The net contribution of that <strong>power</strong> <strong>plant</strong> to the electric grid can be calculated by subtract<strong>in</strong>g all <strong>in</strong>ternal<strong>power</strong> consumption to the generator output.Condenser with heat exchangeSteam exhaust from the turb<strong>in</strong>e is cooled without mix<strong>in</strong>g us<strong>in</strong>g water from the cool<strong>in</strong>g tower <strong>in</strong> asurface type condenser. The goal is to condense this steam by extract<strong>in</strong>g energy because it requiresless work to pump an <strong>in</strong>compressible liquid than compressible gas or steam at state 4. The energyextracted is calculated by us<strong>in</strong>g the mass flow of steam and the enthalpy difference at stations 3 and 4,as followsEquation 11, based on the energy balance <strong>in</strong> the exchanger, is = ( h − h ) (10) ( h − h ) = ( h − h ) (11)The heat exchange is determ<strong>in</strong>ed by the temperature difference; therefore, the maximum temperatureof the cool<strong>in</strong>g water must not exceed the condensation temperature <strong>in</strong> the condenser. Accord<strong>in</strong>g toPálsson (2010) there should be at least 5°C difference between those numbers, written as follows = −5 (12)Assum<strong>in</strong>g that condensation takes place at a constant temperature, a simplified equation can be givenas = (13)S<strong>in</strong>ce a temperature value is fixed on the design for the <strong>in</strong>let cool<strong>in</strong>g water temperature, alltemperature variables can be identified. Therefore, Equation 11 can be used to calculate the requiredflow rate of the cool<strong>in</strong>g water at station c1.Gas extractionThe <strong>geothermal</strong> steam <strong>in</strong>cludes non condensable gases all the time. Carbon dioxide is typically about98% of the gas content and is released to the atmosphere <strong>in</strong> most <strong>geothermal</strong> <strong>power</strong> <strong>plant</strong>s(Thorhallsson, 2006). In this analysis, the composition of the non-condensable gases is assumed to be100 % CO 2 .Non condensable gases cause a problem <strong>in</strong> the condenser; while the steam is condensed and pumpedout, the gases are kept on <strong>in</strong> gaseous form produc<strong>in</strong>g an <strong>in</strong>crease <strong>in</strong> the pressure <strong>in</strong> the condenser. Apossible solution to this problem is to compress the gases and suck them out of the condenser.In the extraction process, some amount of steam will always be <strong>in</strong>cluded s<strong>in</strong>ce the steam is mixed withother gases <strong>in</strong>side. Hence, the gas mixture is then assumed to be saturated with steam when it issucked out from the condenser. Accord<strong>in</strong>g to Pálsson (2010) the mass of steam extracted can bedef<strong>in</strong>ed as = ( ) (14)where is the mass molar mass of water and is the mass molar mass of gases, is thesaturation pressure of steam at the gas outlet temperature, is the condenser pressure and is themass flow of gases <strong>in</strong>to the condenser.The energy required for the pump is calculated by an ideal isentropic process between the condenserpressure and the atmospheric pressure. The mixture properties are calculated as follows17
= +( − ) ( )(15)= +( − ) ( )(16)where is the specific heat of the gas and the vapor mixture that is pumped out of the condenser, andR is the ideal gas constant for the mixture. The ideal enthalpy change of the fluid when compressed toatmospheric pressure can be written as∆h = − 1 (17)Includ<strong>in</strong>g the compressor efficiency , the demand<strong>in</strong>g <strong>power</strong> for the pump can be calculated as = ( ) ∆ (18)Cool<strong>in</strong>g towerIn this case, air cool<strong>in</strong>g <strong>in</strong> a forced flow cool<strong>in</strong>g tower is used to accommodate the heat load from thecondens<strong>in</strong>g steam. A cool<strong>in</strong>g tower is an evaporative heat transfer device <strong>in</strong> which atmospheric aircools warm water with direct contact between the water and the air, by evaporat<strong>in</strong>g part of the water(Siregar, 2004). As shown <strong>in</strong> Figure 13, the cool<strong>in</strong>g water is pumped from the pond to the condenserat station 1; after this, warm water at station c2 is cooled by be<strong>in</strong>g sprayed <strong>in</strong>to the tower where it fallsthrough; us<strong>in</strong>g fans at the top of the tower, an air stream is drawn <strong>in</strong>to the tower at station c3, andflows out at station c4.Accord<strong>in</strong>g to Pálsson (2010) it can be assumed that the relative humidity of the outlet (c4) is 100% ifthe tower is satisfactorily large. In regards to a mixture of air and water, with their respectively molarmasses be<strong>in</strong>g M a and M w , the partial pressures of the air and water are def<strong>in</strong>ed as =∗ (19) =∗ (20)Then, tak<strong>in</strong>g <strong>in</strong>to account the saturation pressure of water at given pressure , the relative humidity isdenoted asThe humidity ratio is def<strong>in</strong>ed as= (21)= ∗∗ ∗( )(22)Overall, cool<strong>in</strong>g tower balance equations are formulated <strong>in</strong> order to f<strong>in</strong>d the required mass flow rate.Mass balance for dry air (Equation 19) and water (Equation 20) are given byAnd the energy balance equation is , = , = (23) , + , = , + , (24)h , , +h , , + h , , = h , , +h , , +h , , (25)18
- Page 1 and 2: GEOTHERMAL TRAINING PROGRAMMEHot sp
- Page 3 and 4: This MSc thesis has also been publi
- Page 5 and 6: ACKNOWLEDGEMENTSMy gratitude to the
- Page 7 and 8: TABLE OF CONTENTSPage1. INTRODUCTIO
- Page 9 and 10: PageAPPENDIX A: FINANCIAL MODEL ...
- Page 12 and 13: 1. INTRODUCTIONRecent research on r
- Page 14 and 15: 2. CENTRAL AMERICAN DATA2.1 Power p
- Page 16 and 17: 2.2.3 HondurasThe Honduran electric
- Page 18 and 19: NET INJECTION BY SOURCE (2010)INSTA
- Page 20 and 21: income taxes for a period of 10 yea
- Page 22 and 23: annual temperature ranges from 17 t
- Page 24 and 25: egional reconnaissance in 1981ident
- Page 26 and 27: 4. GEOTHERMAL ELECTRICAL POWER ASSE
- Page 30 and 31: Introducing , = , and , = ,
- Page 32 and 33: 9ProductionWellBoiler5Turbine~1046P
- Page 34 and 35: TABLE 3: Parameters and boundary co
- Page 36 and 37: eaches the maximum limit, and for h
- Page 38 and 39: 160180140160tc vap[i], th vap[i]120
- Page 40 and 41: average results, and combining them
- Page 42 and 43: The base cost ( ) can be calculate
- Page 44 and 45: calculation for another separator c
- Page 46 and 47: mass flow rate (kg/s) on the plant
- Page 48 and 49: Table 11 shows a summary of costs f
- Page 50 and 51: 5.6.4 Comparison of capital costs b
- Page 52 and 53: 6. FINANCIAL FEASIBILITY ASSESSMENT
- Page 54 and 55: 6.2 Model structureThe financial fe
- Page 56 and 57: CCF = EBITDA − ∆Working Capital
- Page 58 and 59: Interest on loansFleischmann (2007)
- Page 60 and 61: IRR30%25%IRR CapitalIRR Equity20%Si
- Page 62 and 63: FIGURE 42: Allocation of funds for:
- Page 64 and 65: 340IRR Free Cash Flow to Equity [ %
- Page 66 and 67: flash technology is between 0.3 and
- Page 68 and 69: Energy Price Availability Factor O&
- Page 70 and 71: FIGURE 50: Density and cumulative p
- Page 72 and 73: In Chapter 6, Figure 44 illustrated
- Page 74 and 75: The internal rate of return is offs
- Page 76 and 77: Cengel, Y. and Tuner, R., 2005: Fun
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IEAb, 2011: Technology roadmap: Geo
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Salmon, J., Meurice, J., Wobus, N.,
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APPENDIX A: SUMMARY OF FINANCIAL MO
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APPENDIX C: INVESTMENT AND FINANCIN
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APPENDIX E: BALANCE SHEETBALANCE SH