0.39 Y_J FlueGas CO 0.26
START Y_J FlueGas CO2 0.07 X_J Ash ASH 1
444

17.124 GASCLE_2
Syngas cleaning. The syntax is struc Componentname GASCLE 2 7 1 2 3 301
0 8 9 10 31 32 38 39. So the first number determines how many compounds
is off-seperated. The 7 numbers from 8 to 39 is therefore compound numbers
(8 is NH3).
17.124.1 Nodes
Number of nodes: 4
1. Dirty gas in (Internal Number: -4) : any gas (I/V)
2. Clean gas out (Internal Number: -4) : any gas (I/V)
3. Off-separated gas (Internal Number: -4) : any gas (I/V)
4. Heat loss (Internal Number: 300) : heat
17.124.2 Parameters
Number of parameters: 42
1. Pressure loss: ∆p [bar]
2. Compound number
3. Compound number
4. Compound number
5. Compound number
6. Compound number
7. Compound number
8. Compound number
9. Compound number
10. Compound number
11. Compound number
12. Compound number
445

13. Compound number
14. Compound number
15. Compound number
16. Compound number
17. Compound number
18. Compound number
19. Compound number
20. Compound number
21. Compound number
22. Compound number
23. Compound number
24. Compound number
25. Compound number
26. Compound number
27. Compound number
28. Compound number
29. Compound number
30. Compound number
31. Compound number
32. Compound number
33. Compound number
34. Compound number
35. Compound number
36. Compound number
37. Compound number
446

38. Compound number
39. Compound number
40. Compound number
41. Compound number
42. Compound number
17.124.3 Equations
Number of equations: 86
1. –
2. –
3. –
4. –
5. –
6. –
7. –
8. –
9. –
10. –
11. –
12. –
13. –
14. –
15. –
16. –
17. –
447

18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
29. –
30. –
31. –
32. –
33. –
34. –
35. –
36. –
37. –
38. –
39. –
40. –
41. –
42. –
448

43. –
44. –
45. –
46. –
47. –
48. –
49. –
50. –
51. –
52. –
53. –
54. –
55. –
56. –
57. –
58. –
59. –
60. –
61. –
62. –
63. –
64. –
65. –
66. –
67. –
449

68. –
69. –
70. –
71. –
72. –
73. –
74. –
75. –
76. –
77. –
78. –
79. –
80. –
81. –
82. –
83. –
84. –
85. –
86. –
17.124.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 < 0
˙Q < 0
450

17.124.5 Example
struc Cleaner GASCLE_2 7 13 14 15 308 0 8 9 10 31 32 38 39
media 13 GG 14 GG-clean 15 H2S
fluid GG H2 0.5 CO 0.3 CO2 0.1 H2O-G 0.05 CH4 0.02 H2S 0.03
addco Q Cleaner 308 0
addco t Cleaner 13 70 p 13 1 m Cleaner 13 1
START M Cleaner 14 -0.93 t Cleaner 14 70
START Y_J GG-clean H2 0.5 Y_J GG-clean CO 0.30
start Y_J GG-clean CO2 0.1 Y_J H2S H2S 1
451

17.125 STEAM_REFORMER
Steam reformer - with the possibillity of auto thermal reforming (oxygen as
input massflow in node 2).
17.125.1 Nodes
Number of nodes: 5
1. Inlet gas (Internal Number: -4) : any gas (I/V)
2. Oxygen or another gas (Internal Number: -4) : any gas (I/V)
3. Steam (Internal Number: 97) : water for gas app (C)
4. Reformed gas (Internal Number: -4) : any gas (I/V)
5. Heat (Internal Number: 300) : heat
17.125.2 Parameters
Number of parameters: 1
1. Gas/steam fraction: ˙m3
˙m1
17.125.3 Equations
Number of equations: 13
1. –
2. –
3. –
4. –
5. –
6. –
7. –
8. –
9. –
452

10. –
11. –
12. –
13. –
17.125.4 Conditions
˙m1 > 0
˙m2 > 0
˙m3 > 0
˙m4 < 0
17.125.5 Example
struc NG_reformer STEAM_REFORMER 412 403 423 431 313 1
media 412 NATURAL_GAS 403 O2 431 NG_reformat
fluid O2 O2 1
addco q NG_reformer 313 0
addco t NG_reformer 403 850 t NG_reformer 423 850 t NG_reformer 412
667
addco t NG_reformer 431 950 M NG_reformer 412 0.34 p 403 10
START M NG_reformer 403 0.3 M NG_reformer 423 0.3
START Y_J NG_reformat H2 0.55 Y_J NG_reformat CO 0.21 Y_J NG_reformat
H2O-G 0.18
453

17.126 GASCOOL2
Gas cooler with outlet for condensed water. The pinch point temperature is
set as a parameter. The component checks if the pinch point is at the inlet or
outlet - or where the condensation starts. If the cooling medium evaporates
the component also checks if the pinch point is where the evaporation starts.
17.126.1 Nodes
Number of nodes: 5
1. Hot gas inlet (Internal Number: -4) : any gas (I/V)
2. Hot gas outlet (Internal Number: -4) : any gas (I/V)
3. Condensate outlet (Internal Number: 97) : water for gas app (C)
4. Coolant inlet (Internal Number: -3) : any fluid (I/V)
5. Coolant outlet (Internal Number: -3) : any fluid (I/V)
17.126.2 Parameters
Number of parameters: 3
1. Pressure loss side 1: ∆p [bar]
2. Pressure loss side 2: ∆p [bar]
3. Pinch point temperature diffence
17.126.3 Equations
Number of equations: 52
1. –
2. –
3. –
4. –
5. –
6. –
454

7. –
8. –
9. –
10. –
11. –
12. –
13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
29. –
30. –
31. –
455

32. –
33. –
34. –
35. –
36. –
37. –
38. –
39. –
40. –
41. –
42. –
43. –
44. –
45. –
46. –
47. –
48. –
49. –
50. –
51. –
52. –
456

17.126.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 < 0
˙m4 > 0
˙m5 < 0
T1 > T2
T1 > T5
T2 > T4
T5 > T4
y1,H2O > y2,H2O
p1 ∗ y1,H2O < psat,H2O
17.126.5 Example
STRUC Cooler GASCOOL2 3 5 6 10 11 0 0 10
MEDIA 10 NATURAL_GAS 5 Coolgas 3 FG
FLUID FG H2 0.44 CO 0.21 CO2 0.02 7 0.078 CH4 0.252
addco t Cooler 3 150 m Cooler 3 1 p 3 4
ADDCO P 10 20 T Cooler 11 100 T Cooler 5 51.46
START M Cooler 5 -0.9 M Cooler 10 2.1 t Cooler 10 18
START Y_J Coolgas H2 0.46 Y_J Coolgas CO 0.22
START Y_J Coolgas CH4 0.26 Y_J Coolgas H2O-G 0.03
457

17.127 MEOH_CONVERTER
Methanol converter. Outlet gas is at equilibrium between H2, CO, CO2, H2O
and CH3OH. One of the conditions for the component is that condensation
of methanol and water does not occur.
17.127.1 Nodes
Number of nodes: 3
1. Inlet gas (Internal Number: -4) : any gas (I/V)
2. Oulet gas (Internal Number: -4) : any gas (I/V)
3. Heat loss (Internal Number: 300) : heat
17.127.2 Parameters
Number of parameters: 1
1. Pressure loss: ∆p [bar]
17.127.3 Equations
Number of equations: 44
1. –
2. –
3. –
4. –
5. –
6. –
7. –
8. –
9. –
10. –
458

11. –
12. –
13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
29. –
30. –
31. –
32. –
33. –
34. –
35. –
459

36. –
37. –
38. –
39. –
40. –
41. –
42. –
43. –
44. –
17.127.4 Conditions
˙m1 > 0
˙m2 < 0
˙Q < 0
T2 > Tcondensation
17.127.5 Example
struc Meoh-convert MEOH_CONVERTER 601 602 311 0.01
media 601 Syngas 602 Syngas-meoh
fluid Syngas H2 0.5 CO 0.3 CO2 0.2
addco p 601 144
addco t Meoh-convert 602 235 t Meoh-convert 601 230 m Meoh-convert
601 100
START Y_J Syngas-meoh H2 0.15 Y_J Syngas-meoh CO 0.16
START Y_J Syngas-meoh CO2 0.33 Y_J Syngas-meoh CH3OH 0.34
START ZA Meoh-convert 5 230
460

17.128 SET_M
Utility component for setting the M-factor for a syngas used for production
of a liquid fuel. The M-factor is defined in the equations below. If the Mfactor
is 2 for methanol production it means that all the syngas in theory
can be converted to methanol. The M-factor is defined as a control variable
(ZC).
17.128.1 Nodes
Number of nodes: 3
1. Gas in (Internal Number: -4) : any gas (I/V)
2. Gas out (Internal Number: -4) : any gas (I/V)
3. M-factor (Internal Number: 999) : control
17.128.2 Equations
Number of equations: 2
1. Equal pressures: p1 = p2
2. M-factor: ZC(1) = yH 2 −yCO 2
yCO 2 +yCO
17.128.3 Conditions
m1 ˙ > 0
m2 ˙ < 0
yCO + yCO2 > 0
17.128.4 Example
struc set-M SET_M 611 612 900
MEDIA 611 gas
fluid gas N2 0.1 H2 0.6 CO 0.1 CO2 0.2
addco m set-M 611 1 t set-M 611 50 p 611 1
461

17.129 GASCOOL4
Gas cooler with outlet for condensed water and methanol. The pinch point
temperature is set as a parameter. The component checks if the pinch point
is at the inlet or outlet - or where the condensation starts. If the cooling
medium evaporates the component also checks if the pinch point is where
the evaporation starts.
17.129.1 Nodes
Number of nodes: 7
1. Hot gas inlet (Internal Number: -4) : any gas (I/V)
2. Hot gas outlet (Internal Number: -4) : any gas (I/V)
3. Water condensate outlet (Internal Number: 97) : water for gas app
(C)
4. Methanol condensate outlet (Internal Number: 94) : methanol (C)
5. Coolant inlet (Internal Number: -3) : any fluid (I/V)
6. Coolant outlet (Internal Number: -3) : any fluid (I/V)
7. Pinch point temperature diffence (Internal Number: 999) : control
17.129.2 Parameters
Number of parameters: 3
1. Pressure loss side 1: ∆p [bar]
2. Pressure loss side 2: ∆p [bar]
3. Minimum pinch point temperature diffence
17.129.3 Equations
Number of equations: 53
1. –
2. –
3. –
462

4. –
5. –
6. –
7. –
8. –
9. –
10. –
11. –
12. –
13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
463

29. –
30. –
31. –
32. –
33. –
34. –
35. –
36. –
37. –
38. –
39. –
40. –
41. –
42. –
43. –
44. –
45. –
46. –
47. –
48. –
49. –
50. –
51. –
52. –
53. –
464

17.129.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 < 0
˙m4 < 0
˙m5 > 0
˙m6 < 0
T1 > T2
T1 > T6
T2 > T5
T6 > T5
T1 > Tcondensation
node 7 > Parameter 3
17.129.5 Example
STRUC Cooler GASCOOL4 3 5 6 7 10 11 901 0 0 10
MEDIA 10 STEAM 5 Coolgas 3 FG
FLUID FG H2 0.4844 CO2 0.2815 7 0.10 CH3OH 0.10 N2 0.0341
addco p 3 144 t Cooler 3 410 m Cooler 3 22.1
addco P 10 400 t Cooler 5 109 t Cooler 11 300
addco ZC 901 10
START M Cooler 5 -16 M Cooler 6 -1.9 M Cooler 10 19
START t Cooler 6 109 t Cooler 10 50
START ZA Cooler 4 207
START Y_J Coolgas H2 0.59 Y_J Coolgas N2 0.04 Y_J Coolgas CO2 0.34
465

17.130 MIXING_TANK
Heat exchanger used as a model for a mixing tank. This means that the
outlet temperatures are set equal.
17.130.1 Nodes
Number of nodes: 5
1. Fluid 1 inlet (Internal Number: -9) : any real fluid
2. Fluid 1 outlet (Internal Number: -9) : any real fluid
3. Fluid 2 inlet (Internal Number: -9) : any real fluid
4. Fluid 2 outlet (Internal Number: -9) : any real fluid
5. Heat loss (Internal Number: 300) : heat
17.130.2 Parameters
Number of parameters: 2
1. Pressure loss side 1, ∆p12 [bar]
2. Pressure loss side 2, ∆p34 [bar]
17.130.3 Equations
Number of equations: 5
1. –
2. –
3. –
4. –
5. –
466

17.130.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 > 0
˙m4 < 0
˙Q < 0
17.130.5 Example
struc Water-meoh-t MIXING_TANK 623 624 633 634 330 0 0
media 623 STEAM-HF 633 METHANOL
addco q Water-meoh-t 330 0
addco t Water-meoh-t 623 90 t Water-meoh-t 633 40
addco p 623 1 p 633 1
addco m Water-meoh-t 623 1 m Water-meoh-t 633 1
start t Water-meoh-t 624 60
467

17.131 DISTILLATION_STAGE
Distillation stage for a distillation column. A column can consist of several
stages in series. The distillation stage calculates VLE (vapor liquid
equilibrium) between water and methanol. The component can be used for
distillation of other media by changing 3 constants in the source code. The
method is NRTL (Non Random Two Liquid). Can only be used with real
fluids. The pressure is assigned in node 10 - not in the seperate nodes
17.131.1 Nodes
Number of nodes: 13
1. Liquid water inlet (Internal Number: 97) : water for gas app (C)
2. Liquid water outlet (Internal Number: 97) : water for gas app (C)
3. Water vapor inlet (Internal Number: 97) : water for gas app (C)
4. Water vapor outlet (Internal Number: 97) : water for gas app (C)
5. Liquid methanol inlet (Internal Number: 94) : methanol (C)
6. Liquid methanol outlet (Internal Number: 94) : methanol (C)
7. Methanol vapor inlet (Internal Number: 94) : methanol (C)
8. Methanol vapor outlet (Internal Number: 94) : methanol (C)
9. Heat (Internal Number: 300) : heat
10. Pressure in system (Internal Number: 999) : control
11. Temperature of system (Internal Number: 999) : control
12. Molar fraction of methanol in the liquid phase (Internal Number: 999)
: control
13. Molar fraction of methanol in the gas phase (Internal Number: 999) :
control
468

17.131.2 Equations
Number of equations: 15
1. –
2. –
3. –
4. –
5. –
6. –
7. –
8. –
9. –
10. –
11. –
12. –
13. –
14. –
15. –
17.131.3 Conditions
˙m1 > 0
˙m2 < 0
˙m3 > 0
˙m4 < 0
˙m5 > 0
˙m6 < 0
˙m7 > 0
˙m8 < 0
469

17.131.4 Example
struc Dis_stage_1 DISTILLATION_STAGE 701 707 705 703 702 708 /
706 704 343 906 907 908 909 0 0
addco q Dis_stage_1 343 0 ZC 906 1
addco tsat 701 80 x Dis_stage_1 701 0 m Dis_stage_1 701 1
addco tsat 705 70 x Dis_stage_1 705 1 m Dis_stage_1 705 1
addco tsat 702 80 x Dis_stage_1 702 0 m Dis_stage_1 702 1
addco tsat 706 70 x Dis_stage_1 706 1 m Dis_stage_1 706 1
start m Dis_stage_1 707 -1 m Dis_stage_1 708 -1
start x Dis_stage_1 708 0 x Dis_stage_1 703 1 x Dis_stage_1 704 1
START ZC 907 83
470

17.132 EL-MOTOR
Motor with efficiency.
17.132.1 Nodes
Number of nodes: 3
1. Power in (Internal Number: 200) : electrical power
2. Heat loss (Internal Number: 300) : heat
3. Shaft power (Internal Number: 100) : shaft (STATIC)
17.132.2 Parameters
Number of parameters: 1
1. Motor efficiency, ηm [-]
17.132.3 Equations
Number of equations: 1
1. Motor efficiency: ηm = ˙ W ˙E
17.132.4 Conditions
˙E > 0
˙W < 0
˙Q < 0
17.132.5 Example
struc El-motor EL-MOTOR 203 319 101 0.95
addco e El-motor 203 100
start q El-motor 319 -1
471

17.133 SPLITTER2
Flow splitter - variable number of outlets for splitting up and later re-uniting
the massflow - this means that only the pressure in node 2 is set.This documentation
is for 3 outlets.
17.133.1 Nodes
Number of nodes: 10
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Fluid out (Internal Number: -3) : any fluid (I/V)
4. Fluid out (Internal Number: -3) : any fluid (I/V)
5. (Internal Number: -3) : any fluid (I/V)
6. (Internal Number: -3) : any fluid (I/V)
7. (Internal Number: -3) : any fluid (I/V)
8. (Internal Number: -3) : any fluid (I/V)
9. (Internal Number: -3) : any fluid (I/V)
10. (Internal Number: -3) : any fluid (I/V)
17.133.2 Equations
Number of equations: 9
1. Equal pressures: p1 = p2
2. Equal enthalpy of outlets: h1 = h2
3. Equal enthalpy of outlets: h1 = h3
4. –
5. –
6. –
7. –
472

8. –
9. –
17.133.3 Conditions
˙m1 > 0
˙m2 < 0
˙m3 < 0
˙m4 < 0
17.133.4 Example
struc split splitter2 4 1 2 3 4
media 1 SIMPLE_AIR
addco m split 1 10 t split 1 50 p 1 1
addco m split 2 -3 m split 3 -3
addco p 3 1 p 4 1
start t split 2 50 t split 3 50
473

17.134 SPLITTER3
Flow splitter. The distribution of the inlet massflow between the outlets is
set by the parameter.
17.134.1 Nodes
Number of nodes: 3
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Fluid out (Internal Number: -3) : any fluid (I/V)
17.134.2 Parameters
Number of parameters: 1
1. Fraction:
− ˙ m2
m1 ˙
17.134.3 Equations
Number of equations: 4
1. Equal enthalpy of outlets: h2 = h3
2. Equal pressures: p1 = p2
3. Equal pressures: p1 = p3
4. –
17.134.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 < 0
17.134.5 Example
struc split splitter3 1 2 3 0.4
media 1 SIMPLE_AIR
addco m split 1 10 t split 1 50 p 1 1
START M split 2 -4 t split 2 50
474

17.135 MIXER_03
Mixer for ideal gases with variable number of inlet massflows. The documentation
is for 2 inlets.
17.135.1 Nodes
Number of nodes: 10
1. Gas in (Internal Number: -4) : any gas (I/V)
2. Gas in (Internal Number: -4) : any gas (I/V)
3. Gas mix out (Internal Number: -4) : any gas (I/V)
4. (Internal Number: -4) : any gas (I/V)
5. (Internal Number: -4) : any gas (I/V)
6. (Internal Number: -4) : any gas (I/V)
7. (Internal Number: -4) : any gas (I/V)
8. (Internal Number: -4) : any gas (I/V)
9. (Internal Number: -4) : any gas (I/V)
10. (Internal Number: -4) : any gas (I/V)
17.135.2 Equations
Number of equations: 47
1. –
2. –
3. –
4. –
5. –
6. –
7. –
475

8. –
9. –
10. –
11. –
12. –
13. –
14. –
15. –
16. –
17. –
18. –
19. –
20. –
21. –
22. –
23. –
24. –
25. –
26. –
27. –
28. –
29. –
30. –
31. –
32. –
476

33. –
34. –
35. –
36. –
37. –
38. –
39. –
40. –
41. –
42. –
43. –
44. –
45. –
46. –
47. –
17.135.3 Conditions
˙m1 > 0
˙m2 > 0
˙m3 < 0
17.135.4 Example
struc mixer mixer_03 3 1 2 3
media 1 SIMPLE_AIR 2 METHANE 3 mix
addco m mixer 1 10 t mixer 1 110 p 1 1
addco m mixer 2 1 t mixer 2 60
START Y_J mix O2 0.17 Y_J mix N2 0.66 Y_J mix CH4 0.15
477

17.136 PRES_SEP
Utility component for seperating nodes which both have assigned the pressure.
Can also be used as a throttle valve.
17.136.1 Nodes
Number of nodes: 2
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
17.136.2 Conditions
˙m1 > 0
˙m2 < 0
17.136.3 Example
struc dummy PRES_SEP 1 2
media 1 STEAM
addco m dummy 1 1 t dummy 1 50 p 1 1 p 2 1
478

17.137 SET_X
Utility component for setting the molar fraction of a compund in a ideal gas
mixture.
17.137.1 Nodes
Number of nodes: 3
1. Gas in (Internal Number: -4) : any gas (I/V)
2. Gas out (Internal Number: -4) : any gas (I/V)
3. Molar fraction of compound (Internal Number: 999) : control
17.137.2 Parameters
Number of parameters: 1
1. Compound number (H2 is 1)
17.137.3 Equations
Number of equations: 2
1. –
2. –
17.137.4 Conditions
m1 ˙ > 0
m2 ˙ < 0
17.137.5 Example
struc set-X_H2 SET_X 611 612 900 1
MEDIA 611 gas
fluid gas N2 0.6 H2 0.4
addco m set-X_H2 611 1 t set-X_H2 611 50 p 611 1
479

17.138 SET_X_REALFLUID
Utillity component for setting the molar fraction of fluid 2 (fluid 1 and 2 are
considered as a mixture).
17.138.1 Nodes
Number of nodes: 5
1. Fluid 1 inlet (Internal Number: -9) : any real fluid
2. Fluid 1 outlet (Internal Number: -9) : any real fluid
3. Fluid 2 inlet (Internal Number: -9) : any real fluid
4. Fluid 2 outlet (Internal Number: -9) : any real fluid
5. molar fraction of fluid 2 (Internal Number: 999) : control
17.138.2 Parameters
Number of parameters: 2
1. Pressure loss side 1, ∆p12 [bar]
2. Pressure loss side 2, ∆p34 [bar]
17.138.3 Equations
Number of equations: 6
1. –
2. –
3. –
4. –
5. –
6. –
480

17.138.4 Conditions
˙m1 > 0
˙m2 < 0
˙m3 > 0
˙m4 < 0
17.138.5 Example
struc set-x SET_X_REALFLUID 691 693 692 694 908 0 0
MEDIA 691 STEAM-HF 692 METHANOL
addco p 691 1 p 692 1
addco m set-x 691 1 t set-x 691 80 t set-x 692 80
addco ZC 908 0.36
start t set-x 693 60 m set-x 692 1
481

17.139 MEASURE_FLOW
Utillity component for converting a massflow to a control signal (ZC). Could
be used with the component SET FLOW
17.139.1 Nodes
Number of nodes: 3
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Measured massflow (Internal Number: 999) : control
17.139.2 Equations
Number of equations: 2
1. Equal pressures: p1 = p2
2. Massflow: m1 ˙ = ZC(1)
17.139.3 Conditions
m1 ˙ > 0
m2 ˙ < 0
17.139.4 Example
struc meas_flow MEASURE_FLOW 635 636 990
MEDIA 635 STEAM
addco t meas_flow 635 50 m meas_flow 635 1 p 635 1
482

17.140 SET_FLOW
Utillity component for setting the massflow based on 2 control signals (ZC) -
typicly one control signal for a measured massflow and the other a fraction.
The component MEASURE FLOW can be used.
17.140.1 Nodes
Number of nodes: 4
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Measured massflow (Internal Number: 999) : control
4. Fraction (Internal Number: 999) : control
17.140.2 Equations
Number of equations: 2
1. Equal pressures: p1 = p2
2. Massflow: m1 ˙ = ZC(1) ∗ ZC(2)
17.140.3 Conditions
m1 ˙ > 0
m2 ˙ < 0
17.140.4 Example
STRUC Flow SET_FLOW 2 3 900 901
MEDIA 2 STEAM
addco t Flow 2 50 p 2 1 m Flow 2 10
addco ZC 901 2
START ZC 901 2
483

17.141 SET_TEMP
Utillity component for setting or measuring the temperature by use of a
control signal (ZC).
17.141.1 Nodes
Number of nodes: 3
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Temperature (Internal Number: 999) : control
17.141.2 Equations
Number of equations: 2
1. Equal pressures: p1 = p2
2. Temperature: T = ZC(1)
17.141.3 Conditions
m1 ˙ > 0
m2 ˙ < 0
17.141.4 Example
struc set_temp SET_TEMP 1 2 900
media 1 STEAM
addco p 1 1 m set_temp 1 60 t set_temp 1 60
484

17.142 SET_TEMP2
Utillity component for setting the temperature by use of 2 control signals
(ZC).
17.142.1 Nodes
Number of nodes: 4
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Temperature (Internal Number: 999) : control
4. Temperature difference (Internal Number: 999) : control
17.142.2 Equations
Number of equations: 2
1. Equal pressures: p1 = p2
2. Temperature: T = ZC(1)+ZC(2)
17.142.3 Conditions
m1 ˙ > 0
m2 ˙ < 0
17.142.4 Example
struc set_temp SET_TEMP2 1 2 900 901
media 1 STEAM
addco p 1 1 m set_temp 1 60
addco ZC 900 50 ZC 901 -10
start t set_temp 1 60
485

17.143 SET_PRES
Utillity component for converting the pressure to a control signal (ZC). The
component can therefore be used for measuring or setting the pressure
17.143.1 Nodes
Number of nodes: 3
1. Fluid in (Internal Number: -3) : any fluid (I/V)
2. Fluid out (Internal Number: -3) : any fluid (I/V)
3. Pressure (Internal Number: 999) : control
17.143.2 Equations
Number of equations: 2
1. Equal pressures: p1 = p2
2. Pressure: p1 = ZC(1)
17.143.3 Conditions
m1 ˙ > 0
m2 ˙ < 0
17.143.4 Example
struc set-pres SET_PRES 635 636 990
MEDIA 635 STEAM
addco t set-pres 635 50 m set-pres 635 1 p 635 1
486

34. Tilføjede komponenter til DNA – Fortran-kode

VEnzin.for
c:/dna/source/
C***********************************************************************
SUBROUTINE ELECTROLYSER(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,MEDIE
$ ,ANTME,VARME,antel,varel,MDOT,P,H,Q,E,PAR,RES,X_J,KOMDSC
$ ,K_PAR,K_lig,K_bet,KMEDDS,K_inp,ZA,ZANAM)
C***********************************************************************
C
C ELYSE is a component that converts water to H2 and O2 by
C elektrolysis. The component uses water (ideal gas) and not STEAM
C (real fluid). The efficiency and the temperature are parameters to
C the component.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA Q − INPUT − Exchanged heat.
CA E − INPUT − Power.
CA PAR − INPUT − Parameters of the component.
CA X_J − INPUT − Fluid composition.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters for the component.
CA ANTLK − OUTPUT − Number of equations in the component.
CA ANTEX − OUTPUT − Number of independent equations in the component.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean :
CA 1 : Air.
CA 27 : Oxygen rich gas.
CA 28 : Nitrogen rich gas.
CA 200 : Power.
CA 300 : Heat.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL S Entropy.
CL V Specific volume.
CL T2 Temperature in node 2.
CL T3 Temperature in node 3.
CL X Quality.
CL U Internal energy.
CL DELP Pressure drop through the plant.
CL PRO Oxygen mole ratio in oxygen rich gas.
CL MNOM Nominal mass flow through the plant.
CL ENOM Nominal power consumption of the plant.
CL M1 Mass flow into the separation plant.
CL M2 Mass flow found using PRO.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : COMINF
C STATES
C SPLIT
C
CP Programmer : Bent Lorentzen 1994 (Niels Emsholm 1991)
CP Lab. for Energetics, DTH, Denmark.
C***********************************************************************
C
C Including the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
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C
C Parameter variables
C
INTEGER ANTLK, ANTEX,ANTKN, MEDIE(5), ANTPK, ANTM1,
$ ANTME,VARME(3),varel(antst,3),antel(3)
DOUBLE PRECISION X_J(MAXME,ANTST), PAR(2), RES(8), MDOT(3),
: P(3),H(3),E,Q,ZA
CHARACTER*80 KOMTY,ZANAM(1)
C
C Local variables
C
DOUBLE PRECISION Virk, Temp, T2, T3, S, V, X, U
CHARACTER*100 K_PAR(2)
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*500 K_LIG(8), K_BET
CHARACTER*100 KMEDDS(5)
EXTERNAL STATES
INTRINSIC DABS
INCLUDE ’THERPROP.INI’
C========================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’ELECTROLYSER’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’ELECTROLYSER’
ANTKN = 5
ANTPK = 2
ANTLK = 8
ANTEX = 0
ANTM1 = 3
MEDIE(1) = 97
MEDIE(2) = ANYGAS$
MEDIE(3) = ANYGAS$
MEDIE(4) = power$
MEDIE(5) = heat$
ANTME = 3
VARME(1) = NODE1$
VARME(2) = NODE2$
antel(2) = 1
VARME(3) = NODE3$
antel(3) = 1
varel(1,2) = H2$
varel(1,3) = O2$
IF (FKOMP.EQ.6) GOTO 600
FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws, since these are treated
C automatically by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
Temp = PAR(1)
Virk = PAR(2)
C
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(3),H(3),T3,V,S,X,U,1,2,MEDIE(3))
C
res(1)=x_j(medie(2),H2$)−1.0
res(2)=x_j(medie(3),O2$)−1.0
res(3)=mdot(2)+mdot(1)/m_mol(H2O_L$)*m_mol(H2$)
res(4)=P(1)−P(2)
res(5)=P(1)−P(3)
res(6)=T2−Temp
res(7)=T2−T3
c res(8)=(E+Q)/E−Virk
res(8)=E*virk+ned_H(H2$)/m_mol(H2$)*MDOT(2)
C
IF (FKOMP.EQ.5) GOTO 500
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GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).GT.1D−10) GOTO 550
IF (Q.GT.1D−10) GOTO 550
IF (E.LT.−1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Water elektrolysis with efficiency.’
KMEDDS(1) = ’Water in’
KMEDDS(2) = ’H2 out’
KMEDDS(3) = ’O2 out’
KMEDDS(4) = ’Power in’
KMEDDS(5) = ’Heat loss’
K_PAR(1) = ’Temperature: Temp [C]’
K_PAR(2) = ’Efficiency of elektrolysis: $\\eta$ [−−]’
K_LIG(1) = ’Only H2 in node 2: $y_j(H2,medie(2)) = 1$’
K_LIG(2) = ’Only O2 in node 3: $y_j(O2,medie(3)) = 1$’
K_LIG(3) = ’Mol balance:
$$−\\dot{m}_2 = \\dot{m}_1 M_{mol}(H2)/M_{mol}(H2O)$’
K_LIG(4) = ’Equal pressures: $p_1 = p_2$’
K_LIG(5) = ’Equal pressures: $p_1 = p_3$’
K_LIG(6) = ’Temperature of outlet gas: $Temp = T_2$’
K_LIG(7) = ’Equal temperature of outlet gases: $T_3 = T_2$’
K_LIG(8) = ’Efficiency of elektrolysis:
$$\\dot{E} \\eta=−\\dot{m}_2 LHV_{H2}$’
K_BET = ’$\\dot{m}_1\\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\
$\\dot{m}_3 \\lt 0 \\\\ \\dot{Q} \\lt 0 \\\\ \\dot{E} \\gt 0$’
k_inp=’struc Elyse ELECTROLYSER 1 2 3 201 301 90 0.8\\\\
$media 2 H2 3 O2\\\\
$addco p 1 1 m Elyse 1 1 t Elyse 1 15\\\\
$start m Elyse 2 −1 m Elyse 3 −1\\\\
$start t Elyse 2 90 t Elyse 3 90\\\\
$start e Elyse 201 100\\\\
$start y_j H2 H2 1 y_j O2 O2 1\\\\
$start p 2 1 p 3 1 q Elyse 301 −10’
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE DRYER_04(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,MEDIE,
& ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q,PAR,RES,X_J,CP,HV,HF,ZA,
$ ZANAM,KOMDSC,K_PAR,K_lig,K_bet,KMEDDS,K_inp)
C***********************************************************************
C
C DRYER_02 is a model of a steam fuel dryer.
C The model does not include equations concerning the heat exchange.
C 1−2 is the heat emitting fluid.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
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CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL T1,T2 Temperature in first and second node.
CL T3,T4 Temperature in third and fourth node.
CL S Entropy.
CL V Specific volume.
CL X Quality.
CL U Internal energy.
CL DPA,DPB Pressure loss in heat exchanger.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : COMINF
C STATES
C
CP Programmer : Brian Elmegaard 2000
CP Dept. of Energy Eng., DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX,ANTKN, MEDIE(5), ANTPK,
& ANTM1, ANTME, VARME(4), ANTEL(4),
& VAREL(ANTST,4)
DOUBLE PRECISION RES(77), MDOT(4), P(4), H(4), Q, PAR(2),ZA(1),
& X_J(MAXME,ANTST),CP(MAXME),HV(MAXME),HF(MAXME)
CHARACTER*80 KOMTY,ZANAM(1)
C
C Local variables
C
INTEGER K_MED(5),I
DOUBLE PRECISION V, S, U, DP, MOIIN, MOIOUT, T1,
$ T2, T3, T4, X, H4
CHARACTER*100 K_PAR(2),K_STAT(1)
CHARACTER*500 K_LIG(77), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(5)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200,350) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’DRYER_04’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’DRYER_04’
ANTKN = 5
ANTPK = 2
ANTLK = 40
ANTEX = 1
ANTM1 = 4
MEDIE(1) = −5
MEDIE(2) = 97
MEDIE(3) = −5
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C
MEDIE(4) = 97
MEDIE(5) = 300
ANTME = 2
VARME(1) = −1
VARME(2) = −3
ANTEL(1) = 0
ANTEL(2) = 38
DO I = 1, 36
VAREL(I,2) = I
ENDDO
VAREL(7,2) =37
VAREL(37,2) = 38
VAREL(38,2) = 39
ZANAM(1) = ’Trans. heat’
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Properties for outlet fuel
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
350 CONTINUE
CP(MEDIE(3)) = CP(MEDIE(1))
HV(MEDIE(3)) = HV(MEDIE(1))
HF(MEDIE(3)) = HF(MEDIE(1))
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
MOIOUT = PAR(1)
DP = PAR(2)
MOIIN = X_J(MEDIE(1),7)+X_J(MEDIE(1),37)
CP(MEDIE(3)) = CP(MEDIE(1))
HV(MEDIE(3)) = HV(MEDIE(1))
HF(MEDIE(3)) = HF(MEDIE(1))
C
C Pressure losses
C
RES(1) = P(2) − P(4) − DP
C
C Mass flow of dry fuel
RES(2) = MDOT(3)*(1.0D0−MOIOUT) + MDOT(1)*(1.0D0−MOIIN)
C
C Fuel outlet composition
C
RES(10) = X_J(MEDIE(3),37) − MOIOUT
DO I=1,6
RES(I+3) = X_J(MEDIE(3),I)*MDOT(3) + X_J(MEDIE(1),I)*MDOT(1)
ENDDO
DO I=8,36
RES(I+3) = X_J(MEDIE(3),I)*MDOT(3) + X_J(MEDIE(1),I)*MDOT(1)
ENDDO
RES(40) = X_J(MEDIE(3),38)*MDOT(3) + X_J(MEDIE(1),38)*MDOT(1)
RES(3) = X_J(MEDIE(3),39)*MDOT(3) + X_J(MEDIE(1),39)*MDOT(1)
C
C Gas and fuel outlet temperature are equal
C
c CALL STATES(P(3),H(3),T3,V,S,X,U,1,2,MEDIE(3))
c CALL STATES(P(4),H4,T3,V,S,X,U,1,3,MEDIE(4))
c RES(3) = H(4) − H4
C
RES(41) = ZA(1) − MDOT(2)*(H(2)−H(4))
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
CALL STATES(P(1),H(1),T1,V,S,X,U,1,2,MEDIE(1))
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(3),H(3),T3,V,S,X,U,1,2,MEDIE(3))
CALL STATES(P(4),H(4),T4,V,S,X,U,1,2,MEDIE(4))
IF (MDOT(1).LT.−1D−10) GOTO 550
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IF (MDOT(2).LT.−1D−10) GOTO 550
IF (MDOT(3).GT.1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
IF (T1.GT.T3) GOTO 550
IF (T2.LT.T4) GOTO 550
IF (Q.GT.1D−10) GOTO 550
IF (X_J(MEDIE(1),37)−X_J(MEDIE(3),37).LT.−1D−6) GOTO 550
IF (X_J(MEDIE(1),7).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Steam dryer for solid fuels (Steam is a real fluid).’
K_PAR(1) = ’Moisture content of dried fuel’
K_PAR(2) = ’Pressure loss: $\\Delta p$ [bar]’
K_BET = ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\gt 0 \\\\
$\\dot{m}_3 \\lt 0 \\\\ \\dot{m}_4 \\lt 0 \\\\
$T_1 \\lt T_3 \\\\ T_2 \\gt T_4 \\\\ Q \\lt 0 \\\\
$x_{1,H_2O} \\gt x_{3,H_2O}$’
KMEDDS(1) = ’Solid in’
KMEDDS(2) = ’Steam in’
KMEDDS(3) = ’Dry solid out’
KMEDDS(4) = ’Steam out’
KMEDDS(5) = ’Heat loss’
K_INP=’struc dryer DRYER_04 1 2 3 4 300 0.05 0\\\\
$media 1 Wood 3 dry−wood\\\\
$SOLID Wood H .0305 O .1886 H2O−L .5 C .2503 S .00005 ASH .0255\\\\
$+ N 0.003 36 0.00205\\\\
$+ LHV 21750 CP 1.35\\\\
$addco m dryer 1 2.05 t dryer 1 15 p 1 1\\\\
$addco t dryer 2 322 t dryer 3 150 t dryer 4 150\\\\
$addco p 2 1 p 3 1\\\\
$addco q dryer 300 0\\\\
$START M dryer 2 8.3 M dryer 3 −1\\\\
$START X_J dry−wood H2 0.057 X_J dry−wood O2 0.35\\\\
$START X_J dry−wood C 0.47 X_J dry−wood H2O−L 0.05’
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE GASIFI_3_VENZIN(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,
: MMVAR,PARNAM,ZANAM,MEDIE,
: ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q,PAR,ZA,ZC,
: RES,X_J,CP,HV,HF,KOMDSC,KMEDDS,K_LIG,k_par,K_BET,k_inp)
C***********************************************************************
C
C GASIFI_3 is a model of a gasifier. The fuel is added
C with water based on the steam table and is gasified using an
C oxydant. The
C gasifier works at given pressure and temperature. Through the plant
C is a constant pressure drop. A heat loss representing real losses
C due to radiation and convection, and also the removed high tempe−
C ture ashes is modelled. Using equilibrium assumption and minimizing
C Gibbs energy the composition of the raw gas is found. Pressure and
C temperature are identical on all outlets.
C
c be 20041117 A new parameter for bypassing methane from the
c equilibrium calculation has been added
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA Q − INPUT − Exchanged heat.
CA PAR − INPUT − Parameters of the component.
CA X_J − INPUT − Fluid composition.
CA KOMTY − OUTPUT − Component name.
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CA ANTPK − OUTPUT − Number of parameters for the component.
CA ANTLK − OUTPUT − Number of equations in the component.
CA ANTEX − OUTPUT − Number of independent equations in the component.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean :
CA 2 : Coal.
CA 8 : Water (liquid).
CA 27 : Oxygen rich gas.
CA 25 : Raw gas.
CA 300 : Heat.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA VARME − OUTPUT − Fluid numbers (with variable composition).
CA ANTEL − OUTPUT − Number of compounds in these variable fluids.
CA VAREL − OUTPUT − Compound numbers in variable fluids.
CA RES − OUTPUT − Residuals for the component.
C
CL M4 Mass flow of raw gas.
CL DELP Pressure drop through the plant.
CL PGAS Gasifier pressure.
CL TGAS Gasifier temperature.
CL DMVC Amount of water relative to amount of coal.
CL XRAW Composition of raw gas.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : COMINF
C REAC
C
CP Programmer : Brian Elmegaard 2000 (Bent Lorentzen 1994, Niels Emsholm 1991)
CP Dept. Energy Engr., DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
INCLUDE ’GASI.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(7), ANTPK,
: ANTM1, ANTME, VARME(4), ANTEL(4),
: VAREL(ANTST,4),MMVAR(MAXMM)
DOUBLE PRECISION X_J(MAXME,ANTST), PAR(20), RES(30),
: MDOT(5),P(5),Q(1),CP(MAXME),HV(MAXNM),HF(MAXME),
: H(5),ZA(7),ZC(1)
CHARACTER*80 KOMTY
CHARACTER*80 ZANAM(7),PARNAM(20)
C
C Local variables
C
INTEGER K_MED(6),I,J,CALCOM(ANTST)
DOUBLE PRECISION DELP, PGAS, TGAS, DMVC,
: T4,H5,V,S,X,U,CC,NIN(ANTST+1),NOUT(ANTST+1),
: M_BL(5),G(15),R,METH,XEQ(ANTST)
CHARACTER*100 K_PAR(5),K_STAT(1)
CHARACTER*500 K_LIG(30), K_BET,K_GRAF
$ ,warnstring
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(7)
EXTERNAL COMINF,GIBBS,STATES
INTRINSIC DABS,DLOG,NINT,EXP
INCLUDE ’THERPROP.INI’
INCLUDE ’GASI.INI’
C=======================================================================
GOTO (100,200,1,400,400,200,350,1,250) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’GASIFI_3_VENZIN’
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MMVAR(1) = 15
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’GASIFI_3_VENZIN’
ANTKN = 7
ANTPK = 5+MMVAR(1)
ANTLK = 23
ANTEX = 7
ANTM1 = 5
ZANAM(1) = ’MULTIPLIER H’
ZANAM(2) = ’MULTIPLIER C’
ZANAM(3) = ’MULTIPLIER N’
ZANAM(4) = ’MULTIPLIER O’
ZANAM(5) = ’MULTIPLIER S’
ZANAM(6) = ’MULTIPL Ar’
ZANAM(7) = ’GIBBS ENERGY’
DO I=1,ANTM1
PARNAM(I) = ’CAL COMPOUND’
ENDDO
PARNAM(ANTM1+1) = ’EQ PRESSURE’
PARNAM(ANTM1+2) = ’EQ TEMPERAT’
PARNAM(ANTM1+3) = ’PRESSURELOSS’
c PARNAM(ANTM1+4) = ’STEAM FLOW’
PARNAM(ANTM1+4) = ’UNCONV CARBO’
PARNAM(ANTM1+5) = ’METHANE PERC’
MEDIE(1) = −5
MEDIE(2) = 97
MEDIE(3) = −4
MEDIE(4) = −4
MEDIE(5) = −5
MEDIE(6) = 300
MEDIE(7) = 999
ANTME = 4
VARME(1) = −1
VARME(2) = −3
VARME(3) = −4
VARME(4) = −5
ANTEL(1) = 0
ANTEL(2) = 0
ANTEL(3) = 15
ANTEL(4) = 2
VAREL(1,3) = 1
VAREL(2,3) = 2
VAREL(3,3) = 3
VAREL(4,3) = 4
VAREL(5,3) = 5
VAREL(6,3) = 6
VAREL(7,3) = 7
VAREL(8,3) = 8
VAREL(9,3) = 9
VAREL(10,3) = 10
VAREL(11,3) = 11
VAREL(12,3) = 30
VAREL(13,3) = 31
VAREL(14,3) = 32
VAREL(15,3) = 36
VAREL(1,4) = 28
VAREL(2,4) = 38
IF (FKOMP.EQ.6) GOTO 600
*** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Initialization of algebraic variables.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
250 CONTINUE
ZA(7) = −.1D+1
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Specific heat, heat of formation, heating value of ashes
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
350 CONTINUE
CP(MEDIE(5)) = 1
HF(MEDIE(5)) = −5083.0D0
HV(MEDIE(5)) = X_J(MEDIE(5),28)*NED_H(28)/M_MOL(28)
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
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C Component equations. All in residual form.
C Do not include the conservation laws, since these are treated
C automatically by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
C Ash characteristics
C
CP(MEDIE(5)) = 1
HF(MEDIE(5)) = −5083.0D0
HV(MEDIE(5)) = X_J(MEDIE(5),28)*NED_H(28)/M_MOL(28)
C
CALCOM(1) = −1
CALCOM(2) = −2
CALCOM(3) = −3
CALCOM(4) = −4
CALCOM(5) = −5
CALCOM(6) = −6
CALCOM(7) = −7
CALCOM(8) = −8
CALCOM(9) = −9
CALCOM(10) = −10
CALCOM(11) = −11
CALCOM(12) = −30
CALCOM(13) = −31
CALCOM(14) = −32
CALCOM(15) = −36
DO I=1,ANTPK−5
DO J=1,15
IF (CALCOM(J).EQ.−NINT(PAR(I))) THEN
CALCOM(J)=−CALCOM(J)
ENDIF
ENDDO
ENDDO
PGAS = PAR(ANTPK−4)
TGAS = PAR(ANTPK−3)+273.15
DELP = PAR(ANTPK−2)
c DMVC = PAR(ANTPK−2)
CC = PAR(ANTPK−1)
cbe 20041711 parameter for "non−equilibrium" methane
METH = PAR(ANTPK)
R = 8.314D0
C
C Pressure
C
RES(1) = P(2) − P(3)
RES(2) = P(3) − P(4) − DELP
RES(3) = P(4) − PGAS
C
C Amount of water relative to coal
C
c RES(4) = MDOT(2) − DMVC*MDOT(1)
RES(4) = MDOT(2) − ZC(1)*MDOT(1)
C
C Ash
C
RES(5) = MDOT(5) +
: MDOT(1)*(X_J(MEDIE(1),38)+X_J(MEDIE(1),28)*(1.0D0−CC))
IF (MDOT(5).EQ.0D0) THEN
RES(6) = X_J(MEDIE(5),38)
ELSE
RES(6) = X_J(MEDIE(5),38) + MDOT(1)*X_J(MEDIE(1),38)/MDOT(5)
ENDIF
RES(7) = X_J(MEDIE(5),28) − (1.0D0−X_J(MEDIE(5),38))
CALL STATES(P(4),H(4),T4,V,S,X,U,1,2,MEDIE(4))
CALL STATES(P(5),H5,T4,V,S,X,U,1,3,MEDIE(5))
RES(8) = H(5) − H5
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Find the composition of the equilibrium gas
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C
C Calculate mole flow of each species in
C
M_BL(3) = 0D0
DO I=1,ANTST
M_BL(3)=M_BL(3)+X_J(MEDIE(3),I)*M_MOL(I)
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ENDDO
DO I=1,ANTST
NIN(I)=MDOT(1)*X_J(MEDIE(1),I)/M_MOL(I) +
+ MDOT(3)*X_J(MEDIE(3),I)/M_BL(3)
ENDDO
NIN(37)=NIN(37)+MDOT(2)/M_MOL(37)
NIN(28)=NIN(28)*CC
C
C Calculate mole flow of each species out
C
M_BL(4) = 0D0
DO I=1,ANTST
M_BL(4)=M_BL(4)+X_J(MEDIE(4),I)*M_MOL(I)
ENDDO
NOUT(ANTST+1) = (−MDOT(4))/M_BL(4)
DO I=1,ANTST
NOUT(I)=NOUT(ANTST+1)*X_J(MEDIE(4),I)
cbe 20041711 molar fractions excluding "non−equilibrium" methane
IF (I.EQ.11) THEN
XEQ(I)=(X_J(MEDIE(4),i)−METH)/(1.D0−METH)
ELSE
XEQ(I)=X_J(MEDIE(4),I)/(1.D0−METH)
ENDIF
ENDDO
C
C Gibbs’ free energy of each compound
C
DO I=1,15
IF (CALCOM(I).GT.0)
$ CALL GIBBS(CALCOM(I),TGAS,PGAS*(1.D0−METH)*XEQ(CALCOM(I))
$ ,G(I))
ENDDO
C
C Partial derivatives of the function to be minimized with respect to
C each species molar fraction
DO I=1,15
IF (CALCOM(I).LT.0) THEN
RES(I+8) = X_J(MEDIE(4),−CALCOM(I))
ELSEIF (X_J(MEDIE(4),CALCOM(I)).GT.1.0D−5) THEN
RES(I+8) = G(I)
c /(R*TGAS) +
c : DLOG(PGAS*NOUT(CALCOM(I))/NOUT(ANTST+1))
cbe 041117 part of the fuel is not reaching equilibrium
c : DLOG(PGAS*XEQ(CALCOM(I)))
DO J=1,6
RES(I+8) = RES(I+8) + ZA(J)*EL(CALCOM(I),J)
ENDDO
ELSE
RES(I+8) = G(I)
c /(R*TGAS) +
c : DLOG(1.d−5)+
c $ 1.d5*(pgas*NOUT(CALCOM(I))/NOUT(ANTST+1)−1.d−5)
c RES(I+8) = X_J(MEDIE(4),CALCOM(I))−1.0D−10
DO J=1,6
RES(I+8) = RES(I+8) + ZA(J)*EL(CALCOM(I),J)
ENDDO
if (fiter) then
write(warnstring,’(a,a,a,a)’) ’Warning: The compound ’,
$ COMPNA(CALCOM(I)),
$ ’should be removed from the ’,
$ ’compound equilibrium calculation.’
call printout(warnstring)
endif
ENDIF
ENDDO
C
C Molar balance for each atom (H,C,N,O,S,Ar)
C
DO J=1,ANTEX−1
RES(ANTLK+J) = 0D0
DO I=1,ANTST
RES(ANTLK+J)=RES(ANTLK+J)−(NIN(I)−NOUT(I))*EL(I,J)
ENDDO
ENDDO
RES(29) = 1.0D0
DO I=1,ANTST
RES(29)= RES(29)−X_J(MEDIE(4),I)
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ENDDO
C
C Gibbs free energy of the mixture
C
RES(30) = ZA(7)
DO I=1,15
IF (CALCOM(I).GT.0) THEN
IF (NOUT(CALCOM(I)).GT.1.D−10) THEN
RES(30) = RES(30) − XEQ(CALCOM(I))*G(I)
ENDIF
ENDIF
ENDDO
c$$$ RES(30) = 0.D0
c$$$ GIBTEM = ZA(7)
c$$$ DO I=1,15
c$$$ IF (CALCOM(I).GT.0) THEN
c$$$ IF (NOUT(CALCOM(I)).GT.1.D0−10) THEN
c$$$ RES(30) = RES(30) −
c$$$ : (G(I)+R*TGAS*DLOG(NOUT(CALCOM(I))/NOUT(ANTST+1)*PGAS))
c$$$ ENDIF
c$$$ ENDIF
c$$$c$$$ IF (CALCOM(I).GT.0) THEN
c$$$c$$$C IF (NOUT(CALCOM(I)).NE.0.D0) THEN
c$$$c$$$ GIBTEM = GIBTEM − G(I)
c$$$c$$$ RES(30) = RES(30) − NOUT(CALCOM(I))/NOUT(ANTST+1)*PGAS
c$$$c$$$C ELSE
c$$$c$$$C RES(30) = RES(30) −
c$$$c$$$C : (G(I)+R*TGAS*DLOG(1.D−15*PGAS))
c$$$c$$$C ENDIF
c$$$c$$$ IF ((CALCOM(I).GT.0).AND.(NOUT(CALCOM(I)).GT.1.D0−10))
c$$$c$$$ $ RES(30) = RES(30) −
c$$$c$$$ : (G(I)+R*TGAS*DLOG(NOUT(CALCOM(I))/NOUT(ANTST+1)*PGAS))
c$$$c$$$ ENDIF
c$$$ ENDDO
C RES(30) = RES(30) − GIBTEM/(R*TGAS)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).LT.−1D−10) GOTO 550
IF (MDOT(3).LT.−1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
IF (MDOT(5).GT.1D−10) GOTO 550
IF (Q(1).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC =
$’Gasifier with water/steam. 1 identifier: Calculated compounds.
$The difference between GASIFI_3 and this component is that the wat
$er to fuel ratio is defined as a control variable.’
K_PAR(1) = ’Gasifier pressure: PGAS’
K_PAR(2) = ’Gasifier temperature: TGAS’
K_PAR(3) = ’Pressure loss: DELP’
K_PAR(4) = ’Carbon conversion ratio’
K_PAR(5) = ’Non−equilibrium methane’
K_BET =
$ ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\gt 0 \\\\ \\dot{m_3}
$\\gt 0 \\\\ \\dot{m_4} \\lt 0 \\\\ \\dot{m_5} \\lt 0 \\\\ \\dot{Q}
$\\lt 0$’
KMEDDS(1) = ’Fuel in’
KMEDDS(2) = ’Steam in’
KMEDDS(3) = ’Air in’
KMEDDS(4) = ’Product gas out’
KMEDDS(5) = ’Ash out’
KMEDDS(6) = ’Heat loss¨’
KMEDDS(7) = ’water to fuel ratio (DMVC)’
k_inp=’STRUC Gasifier GASIFI_3_VENZIN 8 2 34 25 3 4 302 900 /\\\\
$1 3 4 6 7 9 11 36 2 750 0 1.0 0.0\\\\
$MEDIA 2 Wood 25 O2 3 FlueGas 4 Ash\\\\
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$fluid O2 O2 1\\\\
$SOLID Wood H .057 O .4085 H2O−L .05 C .4750 S .0001 ASH .0092\\\\
$+ N 0.0001 36 0.0001\\\\
$+ LHV 19000 CP 1.35\\\\
$ADDCO Q Gasifier 302 0 P 4 1 M Gasifier 2 1.2 T Gasifier 3 700\\\\
$addco T Gasifier 2 150 T Gasifier 34 600 T Gasifier 25 600\\\\
$addco p 2 1 ZC 900 0.35\\\\
$START M Gasifier 34 0.0 M Gasifier 25 1.8 M Gasifier 4 −0.01\\\\
$START Y_J FlueGas H2 0.21 Y_J FlueGas N2 0.39 Y_J FlueGas CO 0.26
$\\\\START Y_J FlueGas CO2 0.07 X_J Ash ASH 1’
C
9999 CONTINUE
RETURN
END
C***********************************************************************
SUBROUTINE GASCLE_2(KOMTY,MMVAR,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE
$ ,ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q,PAR,RES,X_J,komdsc,kmedds
$ ,k_lig,k_bet,k_inp,K_PAR)
C***********************************************************************
C Copied from GASCLE_1 − the difference is that N2 and Argon is off−seperated
C GASCLE_1 is a model of a gas cleaning plant. The not desired chemi−
C cal compounds are cleaned out. From the gas H2O, H2S, NH3, COS,
C SO2 and HCN is removed. The mass flow of removed gas is found using
C M1 and X_J. Through the plant is a constant pressure drop. On the
C outlets the pressure and temperature are identical. From the plant
C is a heat loss.
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA Q − INPUT − Exchanged heat.
CA PAR − INPUT − Parameters of the component.
CA X_J − INPUT − Fluid composition.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters for the component.
CA ANTLK − OUTPUT − Number of equations in the component.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean :
CA 25 : Raw gas.
CA 26 : Syngas.
CA 24 : Removed gas.
CA 300 : Heat.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA VARME − OUTPUT − Fluid numbers (with variable composition).
CA ANTEL − OUTPUT − Number of compounds in these variable fluids.
CA VAREL − OUTPUT − Compound numbers in variable fluids.
CA RES − OUTPUT − Residuals for the component.
C
CL S Entropy.
CL V Specific volume.
CL T2 Temperature in node 2.
CL T3 Temperature in node 3.
CL X Quality.
CL U Internal energy.
CL DELP Pressure drop through the plant.
CL M1 Mass flow of raw gas.
CL M3 Mass flow 3 found using M1 and raw gas composition.
CL XSYN Composition of syngas.
CL XUD Composition of removed gas.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
CA X_J − INPUT − Fluid composition. The compounds are :
CA 1: Hydrogen (H2)
CA 2: Oxygen (O2)
CA 3: Nitrogen (N2)
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CA 4: Carbon monoxide (CO)
CA 5: Nitrogen oxide (NO)
CA 6: Carbon dioxide (CO2)
CA 7: Steam (ideal gas) (H2O)
CA 8: Ammonia (NH3)
CA 9: Hydrogen sulfide (H2S)
CA 10: Sulfur dioxide (SO2)
CA 11: Methane (CH4)
CA 12: Ethane (C2H6)
CA 13: Propane (C3H8)
CA 14: n−Butane (C4H10)
CA 15: iso−Butane (C4H10)
CA 16: n−Pentane (C5H12)
CA 17: n−Hexane (C6H14)
CA 18: n−Heptane (C7H16)
CA 19: n−Octane (C8H18)
CA 20: Ethylene (C2H4)
CA 21: Propylene (C3H6)
CA 22: 1−Pentene (C5H10)
CA 23: 1−Hexene (C6H12)
CA 24: 1−Heptene (C7H14)
CA 25: Acetylene (C2H2)
CA 26: Benzene (C6H6)
CA 27: Cyclohexane (C6H12)
CA 28: Carbon (graphite, solid) (C)
CA 29: Sulfur (crystal, solid) (S)
CA 30: Nitrogen dioxide (NO2)
CA 31: Hydrogen cyanide (HCN)
CA 32: Carbonyl sulfide (COS)
CA 33: Nitrous oxide (N2O)
CA 34: Nitrogen trioxide (NO3)
CA 35: Sulfur trioxide (SO3)
CA 36: Argon (Ar)
CA 37: Water (liquid, 1 bar) (H2O)
CA 38: Ashes (SiO2)
CA 39: Tar
CA 40: Methanol (CH3OH)
CA 41: Methanol (liquid, 1 bar) (CH3OH)
C
C Subroutines : COMINF
C STATES
C CLEAN
C
CP Programmer : Brian Elmagaard 1997
CP (Bent Lorentzen 1994, Niels Emsholm 1991
CP Lab. for Energetics, DTH, Denmark.)
C***********************************************************************
C
C Including the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
C Parameter variables
C
INTEGER ANTLK, ANTKN, MEDIE(4), ANTPK,
: ANTM1, ANTME, VARME(3), ANTEL(3),
: VAREL(ANTST,3),MMVAR(MAXMM)
DOUBLE PRECISION X_J(MAXME,ANTST), PAR(1+ANTST), RES(4+ANTST*2),
: MDOT(3),P(3), H(3), Q(1)
CHARACTER*80 KOMTY
C
C Local variables
C
DOUBLE PRECISION DELP, M1, M3, T2, T3, S, V, X, U,
: XSYN(ANTST), XUD(ANTST),M_BL1,N(ANTST),NTOT,T_SUM
INTEGER I,Compound_clean(ANTST),Nr_clean
CHARACTER*100 K_PAR(1+ANTST)
CHARACTER*500 K_LIG(24), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(4)
EXTERNAL STATES,CLEAN1,COMINF
INTRINSIC DABS
INCLUDE ’THERPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’GASCLE_2’
MMVAR(1) = ANTST
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’GASCLE_2’
ANTKN = 4
ANTPK = 1+MMVAR(1)
ANTLK = 4+2*ANTST
ANTM1 = 3
MEDIE(1) = −4
MEDIE(2) = −4
MEDIE(3) = −4
MEDIE(4) = 300
ANTME = 3
VARME(1) = −1
VARME(2) = −2
VARME(3) = −3
ANTEL(1) = 0
ANTEL(2) = ANTST
ANTEL(3) = ANTST
DO I = 1,ANTST
VAREL(I,2) = I
VAREL(I,3) = I
ENDDO
C
IF (FKOMP.EQ.6) GOTO 600
*** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws, since these are treated
C automatically by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
DELP = PAR(1)
Nr_clean=ANTPK−1
C
DO I = 1,Nr_clean
Compound_clean(I)=PAR(I+1)
ENDDO
C
M_BL1 = 0.D0
DO I=1, ANTST
M_BL1 = M_BL1 + X_J(MEDIE(1),I)*M_MOL(I)
XUD(I) = 0.D0
ENDDO
C
DO I=1, ANTST
N(I) = X_J(MEDIE(1),I)*MDOT(1)/M_BL1
ENDDO
C
NTOT=0D0
M3=0D0
DO I=1, Nr_clean
NTOT = NTOT+N(Compound_clean(I))
M3=M3+N(Compound_clean(I))*M_MOL(Compound_clean(I))
ENDDO
C
DO I=1, Nr_clean
XUD(Compound_clean(I)) = N(Compound_clean(I))/NTOT
N(Compound_clean(I)) = 0D0
ENDDO
C
T_SUM = 0D0
DO I=1, ANTST
T_SUM = T_SUM + N(I)
ENDDO
C
C Find mole ratios in syngas
C
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
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CALL STATES(P(3),H(3),T3,V,S,X,U,1,2,MEDIE(3))
C
C Pressure
C
RES(1) = P(3) − P(2)
RES(2) = P(1) − P(2) − DELP
C
C Outlet temperatures are identical
C
RES(3) = T2 − T3
C
C Mass flow of removed gas found using M1 and X_J
C
RES(4) = MDOT(3) + M3
C
C Variable mole ratios (first removed gas, then syngas)
C
DO I = 1,ANTST
RES(4+I)=X_J(MEDIE(3),I)−XUD(I)
RES(4+ANTST+I)=X_J(MEDIE(2),I)−N(I)/T_SUM
ENDDO
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).GT.1D−10) GOTO 550
IF (Q(1).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Syngas cleaning. The syntax is struc Componentname
$ GASCLE_2 7 1 2 3 301 0 8 9 10 31 32 38 39. So the first
$ number determines how many compounds is off−seperated. The
$ 7 numbers from 8 to 39 is therefore compound numbers (8
$ is $NH_3$).’
K_PAR(1) = ’Pressure loss: $\\Delta p$ [bar]’
DO I = 2,ANTST+1
K_PAR(I) = ’Compound number’
ENDDO
K_BET = ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0
$\\\\ \\dot{m}_3 \\lt 0 \\\\ \\dot{Q} \\lt 0$’
KMEDDS(1) = ’Dirty gas in’
KMEDDS(2) = ’Clean gas out’
KMEDDS(3) = ’Off−separated gas’
KMEDDS(4) = ’Heat loss’
k_inp=’struc Cleaner GASCLE_2 7 13 14 15 308 0 8 9 10 31 32 38 39
$\\\\media 13 GG 14 GG−clean 15 H2S\\\\
$fluid GG H2 0.5 CO 0.3 CO2 0.1 H2O−G 0.05 CH4 0.02 H2S 0.03\\\\
$addco Q Cleaner 308 0\\\\
$addco t Cleaner 13 70 p 13 1 m Cleaner 13 1\\\\
$START M Cleaner 14 −0.93 t Cleaner 14 70\\\\
$START Y_J GG−clean H2 0.5 Y_J GG−clean CO 0.30\\\\
$start Y_J GG−clean CO2 0.1 Y_J H2S H2S 1’
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE STEAM_REFORMER(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,
$ MMVAR,PARNAM,ZANAM,MEDIE, ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q
$ ,PAR,ZA, RES,X_J,KOMDSC,KMEDDS,K_PAR,K_LIG ,K_BET,k_inp)
C***********************************************************************
C
C STEREF_0 is a model of a steam reformer. The outlet composition is
C based on an assumption of chemical equilibrium.
C
C***********************************************************************
C
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CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA Q − INPUT − Exchanged heat.
CA PAR − INPUT − Parameters of the component.
CA X_J − INPUT − Fluid composition.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters for the component.
CA ANTLK − OUTPUT − Number of equations in the component.
CA ANTEX − OUTPUT − Number of independent equations in the component.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean :
CA 2 : Coal.
CA 8 : Water (liquid).
CA 27 : Oxygen rich gas.
CA 25 : Raw gas.
CA 300 : Heat.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA VARME − OUTPUT − Fluid numbers (with variable composition).
CA ANTEL − OUTPUT − Number of compounds in these variable fluids.
CA VAREL − OUTPUT − Compound numbers in variable fluids.
CA RES − OUTPUT − Residuals for the component.
C
C Subroutines : COMINF
C
CP Programmer : Brian Elmegaard, MEK, DTU, 2000
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
INCLUDE ’GASI.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(5), ANTPK,
: ANTM1, ANTME, VARME(4), ANTEL(4),
: VAREL(ANTST,4),MMVAR(MAXMM)
DOUBLE PRECISION X_J(MAXME,ANTST), PAR(2), RES(30),
: MDOT(4),P(4),Q(1),H(4),ZA(20)
CHARACTER*80 KOMTY
CHARACTER*80 ZANAM(20),PARNAM(1)
C
C Local variables
C
LOGICAL CON
INTEGER I,J,RES_NR
DOUBLE PRECISION DELP, PGAS, TGAS, T_sat, Ratio,
: V,S,X,U,H1,Psat_meoh,Psat_water,NIN(ANTST+1),NOUT(ANTST+1),
: M_BL(6),G(7),R,G_met
CHARACTER*100 KMEDDS(6)
CHARACTER*100 K_PAR(4)
CHARACTER*500 K_LIG(29), K_BET
CHARACTER*1000 KOMDSC,K_INP
EXTERNAL COMINF,GIBBS,STATES
INTRINSIC DABS,DLOG,NINT,EXP
INCLUDE ’THERPROP.INI’
INCLUDE ’GASI.INI’
CON=.false.
C=======================================================================
GOTO (100,200,1,400,400,200,1) FKOMP
1 RETURN
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’STEAM_REFORMER’
MMVAR(1) = 0
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’STEAM_REFORMER’
ANTKN = 5
ANTPK = 1
ANTEX = 4
ANTM1 = 4
ZANAM(1) = ’MULTIPLIER H’
ZANAM(2) = ’MULTIPLIER C’
ZANAM(3) = ’MULTIPLIER O’
ZANAM(4) = ’GIBBS ENERGY’
MEDIE(1) = ANYGAS$
MEDIE(2) = ANYGAS$
MEDIE(3) = 97
MEDIE(4) = ANYGAS$
MEDIE(5) = HEAT$
ANTME = 4
VARME(1) = NODE1$
VARME(2) = NODE2$
VARME(3) = NODE3$
VARME(4) = NODE4$
C
204 ANTEL(4) = 5
ANTLK = 4+ANTEL(4)
VAREL(1,4) = H2$
VAREL(2,4) = CO$
VAREL(3,4) = CO2$
VAREL(4,4) = H2O_G$
VAREL(5,4) = CH4$
C
IF (FKOMP.EQ.6) GOTO 600
IF (CON) GOTO 404
*** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws, since these are treated
C automatically by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
CON=.true.
GOTO 204
404 Continue
C
C Pressure
C
RES(1) = P(1) − P(2)
RES(2) = P(1) − P(3)
RES(3) = P(1) − P(4)
RES(4) = MDOT(1)*PAR(1)−MDOT(3)
C
RES_NR=4
C
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Find the composition of the equilibrium gas
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C
C Calculate mole flow of each species in
C
M_BL(1)=0.D0
M_BL(2)=0.D0
DO I=1,ANTST
M_BL(1)=X_J(MEDIE(1),I)*M_MOL(I)+M_BL(1)
M_BL(2)=X_J(MEDIE(2),I)*M_MOL(I)+M_BL(2)
ENDDO
DO I=1,ANTST
NIN(I)= MDOT(1)/M_BL(1)*X_J(MEDIE(1),I)+
$ MDOT(2)/M_BL(2)*X_J(MEDIE(2),I)
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ENDDO
NIN(H2O_G$)=NIN(H2O_G$)+MDOT(3)/M_MOL(H2O_G$)
C
C Calculate mole flow of each species out
C
M_BL(4)=0.D0
DO I=1,ANTST
M_BL(4)=X_J(MEDIE(4),I)*M_MOL(I)+M_BL(4)
ENDDO
C
NOUT(ANTST+1)=0.D0
DO I=1,ANTST
NOUT(I)=(−MDOT(4))*X_J(MEDIE(4),I)/M_BL(4)
NOUT(ANTST+1)=NOUT(ANTST+1)+NOUT(I)
ENDDO
C
C Molar balance for each atom (H,C,O)
C
DO J=1,2
RES(RES_NR+J) = 0.D0
DO I=1,ANTST
RES(RES_NR+J)=RES(RES_NR+J)−(NIN(I)−NOUT(I))*EL(I,J)
ENDDO
ENDDO
RES_NR=RES_NR+3
C
RES(RES_NR)=1.D0
DO I=1,ANTST
RES(RES_NR)= RES(RES_NR)−X_J(MEDIE(4),I)
ENDDO
RES_NR=RES_NR+1
C
C Gibbs’ free energy of each compound
C
CALL STATES(P(4),H(4),TGAS,V,S,X,U,1,2,MEDIE(4))
TGAS = TGAS+273.15D0
DO I=1,ANTEL(4)
CALL GIBBS(VAREL(I,4),TGAS,P(4)*X_J(MEDIE(4),VAREL(I,4)),G(I))
ENDDO
C
C Gibbs free energy of the mixture
C
RES(RES_NR) = ZA(4)
DO I=1,ANTEL(4)
RES(RES_NR) = RES(RES_NR) − X_J(MEDIE(4),VAREL(I,4))*G(I)
ENDDO
C
C Partial derivatives of the function to be minimized with respect to
C each species molar fraction
C
DO I=1,ANTEL(4)
RES(I+RES_NR)=G(I)
DO J=1,2
RES(I+RES_NR) = RES(I+RES_NR) + ZA(J)*EL(VAREL(I,4),J)
ENDDO
RES(I+RES_NR) = RES(I+RES_NR) + ZA(3)*EL(VAREL(I,4),4)
ENDDO
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).LT.−1D−10) GOTO 550
IF (MDOT(3).LT.−1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC =’Steam reformer − with the possibillity of auto thermal
$ reforming (oxygen as input massflow in node 2).’
K_PAR(1) = ’Gas/steam fraction: $\\frac{\\dot{m}_3}{\\dot{m}_1}$’
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K_BET =
$ ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\gt 0 \\\\ \\dot{m}_3 \\
$gt 0 \\\\ \\dot{m}_4 \\lt 0 $’
KMEDDS(1) =’Inlet gas’
KMEDDS(2) =’Oxygen or another gas’
KMEDDS(3) =’Steam’
KMEDDS(4) =’Reformed gas’
KMEDDS(5) =’Heat’
k_inp=’struc NG_reformer STEAM_REFORMER 412 403 423 431 313 1\\\\
$media 412 NATURAL_GAS 403 O2 431 NG_reformat\\\\
$fluid O2 O2 1\\\\
$addco q NG_reformer 313 0\\\\
$addco t NG_reformer 403 850 t NG_reformer 423 850 t NG_reformer
$ 412 667\\\\
$addco t NG_reformer 431 950 M NG_reformer 412 0.34 p 403 10\\\\
$START M NG_reformer 403 0.3 M NG_reformer 423 0.3\\\\
$START Y_J NG_reformat H2 0.55 Y_J NG_reformat CO 0.21 Y_J
$ NG_reformat H2O−G 0.18’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE GASCOOL2(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,ANTM2,MEDIE,
$ ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q,PAR,RES,X_J,ZA,ZANAM,
$ ANTEX,KOMDSC,K_PAR,K_lig,K_bet,KMEDDS,K_inp)
C***********************************************************************
C
C GASCOOL1 is a model of a gas cooler with steam condensation.
C The model does not include equations concerning the heat exchange.
C 1−2 is the heat emitting fluid.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL T1,T2 Temperature in first and second node.
CL T3,T4 Temperature in third and fourth node.
CL S Entropy.
CL V Specific volume.
CL X Quality.
CL U Internal energy.
CL DPA,DPB Pressure loss in heat exchanger.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
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C Subroutines : STATES
C
CP Programmer : Brian Elmegaard 2000
CP Dept. of Energy Eng., DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN, MEDIE(6), ANTPK, ANTEX,
& ANTM1, ANTM2, ANTME, VARME(4), ANTEL(4),
& VAREL(ANTST,4)
DOUBLE PRECISION RES(52), MDOT(5), P(5), H(5), Q, PAR(3),
& X_J(MAXME,ANTST),ZA(10)
CHARACTER*80 KOMTY,ZANAM(10)
C
C Local variables
C
INTEGER K_MED(6),I
DOUBLE PRECISION V, S, U,M_BL1,M_BL2, T1, T2, T3, T4, T5, X,
: NIN,NOUT,NSTIN,NSTOUT,NCOND,PSTOUT,X0,HD,XSTOUT,H2,
: X1,HPH,TPH,HSAT0,TPL,TPL1,TPH1,DTP,E1,E2,XST,HPHST,Ntotal,N
$ ,PST,NCONDST,HST,HX(ANTST),Htotal,H_water,H_water2,H1,P3
CHARACTER*100 K_PAR(3),K_STAT(1)
CHARACTER*500 K_LIG(50), K_BET
CHARACTER*1000 KOMDSC, K_INP
CHARACTER*100 KMEDDS(6)
logical EVAP
EXTERNAL STATES
INCLUDE ’THERPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200,1) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’GASCOOL2’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’GASCOOL2’
ANTKN = 5
ANTPK = 3
ANTLK = 47
ANTEX = 5
ANTM1 = 3
ANTM2 = 2
MEDIE(1) = ANYGAS$
MEDIE(2) = ANYGAS$
MEDIE(3) = 97
MEDIE(4) = ANYFLU$
MEDIE(5) = ANYFLU$
ANTME = 4
VARME(1) = NODE1$
VARME(2) = NODE2$
VARME(3) = NODE4$
VARME(4) = NODE4$
ANTEL(1) = 0
ANTEL(2) = ANTST
ANTEL(3) = 0
ANTEL(4) = 0
DO I=1,ANTST
VAREL(I,2) = I
ENDDO
ZANAM(1) = ’T−diff boil’
ZANAM(2) = ’T−boil’
ZANAM(3) = ’T−diff cond’
ZANAM(4) = ’T−cond’
ZANAM(5) = ’Trans. heat’
C
IF (FKOMP.EQ.6) GOTO 600
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** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
C Calculate mole flow in
C
M_BL1 = 0.D0
DO I=1,ANTST
M_BL1=M_BL1+X_J(MEDIE(1),I)*M_MOL(I)
ENDDO
NIN = MDOT(1)/M_BL1
NSTIN = X_J(MEDIE(1),7)*NIN
N = NIN−NSTIN
C
C Calculate mole flow out
C
M_BL2 = 0.D0
DO I=1,ANTST
M_BL2=M_BL2+X_J(MEDIE(2),I)*M_MOL(I)
ENDDO
NOUT = (−MDOT(2))/M_BL2
C
C Same temperature out
C
X0 = 0.D0
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
X0 = 0.D0
CALL STATES(PSTOUT,HD,T2,V,S,X0,U,3,6,MEDIE(3))
CALL STATES(P(3),H2,T2,V,S,X,U,1,3,MEDIE(3))
RES(1) = H2 − H(3)
C
C Molar flow and ratio of steam out
C
XSTOUT = PSTOUT/P(2)
IF (XSTOUT.GT.X_J(MEDIE(1),7)) XSTOUT = X_J(MEDIE(1),7)
NSTOUT = XSTOUT*(NIN−NSTIN)/(1−XSTOUT)
C
C Molar flow of condensate
C
NCOND = NSTIN − NSTOUT
c if (NCOND.lt.2D−7) NCOND=1D−7
RES(2) = MDOT(3) + NCOND*M_MOL(7)
C
C Pressure out
C
RES(3) = P(1) − P(2) − PAR(1)
RES(4) = P(2) − P(3)
RES(5) = P(4) − P(5) − PAR(2)
C
C Outlet composition of gas
C
DO I = 1,6
RES(I+5) = X_J(MEDIE(2),I)*NOUT − X_J(MEDIE(1),I)*NIN
ENDDO
RES(7+5) = X_J(MEDIE(2),7) − XSTOUT
DO I = 8,ANTST
RES(I+5) = X_J(MEDIE(2),I)*NOUT − X_J(MEDIE(1),I)*NIN
ENDDO
C −−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Pinch point analysis
C −−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C
C Check if pinch point is where the water condenses
C
DTP = PAR(3)
EVAP=.false.
if (MDOT(3).lt.−1d−5) then
EVAP=.true.
X0 = 0.0D0
CALL STATES(P(1)*X_J(MEDIE(1),7),HD,TPH,V,S,X0,U,1,6,
$ MEDIE(3))
CALL STATES(P(1),HSAT0,TPH,V,S,X,U,1,3,MEDIE(1))
HPH = H(5) − MDOT(1)*(H(1)−HSAT0)/MDOT(4)
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CALL STATES(P(4),HPH,TPL,V,S,X,U,1,2,MEDIE(4))
RES(50) = TPH − TPL − ZA(3)
HPHST=HPH
RES(51)=ZA(4)−TPH
else
RES(50) = ZA(3)
RES(51)=ZA(4)
TPH=99999
TPL=0
endif
C
C Check if pinch point is where the water starts evaporating
C (if the cold medium is water)
C
IF (MEDIE(4).GE.80) THEN
CALL STATES(P(4),H(4),T4,V,S,X0,U,1,2,MEDIE(4))
CALL STATES(P(5),H(5),T5,V,S,X1,U,1,2,MEDIE(5))
IF ((X1.GT.(1.D−12)).AND.(X0.LT.1.D−12)) THEN
X0 = 0.0D0
CALL STATES(P(4),HSAT0,TPL1,V,S,X0,U,1,6,MEDIE(4))
CALL STATES(P(1),HPH,TPL1+ZA(1),V,S,X,U,1,3,MEDIE(1))
E1=MDOT(4)*(H(5)−HSAT0)
if ((EVAP).and.(HPHST.gt.HSAT0)) then
X0 = 0.D0
CALL STATES(PST,HD,TPL1+ZA(1),V,S,X0,U,3,6,MEDIE(3))
XST = PST/P(2)
Ntotal=N/(1−XST)
NCONDST=NSTIN−Ntotal*XST
CALL ENTHALPY(7,TPL1+ZA(1),H_water)
HPH=(HPH*MDOT(1)−H_water*NCONDST*M_MOL(7))/(MDOT(1)
$ −NCONDST*M_MOL(7))
CALL STATES(P(3),HST,TPL1+ZA(1),V,S,X0,U,1,3,MEDIE(3))
E2=H(1)*MDOT(1)−(HPH*(MDOT(1)−NCONDST*M_MOL(7))
$ +HST*NCONDST*M_MOL(7))
else
E2=H(1)*MDOT(1)−HPH*MDOT(1)
endif
RES(48)=E2−E1
RES(49)=ZA(2)−(TPL1+ZA(1))
EVAP=.true.
if (ZA(1).lt.(TPH−TPL)) then
TPH=TPL1+ZA(1)
TPL=TPL1
endif
ELSE
RES(48) = ZA(1)
RES(49)=ZA(2)
ENDIF
ELSE
RES(48) = ZA(1)
RES(49)=ZA(2)
ENDIF
C
C Check if pinch point is at the beginning or the end of the component
C
CALL STATES(P(1),H(1),T1,V,S,X,U,1,2,MEDIE(1))
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(4),H(4),T4,V,S,X,U,1,2,MEDIE(4))
CALL STATES(P(5),H(5),T5,V,S,X,U,1,2,MEDIE(5))
if ((.not.EVAP).or.(EVAP.and.
$ (((T2−T4).lt.(TPH−TPL)).or.((T1−T5).lt.(TPH−TPL))))) then
IF ((T1−T5).LT.(T2−T4)) THEN
TPH = T1
TPL = T5
ELSE
TPH = T2
TPL = T4
ENDIF
ENDIF
C
C At the pinch point DTP is used
C
RES(47) = TPH − TPL − DTP
C
RES(52) = ZA(5) − MDOT(4)*(H(5)−H(4))
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
CALL STATES(P(1),H(1),T1,V,S,X,U,1,2,MEDIE(1))
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(4),H(4),T4,V,S,X,U,1,2,MEDIE(4))
CALL STATES(P(5),H(5),T5,V,S,X,U,1,2,MEDIE(5))
IF (MDOT(3).LT.−1D−5) then
X0 = 0.0D0
CALL STATES(P(1)*X_J(MEDIE(1),7),HSAT0,TPH,V,S,X0,U,1,6,
$ MEDIE(3))
IF (T1−TPH.LT.−1.D−1) GOTO 550
ENDIF
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).GT.1D−10) GOTO 550
IF (MDOT(4).LT.−1D−10) GOTO 550
IF (MDOT(5).GT.1D−10) GOTO 550
IF (T1−T2.LT.−1.D−10) GOTO 550
IF (T1−T5.LT.−1.D−10) GOTO 550
IF (T5−T4.LT.−1.D−10) GOTO 550
IF (T2−T4.LT.−1.D−10) GOTO 550
IF (X_J(MEDIE(1),7)−X_J(MEDIE(2),7).LT.−1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Gas cooler with outlet for condensed water. The pinch
$ point temperature is set as a parameter. The component checks
$ if the pinch point is at the inlet or outlet − or where the
$ condensation starts. If the cooling medium evaporates the
$ component also checks if the pinch point is where the
$ evaporation starts.’
K_PAR(1) = ’Pressure loss side 1: $\\Delta p$ [bar]’
K_PAR(2) = ’Pressure loss side 2: $\\Delta p$ [bar]’
K_PAR(3) = ’Pinch point temperature diffence’
K_BET =
$ ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\ \\dot{m}_3
$\\lt 0 \\\\ \\dot{m}_4 \\gt 0 \\\\ \\dot{m}_5 \\lt 0 \\\\ T_1
$\\gt T_2 \\\\ T_1 \\gt T_5 \\\\ T_2 \\gt T_4 \\\\ T_5 \\gt T_4 \\\
$\ y_{1,H_2O} \\gt y_{2,H_2O} \\\\ p_1*y_{1,H_2O} \\lt p_{sat,H_2O}
$$’
KMEDDS(1) = ’Hot gas inlet’
KMEDDS(2) = ’Hot gas outlet’
KMEDDS(3) = ’Condensate outlet’
KMEDDS(4) = ’Coolant inlet’
KMEDDS(5) = ’Coolant outlet’
K_INP=’STRUC Cooler GASCOOL2 3 5 6 10 11 0 0 10\\\\
$MEDIA 10 NATURAL_GAS 5 Coolgas 3 FG\\\\
$FLUID FG H2 0.44 CO 0.21 CO2 0.02 7 0.078 CH4 0.252\\\\
$addco t Cooler 3 150 m Cooler 3 1 p 3 4\\\\
$ADDCO P 10 20 T Cooler 11 100 T Cooler 5 51.46\\\\
$START M Cooler 5 −0.9 M Cooler 10 2.1 t Cooler 10 18\\\\
$START Y_J Coolgas H2 0.46 Y_J Coolgas CO 0.22\\\\
$START Y_J Coolgas CH4 0.26 Y_J Coolgas H2O−G 0.03’
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE MEOH_CONVERTER(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,
$ MMVAR,PARNAM,ZANAM,MEDIE, ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q
$ ,PAR,ZA, RES,X_J,KOMDSC,KMEDDS,K_PAR,K_LIG ,K_BET,k_inp)
C***********************************************************************
C
C STEREF_0 is a model of a steam reformer. The outlet composition is
C based on an assumption of chemical equilibrium.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
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CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA Q − INPUT − Exchanged heat.
CA PAR − INPUT − Parameters of the component.
CA X_J − INPUT − Fluid composition.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters for the component.
CA ANTLK − OUTPUT − Number of equations in the component.
CA ANTEX − OUTPUT − Number of independent equations in the component.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean :
CA 2 : Coal.
CA 8 : Water (liquid).
CA 27 : Oxygen rich gas.
CA 25 : Raw gas.
CA 300 : Heat.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA VARME − OUTPUT − Fluid numbers (with variable composition).
CA ANTEL − OUTPUT − Number of compounds in these variable fluids.
CA VAREL − OUTPUT − Compound numbers in variable fluids.
CA RES − OUTPUT − Residuals for the component.
C
C Subroutines : COMINF
C
CP Programmer : Brian Elmegaard, MEK, DTU, 2000
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
INCLUDE ’GASI.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(5), ANTPK,
: ANTM1, ANTME, VARME(3), ANTEL(3),
: VAREL(ANTST,3),MMVAR(MAXMM)
DOUBLE PRECISION X_J(MAXME,ANTST), PAR(2), RES(50),
: MDOT(4),P(4),Q(1),H(4),ZA(10)
CHARACTER*80 KOMTY
CHARACTER*80 ZANAM(10),PARNAM(1)
C
C Local variables
C
LOGICAL CON
INTEGER I,J,RES_NR,ANTGIBBS
DOUBLE PRECISION DELP, PGAS, TGAS, T_sat, Ratio,
: V,S,X,U,H1,Psat_meoh,Psat_water,NIN(ANTST+1),NOUT(ANTST+1),
: M_BL(6),G(7),R,G_met,b_2_1,b_1_2,alpha,R_u
$ ,T_K,tau_2_1,tau_1_2,gamma_2,gamma_1,y_ME,y_ST,x_ME,x_ST,P_ME
$ ,P_ST,T,P_SAT_ME,P_SAT_ST,x_ME_2,x_ME_3,x_ST_3,P_ME_IN,NOUTME
$ ,NOUTST,P_ST_IN,X0,HD,P_ST_2,T2
CHARACTER*100 KMEDDS(6)
CHARACTER*100 K_PAR(4)
CHARACTER*500 K_LIG(29), K_BET
CHARACTER*1000 KOMDSC,K_INP
EXTERNAL COMINF,GIBBS,STATES
INTRINSIC DABS,DLOG,NINT,EXP
INCLUDE ’THERPROP.INI’
INCLUDE ’GASI.INI’
CON=.false.
C=======================================================================
GOTO (100,200,1,400,400,200,1) FKOMP
1 RETURN
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’MEOH_CONVERTER’
MMVAR(1) = 0
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’MEOH_CONVERTER’
ANTKN = 3
ANTPK = 1
ANTEX = 6
ANTM1 = 2
ZANAM(1) = ’MULTIPLIER H’
ZANAM(2) = ’MULTIPLIER C’
ZANAM(3) = ’MULTIPLIER O’
ZANAM(4) = ’GIBBS ENERGY’
ZANAM(5) = ’T−COND’
MEDIE(1) = ANYGAS$
MEDIE(2) = ANYGAS$
MEDIE(3) = HEAT$
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE2$
C
204 ANTEL(2) = 37
ANTLK = 1+ANTEL(2)
VAREL(1,2) = H2$
VAREL(2,2) = CO$
VAREL(3,2) = CO2$
VAREL(4,2) = H2O_G$
VAREL(5,2) = CH3OH$
VAREL(6,2) = 2
VAREL(7,2) = 3
VAREL(8,2) = 5
DO I=8,36
VAREL(I+1,2) = I
ENDDO
C
IF (FKOMP.EQ.6) GOTO 600
IF (CON) GOTO 404
*** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws, since these are treated
C automatically by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
CON=.true.
GOTO 204
404 Continue
C
C Pressure
C
ANTGIBBS=5
RES(1) = P(1) − P(2) − PAR(1)
RES_NR=1
C
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Find the composition of the equilibrium gas
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C
C Calculate mole flow of each species in
C
M_BL(1)=0.D0
DO I=1,ANTST
M_BL(1)=X_J(MEDIE(1),I)*M_MOL(I)+M_BL(1)
ENDDO
DO I=1,ANTST
NIN(I)= MDOT(1)/M_BL(1)*X_J(MEDIE(1),I)
ENDDO
C
C Calculate mole flow of each species out
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C
C
C
M_BL(2)=0.D0
DO I=1,ANTST
M_BL(2)=X_J(MEDIE(2),I)*M_MOL(I)+M_BL(2)
ENDDO
NOUT(ANTST+1)=0.D0
DO I=1,ANTST
NOUT(I)=(−MDOT(2))*X_J(MEDIE(2),I)/M_BL(2)
NOUT(ANTST+1)=NOUT(ANTST+1)+NOUT(I)
ENDDO
DO J=ANTGIBBS+1,ANTEL(2)
RES(RES_NR+J−ANTGIBBS)=NOUT(VAREL(J,2))−NIN(VAREL(J,2))
ENDDO
RES_NR=RES_NR+ANTEL(2)−ANTGIBBS
C
C Molar balance for each atom (H,C,O)
C
DO J=1,2
RES(RES_NR+J) = 0.D0
DO I=1,ANTST
RES(RES_NR+J)=RES(RES_NR+J)−(NIN(I)−NOUT(I))*EL(I,J)
ENDDO
ENDDO
RES_NR=RES_NR+3
C
RES(RES_NR)=1.D0
DO I=1,ANTST
RES(RES_NR)= RES(RES_NR)−X_J(MEDIE(2),I)
ENDDO
RES_NR=RES_NR+1
C
C Gibbs’ free energy of each compound
C
CALL STATES(P(2),H(2),TGAS,V,S,X,U,1,2,MEDIE(2))
TGAS = TGAS+273.15D0
C
DO I=1,ANTGIBBS
CALL GIBBS(VAREL(I,2),TGAS,P(2)*X_J(MEDIE(2),VAREL(I,2)),G(I))
ENDDO
C
C Gibbs free energy of the mixture
C
RES(RES_NR)=ZA(4)
DO I=1,ANTGIBBS
RES(RES_NR)=RES(RES_NR)−X_J(MEDIE(2),VAREL(I,2))*G(I)
ENDDO
C
C Partial derivatives of the function to be minimized with respect to
C each species molar fraction
C
DO I=1,ANTGIBBS
RES(I+RES_NR)=G(I)
DO J=1,2
RES(I+RES_NR) = RES(I+RES_NR) + ZA(J)*EL(VAREL(I,2),J)
ENDDO
RES(I+RES_NR) = RES(I+RES_NR) + ZA(3)*EL(VAREL(I,2),4)
ENDDO
RES_NR=RES_NR+ANTGIBBS+1
C
C Check if condensation of water and methanol occurs at equllibrium
C
b_2_1=−1062.945621D0
b_1_2=3538.709318D0
c J/mol
alpha=0.2994D0
R_u=8.314D0
c J/(mol*K)
c
T=ZA(5)
X0 = 0.D0
CALL STATES(P_SAT_ST,HD,T,V,S,X0,U,3,6,WATHF$)
X0 = 0.D0
CALL STATES(P_SAT_ME,HD,T,V,S,X0,U,3,6,MEOH$)
T_K=T+273.15D0
c
tau_2_1=b_2_1/(R_u*T_K)
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tau_1_2=b_1_2/(R_u*T_K)
c
x_ME_3=ZA(6)
x_ST_3=1D0−x_ME_3
gamma_2=exp((x_ST_3**2*(tau_1_2*((exp(−(alpha
$ *tau_1_2))/(x_ME_3+x_ST_3*exp(−(alpha*tau_1_2))))
$ )**2+(tau_2_1*(exp(−(alpha*tau_2_1))/(x_ST_3+x_ME_3
$ *exp(−(alpha*tau_2_1)))**2)))))
gamma_1=exp((x_ME_3**2*(tau_2_1*((exp(−(alpha
$ *tau_2_1))/(x_ST_3+x_ME_3*exp(−(alpha*tau_2_1))))
$ )**2+(tau_1_2*(exp(−(alpha*tau_1_2))/(x_ME_3+x_ST_3
$ *exp(−(alpha*tau_1_2)))**2)))))
c
P_ST_IN=X_J(MEDIE(2),H2O_G$)*P(2)
P_ME_IN=X_J(MEDIE(2),CH3OH$)*P(2)
c
P_ME=P_ME_IN*0.999d0
x_ME=P_ME/(gamma_2*P_SAT_ME)
x_ST=1D0−x_ME
P_ST_2=gamma_1*P_SAT_ST*x_ST
P_ST=(P_ME_IN−P_ME+P_ST_IN)−(P_ME_IN−P_ME)/x_ME
if (T.gt.239.1) then
RES(RES_NR)=T−238
else
RES(RES_NR)=P_ST−P_ST_2
endif
c
RES(RES_NR+1)=x_ME−x_ME_3
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (Q(1).GT.1D−10) GOTO 550
IF (T2.LT.T) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Methanol converter. Outlet gas is at equilibrium
$ between $ H_2$, CO, $CO_2$, $H_2O$ and $CH_3OH$. One of the
$ conditions for the component is that condensation of methanol
$ and water does not occur.’
K_PAR(1) = ’Pressure loss: $\\Delta p$ [bar]’
K_BET =
$ ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\ \\dot{Q} \\lt
$0 \\\\ T_2 \\gt T_{condensation} $’
KMEDDS(1) =’Inlet gas’
KMEDDS(2) =’Oulet gas’
KMEDDS(3) =’Heat loss’
k_inp=’struc Meoh−convert MEOH_CONVERTER 601 602 311 0.01\\\\
$media 601 Syngas 602 Syngas−meoh\\\\
$fluid Syngas H2 0.5 CO 0.3 CO2 0.2\\\\
$addco p 601 144\\\\
$addco t Meoh−convert 602 235 t Meoh−convert 601 230 m Meoh−convert
$ 601 100\\\\
$START Y_J Syngas−meoh H2 0.15 Y_J Syngas−meoh CO 0.16\\\\
$START Y_J Syngas−meoh CO2 0.33 Y_J Syngas−meoh CH3OH 0.34\\\\
$START ZA Meoh−convert 5 230’
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE SET_M(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,X_J,KOMDSC,K_PAR,K_lig,K_bet
$ ,KMEDDS,K_inp)
C***********************************************************************
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C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media of the connected nodes.
CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(3), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(1),PAR(2)
$ ,X_J(MAXME,ANTST)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3)
DOUBLE PRECISION MAXF,maxp
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
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KOMTY = ’SET_M’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_M’
ANTKN = 3
ANTPK = 0
ANTLK = 2
ANTM1 = 2
MEDIE(1) = ANYGAS$
MEDIE(2) = ANYGAS$
MEDIE(3) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
RES(1) = P(1) − P(2)
RES(2) = ZC(1)−(X_J(MEDIE(1),H2$)−X_J(MEDIE(1),CO2$))/
$ (X_J(MEDIE(1),CO2$)+X_J(MEDIE(1),CO$))
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (X_J(MEDIE(1),CO$)+X_J(MEDIE(1),CO2$).LT.1D−3) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utility component for setting the M−factor for a syngas
$ used for production of a liquid fuel. The M−factor is defined
$ in the equations below. If the M−factor is 2 for methanol
$ production it means that all the syngas in theory can be
$ converted to methanol. The M−factor is defined as a control
$ variable (ZC).’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) =
$ ’M−factor: $ZC(1)=\\frac{y_{H_2}−y_{CO_2}}{y_{CO_2}+y_{CO}}$’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 \\\\
$y_{CO}+y_{CO_2} \\gt 0$’
KMEDDS(1) = ’Gas in’
KMEDDS(2) = ’Gas out’
KMEDDS(3) = ’M−factor’
K_INP=’struc set−M SET_M 611 612 900\\\\
$MEDIA 611 gas\\\\
$fluid gas N2 0.1 H2 0.6 CO 0.1 CO2 0.2\\\\
$addco m set−M 611 1 t set−M 611 50 p 611 1’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C
C=======================================================================
C***********************************************************************
SUBROUTINE GASCOOL4(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,ANTM2,MEDIE,
$ ANTME,VARME,ANTEL,VAREL,MDOT,P,H,Q,PAR,RES,X_J,ZA,ZANAM,ZC,
$ ANTEX,KOMDSC,K_PAR,K_lig,K_bet,KMEDDS,K_inp)
C***********************************************************************
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C
C GASCOOL1 is a model of a gas cooler with steam condensation.
C The model does not include equations concerning the heat exchange.
C 1−2 is the heat emitting fluid.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL T1,T2 Temperature in first and second node.
CL T3,T4 Temperature in third and fourth node.
CL S Entropy.
CL V Specific volume.
CL X Quality.
CL U Internal energy.
CL DPA,DPB Pressure loss in heat exchanger.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C
CP Programmer : Brian Elmegaard 2000
CP Dept. of Energy Eng., DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN, MEDIE(8), ANTPK, ANTEX,
& ANTM1, ANTM2, ANTME, VARME(4), ANTEL(4),
& VAREL(ANTST,4)
DOUBLE PRECISION RES(60), MDOT(6), P(6), H(6), Q, PAR(3),
& X_J(MAXME,ANTST),ZA(12),ZC(1)
CHARACTER*80 KOMTY,ZANAM(12)
C
C Local variables
C
INTEGER K_MED(6),I
DOUBLE PRECISION V, S, U,M_BL1,M_BL2, T1, T2, T3, T4, T5,T6, X,
: NIN,NOUT,NINST,NSTOUT,NCOND,PSTOUT,X0,HD,XSTOUT,H3,H4
$ ,X1,HPH,TPH,HSAT0,TPL,TPL1,TPH1,DTP,PMEOUT,XMEOUT,NCOND_MEOH
$ ,NINME,NMEOUT,HPH_min,NCONDST,NCONDME,XST,XME,N,E1,E2,Ntotal
$ ,HPHME,HPHST,PST,PME,HST,HME,HPH2,MPH,HSTV,HMEV,HPLST,HPLME
$ ,TPHST,TPHME,TPLST,TPLME,TPHME2,TPHST2,b_2_1,b_1_2,alpha,R_u
$ ,T_K,tau_2_1,tau_1_2,gamma_2,gamma_1,y_ME,y_ST,x_ME,x_ST,P_ME
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$ ,P_ST,T,P_SAT_ME,P_SAT_ST,x_ME_2,x_ME_3,x_ST_3,P_ME_IN,NOUTME
$ ,NOUTST,P_ST_IN,HPL,P_ST_2
CHARACTER*100 K_PAR(3),K_STAT(1)
CHARACTER*500 K_LIG(47), K_BET
CHARACTER*1000 KOMDSC, K_INP
CHARACTER*100 KMEDDS(7)
logical EVAP,EVAPST,EVAPME
EXTERNAL STATES
INCLUDE ’THERPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200,1) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’GASCOOL4’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’GASCOOL4’
ANTKN = 7
ANTPK = 3
ANTLK = 44
ANTEX = 9
ANTM1 = 4
ANTM2 = 2
MEDIE(1) = ANYGAS$
MEDIE(2) = ANYGAS$
MEDIE(3) = WATHF$
MEDIE(4) = MEOH$
MEDIE(5) = ANYFLU$
MEDIE(6) = ANYFLU$
MEDIE(7) = CONTROL$
ANTME = 4
VARME(1) = NODE1$
VARME(2) = NODE2$
VARME(3) = NODE5$
VARME(4) = NODE5$
ANTEL(1) = 0
ANTEL(2) = 37
ANTEL(3) = 0
ANTEL(4) = 0
DO I=1,36
VAREL(I,2) = I
ENDDO
VAREL(37,2) = CH3OH$
ZANAM(1) = ’t−diff boil’
ZANAM(2) = ’t−diff cond’
ZANAM(3) = ’T−boil’
ZANAM(4) = ’T−condense’
ZANAM(5) = ’CH3OH mass−%’
ZANAM(6) = ’CH3OH vol−%’
ZANAM(7) = ’Transferred’
C
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
RES(1) = P(1) − P(2) − PAR(1)
c RES(2) = P(2) − P(3)
c RES(3) = P(2) − P(4)
RES(4) = P(5) − P(6) − PAR(2)
C
C Same temperature out
C
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(3),H3,T2,V,S,X,U,1,3,MEDIE(3))
CALL STATES(P(4),H4,T2,V,S,X,U,1,3,MEDIE(4))
C
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RES(5) = H3 − H(3)
RES(6) = H4 − H(4)
C
C Calculate mole flow in
C
M_BL1 = 0.D0
DO I=1,ANTST
M_BL1=M_BL1+X_J(MEDIE(1),I)*M_MOL(I)
ENDDO
NIN = MDOT(1)/M_BL1
NINST=NIN*X_J(MEDIE(1),7)
NINME=NIN*X_J(MEDIE(1),CH3OH$)
N=NIN−NINST−NINME
C
C Calculate mole flow out
C
M_BL2 = 0.D0
DO I=1,ANTST
M_BL2=M_BL2+X_J(MEDIE(2),I)*M_MOL(I)
ENDDO
NOUT = (−MDOT(2))/M_BL2
C
C Outlet composition of gas
C
DO I = 1,6
RES(I+6) = X_J(MEDIE(2),I)*NOUT − X_J(MEDIE(1),I)*NIN
ENDDO
DO I = 8,35
RES(I+5) = X_J(MEDIE(2),I)*NOUT − X_J(MEDIE(1),I)*NIN
ENDDO
C
RES(41)=1.0D0
DO I = 1,ANTST
RES(41) = RES(41)−X_J(MEDIE(2),I)
ENDDO
C
C Check for condensing water or methanol
C
b_2_1=−1062.945621D0
b_1_2=3538.709318D0
c J/mol
alpha=0.2994D0
R_u=8.314D0
c J/(mol*K)
c
T=ZA(4)
X0 = 0.D0
CALL STATES(P_SAT_ST,HD,T,V,S,X0,U,3,6,MEDIE(3))
X0 = 0.D0
CALL STATES(P_SAT_ME,HD,T,V,S,X0,U,3,6,MEDIE(4))
T_K=T+273.15D0
c
tau_2_1=b_2_1/(R_u*T_K)
tau_1_2=b_1_2/(R_u*T_K)
c
x_ME_3=ZA(8)
x_ST_3=1D0−x_ME_3
gamma_2=exp((x_ST_3**2*(tau_1_2*((exp(−(alpha
$ *tau_1_2))/(x_ME_3+x_ST_3*exp(−(alpha*tau_1_2))))
$ )**2+(tau_2_1*(exp(−(alpha*tau_2_1))/(x_ST_3+x_ME_3
$ *exp(−(alpha*tau_2_1)))**2)))))
gamma_1=exp((x_ME_3**2*(tau_2_1*((exp(−(alpha
$ *tau_2_1))/(x_ST_3+x_ME_3*exp(−(alpha*tau_2_1))))
$ )**2+(tau_1_2*(exp(−(alpha*tau_1_2))/(x_ME_3+x_ST_3
$ *exp(−(alpha*tau_1_2)))**2)))))
c
P_ST_IN=X_J(MEDIE(1),7)*P(1)
P_ME_IN=X_J(MEDIE(1),CH3OH$)*P(1)
c
P_ME=P_ME_IN*0.999d0
x_ME=P_ME/(gamma_2*P_SAT_ME)
x_ST=1D0−x_ME
P_ST_2=gamma_1*P_SAT_ST*x_ST
P_ST=(P_ME_IN−P_ME+P_ST_IN)−(P_ME_IN−P_ME)/x_ME
if (T.gt.239.1) then
RES(52)=T−238
else
RES(52)=P_ST−P_ST_2
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c
c
c
c
c
endif
RES(53)=x_ME−x_ME_3
if (T.gt.(T2)) then
X0 = 0.D0
CALL STATES(P_SAT_ST,HD,T2,V,S,X0,U,3,6,MEDIE(3))
X0 = 0.D0
CALL STATES(P_SAT_ME,HD,T2,V,S,X0,U,3,6,MEDIE(4))
T_K=T2+273.15D0
tau_2_1=b_2_1/(R_u*T_K)
tau_1_2=b_1_2/(R_u*T_K)
x_ME_3=ZA(6)
x_ST_3=1D0−x_ME_3
gamma_2=exp((x_ST_3**2*(tau_1_2*((exp(−(alpha
$ *tau_1_2))/(x_ME_3+x_ST_3*exp(−(alpha*tau_1_2))))
$ )**2+(tau_2_1*(exp(−(alpha*tau_2_1))/(x_ST_3+x_ME_3
$ *exp(−(alpha*tau_2_1)))**2)))))
gamma_1=exp((x_ME_3**2*(tau_2_1*((exp(−(alpha
$ *tau_2_1))/(x_ST_3+x_ME_3*exp(−(alpha*tau_2_1))))
$ )**2+(tau_1_2*(exp(−(alpha*tau_1_2))/(x_ME_3+x_ST_3
$ *exp(−(alpha*tau_1_2)))**2)))))
P_ME=gamma_2*P_SAT_ME*x_ME_3
x_ST=1D0−x_ME_3
P_ST=gamma_1*P_SAT_ST*x_ST
NOUTME=P_ME/P(2)*NOUT
NOUTST=P_ST/P(2)*NOUT
NCONDST=NINST−NOUTST
NCONDME=NINME−NOUTME
x_ME_2=NCONDME/(NCONDME+NCONDST)
RES(51)=x_ME_3−x_ME_2
RES(42) = MDOT(3) + NCONDST*M_MOL(7)
RES(43) = X_J(MEDIE(2),7) − P_ST/P(2)
RES(44) = MDOT(4) + NCONDME*M_MOL(CH3OH$)
RES(45) = X_J(MEDIE(2),CH3OH$) − P_ME/P(2)
RES(50) = MDOT(4)/(MDOT(4)+MDOT(3))−ZA(5)
else
RES(42) = MDOT(3)
RES(43) = X_J(MEDIE(2),7) − X_J(MEDIE(1),7)*NIN/NOUT
RES(44) = MDOT(4)
RES(45) = X_J(MEDIE(2),CH3OH$) − X_J(MEDIE(1),CH3OH$)*NIN/NOUT
RES(50) = 0−ZA(5)
RES(51) = ZA(6)−x_ME
endif
C
C −−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Pinch point analysis
C −−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C
C Check if pinch point is where water and methanol condenses
C
if (MDOT(3).lt.−1d−10) then
CALL STATES(P(1),HPH,T,V,S,X,U,1,3,MEDIE(1))
HPL=H(6)−(H(1)−HPH)*MDOT(1)/MDOT(5)
CALL STATES(P(6),HPL,TPL,V,S,X,U,1,2,MEDIE(6))
TPH=T
RES(47)=(TPH−TPL)−ZA(2)
else
TPH=99999
TPL=0
RES(47) = 0−ZA(2)
endif
C
C Check if pinch point is where the water starts evaporating
C (if the cold medium is water)
C
IF (MEDIE(5).GE.80) THEN
CALL STATES(P(5),H(5),T5,V,S,X0,U,1,2,MEDIE(5))
CALL STATES(P(6),H(6),T6,V,S,X1,U,1,2,MEDIE(6))
IF ((X1.GT.(1.D−12)).AND.(X0.LT.1.D−12)) THEN
X0 = 0.0D0
CALL STATES(P(5),HSAT0,TPL1,V,S,X0,U,1,6,MEDIE(5))
E1=MDOT(5)*(H(6)−HSAT0)
CALL STATES(P(1),HPH,TPL1+ZA(1),V,S,X,U,1,3,MEDIE(1))
if ((TPL1+ZA(1)).gt.T) then
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c
c
c
E2=(H(1)−HPH)*MDOT(1)
RES(46) = ZA(9)
else
X0 = 0.D0
CALL STATES(P_SAT_ST,HD,TPL1+ZA(1),V,S,X0,U,3,6,MEDIE(3))
X0 = 0.D0
CALL STATES(P_SAT_ME,HD,TPL1+ZA(1),V,S,X0,U,3,6,MEDIE(4))
T_K=TPL1+ZA(1)+273.15D0
tau_2_1=b_2_1/(R_u*T_K)
tau_1_2=b_1_2/(R_u*T_K)
x_ME_3=ZA(9)
x_ST_3=1D0−x_ME_3
gamma_2=exp((x_ST_3**2*(tau_1_2*((exp(−(alpha
$ *tau_1_2))/(x_ME_3+x_ST_3*exp(−(alpha*tau_1_2))))
$ )**2+(tau_2_1*(exp(−(alpha*tau_2_1))/(x_ST_3+x_ME_3
$ *exp(−(alpha*tau_2_1)))**2)))))
gamma_1=exp((x_ME_3**2*(tau_2_1*((exp(−(alpha
$ *tau_2_1))/(x_ST_3+x_ME_3*exp(−(alpha*tau_2_1))))
$ )**2+(tau_1_2*(exp(−(alpha*tau_1_2))/(x_ME_3+x_ST_3
$ *exp(−(alpha*tau_1_2)))**2)))))
P_ME=gamma_2*P_SAT_ME*x_ME_3
x_ST=1D0−x_ME_3
P_ST=gamma_1*P_SAT_ST*x_ST
NOUTME=P_ME/P(2)*NOUT
NOUTST=P_ST/P(2)*NOUT
NCONDST=NINST−NOUTST
NCONDME=NINME−NOUTME
x_ME_2=NCONDME/(NCONDME+NCONDST)
RES(46)=x_ME_3−x_ME_2
MPH=MDOT(1)−NCONDST*M_MOL(7)−NCONDME*M_MOL(CH3OH$)
CALL STATES(P(3),HST,TPL1+ZA(1),V,S,X0,U,1,3,MEDIE(3))
CALL STATES(P(4),HME,TPL1+ZA(1),V,S,X0,U,1,3,MEDIE(4))
CALL ENTHALPY(7,TPL1+ZA(1),HSTV)
CALL ENTHALPY(CH3OH$,TPL1+ZA(1),HMEV)
HPH=(HPH*MDOT(1)−HSTV*NCONDST*M_MOL(7)−HMEV*NCONDME
$ *M_MOL(CH3OH$))/MPH
E2=H(1)*MDOT(1)−(HPH*MPH+HST*NCONDST*M_MOL(7)+HME
$ *NCONDME*M_MOL(CH3OH$))
endif
RES(48)=E2−E1
RES(2) = (TPL1+ZA(1)) − ZA(3)
if (ZA(1).lt.(TPH−TPL)) then
TPH=TPL1+ZA(1)
TPL=TPL1
endif
ELSE
RES(46) = ZA(9)
RES(48) = ZA(1)
RES(2) = ZA(3)
ENDIF
ELSE
RES(46) = ZA(9)
RES(48) = ZA(1)
RES(2) = ZA(3)
ENDIF
C
C Check if pinch point is at the beginning or the end of the component
C
CALL STATES(P(1),H(1),T1,V,S,X,U,1,2,MEDIE(1))
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(5),H(5),T5,V,S,X,U,1,2,MEDIE(5))
CALL STATES(P(6),H(6),T6,V,S,X,U,1,2,MEDIE(6))
C
if (((T2−T5).lt.(TPH−TPL)).or.((T1−T6).lt.(TPH−TPL))) then
IF ((T1−T6).LT.(T2−T5)) THEN
TPH = T1
TPL = T6
ELSE
TPH = T2
TPL = T5
ENDIF
ENDIF
C
C At the pinch point DTP is used
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C
RES(49) = TPH − TPL − ZC(1)
C
RES(3) = ZA(7) − MDOT(5)*(H(6)−H(5))
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
CALL STATES(P(1),H(1),T1,V,S,X,U,1,2,MEDIE(1))
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(5),H(5),T5,V,S,X,U,1,2,MEDIE(5))
CALL STATES(P(6),H(6),T6,V,S,X,U,1,2,MEDIE(6))
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).GT.1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
IF (MDOT(5).LT.−1D−10) GOTO 550
IF (MDOT(6).GT.1D−10) GOTO 550
IF (T1−T2.LT.−1.D−10) GOTO 550
IF (T1−T6.LT.−1.D−10) GOTO 550
IF (T6−T5.LT.−1.D−10) GOTO 550
IF (T2−T5.LT.−1.D−10) GOTO 550
IF (T.GT.T1) GOTO 550
IF (ZC(1).LT.PAR(3)−1D−2) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Gas cooler with outlet for condensed water and
$ methanol. The pinch point temperature is set as a parameter.
$ The component checks if the pinch point is at the inlet or
$ outlet − or where the condensation starts. If the cooling
$ medium evaporates the component also checks if the pinch
$ point is where the evaporation starts.’
K_PAR(1) = ’Pressure loss side 1: $\\Delta p$ [bar]’
K_PAR(2) = ’Pressure loss side 2: $\\Delta p$ [bar]’
K_PAR(3) = ’Minimum pinch point temperature diffence’
K_BET = ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\
$\\dot{m}_3 \\lt 0 \\\\ \\dot{m}_4 \\lt 0 \\\\ \\dot{m}_5 \\gt 0
$\\\\ \\dot{m}_6 \\lt 0 \\\\ T_1 \\gt T_2 \\\\ T_1 \\gt T_6 \\\\ T_
$2 \\gt T_5 \\\\ T_6 \\gt T_5 \\\\ T_1 \\gt T_{condensation} \\\\$
$node 7 $\\gt$ Parameter 3’
KMEDDS(1) = ’Hot gas inlet’
KMEDDS(2) = ’Hot gas outlet’
KMEDDS(3) = ’Water condensate outlet’
KMEDDS(4) = ’Methanol condensate outlet’
KMEDDS(5) = ’Coolant inlet’
KMEDDS(6) = ’Coolant outlet’
KMEDDS(7) = ’Pinch point temperature diffence’
K_INP=’STRUC Cooler GASCOOL4 3 5 6 7 10 11 901 0 0 10\\\\
$MEDIA 10 STEAM 5 Coolgas 3 FG\\\\
$FLUID FG H2 0.4844 CO2 0.2815 7 0.10 CH3OH 0.10 N2 0.0341\\\\
$addco p 3 144 t Cooler 3 410 m Cooler 3 22.1\\\\
$addco P 10 400 t Cooler 5 109 t Cooler 11 300\\\\
$addco ZC 901 10\\\\
$START M Cooler 5 −16 M Cooler 6 −1.9 M Cooler 10 19\\\\
$START t Cooler 6 109 t Cooler 10 50\\\\
$START ZA Cooler 4 207\\\\
$START Y_J Coolgas H2 0.59 Y_J Coolgas N2 0.04 Y_J Coolgas CO2 0.34
$’
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE MIXING_TANK(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,
& ANTM2,MEDIE,ANTME,VARME,
& MDOT,P,H,Q,ZA,PAR,RES,PARNAM,ZANAM,
$ KOMDSC,KMEDDS,K_PAR,K_LIG,K_STAT,K_BET,k_inp)
C***********************************************************************
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C
C HEATEX_1 is a model of a heat exchanger.
C The model does not include equations concerning the heat exchange.
C 1−2 is the heat emitting fluid.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL T1,T2 Temperature in first and second node.
CL T3,T4 Temperature in third and fourth node.
CL S Entropy.
CL V Specific volume.
CL X Quality.
CL U Internal energy.
CL DPA,DPB Pressure loss in heat exchanger.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C STATES
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’REALPROP.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(5), ANTPK,
& ANTM1, ANTM2, ANTME, VARME(4)
DOUBLE PRECISION RES(5), MDOT(4), P(4), H(4), PAR(2), Q,ZA(2)
CHARACTER*80 KOMTY,PARNAM(2),ZANAM(2)
C
C Local variables
C
INTEGER K_MED(5)
DOUBLE PRECISION T1, T2, T3, T4, V, X, S, U, DPA, DPB
CHARACTER*100 K_PAR(2),K_STAT(1)
CHARACTER*500 K_LIG(3), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(5)
EXTERNAL STATES
INCLUDE ’REALPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’MIXING_TANK’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’MIXING_TANK’
ANTKN = 5
ANTPK = 2
ANTLK = 3
ANTEX = 2
ANTM1 = 2
ANTM2 = 2
MEDIE(1) = REALFL$
MEDIE(2) = REALFL$
MEDIE(3) = REALFL$
MEDIE(4) = REALFL$
MEDIE(5) = HEAT$
ANTME = 4
VARME(1) = NODE1$
VARME(2) = NODE1$
VARME(3) = NODE3$
VARME(4) = NODE3$
PARNAM(1) = ’Pressure loss side 1’
PARNAM(2) = ’Pressure loss side 2’
ZANAM(1) = ’Flu 2 mass−%’
ZANAM(2) = ’Flu 2 vol−%’
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
DPA = PAR(1)
DPB = PAR(2)
C
C Pressure losses
C
RES(1) = P(1) − P(2) − DPA
RES(2) = P(3) − P(4) − DPB
C
CALL STATES(P(2),H(2),T2,V,S,X,U,1,2,MEDIE(2))
CALL STATES(P(4),H(4),T4,V,S,X,U,1,2,MEDIE(4))
RES(3) = T2−T4
C
RES(4) = ZA(1) − MDOT(3)/(MDOT(3)+MDOT(1))
RES(5) = ZA(2) − (MDOT(3)/RM_MOL(MEDIE(3)))/(MDOT(3)
$ /RM_MOL(MEDIE(3))+MDOT(1)/RM_MOL(MEDIE(1)))
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).LT.−1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
IF (Q.GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Heat exchanger used as a model for a mixing tank. This
$ means that the outlet temperatures are set equal.’
K_PAR(1) = ’Pressure loss side 1, $\\Delta p_{12}$ [bar]’
K_PAR(2) = ’Pressure loss side 2, $\\Delta p_{34}$ [bar]’
K_BET =
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$ ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\ \\dot{m}_3
$\\gt 0 \\\\ \\dot{m}_4 \\lt 0 \\\\ \\dot{Q} \\lt 0$’
KMEDDS(1) = ’Fluid 1 inlet’
KMEDDS(2) = ’Fluid 1 outlet’
KMEDDS(3) = ’Fluid 2 inlet’
KMEDDS(4) = ’Fluid 2 outlet’
KMEDDS(5) = ’Heat loss’
K_INP= ’struc Water−meoh−t MIXING_TANK 623 624 633 634 330 0 0
$\\\\media 623 STEAM−HF 633 METHANOL\\\\
$addco q Water−meoh−t 330 0\\\\
$addco t Water−meoh−t 623 90 t Water−meoh−t 633 40\\\\
$addco p 623 1 p 633 1\\\\
$addco m Water−meoh−t 623 1 m Water−meoh−t 633 1\\\\
$start t Water−meoh−t 624 60’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE DISTILLATION_STAGE(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,
& ANTM2,MEDIE,ANTME,VARME,
& MDOT,P,H,Q,ZA,ZC,PAR,RES,PARNAM,ZANAM,
$ KOMDSC,KMEDDS,K_PAR,K_LIG,K_STAT,K_BET,k_inp)
C***********************************************************************
C
C HEATEX_1 is a model of a heat exchanger.
C The model does not include equations concerning the heat exchange.
C 1−2 is the heat emitting fluid.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL T1,T2 Temperature in first and second node.
CL T3,T4 Temperature in third and fourth node.
CL S Entropy.
CL V Specific volume.
CL X Quality.
CL U Internal energy.
CL DPA,DPB Pressure loss in heat exchanger.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C STATES
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
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C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’REALPROP.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(13), ANTPK,
& ANTM1, ANTM2, ANTME, VARME(8)
DOUBLE PRECISION RES(25), MDOT(8), P(8), H(8), PAR(2), Q,ZA(3)
$ ,ZC(4)
CHARACTER*80 KOMTY,PARNAM(2),ZANAM(3),ZCNAM(4)
C
C Local variables
C
INTEGER K_MED(5),I,I_liq,I_vap
DOUBLE PRECISION T, V, X, S, U,P_sat(8),H_sat(8),x_1,x_2,X0,X1
$ ,M_MOL1,M_MOL2,y_1,y_2,P_system,R_u,alpha,tau_1_2,tau_2_1
$ ,b_1_2,b_2_1,gamma_1,gamma_2,y_1_new,y_2_new,T_K,P_sat_1
$ ,P_sat_2,a_2_1,K_1,K_2
CHARACTER*100 K_PAR(2),K_STAT(1)
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*500 K_LIG(3), K_BET
CHARACTER*100 KMEDDS(13)
EXTERNAL STATES
INCLUDE ’REALPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’DISTILLATION_STAGE’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’DISTILLATION_STAGE’
ANTKN = 13
ANTPK = 0
ANTLK = 12
ANTEX = 3
ANTM1 = 4
ANTM2 = 4
MEDIE(1) = WATHF$
MEDIE(2) = WATHF$
MEDIE(3) = WATHF$
MEDIE(4) = WATHF$
MEDIE(5) = MEOH$
MEDIE(6) = MEOH$
MEDIE(7) = MEOH$
MEDIE(8) = MEOH$
MEDIE(9) = HEAT$
MEDIE(10) = 999
MEDIE(11) = 999
MEDIE(12) = 999
MEDIE(13) = 999
ANTME = 0
ZANAM(1) = ’x_Methanol’
ZANAM(2) = ’y_Methanol’
ZANAM(3) = ’alpha’
ZCNAM(1) = ’Pressure’
ZCNAM(2) = ’Temperature’
ZCNAM(3) = ’x_Methanol’
ZCNAM(4) = ’y_Methanol’
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
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c 1 = Water
c 2 = Methanol
c
c Constants
c
M_MOL1=RM_MOL(MEDIE(1))
M_MOL2=RM_MOL(MEDIE(5))
b_2_1=−1062.945621D0
b_1_2=3538.709318D0
c J/mol
alpha=0.2994D0
R_u=8.314D0
c J/(mol*K)
P_system=ZC(1)
c
c Boling temperature of stage mixture
c
T=ZC(2)
c CALL STATES(P(4),H(4),T,V,S,X,U,1,2,MEDIE(4))
X0=0.D0
X1=1.D0
CALL STATES(P_sat(2),H_sat(2),T,V,S,X0,U,3,6,MEDIE(2))
CALL STATES(P_sat(4),H_sat(4),T,V,S,X1,U,3,6,MEDIE(4))
X0=0.D0
X1=1.D0
CALL STATES(P_sat(6),H_sat(6),T,V,S,X0,U,3,6,MEDIE(6))
CALL STATES(P_sat(8),H_sat(8),T,V,S,X1,U,3,6,MEDIE(8))
c
RES(1)=P(2)−P_sat(2)
RES(2)=P(4)−P_sat(4)
RES(3)=P(6)−P_sat(6)
RES(4)=P(8)−P_sat(8)
RES(5)=H(2)−H_sat(2)
RES(6)=H(4)−H_sat(4)
RES(7)=H(6)−H_sat(6)
RES(8)=H(8)−H_sat(8)
c
c x_1,x_2,y_1 and y_2 is molar fractions in respectively liquid and
c gas phase.
c
x_2=(MDOT(6)/M_MOL2)/(MDOT(2)/M_MOL1+MDOT(6)/M_MOL2)
x_1=1−x_2
y_2=(MDOT(8)/M_MOL2)/(MDOT(4)/M_MOL1+MDOT(8)/M_MOL2)
y_1=1−y_2
c
K_1=y_1/x_1
K_2=y_2/x_2
a_2_1=K_2/K_1
c
c Calculation of y_1_new and y_2_new
c
T_K=T+273.15D0
tau_2_1=b_2_1/(R_u*T_K)
tau_1_2=b_1_2/(R_u*T_K)
gamma_2=exp((x_1**2*(tau_1_2*((exp(−(alpha
$ *tau_1_2))/(x_2+x_1*exp(−(alpha*tau_1_2))))
$ )**2+(tau_2_1*(exp(−(alpha*tau_2_1))/(x_1+x_2
$ *exp(−(alpha*tau_2_1)))**2)))))
gamma_1=exp((x_2**2*(tau_2_1*((exp(−(alpha
$ *tau_2_1))/(x_1+x_2*exp(−(alpha*tau_2_1))))
$ )**2+(tau_1_2*(exp(−(alpha*tau_1_2))/(x_2+x_1
$ *exp(−(alpha*tau_1_2)))**2)))))
c
P_sat_1=P_sat(4)
P_sat_2=P_sat(8)
c
y_2_new=gamma_2*P_sat_2*x_2/P_system
y_1_new=gamma_1*P_sat_1*x_1/P_system
C
RES(9)=y_2−y_2_new
RES(10)=y_1−y_1_new
c
RES(11)=x_2−ZA(1)
RES(12)=y_2−ZA(2)
RES(13)=a_2_1−ZA(3)
RES(14)=x_2−ZC(3)
RES(15)=y_2−ZC(4)
c
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IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).LT.−1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
IF (MDOT(5).LT.−1D−10) GOTO 550
IF (MDOT(6).GT.1D−10) GOTO 550
IF (MDOT(7).LT.−1D−10) GOTO 550
IF (MDOT(8).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Distillation stage for a distillation column. A column
$ can consist of several stages in series. The distillation
$ stage calculates VLE (vapor liquid equilibrium) between water
$ and methanol. The component can be used for distillation of
$ other media by changing 3 constants in the source code. The
$ method is NRTL (Non Random Two Liquid). Can only be used with
$ real fluids. The pressure is assigned in node 10 − not in the
$ seperate nodes’
K_BET =’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\
$\\dot{m}_3 \\gt 0 \\\\ \\dot{m}_4 \\lt 0 \\\\ \\dot{m}_5 \\gt 0 \\
$\\ \\dot{m}_6 \\lt 0 \\\\ \\dot{m}_7 \\gt 0 \\\\ \\dot{m}_8 \\lt 0
$$’
KMEDDS(1) = ’Liquid water inlet’
KMEDDS(2) = ’Liquid water outlet’
KMEDDS(3) = ’Water vapor inlet’
KMEDDS(4) = ’Water vapor outlet’
KMEDDS(5) = ’Liquid methanol inlet’
KMEDDS(6) = ’Liquid methanol outlet’
KMEDDS(7) = ’Methanol vapor inlet’
KMEDDS(8) = ’Methanol vapor outlet’
KMEDDS(9) = ’Heat’
KMEDDS(10) = ’Pressure in system’
KMEDDS(11) = ’Temperature of system’
KMEDDS(12) = ’Molar fraction of methanol in the liquid phase’
KMEDDS(13) = ’Molar fraction of methanol in the gas phase’
K_INP= ’struc Dis_stage_1 DISTILLATION_STAGE 701 707 705 703 702
$708 /\\\\ 706 704 343 906 907 908 909 0 0\\\\
$addco q Dis_stage_1 343 0 ZC 906 1\\\\
$addco tsat 701 80 x Dis_stage_1 701 0 m Dis_stage_1 701 1\\\\
$addco tsat 705 70 x Dis_stage_1 705 1 m Dis_stage_1 705 1\\\\
$addco tsat 702 80 x Dis_stage_1 702 0 m Dis_stage_1 702 1\\\\
$addco tsat 706 70 x Dis_stage_1 706 1 m Dis_stage_1 706 1\\\\
$start m Dis_stage_1 707 −1 m Dis_stage_1 708 −1\\\\
$start x Dis_stage_1 708 0 x Dis_stage_1 703 1 x Dis_stage_1 704 1
$\\\\START ZC 907 83’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE EL_MOTOR(KOMTY,ANTLK,ANTKN,ANTPK,
& MEDIE,PAR,Q,E,WK,
& RES,komdsc,k_par,kmedds,k_lig,k_bet,k_inp)
C***********************************************************************
C
C EL−MOTOR is a component that converts electrical power to mechanical
C power and a heat loss. The efficiency is a parameter to the component.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
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CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN,ANTPK, MEDIE(3)
DOUBLE PRECISION RES(1), PAR(1),Q,E,WK
CHARACTER*80 KOMTY
C
C Local variables
C
DOUBLE PRECISION virk
CHARACTER*100 K_PAR(1)
CHARACTER*500 K_LIG(1), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’EL−MOTOR’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’EL−MOTOR’
ANTKN = 3
ANTPK = 1
ANTLK = 1
MEDIE(1) = power$
MEDIE(2) = HEAT$
MEDIE(3) = SHAFT$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
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C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
Virk = PAR(1)
RES(1) = WK/E + virk
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (E.LT.−1D−10) GOTO 450
IF (WK.GT.1D−10) GOTO 450
GOTO 9999
450 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Motor with efficiency.’
K_PAR(1) = ’Motor efficiency, $\\eta_{m}$ [−]’
K_LIG(1) = ’Motor efficiency:
$$\\eta_m=\\frac{\\dot{W}}{\\dot{E}}$’
K_BET = ’$\\dot{E}\\gt 0 \\\\ \\dot{W} \\lt 0 \\\\
$\\dot{Q} \\lt 0 $’
KMEDDS(1) = ’Power in’
KMEDDS(2) = ’Heat loss’
KMEDDS(3) = ’Shaft power’
k_inp=’struc El−motor EL−MOTOR 203 319 101 0.95\\\\
$addco e El−motor 203 100\\\\
$start q El−motor 319 −1’
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE SPLITTER2(KOMTY,ANTLK,ANTKN,ANTM1,MEDIE,ANTME,
$ VARME,MDOT,P,H,RES,MMVAR,komdsc,kmedds,k_lig,k_bet,
$ k_inp)
C***********************************************************************
C
C SPLITTER2 is splitting one mass flow in to a variable number of
C flows. The outlets have the same enthalpy. Only the pressure in node
C 2 is set. This is done so the seperated flows can be mixed again
C (gathered in one node) without having pressure seperaters (like compressors).
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA KOMTY − OUTPUT − Component name.
CA ANTLK − OUTPUT − Number of equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
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CL K_MED Media description.
C
C Subroutines : COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN, MEDIE(30),
& ANTM1, ANTME, VARME(30), MMVAR(MAXMM)
DOUBLE PRECISION RES(30), H(30), MDOT(30), P(30)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER I,M_nr,RES_nr
DOUBLE PRECISION M
CHARACTER*100 K_PAR(1)
CHARACTER*500 K_LIG(3), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(4)
EXTERNAL COMINF
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SPLITTER2’
MMVAR(1) = 10
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SPLITTER2’
ANTKN = MMVAR(1)
ANTLK = MMVAR(1)−1
ANTM1 = MMVAR(1)
DO I=1,MMVAR(1)
MEDIE(I) = ANYFLU$
ENDDO
ANTME = MMVAR(1)
DO I=1,ANTME
VARME(I) = NODE1$
ENDDO
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
C Pressure balance
C
RES(1) = P(1) − P(2)
C
C Same enthalpies on the outlets
C
M=0D0
DO I=2,ANTKN
if (MDOT(I).lt.M) then
M_nr=I
M=MDOT(I)
endif
ENDDO
C
RES_nr=2
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C
DO I=2,ANTKN
if (I.ne.M_nr) then
RES(RES_nr) = H(1) − H(I)
RES_nr=RES_nr+1
endif
ENDDO
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
C
IF (MDOT(1).LT.−1D−10) GOTO 550
DO I=1,ANTKN−1
IF (MDOT(I+1).GT.1D−10) GOTO 550
ENDDO
IF (abs(H(M_nr)−H(1)).GT.1D−1) GOTO 550
C
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Flow splitter − variable number of outlets
$ for splitting up and later re−uniting the massflow − this
$ means that only the pressure in node 2 is set.This
$ documentation is for 3 outlets.’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) = ’Equal enthalpy of outlets: $h_1 = h_2$’
K_LIG(3) = ’Equal enthalpy of outlets: $h_1 = h_3$’
K_BET = ’$\\dot{m}_1\\gt 0 \\\\ \\dot{m}_2\\lt 0
$\\\\ \\dot{m}_3\\lt 0 \\\\ \\dot{m}_4\\lt 0$’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Fluid out’
KMEDDS(4) = ’Fluid out’
k_inp= ’struc split splitter2 4 1 2 3 4\\\\
$media 1 SIMPLE_AIR\\\\
$addco m split 1 10 t split 1 50 p 1 1\\\\
$addco m split 2 −3 m split 3 −3\\\\
$addco p 3 1 p 4 1\\\\
$start t split 2 50 t split 3 50’
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE SPLITTER3(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,PAR,MDOT,P,H,RES,komdsc,k_par,kmedds,k_lig,k_bet,k_inp
$ )
C***********************************************************************
C
C SPLITTER is splitting one mass flow in two. The two outlets have the
C same enthalpy.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA KOMTY − OUTPUT − Component name.
CA ANTLK − OUTPUT − Number of equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
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CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN,ANTPK, MEDIE(3),
& ANTM1, ANTME, VARME(3)
DOUBLE PRECISION RES(4), H(3), MDOT(3), P(3),PAR(1)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3),I
CHARACTER*100 K_PAR(1),K_STAT(1)
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*500 K_LIG(3), K_BET
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SPLITTER3’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SPLITTER3’
ANTKN = 3
ANTPK = 1
ANTLK = 4
ANTM1 = 3
MEDIE(1) = ANYFLU$
MEDIE(2) = ANYFLU$
MEDIE(3) = ANYFLU$
ANTME = 3
DO I=1,ANTME
VARME(I) = NODE1$
ENDDO
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
C Same enthalpies on the two outlets
C
RES(1) = H(1) − H(3)
C
C Pressure balance
C
RES(2) = P(1) − P(2)
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RES(3) = P(1) − P(3)
RES(4) = MDOT(1)*PAR(1) + MDOT(2)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Flow splitter. The distribution of the inlet massflow
$ between the outlets is set by the parameter.’
K_PAR(1) = ’Fraction: $\\frac{−\\dot{m_2}}{\\dot{m_1}}$’
K_LIG(1) = ’Equal enthalpy of outlets: $h_2 = h_3$’
K_LIG(2) = ’Equal pressures: $p_1 = p_2$’
K_LIG(3) = ’Equal pressures: $p_1 = p_3$’
K_BET =
$ ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\ \\dot{m}_3
$\\lt 0 $’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Fluid out’
k_inp= ’struc split splitter3 1 2 3 0.4\\\\
$media 1 SIMPLE_AIR\\\\
$addco m split 1 10 t split 1 50 p 1 1\\\\
$START M split 2 −4 t split 2 50’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C
C=======================================================================
C**********************************************************************
SUBROUTINE MIXER_03(KOMTY,ANTLK,ANTKN,ANTM1, MEDIE,ANTME,VARME
$ ,ANTEL, VAREL,MDOT,P,RES,X_J,komdsc,k_lig,k_bet,kmedds,k_inp
$ ,MMVAR)
C**********************************************************************
C
C MIXER_01 mixes two gasses. Same pressure in all nodes.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA X_J − INPUT − Fluid composition.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters for the component.
CA ANTLK − OUTPUT − Number of equations in the component.
CA ANTEX − OUTPUT − Number of independent equations in the component.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean :
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CA −4 : Any gas
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA VARME − OUTPUT − Pointer to fluid numbers (with variable composition).
CA ANTEL − OUTPUT − Number of computed compounds in these variable fluids.
CA VAREL − OUTPUT − Compound numbers in variable fluids.
CA RES − OUTPUT − Residuals for the component.
C
CL XMIX Composition of the mixture.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
C
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K_MED Media description.
C
C Subroutines : COMINF
C MIXER
C
CP Programmer : Bent Lorentzen 1994 (Niels Emsholm 1991)
CP Lab. for Energetics, DTH, Denmark.
C***********************************************************************
C
C Including the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’THERPROP.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN, MEDIE(10),
: ANTM1, ANTME, VARME(1), ANTEL(1),
: VAREL(ANTST,1),MMVAR(MAXMM)
DOUBLE PRECISION X_J(MAXME,ANTST), RES(60), MDOT(10), P(10)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER I,J,MAXKN
DOUBLE PRECISION XMIX(ANTST),T_SUM,M_BL(10),N(ANTST,10)
$ ,N_total(ANTST)
CHARACTER*500 K_LIG(40), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF,MIXER
INCLUDE ’THERPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’MIXER_03’
MMVAR(1) = 10
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’MIXER_03’
ANTKN = MMVAR(1)
ANTLK = MMVAR(1)+37
ANTM1 = MMVAR(1)
DO I=1,MMVAR(1)
MEDIE(I) = ANYGAS$
ENDDO
ANTME = 1
VARME(1) = −MMVAR(1)
ANTEL(1) = 38
DO I=1,36
VAREL(I,1) = I
ENDDO
VAREL(37,1) = 38
VAREL(38,1) = 39
IF (FKOMP.EQ.6) GOTO 600
*** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws, since these are treated
C automatically by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
DO J=1, ANTKN−1
M_BL(J) = 0.D0
ENDDO
DO J=1, ANTKN−1
DO I=1, ANTST
M_BL(J) = M_BL(J) + X_J(MEDIE(J),I)*M_MOL(I)
N_total(I)=0
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C
ENDDO
ENDDO
T_SUM = 0D0
DO J=1, ANTKN−1
DO I=1, ANTST
N(I,J) = X_J(MEDIE(J),I)*MDOT(J)/M_BL(J)
N_total(I)=N_total(I)+N(I,J)
T_SUM = T_SUM + N(I,J)
ENDDO
ENDDO
C
C Find mole ratios in mixture
C
DO I=1, ANTST
XMIX(I) = N_total(I)/T_SUM
ENDDO
C
C Pressure balance
C
DO J=1, ANTKN−1
RES(J) = P(1) − P(J+1)
ENDDO
C
C Variable mole ratios
C
DO I=1,36
RES(ANTKN−1+I) = X_J(MEDIE(ANTKN),I) − XMIX(I)
ENDDO
RES(ANTKN+36) = X_J(MEDIE(ANTKN),38) − XMIX(38)
RES(ANTKN+37) = X_J(MEDIE(ANTKN),39) − XMIX(39)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
DO J=1, ANTKN−1
IF (MDOT(J).LT.−1D−10) GOTO 550
ENDDO
IF (MDOT(ANTKN).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Mixer for ideal gases with variable number of inlet
$ massflows. The documentation is for 2 inlets.’
K_BET =
$ ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\gt 0 \\\\
$\\dot{m}_3 \\lt 0$’
KMEDDS(1) = ’Gas in’
KMEDDS(2) = ’Gas in’
KMEDDS(3) = ’Gas mix out’
K_INP = ’struc mixer mixer_03 3 1 2 3\\\\
$media 1 SIMPLE_AIR 2 METHANE 3 mix\\\\
$addco m mixer 1 10 t mixer 1 110 p 1 1\\\\
$addco m mixer 2 1 t mixer 2 60\\\\
$START Y_J mix O2 0.17 Y_J mix N2 0.66 Y_J mix CH4 0.15’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE PRES_SEP(KOMTY,ANTLK,ANTKN,ANTM1,
& MEDIE,ANTME,VARME,
& MDOT,P,RES,komdsc,kmedds,k_lig,k_bet,k_inp)
C***********************************************************************
C
C ADDANODE is used when a component otherwise would get the same node
C connected to two different branches. This model puts on an extra
C mass, pressure, and energy balance so that an extra node is added.
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C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTED − OUTPUT − Number of differential independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA DYCOM − OUTPUT − Type of conservation equations (static or dynamic
CA mass and internal energy on side 1 and 2 respectively;
CA and dynamic solid internal energy).
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTKN, MEDIE(2),
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION RES(1), P(2), MDOT(2)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(2)
CHARACTER*100 K_PAR(1),K_STAT(1)
CHARACTER*500 K_LIG(1), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(2)
EXTERNAL COMINF
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’PRES_SEP’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’PRES_SEP’
ANTKN = 2
ANTLK = 0
ANTM1 = 2
MEDIE(1) = ANYFLU$
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MEDIE(2) = ANYFLU$
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
C Pressure balance
C
c RES(1) = P(1) − P(2)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 450
IF (MDOT(2).GT.1D−10) GOTO 450
GOTO 9999
450 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utility component for seperating nodes which both have
$ assigned the pressure. Can also be used as a throttle valve.’
K_BET = ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0$’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
k_INP=’struc dummy PRES_SEP 1 2\\\\
$media 1 STEAM\\\\
$addco m dummy 1 1 t dummy 1 50 p 1 1 p 2 1’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE SET_X(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,X_J,KOMDSC,K_PAR,K_lig,K_bet
$ ,KMEDDS,K_inp)
C***********************************************************************
C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
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CA MEDIE − IN/OUT − Media of the connected nodes.
CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(3), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(1),PAR(2)
$ ,X_J(MAXME,ANTST)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3),temp
DOUBLE PRECISION MAXF,maxp
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SET_X’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_X’
ANTKN = 3
ANTPK = 1
ANTLK = 2
ANTM1 = 2
MEDIE(1) = ANYGAS$
MEDIE(2) = ANYGAS$
MEDIE(3) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
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C
C
400 CONTINUE
temp=PAR(1)
RES(1) = P(1) − P(2)
RES(2) = X_J(MEDIE(1),temp)−ZC(1)
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utility component for setting the molar fraction of a
$ compund in a ideal gas mixture.’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 $’
K_PAR(1) = ’Compound number ($H_2$ is 1)’
KMEDDS(1) = ’Gas in’
KMEDDS(2) = ’Gas out’
KMEDDS(3) = ’Molar fraction of compound’
K_INP=’struc set−X_H2 SET_X 611 612 900 1\\\\
$MEDIA 611 gas\\\\
$fluid gas N2 0.6 H2 0.4\\\\
$addco m set−X_H2 611 1 t set−X_H2 611 50 p 611 1’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C
C=======================================================================
C***********************************************************************
SUBROUTINE SET_X_REALFLUID(KOMTY,ANTLK,ANTEX,ANTKN,ANTPK,ANTM1,
& ANTM2,MEDIE,ANTME,VARME,
& MDOT,P,H,Q,ZA,ZC,PAR,RES,PARNAM,ZANAM,
$ KOMDSC,KMEDDS,K_PAR,K_LIG,K_STAT,K_BET,k_inp)
C***********************************************************************
C
C HEATEX_1 is a model of a heat exchanger.
C The model does not include equations concerning the heat exchange.
C 1−2 is the heat emitting fluid.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA ANTM2 − OUTPUT − Number of massflows in the second.
CA MEDIE − IN/OUT − Media (fluid) of the connected nodes.
CA The values mean:
CA 99 : Water.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
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C
CL T1,T2 Temperature in first and second node.
CL T3,T4 Temperature in third and fourth node.
CL S Entropy.
CL V Specific volume.
CL X Quality.
CL U Internal energy.
CL DPA,DPB Pressure loss in heat exchanger.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C STATES
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
INCLUDE ’REALPROP.DEC’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(5), ANTPK,
& ANTM1, ANTM2, ANTME, VARME(4)
DOUBLE PRECISION RES(6),MDOT(4),P(4),H(4),PAR(2),Q,ZA(2),ZC(2)
CHARACTER*80 KOMTY,PARNAM(2),ZANAM(2)
C
C Local variables
C
INTEGER K_MED(5)
DOUBLE PRECISION T1, T2, T3, T4, V, X, S, U, DPA, DPB
CHARACTER*100 K_PAR(2),K_STAT(1)
CHARACTER*500 K_LIG(3), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(5)
EXTERNAL STATES
INCLUDE ’REALPROP.INI’
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SET_X_REALFLUID’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_X_REALFLUID’
ANTKN = 5
ANTPK = 2
ANTLK = 4
ANTEX = 2
ANTM1 = 2
ANTM2 = 2
MEDIE(1) = REALFL$
MEDIE(2) = REALFL$
MEDIE(3) = REALFL$
MEDIE(4) = REALFL$
MEDIE(5) = 999
ANTME = 4
VARME(1) = NODE1$
VARME(2) = NODE1$
VARME(3) = NODE3$
VARME(4) = NODE3$
PARNAM(1) = ’Pressure loss side 1’
PARNAM(2) = ’Pressure loss side 2’
ZANAM(1) = ’Flu 2 mass−%’
ZANAM(2) = ’Flu 2 vol−%’
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
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GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
DPA = PAR(1)
DPB = PAR(2)
C
C Pressure losses
C
RES(1) = P(1) − P(2) − DPA
RES(2) = P(3) − P(4) − DPB
C
RES(3) = ZA(1) − MDOT(3)/(MDOT(3)+MDOT(1))
RES(4) = ZA(2) − (MDOT(3)/RM_MOL(MEDIE(3)))/(MDOT(3)
$ /RM_MOL(MEDIE(3))+MDOT(1)/RM_MOL(MEDIE(1)))
RES(5) = ZA(2)−ZC(1)
C
RES(6) = H(1) − H(2)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
IF (MDOT(3).LT.−1D−10) GOTO 550
IF (MDOT(4).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utillity component for setting the molar fraction of
$ fluid 2 (fluid 1 and 2 are considered as a mixture).’
K_PAR(1) = ’Pressure loss side 1, $\\Delta p_{12}$ [bar]’
K_PAR(2) = ’Pressure loss side 2, $\\Delta p_{34}$ [bar]’
K_BET = ’$\\dot{m}_1 \\gt 0 \\\\ \\dot{m}_2 \\lt 0 \\\\
$\\dot{m}_3 \\gt 0 \\\\ \\dot{m}_4 \\lt 0 $’
KMEDDS(1) = ’Fluid 1 inlet’
KMEDDS(2) = ’Fluid 1 outlet’
KMEDDS(3) = ’Fluid 2 inlet’
KMEDDS(4) = ’Fluid 2 outlet’
KMEDDS(5) = ’molar fraction of fluid 2’
K_INP= ’struc set−x SET_X_REALFLUID 691 693 692 694 908 0 0\\\\
$MEDIA 691 STEAM−HF 692 METHANOL\\\\
$addco p 691 1 p 692 1\\\\
$addco m set−x 691 1 t set−x 691 80 t set−x 692 80\\\\
$addco ZC 908 0.36\\\\
$start t set−x 693 60 m set−x 692 1’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C=======================================================================
C***********************************************************************
SUBROUTINE MEASURE_FLOW(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,KOMDSC,KMEDDS,K_LIG,K_BET,k_inp)
C***********************************************************************
C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
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CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media of the connected nodes.
CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(3), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(1), PAR(2)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3)
DOUBLE PRECISION MAXF,maxp
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’MEASURE_FLOW’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’MEASURE_FLOW’
ANTKN = 3
ANTPK = 0
ANTLK = 2
ANTM1 = 2
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MEDIE(1) = ANYFLU$
MEDIE(2) = ANYFLU$
MEDIE(3) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
RES(1) = P(1) − P(2)
RES(2) = ZC(1) − MDOT(1)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utillity component for converting a massflow to a
$ control signal (ZC). Could be used with the component
$ SET_FLOW’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) = ’Massflow: $\\dot{m_1} = ZC(1)$’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 $’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Measured massflow’
K_INP=’struc meas_flow MEASURE_FLOW 635 636 990\\\\
$MEDIA 635 STEAM\\\\
$addco t meas_flow 635 50 m meas_flow 635 1 p 635 1’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C***********************************************************************
SUBROUTINE SET_FLOW(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,KOMDSC,K_PAR,K_lig,K_bet,KMEDDS
$ ,K_inp)
C***********************************************************************
C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
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CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media of the connected nodes.
CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(4), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(2), PAR(2)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3)
DOUBLE PRECISION MAXF,maxp
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(4)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SET_FLOW’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_FLOW’
ANTKN = 4
ANTPK = 0
ANTLK = 2
ANTM1 = 2
MEDIE(1) = ANYFLU$
MEDIE(2) = ANYFLU$
MEDIE(3) = 999
MEDIE(4) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
RES(1) = P(1) − P(2)
RES(2) = ZC(1)*ZC(2) − MDOT(1)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utillity component for setting the massflow based on 2
$ control signals (ZC) − typicly one control signal for a
$ measured massflow and the other a fraction. The component
$ MEASURE_FLOW can be used.’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) = ’Massflow: $\\dot{m_1} = ZC(1)*ZC(2)$’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 $’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Measured massflow’
KMEDDS(4) = ’Fraction’
K_INP=’STRUC Flow SET_FLOW 2 3 900 901\\\\
$MEDIA 2 STEAM\\\\
$addco t Flow 2 50 p 2 1 m Flow 2 10\\\\
$addco ZC 901 2\\\\
$START ZC 901 2’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C***********************************************************************
SUBROUTINE SET_TEMP(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,KOMDSC,K_PAR,K_lig,K_bet,KMEDDS
$ ,K_inp)
C***********************************************************************
C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media of the connected nodes.
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CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(4), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(2), PAR(2)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3)
DOUBLE PRECISION MAXF,maxp,T,V,S,X,U
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(4)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SET_TEMP’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_TEMP’
ANTKN = 3
ANTPK = 0
ANTLK = 2
ANTM1 = 2
MEDIE(1) = ANYFLU$
MEDIE(2) = ANYFLU$
MEDIE(3) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
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RES(1) = P(1) − P(2)
C
CALL STATES(P(1),H(1),T,V,S,X,U,1,2,MEDIE(1))
C
RES(2) = ZC(1) − T
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utillity component for setting or measuring the
$ temperature by use of a control signal (ZC).’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) = ’Temperature: T = ZC(1)’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 $’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Temperature’
K_INP=’struc set_temp SET_TEMP 1 2 900\\\\
$media 1 STEAM\\\\
$addco p 1 1 m set_temp 1 60 t set_temp 1 60’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C***********************************************************************
SUBROUTINE SET_TEMP2(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,KOMDSC,K_PAR,K_lig,K_bet,KMEDDS
$ ,K_inp)
C***********************************************************************
C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media of the connected nodes.
CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
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CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(4), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(2), PAR(2)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3)
DOUBLE PRECISION MAXF,maxp,T,V,S,X,U
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(4)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SET_TEMP2’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_TEMP2’
ANTKN = 4
ANTPK = 0
ANTLK = 2
ANTM1 = 2
MEDIE(1) = ANYFLU$
MEDIE(2) = ANYFLU$
MEDIE(3) = 999
MEDIE(4) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
RES(1) = P(1) − P(2)
C
CALL STATES(P(1),H(1),T,V,S,X,U,1,2,MEDIE(1))
C
RES(2) = ZC(1)+ZC(2) − T
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
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C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utillity component for setting the
$ temperature by use of 2 control signals (ZC).’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) = ’Temperature: T = ZC(1)+ZC(2)’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 $’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Temperature’
KMEDDS(4) = ’Temperature difference’
K_INP=’struc set_temp SET_TEMP2 1 2 900 901\\\\
$media 1 STEAM\\\\
$addco p 1 1 m set_temp 1 60\\\\
$addco ZC 900 50 ZC 901 −10\\\\
$start t set_temp 1 60’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C***********************************************************************
SUBROUTINE SET_PRES(KOMTY,ANTLK,ANTKN,ANTPK,ANTM1,MEDIE,ANTME
$ ,VARME,MDOT,P,H,ZC,PAR,RES,KOMDSC,KMEDDS,K_LIG,K_BET,k_inp)
C***********************************************************************
C
C SETFLOW1 is a model of a control valve. The valve controls massflow
C using an error input from a controller.
C
C***********************************************************************
C
CA FKOMP − INPUT − Flag with the value:
CA 1: Initialize the component.
CA 2: Initialize with actual system.
CA 3: Fluid composition calculation (constant).
CA 4: Find residuals.
CA 5: Find residuals and check variables.
CA 6: Output information about component.
CA MDOT − INPUT − Massflows from nodes.
CA P − INPUT − Pressure in nodes.
CA H − INPUT − Enthalpy of massflows.
CA ZC − INPUT − Control variables.
CA PAR − INPUT − Parameters of the component.
CA KOMTY − OUTPUT − Component name.
CA ANTPK − OUTPUT − Number of parameters.
CA ANTLK − OUTPUT − Number of equations.
CA ANTEX − OUTPUT − Number of algebraic independent equations.
CA ANTKN − OUTPUT − Number of nodes connected to the component.
CA ANTM1 − OUTPUT − Number of massflows in the first conservation of
CA mass equation.
CA MEDIE − IN/OUT − Media of the connected nodes.
CA The values mean:
CA 99 : Water.
CA 999 : Control.
CA ANTME − OUTPUT − Number of fluids with variable composition.
CA RES − OUTPUT − Residuals for the component.
C
CL CV Valve friction coefficient.
CL V1 Specific volume for water entering the valve.
CL T Temperature.
CL S Entropy.
CL X Quality.
CL U Internal energy.
CL K_PAR Parameter description.
CL K_LIG Equation description.
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CL K_BET Condition description.
CL K_MED Media description.
C
C Subroutines : STATES
C COMINF
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTU, Denmark.
C***********************************************************************
C
C Include the common "environment"
C
INCLUDE ’ENVIRO.INI’
C
C Parameter variables
C
INTEGER ANTLK, ANTEX, ANTKN, MEDIE(3), ANTPK,
& ANTM1, ANTME, VARME(2)
DOUBLE PRECISION MDOT(2), P(2), H(2), RES(3), ZC(1), PAR(2)
CHARACTER*80 KOMTY
C
C Local variables
C
INTEGER K_MED(3)
DOUBLE PRECISION MAXF,maxp
CHARACTER*100 K_PAR(1),K_STAT(2)
CHARACTER*500 K_LIG(2), K_BET
CHARACTER*1000 KOMDSC,K_INP
CHARACTER*100 KMEDDS(3)
EXTERNAL COMINF,STATES
C=======================================================================
GOTO (100,200,1,400,400,200) FKOMP
1 RETURN
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component name
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
100 CONTINUE
KOMTY = ’SET_PRES’
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component characteristics
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
200 CONTINUE
KOMTY = ’SET_PRES’
ANTKN = 3
ANTPK = 0
ANTLK = 2
ANTM1 = 2
MEDIE(1) = ANYFLU$
MEDIE(2) = ANYFLU$
MEDIE(3) = 999
ANTME = 2
VARME(1) = NODE1$
VARME(2) = NODE1$
IF (FKOMP.EQ.6) GOTO 600
** FKOMP = 3
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Component equations. All in residual form.
C Do not include the conservation laws. These are treated automatically
C by DNA.
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
400 CONTINUE
C
RES(1) = P(1) − P(2)
RES(2) = ZC(1) − P(1)
C
IF (FKOMP.EQ.5) GOTO 500
GOTO 9999
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Solution check
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
500 CONTINUE
IF (MDOT(1).LT.−1D−10) GOTO 550
IF (MDOT(2).GT.1D−10) GOTO 550
GOTO 9999
550 FBETI = .FALSE.
GOTO 9999
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c:/dna/source/
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Write component information
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
600 CONTINUE
KOMDSC = ’Utillity component for converting the pressure to a
$ control signal (ZC). The component can therefore be used for
$ measuring or setting the pressure’
K_LIG(1) = ’Equal pressures: $p_1 = p_2$’
K_LIG(2) = ’Pressure: $p_1 = ZC(1)$’
K_BET = ’$\\dot{m_1} \\gt 0 \\\\ \\dot{m_2} \\lt 0 $’
KMEDDS(1) = ’Fluid in’
KMEDDS(2) = ’Fluid out’
KMEDDS(3) = ’Pressure’
K_INP=’struc set−pres SET_PRES 635 636 990\\\\
$MEDIA 635 STEAM\\\\
$addco t set−pres 635 50 m set−pres 635 1 p 635 1’
C
GOTO 9999
C
9999 CONTINUE
RETURN
END
C***********************************************************************
SUBROUTINE ENTHALPY(J,T,H)
C***********************************************************************
C
C GIBBS finds Gibbs energy at pressure PRES and tempera−
C ture T. The calculation is based on values for enthalpy and entropy.
C
C***********************************************************************
C
CA J − INPUT − For which compound should Gibbs energy be found.
CA TEMP − INPUT − Temperature used finding Gibbs energy.
CA PRES − INPUT − Pressure
CA G − OUTPUT − Gibbs energy.
C
CL T0 Reference temperature (25 C).
CL T Temperature [K].
CL H_MOL Enthalpy [J/mol].
CL S_MOL Entropy [J/(mol K)].
C
CP Programmer : Bent Lorentzen 1994
CP Lab. for Energetics, DTH, Denmark.
C***********************************************************************
C
C Include the common "environment" and thermodynamic properties
C
INCLUDE ’ENVIRO.INI’
CBE INCLUDE ’THERPROP.INI’
INCLUDE ’THERPROP.DEC’
C
C Parameter variables
C
INTEGER J
DOUBLE PRECISION H,T
C
C Local variables
C
DOUBLE PRECISION H_MOL,T0,T00
INTRINSIC DLOG
C
INCLUDE ’THERPROP.INI’
C=======================================================================
T0 = 298.15D0
T00 = 273.15D0
T=T+T00
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
C Find enthalpy using Cp−polynomia
C−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−−
H_MOL = AH(J) +
: T*(A(1,J)+T*(A(2,J)/2D0+T*(A(3,J)/3D0+T*(A(4,J)/4D0+T*
: (A(5,J)/5D0+T*(A(6,J)/6D0+T*A(7,J)/7D0)))))) −
: T0*(A(1,J)+T0*(A(2,J)/2D0+T0*(A(3,J)/3D0+T0*(A(4,J)/4D0+
: T0*(A(5,J)/5D0+T0*(A(6,J)/6D0+T0*A(7,J)/7D0))))))
H=H_MOL/m_mol(J)
C
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T=T−T00
RETURN
END
C=======================================================================
67/67
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35. Metanol (fluid) til DNA – Fortran-kode

methanol.for
d:/DTU/Eksamensprojekt/bilag/
subroutine METTAB(P,h,t,v,s,X,u,IN1,IN2,EPSVA,IVMAX,fiter,fiter0)
implicit none
integer in1,in2,IVMAX,error,i,in(2),KODE,IMAX,k,file_size,rec_nr
double precision p,h,t,v,s,x,u,T_ref,rho,rho_ref,omega,tau,EPSVA
$ ,omega_g,omega_l,M,rho_start,T_start,f(2),par_file(7,100)
$ ,value_old,value,EPSV,R,P_c,T_c,s_ref,h_formation,rho_star
$ ,T_0C,x_start
logical fiter,fiter0,fiters,exist_file,equal,iterate_rho_l,con
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
CHARACTER filename*20
R=8.31448d0
s_ref=239.81d0
c J/(K*mol)
P_c=8.1035d0
c MPa
T_c=512.60d0
T_ref=513.380d0
T_0C=273.15d0
c K
rho_ref=0.00878517d0
rho_star=0.00871d0
c mol/cm^3
M=0.03204216d0
c kg/mol
h_formation=−2.013d5
c J/mol
fiters=fiter
EPSV=EPSVA
IMAX=IVMAX
error=0
file_size=40
i=1
if ((in1.eq.1).or.(in2.eq.1)) then
f(i)=p
in(i)=1
i=i+1
p=1.d5*p
endif
if ((in1.eq.2).or.(in2.eq.2)) then
if (abs(h).lt.0.01) h=0.01d0
f(i)=h
in(i)=2
i=i+1
h=1.d3*h*M−h_formation
endif
if ((in1.eq.3).or.(in2.eq.3)) then
f(i)=t
in(i)=3
i=i+1
T=t+T_0C
tau=T_ref/T
endif
if ((in1.eq.4).or.(in2.eq.4)) then
f(i)=v
in(i)=4
i=i+1
rho=1/(v*M)*1.d−6
endif
if ((in1.eq.5).or.(in2.eq.5)) then
if (abs(s).lt.0.001) s=0.001d0
f(i)=s
in(i)=5
i=i+1
s=1.d3*s*M−s_ref
endif
if ((in1.eq.6).or.(in2.eq.6)) then
if (abs(x).lt.1.d−7) x=1.d−7
f(i)=x
in(i)=6
i=i+1
endif
if ((in1.eq.7).or.(in2.eq.7)) then
if (abs(u).lt.0.01) u=0.01d0
f(i)=u
in(i)=7
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d:/DTU/Eksamensprojekt/bilag/
u=1.d3*u*M−h_formation
endif
rho_start=rho_star
T_start=T_c−1
value_old=99999
filename=’start_guesses’
INQUIRE(FILE=filename,exist=exist_file)
if (exist_file) then
OPEN(UNIT=2, FILE=filename, STATUS=’old’,ACCESS=’DIRECT’, RECL
$ =8*7)
i=1
1 READ(UNIT=2,REC=i,IOSTAT=KODE) par_file(1,i),par_file(2,i),
$ par_file(3,i),par_file(4,i),par_file(5,i),par_file(6,i)
$ ,par_file(7,i)
if (KODE.eq.0) then
c if (fiters) print*,’ny’,i,’ p=’,par_file(1,i),’ h=’
c $ ,par_file(2,i),’ t=’,par_file(3,i),’ v=’,par_file(4,i),
c $ ’s=’,par_file(5,i),’ x=’,par_file(6,i),’ u=’,par_file(7
c $ ,i),’\n’
con=.true.
if (f(1).eq.0) then
if (par_file(in(1),i).eq.0) then
value=abs(par_file(in(2),i)/f(2)−1)
else
value=abs(par_file(in(1),i)/0.1−1)+
$ abs(par_file(in(2),i)/f(2)−1)
con=.false.
endif
elseif (f(2).eq.0) then
if (par_file(in(2),i).eq.0) then
value=abs(par_file(in(1),i)/f(1)−1)
else
value=abs(par_file(in(1),i)/f(1)−1)+
$ abs(par_file(in(2),i)/0.1−1)
con=.false.
endif
else
value=abs(par_file(in(1),i)/f(1)−1)+
$ abs(par_file(in(2),i)/f(2)−1)
if (in(2).eq.2) then
if (in(1).eq.1) then
value=abs(par_file(in(1),i)/f(1)−1)+
$ abs((par_file(in(2),i)/f(2)−1)*10)
else
value=abs(par_file(in(1),i)/f(1)−1)+
$ abs((par_file(in(2),i)/f(2)−1)*5)
endif
endif
endif
if (((f(1).eq.par_file(in(1),i)).and.(f(2).eq.
$ par_file(in(2),i))).or.((value.lt.1.d−13).and.con))
$ then
p=par_file(1,i)
h=par_file(2,i)
t=par_file(3,i)
v=par_file(4,i)
s=par_file(5,i)
x=par_file(6,i)
u=par_file(7,i)
c print*,’identisk’,i,’ p=’,par_file(1,i),’ h=’,par_file(2
c $ ,i),’ t=’,par_file(3,i),’ v=’,par_file(4,i),’ s=’
c $ ,par_file(5,i),’ x=’,par_file(6,i),’ u=’,par_file(7
c $ ,i),’\n’
goto 3
elseif (value.lt.value_old) then
rho_start=1/(par_file(4,i)*M)*1.d−6
T_start=par_file(3,i)+T_0C
x_start=par_file(6,i)
value_old=value
c if (fiters) print*,’bedre’,i,’ p=’,par_file(1,i),’ h=’
c $ ,par_file(2,i),’ t=’,par_file(3,i),’ v=’,par_file(4
c $ ,i),’ s=’,par_file(5,i),’ x=’,par_file(6,i),’ u=’
c $ ,par_file(7,i),’\n’
endif
if (i.lt.file_size) then
i=i+1
2/19
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methanol.for
d:/DTU/Eksamensprojekt/bilag/
goto 1
endif
else
i=i−1
endif
else
OPEN(UNIT=2, FILE=filename, STATUS=’new’,ACCESS=’DIRECT’, RECL
$ =8*7)
i=0
endif
omega=rho_start/rho_ref
tau=T_ref/T_start
c if (fiters) print*,’guess’,T_start−T_0C,1/(rho_start*M)*1.d−6
c $ ,value_old
if ((in1.eq.1).and.(in2.eq.2).or.(in1.eq.2).and.(in2.eq.1))
$then
c if (x_start.eq.1.d−7) then
c print*,’x=0’
c omega=rho_star/rho_ref
c call iterer_tau(P,tau,omega,1,error)
c T=T_ref/tau
c x=1.d−7
c call calculate_v(rho,T,x)
c omega=rho/rho_ref
c endif
call iterer_omega_tau(P,h,tau,omega,1,2,error)
T=T_ref/tau
rho=omega*rho_ref
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.1).and.(in2.eq.3).or.(in1.eq.3).and.(in2.eq.1))
$then
tau=T_ref/T
call iterer_omega(P,tau,omega,1,error)
call calculate_h(h,tau,omega)
rho=omega*rho_ref
call calculate_s(s,tau,omega)
x=100
call calculate_u(u,tau,omega)
elseif ((in1.eq.1).and.(in2.eq.4).or.(in1.eq.4).and.(in2.eq.1))
$then
omega=rho/rho_ref
call iterer_tau(P,tau,omega,1,error)
call calculate_h(h,tau,omega)
T=T_ref/tau
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.1).and.(in2.eq.5).or.(in1.eq.5).and.(in2.eq.1))
$then
call iterer_omega_tau(P,s,tau,omega,1,5,error)
call calculate_h(h,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.1).and.(in2.eq.6).or.(in1.eq.6).and.(in2.eq.1))
$then
omega=rho_star/rho_ref
call iterer_tau(P,tau,omega,1,error)
T=T_ref/tau
call calculate_v(rho,T,x)
omega=rho/rho_ref
call calculate_h(h,tau,omega)
call calculate_s(s,tau,omega)
call calculate_u(u,tau,omega)
elseif ((in1.eq.1).and.(in2.eq.7).or.(in1.eq.7).and.(in2.eq.1))
$then
call iterer_omega_tau(P,u,tau,omega,1,7,error)
call calculate_h(h,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
3/19
19−03−2007

methanol.for
d:/DTU/Eksamensprojekt/bilag/
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
elseif ((in1.eq.2).and.(in2.eq.3).or.(in1.eq.3).and.(in2.eq.2))
$then
tau=T_ref/T
call iterer_omega(h,tau,omega,2,error)
call calculate_P(P,tau,omega)
rho=omega*rho_ref
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.2).and.(in2.eq.4).or.(in1.eq.4).and.(in2.eq.2))
$then
omega=rho/rho_ref
call iterer_tau(h,tau,omega,2,error)
call calculate_P(P,tau,omega)
T=T_ref/tau
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.2).and.(in2.eq.5).or.(in1.eq.5).and.(in2.eq.2))
$then
call iterer_omega_tau(h,s,tau,omega,2,5,error)
call calculate_P(P,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.2).and.(in2.eq.6).or.(in1.eq.6).and.(in2.eq.2))
$then
call iterer_omega_tau(h,x,tau,omega,2,6,error)
call calculate_P(P,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
call calculate_s(s,tau,omega)
call calculate_u(u,tau,omega)
elseif ((in1.eq.2).and.(in2.eq.7).or.(in1.eq.7).and.(in2.eq.2))
$then
call iterer_omega_tau(h,u,tau,omega,2,7,error)
call calculate_P(P,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
elseif ((in1.eq.3).and.(in2.eq.4).or.(in1.eq.4).and.(in2.eq.3))
$then
omega=rho/rho_ref
tau=T_ref/T
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.3).and.(in2.eq.5).or.(in1.eq.5).and.(in2.eq.3))
$then
tau=T_ref/T
call iterer_omega(s,tau,omega,5,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
rho=omega*rho_ref
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.3).and.(in2.eq.6).or.(in1.eq.6).and.(in2.eq.3))
$then
tau=T_ref/T
call calculate_v(rho,T,x)
omega=rho/rho_ref
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
call calculate_s(s,tau,omega)
call calculate_u(u,tau,omega)
4/19
19−03−2007

methanol.for
d:/DTU/Eksamensprojekt/bilag/
elseif ((in1.eq.3).and.(in2.eq.7).or.(in1.eq.7).and.(in2.eq.3))
$then
tau=T_ref/T
call iterer_omega(u,tau,omega,7,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
rho=omega*rho_ref
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
elseif ((in1.eq.4).and.(in2.eq.5).or.(in1.eq.5).and.(in2.eq.4))
$then
omega=rho/rho_ref
call iterer_tau(s,tau,omega,5,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
T=T_ref/tau
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
call calculate_u(u,tau,omega)
elseif ((in1.eq.4).and.(in2.eq.6).or.(in1.eq.6).and.(in2.eq.4))
$then
omega=rho/rho_ref
call iterer_tau(x,tau,omega,6,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
T=T_ref/tau
call calculate_s(s,tau,omega)
call calculate_u(u,tau,omega)
elseif ((in1.eq.4).and.(in2.eq.7).or.(in1.eq.7).and.(in2.eq.4))
$then
omega=rho/rho_ref
call iterer_tau(u,tau,omega,7,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
T=T_ref/tau
call calculate_s(s,tau,omega)
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
elseif ((in1.eq.5).and.(in2.eq.6).or.(in1.eq.6).and.(in2.eq.5))
$then
call iterer_omega_tau(s,x,tau,omega,5,6,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
call calculate_u(u,tau,omega)
elseif ((in1.eq.5).and.(in2.eq.7).or.(in1.eq.7).and.(in2.eq.5))
$then
call iterer_omega_tau(s,u,tau,omega,5,7,error)
call calculate_P(P,tau,omega)
call calculate_h(h,tau,omega)
T=T_ref/tau
rho=omega*rho_ref
iterate_rho_l=.true.
call calculate_x(x,tau,omega,omega_g,omega_l)
elseif (fiter0) then
print*,’METTAB called with wrong inputs’,in1,in2
endif
p=p*1.d−5
h=1.d−3*(h+h_formation)/M
t=T−T_0C
v=1/(rho*M)*1.d−6
s=1.d−3*(s+s_ref)/M
u=1.d−3*(u+h_formation)/M
if (error.eq.5) then
if (fiter0) print*
$ ,’*********No convergence in METTAB***********’
$ ,in(1),f(1),in(2),f(2)
goto 3
endif
call test_tau_omega(tau,omega,error)
if (error.eq.0) then
k=0
5/19
19−03−2007

methanol.for
d:/DTU/Eksamensprojekt/bilag/
equal=.false.
2 if (k.lt.i) then
k=k+1
if ((abs((p−par_file(1,k))/p).lt.1.d−1).and.
$ (abs((h−par_file(2,k))/h).lt.1.d−2)) then
equal=.true.
endif
goto 2
endif
if ((.not.equal).and.(p.lt.500)) then
if (i.eq.(file_size−1)) then
write(UNIT=2, REC=file_size+1) file_size
rec_nr=i+1
elseif (i.eq.file_size) then
read(UNIT=2, REC=file_size+1) rec_nr
if (rec_nr.eq.file_size) then
rec_nr=1
else
rec_nr=rec_nr+1
endif
write(UNIT=2, REC=file_size+1) rec_nr
else
rec_nr=i+1
endif
c if (fiters) print*,’rec_nr: ’,rec_nr
write(UNIT=2,REC=rec_nr)P,h,t,v,s,x,u
endif
endif
3 continue
c if (fiters) print*,in(1),f(1),in(2),f(2)
c if (fiters) print*,’result’,t,v
return
end
subroutine iterer_omega_tau(f1,f2,tau,omega,in1,in2,
$ error)
integer in1,in2,i,error,IMAX,phase,step
double precision f1,f1_old,f1_new,f2,f2_old,f2_new,tau,tau_old,
$ tau_new,omega,omega_old,omega_new,dtau,domega,df1,df2,df
$ ,f1_new_omega,f1_new_tau,f2_new_omega,f2_new_tau,df1domega
$ ,df2domega,df1dtau,df2dtau,factor,rho_star
$ ,omega_l,omega_g,EPSV,R,P_c,T_c,T_ref,rho_ref,M,T_0C,const
logical found,fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
omega_old=omega
tau_old=tau
call calculate(f1_old,tau_old,omega_old,in1)
call calculate(f2_old,tau_old,omega_old,in2)
omega_new=omega_old*(1.d0+1d−11)
tau_new=tau_old*(1.d0+1d−11)
call calculate(f1_new_omega,tau_old,omega_new,in1)
call calculate(f1_new_tau,tau_new,omega_old,in1)
call calculate(f2_new_omega,tau_old,omega_new,in2)
call calculate(f2_new_tau,tau_new,omega_old,in2)
i=0
factor=1
phase=0
step=3
found=.false.
5 if ((i .lt. IMAX) .and.(.not.found)) then
call calculate(f1_new,tau_new,omega_new,in1)
call calculate(f2_new,tau_new,omega_new,in2)
df1=f1_new−f1
df2=f2_new−f2
df=df1*df1+df2*df2
if ((abs(df1/f1).le.EPSV).and.(abs(df2/f2).le.EPSV)) then
found=.true.
goto 10
endif
if ((tau_new.eq.tau_old).and.(omega_new.eq.omega_old)) then
c if (fiters) print*
c $ ,’tau_new=tau_old and omega_new=omega_old ’,abs(df1/f1)
c $ ,abs(df2/f2),factor,f1,f2,phase
if ((abs(df1/f1).le.1.d−8).and.(abs(df2/f2).le.
$ 1.d−8)) then
found=.true.
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c if (fiters) print*,’acceptable precision’
endif
goto 10
endif
if (tau_new.ne.tau_old) then
df1dtau=(f1_new_tau−f1_old)/(tau_new−tau_old)
df2dtau=(f2_new_tau−f2_old)/(tau_new−tau_old)
endif
if (omega_new.ne.omega_old) then
df1domega=(f1_new_omega−f1_old)/(omega_new−omega_old)
df2domega=(f2_new_omega−f2_old)/(omega_new−omega_old)
endif
if (omega_new.eq.omega_old) then
if (df1dtau.eq.0) then
dtau=0.5d0*(−(df2/df2dtau))
elseif (df2dtau.eq.0) then
dtau=0.5d0*(−(df1/df1dtau))
else
dtau=0.5d0*((−(df1/df1dtau))−(df2/df2dtau))
endif
domega=0.d0
elseif (tau_new.eq.tau_old) then
if (df1domega.eq.0) then
domega=0.5d0*(−(df2/df2domega))
elseif (df2domega.eq.0) then
domega=0.5d0*(−(df1/df1domega))
else
domega=0.5d0*((−(df1/df1domega))−(df2/df2domega))
endif
dtau=0.d0
else
dtau=df1dtau*df2domega−df1domega*df2dtau
domega=dtau
dtau=(−(df1*df2domega)+df1domega*df2)/dtau
domega=(−(df1dtau*df2)+df1*df2dtau)/domega
endif
c if (fiters) print*
c $ ,in1,f1,f1_new,abs(df1/f1),’\n’,in2,f2,f2_new,abs(df2/f2)
c $ ,’\n’,1/(omega_old*rho_ref*M)*1.d−6,1/(omega_new*rho_ref*M
c $ )*1.d−6,omega_old,omega_new,omega_l,’\n’,T_ref/tau_old
c $ −T_0C,T_ref/tau_new−T_0C,tau_old,tau_new,’\n’,factor,phase
c $ ,i,’\n’
tau_old=tau_new
omega_old=omega_new
if ((i*1.0/IMAX.gt.step*1.d−1).and.(factor.lt.10)) then
factor=factor*1.6
step=step+1
endif
if (T_ref/tau_old.lt.T_C) then
call rho_l__rho_g(tau_old,omega_l,omega_g)
if (omega_old.gt.omega_l*.9) then
if ((phase.eq.2).and.(factor.lt.10)) factor=factor*1.3
phase=1
else
if ((phase.eq.1).and.(factor.lt.10)) factor=factor*1.3
phase=2
endif
else
if ((phase.eq.1).and.(factor.lt.10)) factor=factor*1.3
phase=2
endif
tau_new=tau_old+dtau
omega_new=omega_old+domega
if (phase.eq.1) then
if ((abs(df1/f1).lt.2).and.(abs(df2/f2).lt.0.01)) then
if (abs(df1/f1)/2.gt.abs(df2/f2)/0.01) then
const=abs(df1/f1)/2
else
const=abs(df2/f2)/0.01
endif
if ((abs(1.d0−tau_new/tau_old).gt.abs(1.d0−omega_new
$ /omega_old)).and.(abs(dtau).gt.abs(tau_old*.0025
$ ))) then
if(abs(domega).gt.abs(omega_old*.0025)) omega_new
$ =omega_old+domega/abs(domega)*omega_old*.0025
$ *abs(1.d0−omega_new/omega_old)/abs(1.d0
$ −tau_new/tau_old)/factor
tau_new=tau_old+dtau/abs(dtau)*tau_old*.0025/factor
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elseif(abs(domega).gt.abs(omega_old*.0025)) then
if(abs(dtau).gt.abs(tau_old*.0025)) tau_new=tau_old
$ +dtau/abs(dtau)*tau_old*.0025*abs(1.d0
$ −tau_new/tau_old)/abs(1.d0−tau_new/tau_old)
$ /factor
omega_new=omega_old+domega/abs(domega)*omega_old
$ *.0025/factor
endif
else
if ((abs(dtau)).gt.(abs(tau_old*.05))) tau_new
$ =tau_old+dtau/abs(dtau)*tau_old*.05
if ((abs(domega)).gt.(abs(omega_old*.05)))
$ omega_new=omega_old+domega/abs(domega)*omega_old*.05
endif
else
if ((abs(dtau)).gt.(abs(tau_old*.2/factor))) tau_new
$ =tau_old+dtau/abs(dtau)*tau_old*.2/factor
if (domega.lt.(−(omega_old*.9/factor))) then
omega_new=omega_old−omega_old*.9/factor
elseif (domega.gt.(omega_old*9/factor)) then
omega_new=omega_old+omega_old*9/factor
else
omega_new=omega_old+domega
endif
endif
call calculate(f1_new_omega,tau_old,omega_new,in1)
call calculate(f1_new_tau,tau_new,omega_old,in1)
call calculate(f2_new_omega,tau_old,omega_new,in2)
call calculate(f2_new_tau,tau_new,omega_old,in2)
f1_old=f1_new
f2_old=f2_new
i=i+1
goto 5
else
goto 10
endif
10 if (.not.found) then
error=5
c if (fiters) print*
c $ ,’Warning: No convergence in iterer_omega_tau’,in1,f1
c $ ,f1_new,abs(df1/f1),in2,f2,f2_new,abs(df2/f2),1/(omega_old
c $ *rho_ref*M)*1.d−6,1/(omega_new*rho_ref*M)*1.d−6,T_ref
c $ /tau_old−T_0C,T_ref/tau_new−T_0C,factor,i
if ((abs(df1/f1).gt.0.01).or.(abs(df2/f2).gt.0.01)) print*
$ ,’Warning: No convergence in iterer_omega_tau’,abs(df1/f1)
$ ,abs(df2/f2)
endif
tau=tau_new
omega=omega_new
c if (fiters) print*,’iterer_omega_tau. Antal iterationer=’,i
return
end
subroutine iterer_omega(f,tau,omega,in,error)
integer in,i,error,IMAX
double precision f,tau,omega,omega_old,omega_new,domega,f_new
$ ,f_old,df,dfdomega,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M
$ ,T_0C
logical found,saturation,fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
c omega_old=omega
omega_old=0.032148/rho_ref
call calculate(f_old,tau,omega_old,in)
omega_new=omega_old*(1d0+1d−3)
if (in.eq.1) then
saturation=.true.
else
saturation=.false.
endif
i=0
found=.false.
5 if ((i .lt. IMAX) .and.(.not.found)) then
if (saturation) call test_saturation(tau,omega_new,error,f)
call calculate(f_new,tau,omega_new,in)
if (error.eq.2) then
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if (omega_new*rho_ref.lt.rho_star) then
omega_old=omega_new*0.999
else
omega_old=omega_new*1.001
endif
call calculate(f_old,tau,omega_old,in)
error=0
endif
df=f_new−f
if ((abs(df/f).le.EPSV).or.(abs(df/f).le.1.d−6.and.
$ omega_old.eq.omega_new)) then
found=.true.
goto 10
end if
if ((f_new−f_old).eq.0) then
dfdomega=(1D−12)/(omega_new−omega_old)
else
dfdomega=(f_new−f_old)/(omega_new−omega_old)
endif
c if (fiters) print*,in
c $ ,f,f_new,f_old,abs(df/f),1/(omega_old*rho_ref*M)*1.d−6,1
c $ /(omega_new*rho_ref*M)*1.d−6,T_ref/tau−T_0C,i
omega_old=omega_new
domega=−(df/dfdomega)
omega_new=omega_old+domega
if (omega_old.lt.1) then
if (domega.lt.(−(omega_old*.9))) then
omega_new=omega_old−omega_old*.9
elseif (domega.gt.(omega_old*9)) then
omega_new=omega_old+omega_old*9
endif
else
if ((abs(domega)).gt.(abs(omega_old*.05)))
$ omega_new=omega_old+domega/abs(domega)*omega_old*.05
endif
f_old=f_new
i=i+1
goto 5
else
goto 10
endif
10 if (.not.found) then
error=5
if (fiters) print*,’Warning: No convergence in iterer_omega’,in
$ ,f,f_new,abs(df/f),1/(omega_old*rho_ref*M)*1.d−6,1
$ /(omega_new*rho_ref*M)*1.d−6,T_ref/tau−T_0C,i
end if
omega=omega_new
c if (fiters) print*,’iterer_omega. Antal iterationer=’,i
return
end
subroutine iterer_tau(f,tau,omega,in,error)
integer in,i,error,IMAX
double precision f,tau,omega,tau_old,tau_new,dtau,f_new
$ ,f_old,df,dfdtau,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical found,fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
tau_old=tau
call calculate(f_old,tau_old,omega,in)
tau_new=tau_old*1.01
i=0
found=.false.
5 if ((i.lt.IMAX).and.(.not.found)) then
call calculate(f_new,tau_new,omega,in)
df=f_new−f
if (abs(df/f).le.EPSV) then
found=.true.
goto 10
end if
dfdtau=(f_new−f_old)/(tau_new−tau_old)
tau_old=tau_new
dtau=−(df/dfdtau)
tau_new=tau_old+dtau
if ((abs(dtau)).gt.(abs(tau_old*.2))) tau_new=tau_old+dtau
$ /abs(dtau)*tau_old*.2
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f_old=f_new
i=i+1
goto 5
else
goto 10
endif
10 if (.not.found) then
error=5
if (fiters) print*,’Warning: No convergence in iterer_tau’,in,f
$ ,f_new,abs(df/f),T_ref/tau_old−T_0C,T_ref/tau_new−T_0C,1
$ /(omega_new*rho_ref*M)*1.d−6,i
end if
tau=tau_new
c if (fiters) print*,’iterer_tau. Antal iterationer=’,i
return
end
subroutine test_tau_omega(tau,omega,error)
integer error,IMAX
double precision tau,omega,T,rho,T_trip,theta,P,T_t,P_t,a(3),EPSV
$ ,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
T_trip=175.61d0
c K
T=T_ref/tau
if (T.gt.620) then
if (fiters) print*
$ ,’Temperature too high: higher than 346.85 C, T=’
$ ,T−T_0C,’ C’
error=4
elseif (T.lt.T_trip) then
if (fiters) print*
$ ,’Temperature too low: lower than triple point’
$ ,’ (−97.54 C), T=’,T−T_0C,’ C’
error=4
endif
rho=omega*rho_ref
if (rho.gt.0.032248) then
if (fiters) print*
$ ,’Specific volume too low: lower than 0.00097 m^3/kg, v=’
$ ,1/(rho*M)*1.d−6,’ m^3/kg’
error=4
elseif (rho.lt.0) then
if (fiters) print*,’Negative specific volume: v=’,
$ 1/(rho*M)*1.d−6,’ m^3/kg’
error=4
endif
call calculate_P(P,tau,omega)
P=1.d−5*P
if (P.gt.8000) then
if (fiters) print*
$ ,’Pressure too high: higher than 8000 bar, P=’,P,’ bar’
error=4
elseif ((T.lt.300).and.(P.gt.2500)) then
if (fiters) print*
$ ,’Pressure too high when temperature is this low:’
$ ,’ Pressure higher than 2500 bar and temperature lower’
$ ,’ than 26.85 C, T=’,T−T_0C,’ C’,’, P=’,P,’ bar’
error=4
elseif ((T.gt.570).and.(P.gt.2)) then
if (fiters) print*
$ ,’Pressure too high when temperature is this high:’
$ ,’ Pressure higher than 2 bar and temperature higher than’
$ ,’ 296.85 C, T=’,T−T_0C,’ C’,’, P=’,P,’ bar’
error=4
elseif ((T.lt.207).and.(P.lt.2500)) then
T_t=175.61d0
theta=(T/T_t)−1
P_t=0.187*1.d−5
a(1)=5.320770*1.d9
a(2)=4.524780*1.d9
a(3)=3.888861*1.d10
P_melt=P_t*(1+a(1)*theta+a(2)*theta**(3./2)+a(3)*theta**(4))
if (P.gt.P_melt) then
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if (fiters) print*,’Below melting curve, T=’,T−T_0C,’ C’,
$ ’, P_melt=’,P_melt,’ bar’,’, P=’,P,’ bar’
error=4
endif
endif
10 return
end
subroutine test_saturation(tau,omega,error,P)
integer error,IMAX
double precision tau,omega,omega_l,omega_g,T,rho,n(13),rho_star
$ ,rho_g,rho_l,theta,P,P_vap,EPSV,R,P_c,T_c,T_ref,rho_ref,M
$ ,T_0C
logical fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
rho=rho_ref*omega
T=T_ref/tau
if (T.lt.T_c) then
call rho_l__rho_g(tau,omega_l,omega_g)
rho_l=rho_ref*omega_l
rho_g=rho_ref*omega_g
if ((rho.lt.rho_l).and.(rho.gt.rho_g)) then
call sub_n(n,2)
theta=(T_c/T)−1
P_vap=P_c*1.d6*exp((T/T_c)*(n(1)*theta+n(2)*theta**1.5+
$ n(3)*theta**2+n(4)*theta**2.5))
if ((P.gt.P_vap).and.(rho.lt.rho_l*0.99)) then
rho=rho_l
omega=rho/rho_ref
error=2
elseif ((P.lt.P_vap).and.(rho.gt.rho_g)) then
rho=rho_g
omega=rho/rho_ref
error=2
endif
endif
endif
return
end
subroutine calculate(f,tau,omega,in)
integer in
double precision f,tau,omega,omega_g,omega_l
logical iterate_rho_l
common/switches/iterate_rho_l
if (in.eq.1) then
call calculate_p(f,tau,omega)
elseif (in.eq.2) then
call calculate_h(f,tau,omega)
elseif (in.eq.5) then
call calculate_s(f,tau,omega)
elseif (in.eq.6) then
iterate_rho_l=.true.
call calculate_x(f,tau,omega,omega_g,omega_l)
elseif (in.eq.7) then
call calculate_u(f,tau,omega)
endif
return
end
subroutine calculate_P(P,tau,omega)
integer IMAX
double precision P,Z,tau,omega,T,v,omega_g,omega_l,x,EPSV,R,P_c
$ ,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical iterate_rho_l
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
iterate_rho_l=.true.
T=T_ref/tau
call calculate_x(x,tau,omega,omega_g,omega_l)
if (x.gt.0.and.x.lt.1) then
v=1/(rho_ref*omega_g)
call calculate_Z(Z,tau,omega_g)
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P=Z*R*T/(v*1.d−6)
else
v=1/(rho_ref*omega)
call calculate_Z(Z,tau,omega)
P=Z*R*T/(v*1.d−6)
endif
return
end
subroutine calculate_h(h,tau,omega)
integer IMAX
double precision h,Z,u,tau,omega,T,omega_g,omega_l,h_l,h_g
$ ,x,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical fiters,iterate_rho_l
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
iterate_rho_l=.false.
T=T_ref/tau
call calculate_x(x,tau,omega,omega_g,omega_l)
if ((x.gt.0).and.(x.lt.1)) then
call calculate_Z(Z,tau,omega_l)
call calculate_u(u,tau,omega_l)
h_l=u+Z*R*T
call calculate_Z(Z,tau,omega_g)
call calculate_u(u,tau,omega_g)
h_g=u+Z*R*T
h=(1−x)*h_l+h_g*x
else
call calculate_Z(Z,tau,omega)
call calculate_u(u,tau,omega)
h=u+Z*R*T
endif
return
end
subroutine calculate_s(s,tau,omega)
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44),IMAX
double precision s,tau,omega,N_i(44),c_i(44),f_i(10),g_i(10),sigma
$ ,vv,omega_a,dalpha_dtau_omega,dalpha_id_dtau,alpha,alpha_id
$ ,omega_l,omega_g,s_l,s_g,x,EPSV,R,P_c,T_c,T_ref,rho_ref
$ ,rho_star,M,T_0C
logical fiters,iterate_rho_l
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
common/constants2/sigma,vv,omega_a
iterate_rho_l=.false.
call IUPAC_constants(N_i,r_i,s_i,k_i,j_i,b_i,c_i,f_i,g_i)
call calculate_x(x,tau,omega,omega_g,omega_l)
if ((x.gt.0).and.(x.lt.1)) then
call sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega_l,f_i,g_i)
call sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega_l,N_i
$ ,r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
call sub_alpha(alpha,tau,omega_l,N_i,r_i,s_i,k_i,j_i,b_i,c_i,
$ sigma,vv)
call sub_alpha_id(alpha_id,tau,omega_l,f_i,g_i)
s_l=R*(tau*(dalpha_id_dtau+dalpha_dtau_omega)−alpha−log(omega_l
$ /omega_a)−alpha_id)
call sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega_g,f_i,g_i)
call sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega_g,N_i
$ ,r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
call sub_alpha(alpha,tau,omega_g,N_i,r_i,s_i,k_i,j_i,b_i,c_i,
$ sigma,vv)
call sub_alpha_id(alpha_id,tau,omega_g,f_i,g_i)
s_g=R*(tau*(dalpha_id_dtau+dalpha_dtau_omega)−alpha−log(omega_g
$ /omega_a)−alpha_id)
s=(1−x)*s_l+s_g*x
else
call sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega,f_i,g_i)
call sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega,N_i,r_i
$ ,s_i,k_i,j_i,b_i,c_i,sigma,vv)
call sub_alpha(alpha,tau,omega,N_i,r_i,s_i,k_i,j_i,b_i,c_i,
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$ sigma,vv)
call sub_alpha_id(alpha_id,tau,omega,f_i,g_i)
s=R*(tau*(dalpha_id_dtau+dalpha_dtau_omega)−alpha−log(omega/
$ omega_a)−alpha_id)
endif
return
end
subroutine calculate_x(x,tau,omega,omega_g,omega_l)
integer IMAX
double precision x,tau,omega,T,rho,rho_l,rho_g,omega_g,omega_l,Z
$ ,P_g,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical fiters,iterate_rho_l
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
T=T_ref/tau
rho=omega*rho_ref
if (T.lt.T_c) then
call rho_l__rho_g(tau,omega_l,omega_g)
rho_l=rho_ref*omega_l
rho_g=rho_ref*omega_g
if ((rho.gt.rho_l*.99).and.(rho.lt.rho_l*1.01).and
$ .iterate_rho_l)then
call calculate_Z(Z,tau,omega_g)
P_g=Z*R*T/(1/rho_g*1.d−6)
call iterer_omega_l(P_g,tau,omega_l)
rho_l=omega_l*rho_ref
endif
if ((rho.gt.rho_g).and.(rho.lt.rho_l)) then
x=rho_g*((rho_l/rho)−1)/(rho_l−rho_g)
elseif (rho.lt.rho_g) then
x=1.0+rho_g−rho
elseif (rho.gt.rho_l) then
x=rho_l−rho*10
else
x=rho_g*((rho_l/rho)−1)/(rho_l−rho_g)
endif
if (x.eq.0) x=1.d−12
else
x=10*T/T_c+1
endif
return
end
subroutine calculate_u(u,tau,omega)
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44),IMAX
double precision u,tau,omega,T,dalpha_id_dtau,N_i(44),omega_a,
$ c_i(44),f_i(10),g_i(10),sigma,vv,dalpha_dtau_omega,x,omega_g
$ ,omega_l,u_g,u_l,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical fiters,iterate_rho_l
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
common/switches/iterate_rho_l
common/constants2/sigma,vv,omega_a
iterate_rho_l=.false.
T=T_ref/tau
call IUPAC_constants(N_i,r_i,s_i,k_i,j_i,b_i,c_i,f_i,g_i)
call calculate_x(x,tau,omega,omega_g,omega_l)
if ((x.gt.0).and.(x.lt.1)) then
call sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega_l,f_i,g_i)
call sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega_l,N_i
$ ,r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
u_l=R*T*tau*(dalpha_id_dtau+dalpha_dtau_omega)
call sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega_g,f_i,g_i)
call sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega_g,N_i
$ ,r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
u_g=R*T*tau*(dalpha_id_dtau+dalpha_dtau_omega)
u=u_g*x+(1−x)*u_l
else
call sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega,f_i,g_i)
call sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega,N_i,r_i
$ ,s_i,k_i,j_i,b_i,c_i,sigma,vv)
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u=R*T*tau*(dalpha_id_dtau+dalpha_dtau_omega)
endif
return
end
subroutine calculate_Z(Z,tau,omega)
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44)
double precision Z,tau,omega,N_i(44),omega_a,
$ c_i(44),f_i(10),g_i(10),sigma,vv,dalpha_domega_tau
common/constants2/sigma,vv,omega_a
call IUPAC_constants(N_i,r_i,s_i,k_i,j_i,b_i,c_i,f_i,g_i)
call sub_dalpha_domega_tau(dalpha_domega_tau,tau,omega,N_i,
$ r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
Z=1+omega*dalpha_domega_tau
return
end
subroutine calculate_v(rho,T,x)
integer IMAX
double precision x,T,rho,rho_l,rho_g,omega_g,omega_l,tau,Z,P_g
$ ,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
tau=T_ref/T
call rho_l__rho_g (tau,omega_l,omega_g)
rho_l=rho_ref*omega_l
rho_g=rho_ref*omega_g
if (T.lt.T_c) then
if (x.lt.1.d−5) then
call calculate_Z(Z,tau,omega_g)
P_g=Z*R*T/(1/rho_g*1.d−6)
call iterer_omega_l(P_g,tau,omega_l)
rho_l=omega_l*rho_ref
endif
rho=rho_l/(1+x*(rho_l−rho_g)/rho_g)
elseif (fiters) then
print*,
$ ’Temperature higher than T_c (239.45 C) in calculate_v’
$ ,’, T=’,T−T_0C,’ C, x=’,x
if (x.lt.0.5) then
rho=rho_star*T/T_c
else
rho=rho_star*T_c/T
endif
endif
return
end
subroutine iterer_omega_l(f,tau,omega)
integer i,IMAX
double precision f,tau,omega,omega_old,omega_new,domega,f_new
$ ,f_old,df,dfdomega,Z,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M
$ ,T_0C
logical found,fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
omega_old=omega
call calculate_Z(Z,tau,omega_old)
f_old=Z*R*(T_ref/tau)/(1/(omega_old*rho_ref)*1.d−6)
omega_new=omega_old*1.01
i=0
found=.false.
5 if ((i .lt. IMAX) .and.(.not.found)) then
call calculate_Z(Z,tau,omega_new)
f_new=Z*R*(T_ref/tau)/(1/(omega_new*rho_ref)*1.d−6)
df=f_new−f
if ((abs(df/f).le.EPSV).or.(abs(df/f).le.1.d−6.and.
$ omega_old.eq.omega_new)) then
found=.true.
goto 10
end if
dfdomega=(f_new−f_old)/(omega_new−omega_old)
omega_old=omega_new
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domega=−(df/dfdomega)
if (domega.lt.(−(omega_old*.9))) then
omega_new=omega_old−omega_old*.9
elseif (domega.gt.(omega_old*9)) then
omega_new=omega_old+omega_old*9
else
omega_new=omega_old+domega
endif
f_old=f_new
i=i+1
goto 5
else
goto 10
endif
10 if (.not.found) then
c if (fiters) print*,’Warning: No convergence in iterer_omega_l’
c $ ,f,f_new,abs(df/f),1/(omega_old*rho_ref*M)*1.d−6,1
c $ /(omega_new*rho_ref*M)*1.d−6,T_ref/tau−T_0C,i
end if
omega=omega_new
return
end
subroutine rho_l__rho_g(tau,omega_l,omega_g)
integer IMAX
double precision T,rho_l,rho_g,omega_g,omega_l,tau,n(13)
$ ,theta,EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C
logical fiters
common/constants/EPSV,R,P_c,T_c,T_ref,rho_ref,rho_star,M,T_0C,IMAX
$ ,fiters
T=T_ref/tau
call sub_n(n,3)
theta=1−(T/T_c)
rho_g=rho_star*exp(n(1)*theta**(1./6)+n(2)*theta**(1./3)+
$ n(3)*theta**(2./3)+n(4)*theta**(7./6)+n(5)*theta**(3./2
$ )+n(6)*theta**(5./2)+n(7)*theta**(8./3)+n(8)*theta**(7.
$ /2)+n(9)*theta**5+n(10)*theta**6+n(11)*theta**15+n(12)
$ *theta**21+n(13)*log(T/T_c))
call sub_n(n,4)
rho_l=rho_star*(1+n(1)*theta**(1./3)+n(2)*theta**(2./3)+n(3)
$ *theta**(4./3)+n(4)*theta**(11./3)+n(5)*theta**(13./3))
omega_l=rho_l/rho_ref
omega_g=rho_g/rho_ref
return
end
subroutine sub_dalpha_id_dtau(dalpha_id_dtau,tau,omega,f_i,g_i)
implicit none
integer I
double precision dalpha_id_dtau,tau,omega,f_i(10),g_i(10)
dalpha_id_dtau=f_i(2)*1/tau+f_i(3)
DO I=4,10
dalpha_id_dtau=dalpha_id_dtau+f_i(I)*g_i(I)*exp(g_i(I)*tau)
$ /(exp(g_i(I)*tau)−1)
ENDDO
return
end
subroutine sub_alpha_id(alpha_id,tau,omega,f_i,g_i)
implicit none
integer I
double precision alpha_id,tau,omega,f_i(10),g_i(10)
alpha_id=f_i(1)+f_i(2)*log(tau)+f_i(3)*tau
DO I=4,10
alpha_id=alpha_id+f_i(I)*log(exp(g_i(I)*tau)−1)
ENDDO
return
end
subroutine sub_dalpha_dtau_omega(dalpha_dtau_omega,tau,omega,N_i,
$r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
implicit none
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44),I
double precision N_i(44),c_i(44),sigma,vv,dalpha_dtau_omega,tau,
$omega
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dalpha_dtau_omega=0.0d0
DO I=1,17
dalpha_dtau_omega=dalpha_dtau_omega+N_i(I)*s_i(I)*omega**
$ r_i(I)*tau**(s_i(I)−1)
ENDDO
DO I = 18,36
dalpha_dtau_omega=dalpha_dtau_omega+N_i(I)*s_i(I)*omega**
$ r_i(I)*tau**(s_i(I)−1)*exp(−((sigma*omega)**k_i(I)))
ENDDO
DO I = 37,44
dalpha_dtau_omega=dalpha_dtau_omega+N_i(I)*c_i(I)*vv*omega**
$ r_i(I)*exp(c_i(I)*vv*tau−b_i(I)−(j_i(I)*sigma*omega)**
$ k_i(I))
ENDDO
return
end
subroutine sub_alpha(alpha,tau,omega,N_i,r_i,s_i,k_i,j_i,b_i,c_i,
$sigma,vv)
implicit none
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44),I
double precision N_i(44),c_i(44),sigma,vv,alpha,tau,
$omega
alpha=0.0d0
DO I = 1,17
alpha=alpha+N_i(I)*omega**r_i(I)*tau**s_i(I)
ENDDO
DO I = 18,36
alpha=alpha+N_i(I)*omega**r_i(I)*tau**s_i(I)*exp(−((sigma*omega
$ )**k_i(I)))
ENDDO
DO I = 37,44
alpha=alpha+N_i(I)*omega**r_i(I)*exp(c_i(I)*vv*tau−b_i(I)−
$ (j_i(I)*sigma*omega)**k_i(I))
ENDDO
return
end
subroutine sub_dalpha_domega_tau(dalpha_domega_tau,tau,omega,N_i,
$r_i,s_i,k_i,j_i,b_i,c_i,sigma,vv)
implicit none
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44),I
double precision N_i(44),c_i(44),sigma,vv,dalpha_domega_tau,tau,
$omega
dalpha_domega_tau=0.0d0
DO I = 1,17
dalpha_domega_tau=dalpha_domega_tau+N_i(I)*r_i(I)*omega**
$ (r_i(I)−1)*tau**s_i(I)
ENDDO
DO I = 18,36
dalpha_domega_tau=dalpha_domega_tau+N_i(I)*omega**(r_i(I)−1)
$ *tau**s_i(I)*(r_i(I)−k_i(I)*(sigma*omega)**k_i(I))*
$ exp(−((sigma*omega)**k_i(I)))
ENDDO
DO I = 37,44
dalpha_domega_tau=dalpha_domega_tau+N_i(I)*omega**(r_i(I)−1)
$ *(r_i(I)−k_i(I)*(j_i(I)*sigma*omega)**k_i(I))*
$ exp(c_i(I)*vv*tau−b_i(I)−((j_i(I)*sigma*omega)**k_i(I)))
ENDDO
return
end
subroutine IUPAC_constants(N_i,r_i,s_i,k_i,j_i,b_i,c_i,f_i,g_i)
implicit none
integer r_i(44),s_i(44),k_i(44),j_i(44),b_i(44)
double precision N_i(44),c_i(44),f_i(10),g_i(10),sigma,vv,omega_a
common/constants2/sigma,vv,omega_a
sigma=1.00863030999d0
vv=0.998480657603d0
omega_a=0.0045917679d0
N_i(1)=−2.80062505988d0
N_i(2)=12.5636372418d0
N_i(3)=−13.0310563173d0
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N_i(4)=3.26593134060d0
N_i(5)=−4.11425343805d0
N_i(6)=3.46397741254d0
N_i(7)=−0.0836443967590d0
N_i(8)=−0.369240098923d0
N_i(9)=0.00313180842152d0
N_i(10)=0.603201474111d0
N_i(11)=−0.231158593638d0
N_i(12)=0.106114844945d0
N_i(13)=−0.0792228164995d0
N_i(14)=−0.0000422419150975d0
N_i(15)=0.00758196739214d0
N_i(16)=−0.0000244617434701d0
N_i(17)=0.00000115080328802d0
N_i(18)=−12.5099747447d0
N_i(19)=27.0392835391d0
N_i(20)=−21.2070717086d0
N_i(21)=6.32799472270d0
N_i(22)=14.3687921636d0
N_i(23)=−28.7450766617d0
N_i(24)=18.5397216068d0
N_i(25)=−3.88720372879d0
N_i(26)=−4.16602487963d0
N_i(27)=5.29665875982d0
N_i(28)=0.509360272812d0
N_i(29)=−3.30257604839d0
N_i(30)=−0.311045210826d0
N_i(31)=0.273460830583d0
N_i(32)=0.518916583979d0
N_i(33)=−0.00227570803104d0
N_i(34)=0.0211658196182d0
N_i(35)=−0.0114335123221d0
N_i(36)=0.00249860798459d0
N_i(37)=−8.19291988442d0
N_i(38)=0.478601004557d0
N_i(39)=−0.444161392885d0
N_i(40)=0.179621810410d0
N_i(41)=−0.687602278259d0
N_i(42)=2.40459848295d0
N_i(43)=−6.88463987466d0
N_i(44)=1.13992982501d0
r_i(1)=1
r_i(2)=1
r_i(3)=1
r_i(4)=1
r_i(5)=2
r_i(6)=2
r_i(7)=2
r_i(8)=2
r_i(9)=2
r_i(10)=3
r_i(11)=3
r_i(12)=3
r_i(13)=4
r_i(14)=4
r_i(15)=5
r_i(16)=6
r_i(17)=7
r_i(18)=1
r_i(19)=1
r_i(20)=1
r_i(21)=1
r_i(22)=2
r_i(23)=2
r_i(24)=2
r_i(25)=2
r_i(26)=3
r_i(27)=4
r_i(28)=5
r_i(29)=5
r_i(30)=5
r_i(31)=5
r_i(32)=6
r_i(33)=9
r_i(34)=6
r_i(35)=6
r_i(36)=4

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r_i(37)=1
r_i(38)=1
r_i(39)=1
r_i(40)=1
r_i(41)=1
r_i(42)=3
r_i(43)=3
r_i(44)=3
s_i(1)=0
s_i(2)=1
s_i(3)=2
s_i(4)=3
s_i(5)=1
s_i(6)=2
s_i(7)=3
s_i(8)=4
s_i(9)=6
s_i(10)=0
s_i(11)=3
s_i(12)=4
s_i(13)=0
s_i(14)=7
s_i(15)=1
s_i(16)=6
s_i(17)=7
s_i(18)=1
s_i(19)=2
s_i(20)=3
s_i(21)=4
s_i(22)=1
s_i(23)=2
s_i(24)=3
s_i(25)=5
s_i(26)=1
s_i(27)=2
s_i(28)=1
s_i(29)=2
s_i(30)=4
s_i(31)=5
s_i(32)=2
s_i(33)=5
s_i(34)=9
s_i(35)=14
s_i(36)=19
k_i(18)=2
k_i(19)=2
k_i(20)=2
k_i(21)=2
k_i(22)=2
k_i(23)=2
k_i(24)=2
k_i(25)=2
k_i(26)=2
k_i(27)=2
k_i(28)=2
k_i(29)=2
k_i(30)=2
k_i(31)=2
k_i(32)=2
k_i(33)=2
k_i(34)=4
k_i(35)=4
k_i(36)=6
k_i(37)=2
k_i(38)=3
k_i(39)=2
k_i(40)=4
k_i(41)=2
k_i(42)=3
k_i(43)=2
k_i(44)=4
j_i(37)=2
j_i(38)=2
j_i(39)=3
j_i(40)=3

methanol.for
d:/DTU/Eksamensprojekt/bilag/
j_i(41)=4
j_i(42)=3
j_i(43)=4
j_i(44)=4
b_i(37)=6
b_i(38)=6
b_i(39)=6
b_i(40)=6
b_i(41)=6
b_i(42)=25
b_i(43)=25
b_i(44)=25
c_i(37)=3.9d0
c_i(38)=3.9d0
c_i(39)=3.9d0
c_i(40)=3.9d0
c_i(41)=3.9d0
c_i(42)=23.1d0
c_i(43)=23.1d0
c_i(44)=23.1d0
f_i(1)=2.49667488720d0
f_i(2)=2.90079118498d0
f_i(3)=−62.5713535015d0
f_i(4)=10.9926773951d0
f_i(5)=18.3368299465d0
f_i(6)=−16.3660043791d0
f_i(7)=−6.22323476219d0
f_i(8)=2.80353628228d0
f_i(9)=1.07780989422d0
f_i(10)=0.969656970177d0
g_i(4)=4.11978538315d0
g_i(5)=3.26499998052d0
g_i(6)=3.76946349682d0
g_i(7)=2.93149354474d0
g_i(8)=8.22555789084d0
g_i(9)=10.3162789084d0
g_i(10)=0.532489267209d0
return
end
subroutine sub_n(n,eq_nr)
integer eq_nr
double precision n(13)
if (eq_nr.eq.2) then
n(1)=−8.8738823d0
n(2)=2.3698322d0
n(3)=−10.852598d0
n(4)=−0.12446396d0
elseif (eq_nr.eq.3) then
n(1)=−9.74320519d0
n(2)=6.27207077d1
n(3)=−(7.11162934d2)
n(4)=−(1.28732378d4)
n(5)=9.54090636d3
n(6)=−(8.06229292d4)
n(7)=8.90380974d4
n(8)=−(2.68827787d4)
n(9)=1.53392797d4
n(10)=−(1.39186128d4)
n(11)=−(8.77428382d3)
n(12)=9.25853159d3
n(13)=−(7.36156195d3)
elseif (eq_nr.eq.4) then
n(1)=1.8145364d0
n(2)=1.2703194d0
n(3)=−1.0182657d0
n(4)=2.7562720d0
n(5)=−1.8958692d0
endif
return
end
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