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Author’s Name Name <strong>of</strong> <strong>the</strong> Paper SessionP<strong>Dynamic</strong><strong>Positioning</strong><strong>Committee</strong>Marine Technology SocietyDYNAMIC POSITIONING CONFERENCESeptember 17-18, 2002IntroductionDP Requirements for Drilling andIntervention UnitsBjørn Abrahamsen<strong>Statoil</strong> (Stavanger)
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical RequirementsTR1029, Version 1, Valid from 01.09.2002Validity area:<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshoreSignatures and info for DocMap (will be deleted when transferred to DocMap):Role in DocMap Role in organisation Name Signature DateAuthor Staff Engineer Bjørn AbrahamsenPublisher 's Administrator Sector Manager Arne MålandPublisher Sector Manager Per HaalandApprover Vice President Mads GrinrødContents1 Introduction.......................................................................................................................................31.1 Objective.............................................................................................................................................31.2 Validity area........................................................................................................................................31.3 Warrant ...............................................................................................................................................31.4 Document replaces..............................................................................................................................31.5 Publishing and follow-up....................................................................................................................31.6 Definitions ..........................................................................................................................................32 Technical requirements ....................................................................................................................42.1 Station keeping....................................................................................................................................42.2 Vessel types ........................................................................................................................................53 Pre hire requirements.......................................................................................................................63.1 Verification Process............................................................................................................................63.2 Documentation Table..........................................................................................................................83.3 DP Capability Requirements (Category A) ......................................................................................133.4 DP Capability Requirements (Category B).......................................................................................133.5 DP Capability Requirements (Category C & D)...............................................................................143.6 Reference System Requirements ......................................................................................................173.7 Additional Equipment Requirements................................................................................................183.8 Technology Development Requirements (Categories A, B, C & D)................................................183.9 Annual Trials ....................................................................................................................................193.10 Industrial experience transfer............................................................................................................204 Field arrival requirements .............................................................................................................204.1 Arrival Trials.....................................................................................................................................204.2 Checklists..........................................................................................................................................215 Operational requirements ..............................................................................................................21
5.1 DP Alert and communications systems (Category A, B, C & D) .....................................................215.2 DP Alerts (Category A) ....................................................................................................................225.3 DP Alerts (Categories B, C & D)......................................................................................................225.4 Incident Priorities..............................................................................................................................255.5 <strong>Statoil</strong> DP Policy (Categories A, B, C & D).....................................................................................265.6 <strong>Statoil</strong> DP Policy (Categories B, C & D)..........................................................................................265.7 Reporting (Categories A, B, C & D).................................................................................................275.8 Reporting (Categories A, B, C & D).................................................................................................285.9 Management & Event Closeout ........................................................................................................285.10 Well Specific Operating Guidelines (WSOG) ..................................................................................295.11 Well Specific Operating Guidelines Notes and Sample Form..........................................................295.12 Well Specific Operating Guidelines (WSOG) Form (Blank) ...........................................................356 Well Testing.....................................................................................................................................366.1 General..............................................................................................................................................367 References........................................................................................................................................367.1 General..............................................................................................................................................367.2 Regulatory acts and regulations ........................................................................................................367.3 Standards and specifications .............................................................................................................377.4 <strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>ation ......................................................................................................38
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20021 IntroductionThis <strong>document</strong> lists <strong>the</strong> types <strong>of</strong> equipment and minimum performance levels that can be expected tosafely conduct drilling or well intervention operations using a DP (dynamically positioned) vessel orunit.It is used to establish a DP control regime for both selection and operation <strong>of</strong> a unit for a given wellprogram.These requirements shall be used as a basis for all DP drilling or DP well intervention vessels or unitscontracted to <strong>Statoil</strong> world-wide.All requirements <strong>document</strong>ed herein are based on existing good practice and serve to streng<strong>the</strong>n<strong>Statoil</strong>’s existing quality management regime.1.1 ObjectiveThe purpose <strong>of</strong> this <strong>document</strong> is to define <strong>the</strong> minimum requirements for vessels and / or units to becontracted for <strong>the</strong> purpose <strong>of</strong> carrying out drilling, well testing and / or well intervention operationsusing dynamic positioning only.1.2 Validity area<strong>Statoil</strong> group. These requirements are valid on a world-wide basis. Guidance notes and explanationare given whenever additional requirements to meet <strong>the</strong> Norwegian operating regime are made.Any DP drilling or intervention unit shall be certified as a marine <strong>of</strong>fshore unit and shall be operated inaccordance with relevant national or flag state regulations during transit. In terms <strong>of</strong> operational DPsafety, <strong>the</strong> transition to <strong>Statoil</strong>’s requirements shall be made when <strong>the</strong> vessel begins deployingpositioning equipment and commences field arrival DP trials at a given location.1.3 Warrant“Drilling, Well & Production Activities” (AR03) (<strong>Statoil</strong> Group/All locations/On- and <strong>of</strong>fshore)1.4 Document replacesWR0581.1.5 Publishing and follow-upF&T BRT is responsible for publishing and follow-up <strong>of</strong> this <strong>document</strong>.1.6 DefinitionsThe following definitions and abbreviations apply:-Validity area: Page 3 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002TermContractorVesselForeign FlagvesselColumnStabilised UnitDNVABSLloydsBVDPIMOIMCAIADCNMDNPDDefinitionVessel owner, operator or charterer responsible for execution <strong>of</strong> <strong>the</strong> workCommon term including ships, barges, column stabilised units, selfelevating units and o<strong>the</strong>r floating units with or without own propulsion,which are subject to registration and classification according to national orinternational maritime regulations.Vessel with Flag state o<strong>the</strong>r than Norwegian.Unit with <strong>the</strong> main deck connected to underwater hull by columns orcaissons.Det Norske VeritasAmerican Bureau <strong>of</strong> ShippingLloyds Register <strong>of</strong> ShippingBureau Veritas<strong>Dynamic</strong> <strong>Positioning</strong>International Maritime OrganisationInternational Marine Contractors AssociationInternational Association <strong>of</strong> Drilling ContractorsNorwegian Maritime DirectorateNorwegian Petroleum DirectorateFur<strong>the</strong>r definitions and abbreviations are given in NORSOK standard, J.003, Marine Operations.2 Technical requirements2.1 Station keepingWhere a DP vessel or unit is chosen for a given drilling, welltesting or intervention program by <strong>Statoil</strong>,it shall be capable <strong>of</strong> performing <strong>the</strong> following:-• <strong>Positioning</strong> in up to contracted water depth within <strong>Statoil</strong>’s performance requirements foraccuracy. This includes minimum levels <strong>of</strong> ‘DP Capability’ as defined herein for both monohulland semisubmersible units.• Locating / spudding in and positioning over a well within <strong>Statoil</strong>’s maximum time scale andaccuracy criteria.• Monitoring both well and drilling unit’s positions throughout <strong>the</strong> drilling programme withoutexception.• Monitoring any riser performance using <strong>the</strong> equipment specifications herein.• Continuous operation. I.e. sufficient redundancy in equipment to meet <strong>Statoil</strong>’s uptimeexpectations.• Operational management to a level <strong>of</strong> competence that complements <strong>Statoil</strong>’s safety goals laid ou<strong>the</strong>rein. This includes areas that are part <strong>of</strong> internationally recognised safety management standards(ISO, ISM Code).• Electronically logging operational data.The requirements are grouped into 3 separate areas being:-Validity area: Page 4 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002• Pre Hire• Field Arrival• Operational2.2 Vessel typesThese Work Process Requirements for drilling and intervention units subdivide requirements betweendifferent operations. Individual requirements are made dependant on <strong>the</strong> nature <strong>of</strong> <strong>the</strong> work, type <strong>of</strong>unit and waterdepth. A categorisation scheme differentiating <strong>the</strong> different types <strong>of</strong> tasks is used <strong>the</strong>define applicability <strong>of</strong> <strong>the</strong> various requirements contained herein. Four operations Categories aredefined:-CATEGORY WORK GROUP TYPEALight InterventionLight intervention vessel without HP riser to surface.Examples include subsea wireline using SubseaIntervention lubricator free-standing on a subsea treeusing guidelines.BMedium InterventionIntervention using HP riser system (Coiled Tubing orWireline operations)CHeavy InterventionIntervention using drilling unit through marine riser andsubsea BOPDDrillingMonohull vessel or semisubmersible unit engaged inexploration or production drilling operations.Throughout this Requirements <strong>document</strong>, tables and additional notes are used to show <strong>the</strong> applicability<strong>of</strong> <strong>the</strong> various requirements within <strong>the</strong> four Categories.Each planned operation is assessed against all relevant legislation and industry guidelines. Therelevant Class <strong>of</strong> operation shall be in force at all times during <strong>the</strong> particular operation. Thisrequirement is central to <strong>Statoil</strong>’s policy <strong>of</strong> continual focus on <strong>the</strong> safety <strong>of</strong> any DP drilling orintervention operations.Validity area: Page 5 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002The following table <strong>of</strong> Classification shall apply for <strong>the</strong> planning <strong>of</strong> intervention and / or drillingoperations world-wide:-CATEGORYABCDWell LocationNW Europe includingNorwegian, Danish,German, Dutch and UKCSNW Europe includingNorwegian, Danish,German, Dutch and UKCSNW Europe includingNorwegian, Danish,German, Dutch and UKCSNW Europe includingNorwegian, Danish,German, Dutch and UKCSMinimum IMOConsequenceClassWorldwide * 2Worldwide * 2Worldwide * 2Worldwide * 22333NotesIf Class 3 unit or vessel is contracted, <strong>the</strong>nNormal operating mode shall be Class 3 forall operations irrespective <strong>of</strong> location* Where no National / local legislation is in force, latest edition <strong>of</strong> IMCA Guidelines shall beminimum <strong>Statoil</strong> world-wide requirement.These requirements point to <strong>the</strong> following and hold distinct safety advantages for both <strong>Statoil</strong> andpotential contractors.The issue <strong>of</strong> different levels <strong>of</strong> equipment specification prescribed by IMO, NMD, Class or industrialguidelines is avoided. When operating for <strong>Statoil</strong>, <strong>the</strong>se levels <strong>of</strong> equipment shall be <strong>the</strong> starting pointand effective reporting <strong>of</strong> deficiencies shall be enforced.No reporting ambiguity is allowed when adopting this philosophy.3 Pre hire requirements3.1 Verification ProcessThe pre-hire process shall take <strong>the</strong> form <strong>of</strong> a review <strong>of</strong> all <strong>document</strong>ation requested in Table 1. Aprospective Contractor will be requested to provide as much <strong>of</strong> <strong>the</strong> information requested as possiblein order that a review may be made <strong>of</strong> <strong>the</strong> unit’s technical integrity. An overall assessment <strong>of</strong> <strong>the</strong> typeand quality <strong>of</strong> <strong>document</strong>ation submitted shall be performed in order to verify <strong>the</strong> unit’s level <strong>of</strong>preparation for <strong>the</strong> proposed program.The review process shall allow <strong>Statoil</strong> to conduct an operational verification program against bothinternational best practice as well as technical minimum and site specific requirements.From <strong>the</strong> outset <strong>of</strong> <strong>the</strong> review process, <strong>the</strong> onus shall be placed on <strong>the</strong> contractor to prove it’s stationkeeping case. The <strong>document</strong>ation table (Table 1) includes explanatory notes in order to clarify <strong>the</strong>standards expected. The <strong>Statoil</strong> Verification Model is illustrated in <strong>the</strong> diagram overleaf:-DP Drilling & Intervention Units Verification Model SchematicValidity area: Page 6 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20023.2 Documentation TableNo. Information requested at Pre-hire Verification Stage OPERATION CATEGORYA B C D1 DP control system <strong>document</strong>ation. Type, year fitted, s<strong>of</strong>tware versions a a a aFull details including year fitted, s<strong>of</strong>tware upgrade history, history <strong>of</strong>reference system interfacing and present spread. One line diagramincluding details <strong>of</strong> power supplies and upgrade history2Satellite based position references one line diagram and maintenance<strong>document</strong>ation, type, s<strong>of</strong>tware versions, maintenance recordsa a a aAs stated. Details <strong>of</strong> systems proposed on site should also besubmitted. Detailed performance analysis <strong>of</strong> diff links in use should beavailable to support coverage3 Hydroacoustic position references one line diagram and <strong>document</strong>ation a a a aOne line diagrams, details <strong>of</strong> beacons proposed, battery types andstatus. Copy <strong>of</strong> beacon log and maintenance records for previousperiod on DP.4 O<strong>the</strong>r reference systems (i.e. Tautwire) one line diagram and <strong>document</strong>ation a a a aAny o<strong>the</strong>r relevant position reference system material5Independent FMEA Study <strong>of</strong> complete unit including control, engineering andelectrical subsystemsa a a aHard copy <strong>of</strong> FMEA (latest version) should be submitted along withdescription <strong>of</strong> action list closeout response. This will be reviewed indetail.As a minimum, <strong>the</strong> vessel FMEA must meet IMCA & CEI/IEC 812 (85)standards and include failure mode proving analysis <strong>of</strong>:-Engineering auxiliariesElectrical HV including single worst case HV failureElectrical MVElectrical LVUPS systemsCooling systems (generation and thruster systems)Control and Service Air systemsFuel systemsLube systemsThruster failure modesThruster auxiliariesDP Control systemsMotion reference sensors, wind sensors & gyrocompassesSatellite based reference systems including diff link failure modesHydro acoustic based reference systemsCommunications methodsDP alert systemsAlarm printing methods (both DP and vessel management systems)Hardcopy <strong>document</strong> and closeout response requiredValidity area: Page 8 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002No. Information requested at Pre-hire Verification Stage OPERATION CATEGORYA B C D6 FMEA DP Control system (if separate report from No 5) a a a aAn FMEA produced by a Control system vendor shall be forinformation only and not acceptable as <strong>the</strong> Vessel FMEA required inpart 57 FMEA Proving trials report a a a aAs a minimum, <strong>the</strong> vessel FMEA Proving trials must meet IMCAstandards and include cause and effect proving analysis <strong>of</strong>:-Engineering auxiliariesElectrical HV including single worst case HV failureElectrical MVElectrical LVUPS systemsCooling systems (generation and thruster systems)Control and Service Air systemsFuel systemsLube systemsThruster failure modesThruster auxiliariesDP Control systemsMotion reference sensors, wind sensors & gyrocompassesSatellite based reference systems including diff link failure modesHydro acoustic based reference systemsCommunications methodsDP alert systemsAlarm printing methods (both DP and vessel management systems)Hardcopy <strong>document</strong> and closeout response required8 Annual DP trials for previous years on DP a a a aAnnual DP trials shall include tests which prove <strong>the</strong> failure modes in<strong>the</strong> following systems:-Engineering auxiliariesElectrical HV including single worst case HV failureElectrical MVElectrical LVUPS systemsCooling systems (generation and thruster systems)Control and Service Air systemsFuel systemsLube systemsThruster failure modesThruster auxiliariesDP Control systemsMotion reference sensors, wind sensors & gyrocompassesSatellite based reference systems including diff link failure modesHydro acoustic based reference systemsCommunications methodsDP alert systemsAlarm printing methods (both DP and vessel management systems)Hardcopy <strong>document</strong> and closeout response requiredValidity area: Page 9 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002No. Information requested at Pre-hire Verification Stage OPERATION CATEGORYA B C D9 DP Performance Trials report a a a aPlots carried out for drift <strong>of</strong>f and drive <strong>of</strong>f and station keeping analysisshowing operating performance in given environmental conditionsPerformance Analysis as follows1. Blackout (when environment ahead) time / distance and headingloss curves2. Blackout (when environment on beam) time / distance and headingloss curves3. Full power manual time / distance curve into environment (ahead)4. Full power manual time / distance curve perpendicular toenvironment (port / stbd)5. Full power manual time / distance curve away from environment(astern)10 DP Capability study report including failure modes <strong>the</strong>oretical plots a a a aPlots must include all intact and failure conditions for any HV networkset-up which may be used during operations. I.e If <strong>the</strong> unit is able tooperate without ALL thrust units online (6 <strong>of</strong> 8 for example) <strong>the</strong>n <strong>the</strong>failed case with reduced intact thruster capacity must also be simulatedAll plots must follow IMCA M141 Specification for DP Capability PlotsPlots generated by Control system vendors are not acceptable to meetthis requirement11 Classification Society Notation <strong>document</strong>ation a a a aHardcopy <strong>of</strong> Class Notation, expiry date and details <strong>of</strong> any outstandingConditions <strong>of</strong> Class12 ERN or equivalent notation report a a a aIf Classed using DNV notations, ERN number and calculation report13 FSVAD (MSC Circ 645) or equivalent compliance <strong>document</strong>ation a a a aAll vessels or units built post 1994 shall be requested to provide a FlagState Verification & Acceptance Document.14 Riser capability study for proposed waterdepth and riser configuration a a a a15Plots or similar analysis showing riser limitations with respect to water depth,tension, overall riser weight, moonpool contact and conductor limitations.a a a aRequirements contained in parts 15 and 16 are made in order to provethat effective guidance for Yellow and Red alerting is provided and isbased on accurate station keeping limitations within <strong>the</strong> equipmentused at <strong>the</strong> specific well.16 DP Incident reports and changes made as a result <strong>of</strong> cause analysis a a a aHard copies <strong>of</strong> all Yellow and Red Alert or o<strong>the</strong>r Incidents reportedduring DP operations shall be provided. Incident reporting shall include<strong>the</strong> following1. Details <strong>of</strong> instances and duration <strong>of</strong> DGPS (or diff. correctionlosses)2. Details <strong>of</strong> instances and duration <strong>of</strong> hydro-acoustic referencesystems losses3. Any Yellow Alert Report (must be completed using IMCA Standardreport form)4. Any Red Alert Report (must be completed using IMCA Standardreport form)5. Any HV electrical installation fault. Report (must be completedusing IMCA Standard report form)6. Any thruster failure. Report (using IMCA Standard report form)Validity area: Page 10 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002No. Information requested at Pre-hire Verification Stage OPERATION CATEGORYA B C D17Copies <strong>of</strong> IN COMMAND DP control system alarm printout for last 7 days <strong>of</strong>continuous DP operations to establish correct online recordinga a a aDetails <strong>of</strong> alarm and response definitions. The data requested in <strong>the</strong> blank18 Operational Limits Form should be completed on an individual well / locationbasis.a a a a19DP additional <strong>document</strong>ation, for example any upgrade <strong>of</strong> station keepingsystems in <strong>the</strong> previous yeara a a a20 DP Operations manual and onboard training schedules a a a a21 DP and ECR Pre-Operations and Periodical checklists proposed a a a a22Schedule <strong>of</strong> all assigned DP Operators certificates and merchant marinelicencesa a a a23 Schedule <strong>of</strong> all assigned Marine Engineers merchant marine licences. a a a a24 Copies <strong>of</strong> all additional DP training certification. I.e. simulator training a a a a25 Details <strong>of</strong> marine and engineering crews record <strong>of</strong> DP hours a a a a26Maintenance schedules covering well program period for equipment such asgenerators and thrusters.a a a aIt shall be <strong>the</strong> Contractors responsibility to inform <strong>Statoil</strong> <strong>of</strong> impendingmaintenance which will require any equipment to be unavailableincluding: Generation, thrusters, DP systems, cooling systems, Fuelpumps, lube pumps, reference systems, UPS’s.27DP Guidance <strong>document</strong>ation (Table 2 contains details <strong>of</strong> expected<strong>document</strong>ation to be held at DP Control location- existence to be verified).a a a aThe unit shall be provided with <strong>the</strong> guidance <strong>document</strong>ation listed inTable 2. There is no requirement to submit such guidance, <strong>the</strong>existence <strong>of</strong> <strong>document</strong>ation will be verified during <strong>the</strong> field arrival trialsprogress. Documentation requirements include, but shall not be limitedto those included in Table 2.28Outline <strong>of</strong> onboard vessel familiarisation and specific training required fornew key DP personnel. IMCA Guidelines Ref. 2a a a aSchedule <strong>of</strong> alerts, drills and familiarisation (DP specific) to be includedWhere National or International requirements for drilling departmentwell control drills are in place, such drills shall be inclusive <strong>of</strong> <strong>the</strong> DP,engineering and electrical departments. Evidence <strong>of</strong> combined drilling/ DP & engineering drills which simulate yellow and red alert conditionsshall be provided. Where no National or Contractor generatedstandards are made, <strong>the</strong> standards applicable on <strong>the</strong> Norwegian Shelfshould be followed and <strong>document</strong>ed as far as practicable.29Details <strong>of</strong> methods employed and fields recorded in dynamic positioningsystems datalogging facilitya a a aCopies <strong>of</strong> Class 3 checklist and details <strong>of</strong> all actions required to complete a30 Class 2 / Class 3 transition (if applicable) I.e. HV / ER segregation/ backupDP checklist etca a a aTable 1. Pre-hire DP Verification <strong>document</strong>ation for Drilling & Intervention UnitsValidity area: Page 11 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Item Ref. Documentation Title DateRef. 1: IMO Guidelines for vessels with dynamic positioning systems MSC / Circ. 645IMCAMay 94Ref. 2: 117 Training and Experience <strong>of</strong> Key DP Personnel - MSC Circ 738 IMCA Jan 96Rev 5GM-1611/01-0189-650, The guidelines for <strong>the</strong> design and operation <strong>of</strong>dynamically positioned vessels IMCA99Ref. 4: 119 Engine Room Fires on DP vessels IMCA Aug 97Ref. 5: 105 Failure modes <strong>of</strong> <strong>the</strong> Artemis position reference system IMCA (if fitted) Jul 92118 Failure modes <strong>of</strong> <strong>the</strong> Artemis positioning reference system IMCA (if fitted) May 94Ref. 6: 128/ QRA for <strong>the</strong> use <strong>of</strong> a dual DGPS system for dynamic positioning IMCA Feb 95141 Guidelines <strong>of</strong> <strong>the</strong> use <strong>of</strong> DGPS as a position reference in DP control systems IMCA Oct 97Ref. 7: 145 Review <strong>of</strong> three dual hydro acoustic position reference systems for deep waterdrilling IMCARef. 9: 125 Safety interface <strong>document</strong> for a DP vessel working near an <strong>of</strong>fshore platform.IMCAApr 98July 97Ref. 11 126 Reliability <strong>of</strong> electrical systems on DP vessels IMCA Feb 95IMCAS&L005Application <strong>of</strong> UK Safety Case Legislation to Specialist Vessels – Well ServicingNote 1Oct 00VarProceedings <strong>of</strong> IMCA Marine Division Station Keeping Seminars1993,4,5,6,7,8,9,2000, 2001 IMCA1998 Edition Deepwater Well Control Guidelines IADC 981998 No 9 OPL Series No 9 <strong>Dynamic</strong> <strong>Positioning</strong> OPL 98A538(13)IMO A.538(13) Maritime Safety Training for Personnel on Mobile OffshoreUnits.IMCADP Logbooks for operators including DPO’s, Marine Engineers and Electrical /Electronic Technicians (IMCA supplied)Note 1: Applicable to all vessels/units in Categories A, B & CTable 2. Onboard guidance <strong>document</strong>ation requirementsValidity area: Page 12 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002The unit shall be fitted with sufficient levels and types <strong>of</strong> equipment in order to safely conduct <strong>the</strong>proposed program. An assessment <strong>of</strong> <strong>the</strong> suitability <strong>of</strong> <strong>the</strong> unit for <strong>the</strong> proposed workscope will beundertaken when submission <strong>of</strong> relevant <strong>document</strong>ation has taken place.The number, type and performance requirements <strong>of</strong> each part <strong>of</strong> <strong>the</strong> vessels station keeping system aredefined in <strong>the</strong> operational requirements section.Deficiencies in <strong>document</strong>ation should not preclude <strong>the</strong> use <strong>of</strong> an individual unit, although <strong>Statoil</strong> maymake recommendations prior to engaging in operations. The vessel’s Alert procedure is an example <strong>of</strong>where changes may require to be made in order to satisfy <strong>Statoil</strong>’s requirements. It is expected that aprospective unit will have an alerting system which can function in <strong>the</strong> manner outlined.3.3 DP Capability Requirements (Category A)In order to safely conduct light well intervention operations, a Category A vessel or unit shall beequipped in order to provide <strong>the</strong> following minimum operational footprints.CATEGORY AMINIMUM INTACT DPCAPABILITYMONOHULL UNITSEMISUB UNITWind (10m/10s) 40 kts 40 ktsSig Sea Ht (Hs) 5.9m 5.9mWind Direction sector +/-30°around head +/-360°Resultant Current**Sum <strong>of</strong> surface and subsurface1.6 kts 1.6 ktsCurrent direction sector +/-30° around head +/-360°StatusRiser connected at well depthRiser connected at welldepthTable 3All figures include intact and single worst case failure condition.Both wind and current co-incidental figures.Vessels or units shall be equipped with sufficient thrust and redundancy in order to operate in <strong>the</strong>Green Status using DP Consequence Analysis ON without alarms for more than brief and isolatedperiods with heading is optimised into <strong>the</strong> prevailing environment.DP Capability plots using <strong>the</strong> IMCA standard format shall be produced which verify that <strong>the</strong>requirements table above can be achieved in both intact and worst case failure modes in all HVnetwork set-up conditions.3.4 DP Capability Requirements (Category B)In order to safely conduct light well intervention operations, a Category B vessel or unit shall beequipped in order to provide <strong>the</strong> following minimum operational footprints.Validity area: Page 13 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002CATEGORY BMINIMUM INTACT DPCAPABILITYMONOHULL UNITSEMISUB UNITWind (10m/10s) 40 kts 40 ktsSig Sea Ht (Hs) 5.9m 5.9mWind Direction sector +/-30°around head +/-360°Resultant Current**Sum <strong>of</strong> surface and subsurface1.6 kts 1.6 ktsCurrent direction sector +/-30° around head +/-360°StatusRiser connected at well depthRiser connected at welldepthTable 4All figures include intact and single worst case failure conditionBoth wind and current co-incidental figures.Vessels or units shall be equipped with sufficient thrust and redundancy in order to operate in <strong>the</strong>Green Status using DP Consequence Analysis ON without alarms for more than brief and isolatedperiods with heading is optimised into <strong>the</strong> prevailing environment.DP Capability plots using <strong>the</strong> IMCA standard format shall be produced which verify that <strong>the</strong>requirements table above can be achieved in both intact and worst case failure modes in all HVnetwork set-up conditions.3.5 DP Capability Requirements (Category C & D)DP capability is defined as <strong>the</strong> ability <strong>of</strong> <strong>the</strong> unit to hold station in certain environmental envelopes.Because monohull DP capability pr<strong>of</strong>iles differ from that <strong>of</strong> semisubmersible, requirements must beplaced in order that <strong>the</strong> unit has sufficient holding capability to withstand changes in resultantenvironmental loads. When considering a monohull vessel’s capability a sector <strong>of</strong> 60° (arc overhorizon <strong>of</strong> +/-30° ei<strong>the</strong>r side <strong>of</strong> <strong>the</strong> vessel head) is used. <strong>Statoil</strong>’s minimum levels <strong>of</strong> DP capabilityduring CONNECTED (Green Status) well operations is thus:-CATEGORY C & DMINIMUM INTACT DPCAPABILITYMONOHULL UNITSEMISUB UNITWind (10m/10s) 45 kts 45 ktsWind Direction sector +/-30°around head +/-360°Resultant Current**Sum <strong>of</strong> surface and subsurface2.0 kts 2.0 ktsCurrent direction sector +/-30° around head +/-360°AFTER WORST CASE FAILURE MONOHULL UNIT SEMISUB UNITWind (10m/10s) 35 kts 35 ktsWind Direction sector +/-30° +/-360°Resultant Current**Sum <strong>of</strong> surface and subsurface2.0 kts 2.0 ktsCurrent direction sector +/-30° +/-360°StatusDrilling riser connected atmaximum contract depthTable 5Drilling riser connected atmaximum contract depthValidity area: Page 14 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Both wind and current co-incidental figures. See example vessel plot.Vessels or units shall be equipped with sufficient thrust and redundancy in order to operate in <strong>the</strong>Green Status using DP Consequence Analysis ON without alarms for more than brief and isolatedperiods with heading is optimised into <strong>the</strong> prevailing environment.An important factor for monohull operations is <strong>the</strong> requirement <strong>of</strong> a minimum level <strong>of</strong> DP Capabilitywithin a 60° sector around <strong>the</strong> head. Minimum requirements will ensure that <strong>the</strong> vessel has sufficientcapability over this arc to react to changes in environmental conditions and be able to be maintained in<strong>the</strong> optimum heading. Semisubmersible requirements are also included in Table 5.To illustrate <strong>the</strong> requirement, <strong>the</strong> following monohull unit’s 1500m drilling DP Capability plot showscapability which complies with <strong>Statoil</strong>’s minimum criteria.Validity area: Page 15 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002SAMPLE UNIT 4 x Azi 2 x BT & 1 x ME / Active RudProven DPCapabilityminimumsector+/-30 deg DP cap45 kts (10m/10s) &Vc 2.0 kts (column)NOTE SAMPLE VESSELFOR GUIDANCE ONLY1500m Drilling case /riser connected IMCAstandard figuresValidity area: Page 16 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20023.6 Reference System RequirementsIn accordance with industry guidelines, <strong>Statoil</strong> require that at all times 3 independent positionreference systems shall be in use and actively selected at <strong>the</strong> main DP Control location. Thisrequirement is made for any operation irrespective <strong>of</strong> Class <strong>of</strong> operation. Any condition where anoperator cannot maintain 3 reference systems online (within performance criteria stipulated) shall beimmediately reported to <strong>the</strong> <strong>Statoil</strong> representative. The use <strong>of</strong> a Yellow or Red Alert may be requireddepending on <strong>the</strong> circumstances <strong>of</strong> <strong>the</strong> situation.The number, type and availability <strong>of</strong> effective position reference systems is an important factor in <strong>the</strong>provision <strong>of</strong> safe DP operations. For this reason, strict adherence to <strong>the</strong>se requirements shall befollowed. Table 6 below is used to add fur<strong>the</strong>r clarity to <strong>the</strong> requirements for position referencesystems which shall be fitted to a given unit.CATEGORYABCDWellWaterdepthDGPSinputsDiff linksDiff linksuppliersHydroacousticinputsTautwireinputs500m 2 3 2 2 0500m 2 3 2 2 0500m 2 3 2 2 0500m 2 3 2 2 0Table 6 Definition <strong>of</strong> Minimum <strong>Statoil</strong> Position Reference RequirementsAny DP unit undertaking drilling or intervention operations in waterdepth
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Input to DP ControlCATEGORYA,B,C,DDGPS SYSTEM 1DGPS SYSTEM 2Differential Corrections Minimum RequirementsMinimum fed with 3 separate means <strong>of</strong> reception <strong>of</strong> Differential Corrections.Sources must use separate Communications systems if satellite based. Oneradio based differential link must also be provided to augment Inmarsat oro<strong>the</strong>r satellite based differential links.Minimum fed with 3 separate means <strong>of</strong> reception <strong>of</strong> Differential Corrections.Sources must use separate Communications systems if satellite based. Oneradio based differential link must also be provided to augment Inmarsat oro<strong>the</strong>r satellite based differential links.Table 7 DGPS Differential corrections requirementsThere shall be provided 2 separate DGPS input buttons at <strong>the</strong> main DP Control system. When 2 inputsfor DGPS are used online, <strong>the</strong> differential corrections in use shall be separately provided. The Masteris responsible for ensuring requirements for reference system redundancy are met at all times and that<strong>the</strong> <strong>Statoil</strong> representative is informed immediately upon any degradation.In order for a particular position reference sensor to be considered effective, <strong>the</strong> device must becapable <strong>of</strong> providing sufficient positional accuracy and repeatability during trials. Performance testsshall require that each vessel position sensor be tested online as a single input to <strong>the</strong> active DP ControlSystem.3.7 Additional Equipment Requirements<strong>Statoil</strong> shall decide on additional requirements for active wave and / or current sensor devices on anindividual location / well basis. The requirements for wave (sea and swell) or current (watercolumn)recording devices may be waived where benign conditions <strong>of</strong> sea or current exist in a givengeographical location.Where a requirement for real-time recording <strong>of</strong> sea height and water column current is made at <strong>the</strong>well planning stage, <strong>the</strong> equipment fitted and data recorded shall be <strong>of</strong> a type accepted by <strong>Statoil</strong>.Verification <strong>of</strong> <strong>the</strong> systems, displays and data recording methods shall be made at <strong>the</strong> field arrivalstage as part <strong>of</strong> location set-up trials.3.8 Technology Development Requirements (Categories A, B, C & D)<strong>Statoil</strong> have adopted requirements for logging vessel operational data. Any contracted vessel or unitshould have <strong>the</strong> ability to log information in an electronic format. This information must be logged insuch a way that it can provide post event analysis <strong>of</strong> any station keeping incident and be used inconjunction with <strong>Statoil</strong>’s continued technology development purposes.The ability to record vessel, ocean, environmental and riser performance data forms <strong>the</strong> cornerstone <strong>of</strong><strong>Statoil</strong>’s continuing process <strong>of</strong> development and should be understood at <strong>the</strong> earliest stage by anycontractor.The requirements for datalogging contained in this section shall be made by <strong>Statoil</strong> on an individualwell or field location basis. The Contractor is responsible for listing all fields which can be logged aspart <strong>of</strong> <strong>the</strong> information requested at <strong>the</strong> pre-hire stage. This will be assessed against <strong>the</strong> itemscontained in Table 8. Upon request, each contractor shall provide electronic logging <strong>of</strong> ALL itemscontained in Table 8.Validity area: Page 18 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002The individual vessel or unit equipment supply will dictate what format <strong>the</strong> electronic data will take.The system should be capable <strong>of</strong> providing at least 7 days <strong>of</strong> previous data at any given time. Thisdata must be available in a simple manner without <strong>the</strong> requirement for time consuming analysis or dataacquisition. During a drilling or intervention program, <strong>the</strong> unit’s historical data should be submitted to<strong>the</strong> onboard <strong>Statoil</strong> representative weekly in ei<strong>the</strong>r CD or diskette formats.This data will be used primarily by <strong>Statoil</strong>’s development department.Information shall required to be electronically logged:-Item Required weekly electronic log <strong>of</strong> data.1 Well or subsea structure position2 Vessel or unit position (Satellite derived) setpoint and actual, reference weight3 Vessel or unit Position (Acoustically derived) setpoint and actual, reference weight4 Subsea vehicle position when in use (acoustically derived)5 Vessel or unit heading data, setpoint and actual6 Vessel or unit motion data (including pitch, roll and heave)7 Wind speed and direction from online sensorWave data (sea and swell). See earlier requirements for online system in certain8geographical locations.Current data (water column, upper and subsea data). See earlier requirements for9online system in certain geographical locations10 Slip joint stoke data. Requirement to log position and amplitude dataRiser tensioners, all types <strong>of</strong> system. Required to log each tensioner and total11tension applied.12 Riser restraint systems (where fitted to harsh environment units)13 Flex joint angles, upper, lower and intermediate (where fitted)14 Power generation and power consumption status15 Thruster status and power consumption (includes azimuth direction, power)Table 8 <strong>Statoil</strong> requirements for electronic dataloggingThe logging process and tests <strong>of</strong> <strong>the</strong> accuracy and validity <strong>of</strong> <strong>the</strong> data being recorded will be includedas part <strong>of</strong> <strong>the</strong> field arrival test procedure to be witnessed by <strong>Statoil</strong>. The nature <strong>of</strong> modern controlsystems fitted to <strong>the</strong> latest drilling units allows this data to be easily collected.3.9 Annual TrialsIn accordance with safe industry practice, where no acceptably <strong>document</strong>ed Annual or FMEA ProvingTrials have been completed within 1 year <strong>of</strong> <strong>the</strong> arrival at <strong>the</strong> field location, <strong>Statoil</strong> will requirecomprehensive Annual DP Trials be conducted. This shall include tests generated to simulate failuremodes within DP Control systems, reference systems, engineering, electrical, cooling, networking,communication or environmental systems and <strong>the</strong> response <strong>of</strong> key DP personnel. Where a unit iscontracted for periods greater than 1 year, an Annual DP Trial shall be performed. This shall beperformed no later than 3 months after <strong>the</strong> anniversary date <strong>of</strong> previous trials. This trial shall form <strong>the</strong>basis <strong>of</strong> risk identification and reduction potential.For all vessels or units intended to carry out drilling and / or intervention operations in <strong>the</strong> NWEuropean area <strong>the</strong> current edition <strong>of</strong> <strong>the</strong> UKOOA Guidelines “Auditing vessels with dynamicpositioning systems” Ref. Issue 2, September 1993 shall be <strong>the</strong> required standard. It shall be <strong>the</strong>contractors responsibility to independently verify trials and report non-conformances. All reports shallbe made available to <strong>Statoil</strong> upon request.Validity area: Page 19 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002For all o<strong>the</strong>r operations world-wide, in accordance with IMO Circ MSC 645 §5.1.2 <strong>the</strong> owner <strong>of</strong> <strong>the</strong>vessel / unit is entrusted to carry out Annual DP trials in accordance with a program accepted by <strong>the</strong>vessel’s Flag state administration. A Flag State approved trials program shall be submitted to <strong>Statoil</strong>.Where no acceptably <strong>document</strong>ed DP performance trials have been completed within 1 year <strong>of</strong> <strong>the</strong>arrival <strong>of</strong> <strong>the</strong> field location, <strong>Statoil</strong> require such trials to be completed after position references aredeployed and before any drilling equipment is connected subsea. This requirement is also made whereany modifications have been made to <strong>the</strong> vessels positioning equipment spread and no performanceanalysis has been performed. Examples <strong>of</strong> <strong>the</strong> format <strong>of</strong> DP performance trials accepted by <strong>Statoil</strong> areavailable upon request. The purpose <strong>of</strong> performance trials is to ensure that vessel systems areoptimised and that any deficiencies in redundancy or performance are established prior to beginninghazardous operations.3.10 Industrial experience transfer<strong>Statoil</strong> require that contractors are pro-active in <strong>the</strong> development and maintenance <strong>of</strong> good stationkeeping practices on <strong>the</strong>ir vessels and units. Contractors are encouraged to use <strong>the</strong> methods detailedbelow to allow effective experience transfer <strong>of</strong> operational knowledge:-• Effective incident reporting, investigation and closeout.• Membership and active participation <strong>of</strong> a recognised industry body such as IMCA, <strong>the</strong>International Marine Contractors Association.• Participation in performance indication and improvement schemes such as <strong>the</strong> IMCA Incidentreporting scheme through a competent person in <strong>the</strong> marine management structure.• Use <strong>of</strong> operational personnel in risk identification and assessment practices. Operational personnelassigned to a given vessel / unit shall take part in <strong>the</strong> WSOG limit setting exercise.4 Field arrival requirements4.1 Arrival TrialsTable 1 requires that previously <strong>document</strong>ed DP Trials be submitted at <strong>the</strong> pre-hire phase. In order tosatisfy <strong>Statoil</strong>’s additional requirements, field arrival trials shall be performed. These shall form part<strong>of</strong> standard operating procedures for any unit. In order to correctly verify <strong>the</strong> performancerequirements, <strong>the</strong> formal field arrival trials checklist shall include <strong>the</strong> following:-ItemAll DP Control systemsAll Reference systems 1Environmental systems including gyro, windand motion sensorsEngineering systemsElectrical systemsUPS checksCommunications systemsVentilation systemsAlarm systemsRiser sensorsWea<strong>the</strong>r forecasting processesDataloggingAlarm recordingRequirementsCheck all operational andGREEN Status requirementsfor number, type andperformance standards arefully achievedCheck forecasts availableCheck parameters as per <strong>Statoil</strong>s data recording criteriaCheck DP and ECR alarm printersValidity area: Page 20 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Table 9 Contents <strong>of</strong> field arrival checklist requirementsNote 1 Performance trials to verify <strong>the</strong> performance requirements for reference systems may beconducted upon set-up completion at a given location. Where additional trials are to be performedsuch trials shall be completed prior to any drilling equipment being connected subsea. Performancespecifications are included in <strong>the</strong> guidelines contained herein. Examples <strong>of</strong> equipment which may beincluded during ‘in-field’ performance trials are:-Each acoustic system’s accuracy and repeatability meets minimum requirements at a given site uponcompletion <strong>of</strong> set-up.Each satellite based sensor’s accuracy and repeatability meets minimum requirements at a given siteupon completion <strong>of</strong> set-up.Each additional reference system (i.e. tautwires, where fitted) provides adequate levels <strong>of</strong> performance.Check <strong>the</strong> correct functioning <strong>of</strong> alerting systems and communications systems.The field arrival process is designed to ensure that all <strong>the</strong> equipment fitted is both operational and fitfor purpose. Special attention may be paid to <strong>the</strong> performance <strong>of</strong> certain systems at a given location.This requirement is made in order to give <strong>Statoil</strong> sufficient confidence that <strong>the</strong> equipment has been setupcorrectly and that maximum performance possible is achieved prior to commencement <strong>of</strong>operations.Field arrival trials will be formally completed when all preparations have been made at a wellsite.This includes any location specific calibration or system adjustments which may be required tooptimise performance. The field arrival tests must be made based on <strong>the</strong> information contained in <strong>the</strong>well program which will indicate <strong>the</strong> vessel set-up PRIOR to arrival in field.4.2 ChecklistsField Arrival and operational checklists for both bridge and engine room shall be completed during <strong>the</strong>vessel set-up on location. Copies <strong>of</strong> <strong>the</strong> field arrivals and periodic checklists will be made available at<strong>the</strong> pre-hire phase. These should be completed formally and any deficiencies reported to <strong>Statoil</strong>.<strong>Statoil</strong> may witness field arrival trials and verify compliance against <strong>the</strong>se requirements. <strong>Statoil</strong> maymake recommendations for any items inclusion in <strong>the</strong> test programme where safety <strong>of</strong> <strong>the</strong> DPoperation is enhanced. Records shall be maintained for both field arrival and periodical checklists.5 Operational requirements5.1 DP Alert and communications systems (Category A, B, C & D)The system shall be provided with adequate redundancy. The initiation point for this alarm systemshall be located adjacent to <strong>the</strong> DP Control location.The lights shall be as follows:-¨• Steady green light to indicate vessel under automatic DP control, normal operational status andconfirming <strong>the</strong> Alert System is functional.• Flashing yellow light to indicate degraded DP control.• Flashing red light to indicate DP emergency.Hardcopy printouts <strong>of</strong> all Alert status changes between Green, Yellow and Red shall be provided by<strong>the</strong> Online DP Control systemAll alert systems shall be tested twice daily and records maintained. Checks shall also include use <strong>of</strong>internal telephone and talkback systemsValidity area: Page 21 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Each vessel or unit shall be fitted with a communication system which allows dedicated, open line,hands free and ‘upon demand’ voice communication between <strong>the</strong> main DP Control location and <strong>the</strong>driller’s / well operations console.5.2 DP Alerts (Category A)Well servicing / intervention operations in Category A shall make use <strong>of</strong> <strong>the</strong> standard Alerting regimeas described in §5.1. Alert lights / sirens shall be located in <strong>the</strong> following positions:-LOCATIONCATEGORYAMain DP Control locationaEngine Control RoomaWell Ops Control RoomaMasters CabinaDive Control (if applicable and using diver assist)aClient OfficeaROV Control RoomaAll deficiencies in equipment shall be reported to <strong>the</strong> <strong>Statoil</strong> Representative immediately5.3 DP Alerts (Categories B, C & D)Definitions <strong>of</strong> <strong>the</strong> various alerts applicable to Category B, C & D operations are contained herein. It isvital that <strong>the</strong> alert systems are effectively used throughout any drilling or intervention operations. Acontractor should assess its procedures against <strong>the</strong>se requirements.A system <strong>of</strong> lights and audible alarms should be used in a similar manner to o<strong>the</strong>r DP operations withaudible and visual indication in <strong>the</strong> following locations. Alerts shall be initiated at <strong>the</strong> Main DPControl location.Alert lights / sirens shall be located in <strong>the</strong> following positions:-LOCATIONMain DP Control locationEngine Control RoomDrill Floor (or well Ops Control)Cellar deck areasMasters CabinClients OfficeToolpusher or Well Ops Supt OfficeROV Control RoomCATEGORYB, C & DaaaaaaaaNote:For vessels / units <strong>of</strong> Categories B, C or D an additional status entitled Advisory Condition is used as apre-warning <strong>of</strong> changes in unit performance which have <strong>the</strong> potential for leading to higher alertconditions. The principle <strong>of</strong> safe and controlled operations suspension is encompassed in <strong>the</strong> overallphilosophy.Validity area: Page 22 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002GreenNormal operational status (green light). The vessel can be defined as connecting or connected to <strong>the</strong>sea bed in normal operational status when <strong>the</strong> following conditions apply:Vessel under DP control and DP system operating normally with appropriate back up systemsavailable.Thruster power and total power consumption is equal to or less that <strong>the</strong> maximum thrust and powerthat would be needed after <strong>the</strong> worst case single failure to avoid exceeding <strong>the</strong> critical excursion.Vessel’s indicated position and heading are within predetermined limits.Negligible risk <strong>of</strong> collision exists from o<strong>the</strong>r vessels.Recipients <strong>of</strong> Green ConditionGreen condition lighting at strategic locations around unit, no fur<strong>the</strong>rcommunications o<strong>the</strong>r than routine necessary.Advisory ConditionThe Advisory Status conditions are defined in <strong>the</strong> Well Specific Operating Guidelines Form (WSOG)included in this <strong>document</strong>. The purpose <strong>of</strong> this condition is to provide early warning <strong>of</strong> any changesoccurring which may lead to a heading or position problem and / or deteriorating wea<strong>the</strong>r conditions.The condition is designed in order that supervisory staff can assess any failure or loss <strong>of</strong> performanceagainst current and planned operations in order to make prudent changes to planned operations. Use <strong>of</strong><strong>the</strong> Advisory condition should be maximised: <strong>the</strong> conditions which apply are predefined by <strong>Statoil</strong>.The basic requirement is that where any DP related equipment fitted to a given unit fails or suffersperformance loss, <strong>the</strong> event shall be reported to Supervisory Staff.Recipients <strong>of</strong> Advisory Condition StatusDuty Senior DPO, Duty driller, Duty Marine Engineer, Master, Duty<strong>Statoil</strong> Representative, Duty well test Supt. (if appl.)Validity area: Page 23 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002YellowDegraded Operational Status (Yellow Alert). The vessel can be defined as being in a degradedoperational status when any <strong>of</strong> <strong>the</strong> following conditions applies:A failure in a sub-system has occurred leaving <strong>the</strong> DP system in an operational state (possibly afterreconfiguration) but with no suitable backup available, so that an additional fault would cause a loss <strong>of</strong>position.Vessel's position keeping performance is deteriorating and/or unstable.Vessel's indicated position deviates beyond limits determined during risk analysis or HAZOP withoutsimple explanation.Risk <strong>of</strong> collision exists from ano<strong>the</strong>r vessel.Approaching wea<strong>the</strong>r conditions are judged to be beyond present DP capability after allowing forworst case single failure.RedRecipients <strong>of</strong> Yellow AlertYellow Alert lighting and audible alerting. Duty Senior DPO, Duty driller,Duty Marine Engineer, Master, Duty <strong>Statoil</strong> Representative, Duty well testSupervisor (if applicable)Emergency Status (Red Alert). A vessel can be defined as in "Emergency Status" if any <strong>of</strong> <strong>the</strong>following conditions apply:System failure results in an inability to maintain position or heading control.Any external condition exists, including imminent collision, preventing <strong>the</strong> vessel maintainingposition.There is no time available for position recovery.Recipients <strong>of</strong> Red AlertRed Alert lighting and audible alerting. Duty Senior DPO, Duty driller,Duty Marine Engineer, Master, Duty <strong>Statoil</strong> Representative, Duty welltest Supervisor (if applicable)Validity area: Page 24 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002DP Alert Response requirementsThe following operational responses would be expected to <strong>the</strong> alert levels initiated by <strong>the</strong> DP Operator:Status NameGreen StatusAdvisory ConditionYellow AlertRed AlertActions / NotesNo action. Operations progress. Routinecommunications. Standard communicationsroutines apply.Informative status prior to issue <strong>of</strong> alarms. Usedby operational personnel to inform supervisors <strong>of</strong>certain changes taking place in <strong>the</strong> DP operation.The Advisory Condition has no lights or bells, ismerely a status condition achieved through use <strong>of</strong>internal telephone / comms systems.Degraded Operational Status; The drill floor shallstart preparing for a disconnection if operatingwith connection subsea. The senior DPO andduty driller shall confer and decide if any fur<strong>the</strong>raction is necessary or if operations can continue.Emergency status; Emergency disconnectsequence to be initiated. All necessary actionsrequired to prevent loss <strong>of</strong> life or damage toequipment or <strong>the</strong> environment shall be taken.Table 10 <strong>Statoil</strong> DP Drilling Status Definitions5.4 Incident PrioritiesIn general, <strong>the</strong> longer time available to a driller, <strong>the</strong> greater <strong>the</strong> level <strong>of</strong> preparation that can be made toeffect well control measures and secure <strong>the</strong> well. An accurate and clear transmission <strong>of</strong> facts isrequired between <strong>the</strong> DP Operator and <strong>the</strong> driller during any use <strong>of</strong> any alert condition.Where a DP Operator is in any doubt whatsoever as to <strong>the</strong> vessel’s position or station keepingperformance, he should, in <strong>the</strong> first instance use <strong>the</strong> YELLOW alert. The contractor must be awarethat <strong>the</strong> Advisory and Yellow Alert processes should be maximised in attempts to reduce <strong>the</strong>possibility <strong>of</strong> immediate (Red) Alert situations. Conversely, if a situation exists where loss <strong>of</strong> positionor heading is occurring and cannot be checked, immediate Red Alert should be initiated in order tomaximise <strong>the</strong> time available to <strong>the</strong> driller and possibility <strong>of</strong> successful disconnection.Priorities should be clearly established for dealing with a DP problem. The authority <strong>of</strong> <strong>the</strong> Master andDrilling Supervisor (Contractors) are <strong>of</strong> fundamental importance at such times (N.B. A red alert willonly involve <strong>the</strong> Master and / or drilling supervisor if <strong>the</strong>y are present at <strong>the</strong> DP control or drillfloorwhen alert is issued). They should co-operate closely on <strong>the</strong>se priorities so that <strong>the</strong>re is no room fordoubt or dissension and that <strong>the</strong> senior DP Operator and driller on duty at <strong>the</strong> time <strong>of</strong> an emergency actto <strong>the</strong> same priorities without undue hesitation. Priorities should take into account that: <strong>the</strong> safety <strong>of</strong>life is <strong>the</strong> first priority, - The Master has ultimate authority to assess and decide on courses <strong>of</strong> action inthis respect, but <strong>the</strong> advice <strong>of</strong> <strong>the</strong> Drilling Supervisor (Contractors) must be taken into account.As a guideline, <strong>the</strong> following information shall be assessed jointly by <strong>the</strong> <strong>Statoil</strong> Representative and<strong>the</strong> unit’s Master / Drilling Supervisor during any Advisory Condition.• Any position or heading performance loss as a result <strong>of</strong> alert cause• Wea<strong>the</strong>r conditions at time <strong>of</strong> alert• Drilling operation in progress at time <strong>of</strong> alertValidity area: Page 25 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002• Expected changes in work progress planned• Additional hazards presented as a result <strong>of</strong> alert• Assessment <strong>of</strong> additional wea<strong>the</strong>r forecasts which may be required• Time required to reach a safe situationAdditionally, for well intervention / testing operations:-• Well parameters• Equipment design limits• Consequences <strong>of</strong> failure5.5 <strong>Statoil</strong> DP Policy (Categories A, B, C & D)Where additional systems are fitted, for example a Class 3 certified unit, <strong>the</strong> policy is that any suchequipment shall be available at all times irrespective <strong>of</strong> class <strong>of</strong> operation. This policy realises thatwhen operating where full NMD Class 3 is not necessarily required, <strong>the</strong> related equipment shouldremain online and in use. This policy will reduce <strong>the</strong> need for procedural changes when conductingdrilling operations with differing legislative requirements.Where any requirements cannot be achieved in full it shall be <strong>the</strong> contractors responsibility to<strong>document</strong> that an equivalent level <strong>of</strong> safety, operability and redundancy is achieved using appropriatetechniques such as risk analysis.It shall be <strong>the</strong> contractors responsibility to inform <strong>Statoil</strong> <strong>of</strong> maintenance schedules relating to all DPassociated equipment in order that prior planning can be made. The purpose <strong>of</strong> this requirement is thatcertain equipment may be taken <strong>of</strong>fline during periods <strong>of</strong> lowest risk activities such as running riserwhere no subsea connection has been made.5.6 <strong>Statoil</strong> DP Policy (Categories B, C & D)Where any contracted DP drilling unit has been assigned Consequence Class 3, this mode <strong>of</strong> operationshall be <strong>the</strong> standard or ‘normal’ operating mode at all times. This follows <strong>Statoil</strong>’s policy <strong>of</strong>operating <strong>the</strong> unit in <strong>the</strong> safest mode possible. The requirements outlined for <strong>the</strong> definition and use <strong>of</strong>“Advisory Conditions” shall be completed and agreed prior to any operations. Any failure in any DPrelated systems must be reported which will allow Supervisory Staff to assess it’s effect on <strong>the</strong> unitsoverall station keeping capability. By <strong>the</strong> adoption <strong>of</strong> this policy, <strong>Statoil</strong> will have in place a system <strong>of</strong>continual risk assessment. This process includes both equipment breakdown and equipmentperformance deficiencies as identified in <strong>the</strong> WSOG (Well Specific Operating Guidelines) Form.Where, due to <strong>the</strong> nature <strong>of</strong> <strong>the</strong> drilling operation proposed or geographical location, a drilling unitcertified to Consequence Class 2 is contracted, <strong>the</strong> risk control process outlined shall be adopted asclosely as possible. The process <strong>of</strong> identification and use <strong>of</strong> green, advisory, yellow and red limitsshall be carried out prior to <strong>the</strong> commencement <strong>of</strong> operations.<strong>Statoil</strong>’s position is that Class changes, i.e. from 2 to 3 shall NOT be undertaken during riserconnected drilling operations where any conditions exist which may make this transition less safe.Where an individual well program contains operations where full Class 3 is a requirement, <strong>the</strong>transition between Class 2 and 3 shall be undertaken in good time and additional checklists completed.Any changes required involving additional risk, i.e. HV (high voltage) network subdivision, shall onlybe conducted following a risk analysis process such as SJA (Safe Job Analysis). The Contractor shallprovide details <strong>of</strong> it’s Class 2 and 3 set-up at <strong>the</strong> pre-hire stage. This should clearly <strong>document</strong> actionsrequired for <strong>the</strong> transition between Class 2 and 3 including copies <strong>of</strong> checklists in use on an individualunit.Validity area: Page 26 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002It shall be <strong>the</strong> Contractors responsibility to inform <strong>Statoil</strong> <strong>of</strong> all maintenance being carried out at anygiven time in order that this information is available when planning future well activities. Thisrequirement does not alter <strong>the</strong> necessity to make use <strong>of</strong> <strong>the</strong> Advisory Condition where any failure <strong>of</strong>loss <strong>of</strong> performance has, or is occurring.5.7 Reporting (Categories A, B, C & D)No part <strong>of</strong> <strong>the</strong> reporting structure shall detract from individual responsibilities given to operationalstaff when situations arise where immediate action is required.Where equipment failure is such that loss <strong>of</strong> position is <strong>the</strong> outcome or possible outcome, nothing in<strong>the</strong>se requirements shall change <strong>the</strong> overriding responsibility <strong>of</strong> <strong>the</strong> operational personnel to takewhatever action is <strong>the</strong>n required. Immediate use <strong>of</strong> ei<strong>the</strong>r Yellow or Red shall be made where <strong>the</strong>immediacy <strong>of</strong> <strong>the</strong> situation requires such action.Equipment failureDP Control systemReferencesystemsWind sensorsMotion sensorsGyrocompassesCommunications systemsThrusterThruster controlPower generationElectrical distributionPower management systemFuel transfer or supply systemCooling systemsDP Capability &Consequence AnalysisNotesAny failure including network, operator station, interface units,Any failure including DGPS, acoustics, Inmarsat, demodulators,antennae, transponders, transceivers, processors, power suppliesAny loss <strong>of</strong> performance in any system where that system cannotbe selected as an effective position measuring device into <strong>the</strong>control systemAny failure or performance lossAny failure or performance lossAny failure or performance lossAny system fitted including telephone, backup systemsAny failure, including redundant or auxiliary equipmentAny failure, including redundant equipmentAny failure, including redundant equipmentAny failure, including redundant equipmentAny failure, including redundant equipmentAny failure, including redundant equipmentAny failure, including redundant equipmentAny Consequence Analysis alarm active for more than brief andisolated periods (>1 minute duration)Table 11 Reporting scheduleFor work Category A <strong>the</strong> contractor shall provide details <strong>of</strong> <strong>the</strong> reporting processes in place and provethat accurate vessel / unit operational status information is made available to Clients as soon aspossible after each event. The use <strong>of</strong> <strong>the</strong> WSOG form is recommended for this purpose.Any unexpected failure <strong>of</strong> any DP related system shall be logged in a DP status report in order thatperformance data can be collected for <strong>Statoil</strong>’s incident research requirements. This requirement isirrespective <strong>of</strong> which alert condition has been used. All alert status changes shall be formallyrecorded. All alarm or status printers (including machinery monitoring) fitted shall be operational atall times.Validity area: Page 27 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002The Master shall be responsible for ensuring that equipment failure information is made available toon duty <strong>Statoil</strong> Representative within a reasonable timeframe and in no cases more than 15 minutesafter any failure or occurrence. A system should be in place where <strong>the</strong> DP Operator is aware <strong>of</strong>failures in any engineering systems and that no failure or equipment (and / or redundant equipment)goes unreported. Additionally, any loss <strong>of</strong> redundancy or any Yellow or Red Alert condition shall bereported - post event, using <strong>the</strong> standard IMCA Incident Report Form or equivalent which shall bemade available to <strong>Statoil</strong> upon completion Ref. §5.9 Management.Although it shall be <strong>the</strong> contractors responsibility to complete and promulgate DP Incident reports, <strong>the</strong><strong>Statoil</strong> Representative onboard will take an active roll in ensuring full compliance with <strong>the</strong>serequirements.A program <strong>of</strong> alert drills shall to be undertaken, aimed at training and maintaining a competent team tocope with emergencies. Where well control drills are required, <strong>the</strong> DP, engineering and electricaldepartments shall be included. Realistic drills which familiarise operators in <strong>the</strong> use <strong>of</strong> <strong>the</strong> variousalerts shall be conducted and <strong>document</strong>ed. These drills shall be inclusive <strong>of</strong> all personnel havinginvolvement in an actual alert condition.<strong>Statoil</strong> reserve <strong>the</strong> right to request suspension <strong>of</strong> operations and preparations for disconnection in anysituation where <strong>the</strong> Senior onboard Representative feels that continued operations may represent actualor potential danger to personnel, equipment or <strong>the</strong> environment.5.8 Reporting (Categories A, B, C & D)An equipment failure or performance failure shall be reported in <strong>the</strong> manner described. <strong>Statoil</strong> shall beinformed immediately when any equipment failure takes place even if <strong>the</strong> failure has no immediateeffect on position or heading control. For operations in operations in Categories B, C & D, <strong>the</strong>Advisory Condition shall be used. The Advisory Alert conditions shall be included in <strong>the</strong> WellSpecific Operating Guidelines Form (WSOG) which shall be completed, agreed and signed <strong>of</strong>f by<strong>Statoil</strong> and <strong>the</strong> contractor prior to operations commencement.The nature <strong>of</strong> any failure, it’s immediate effect, and it’s effect on forthcoming operations will beestablished by both <strong>Statoil</strong> and <strong>the</strong> Contractor’s senior onboard Representative. The informationprovided in <strong>the</strong> WSOG shall be used as guidance for operational staff when deciding to suspend orcontinue operations.If required, it may be necessary to proceed to a formal assessment <strong>of</strong> <strong>the</strong> situation which shall beentitled an SJA or Safe Job Analysis. Details <strong>of</strong> such systems and examples <strong>of</strong> <strong>the</strong> <strong>document</strong>ationshall be provided to <strong>Statoil</strong> before operations commence.5.9 Management & Event CloseoutAll Contractors shall be required to comply with IMO Resolution A.741(18) §5.2 regarding Master’sresponsibility. “The Company should ensure that <strong>the</strong> SMS operating on board <strong>the</strong> ship contains a clearstatement emphasising <strong>the</strong> Master's authority. The Company shall establish in <strong>the</strong> SMS that <strong>the</strong> Masterhas <strong>the</strong> overriding authority and <strong>the</strong> responsibility to make decisions with respect to safety andpollution prevention and to request <strong>the</strong> Company's assistance as may be necessary”.The contractor shall identify a qualified individual within it’s management structure with responsibilityfor DP incident and occurrence investigation and closeout.All liaison regarding station keeping related matters shall be made between <strong>the</strong> Master, <strong>the</strong> onboard<strong>Statoil</strong> Representative and <strong>the</strong> nominated person within <strong>the</strong> contractors management.Each Yellow or Red Alert incident analysis Report shall include <strong>the</strong> following information:-Validity area: Page 28 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002INFORMATION REQUIREDEvent timetable in detailWea<strong>the</strong>r conditions during IncidentPosition (initial and final)Heading (initial and final)Summary <strong>of</strong> eventsSummary <strong>of</strong> consequencesTechnical causesIMCA Incident Report Form (Yellow & Red)Lost time analysisCloseout action, date and responsible personManagementAll DP related events including Yellow and red alert event investigations shall be investigated and allreports made available to <strong>Statoil</strong>. Reports shall be supplemented by electronic data which shall bemade available to <strong>Statoil</strong> upon request.5.10 Well Specific Operating Guidelines (WSOG)The Well Specific Operating Guidelines (WSOG) Form lists guidelines for <strong>the</strong> issue <strong>of</strong> <strong>the</strong> variousAlert status requirements. The form shall be used as guidance for contractors. A blank WSOG Formis enclosed in §5.12. The blank form should be completed by <strong>the</strong> contractor and agreed upon prior to<strong>the</strong> commencement <strong>of</strong> any drilling and / or intervention programme in categories B, C or D. CategoryA operations are also recommended to use <strong>the</strong> WSOG format.5.11 Well Specific Operating Guidelines Notes and Sample FormDrift / Drive / Force Off and Footprint limitationsThe following guidance table in included in order to assist Contractors in <strong>the</strong> limit setting exercise for<strong>the</strong> drift / drive and force <strong>of</strong>f cases. The table below shows Category versus waterdepth and includesdistances for <strong>the</strong> various Alert levels set during previous well operations.Key ConditionA Advisory StatusY Yellow Alert ConditionR Red Alert ConditionDistances are metres from ZAP (vessel wanted / setpoint position)Validity area: Page 29 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002WDCATAB, C, D1000mY R Y R Y R6 8 8 10 10 12A Y R A Y R A Y R A Y R A Y R5 6 8 5 8 12 5 10 15 5 12 20 5 14 25CC, DADDITIONAL NOTES: Completion Operations Category “C”. Standard <strong>of</strong>fset limits appliedduring BOP connected drilling operations ARE constrained by available stroke length <strong>of</strong> <strong>the</strong>top drill string compensator. A full assessment <strong>of</strong> <strong>the</strong> time requirements and hence Advisory,Yellow and Red limiting <strong>of</strong>fset distances is required in <strong>the</strong>se operations.ADDITIONAL NOTES: All heavy intervention and drilling / completion operations. A completeassessment <strong>of</strong> <strong>the</strong> site, vessel, equipment, downhole tool characteristics, potential and effect<strong>of</strong> loss <strong>of</strong> position shall be made in order to assess <strong>the</strong> appropriate distances at which to setAdvisory, Yellow and Red Alert conditions.Figures included above are for guidanceUnit Offset from ZAP Position (m)1501401301201101009080706050403020100200230260STATOIL - DP REQUIREMENTS - OPERATING LIMITS WD 200+m MSLCATEGORY B, C, DOperating Limits200-350m Y 8m R 12m350-600m Y 10m R 15m600-1000m Y 12m R 20m>1000m Y 14m R 25m290320350380410440470500Well waterdepth (MSL)8 deg6 deg4 deg2 deg530560590620650680710740770800830860890920950Validity area: Page 30 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore980
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Example <strong>of</strong> estimating safe disconnect time :Using <strong>the</strong> figure above, for a Category “D” Drilling operation planned at 380m MSL waterdepth. Avertical line is drawn onto <strong>the</strong> diagram above.Well using <strong>the</strong> WSOG guidelines, Yellow Limit is set 10m and Red limit is set at 15m. For a standarddrilling BOP and riser system, a disconnect will require to be completed before lower flex joint anglereaches 8° (maximum <strong>the</strong>oretical). In a linear system, this corresponds to a horizontal distance <strong>of</strong> 53mfrom Zero Angle position (if well centre). In all circumstances, <strong>the</strong> time to disconnect shall be verifiedas being LESS than <strong>the</strong> time required to exceed a 53m <strong>of</strong>fset from initial position. Scenarios to beassessed shall include a full 100% drive-<strong>of</strong>f away from environment with all thrusters online, and a fullblack-out drift-<strong>of</strong>f scenario. Time and distance shall be assessed with full regard to <strong>the</strong> followingvariables :• Physical limitations <strong>of</strong> upper, lower and / or intermediate flex joints• Contact with moonpool and /or BOP guidance or riser restraint systems• Limitations / stroke availability within riser tensioners and top compensating systems• Changes in mudweight and tension throughout <strong>the</strong> drilling program• Riser and rig motions in deteriorating environmental conditions• Time requirements to disconnect BOP for each part <strong>of</strong> <strong>the</strong> well programDistances will not be linear as waterdepth increases <strong>the</strong>refore <strong>the</strong>se notes shall be used as guidanceonly.Validity area: Page 31 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Well Specific Operating Guidelines (WSOG) Category A, B, C, DUnit/Vessel: Deepwater X Well: SAMPLE Operator: STATOILCondition Green Advisory Yellow RedANY DP INCIDENTBLACK-OUT <strong>of</strong> ALL HVNETWORKSDRIVE OFF Incident orDRIFT OFF Incident orFORCE OFF IncidentUnit <strong>of</strong>fset deviation fromstart pointWaterdepth: 380 metres6.5 metresOR Immediately whenrecognised by DPOImmediatelyImmediately whenconfirmed that situationcannot be controlled orNOT > 11 metresINTACT DPSYSTEMDP position footprint < 5 metres > 5 metres 10 metres 15 metresDP heading footprint < 2 deg 2-3 deg If threat to position If threat to positionPower consumption eachnetwork (3-split configuration)Thrust consumption each onlineunit.Position reference availableDP control system (includingIAS- DP controllers)< 50% Any PMS warnings.< 50%Thruster & PMSWarnings3 independent Loss <strong>of</strong> a system or2 + 1 backupWind sensors 3 2Motion sensors (MRU) 3 2Heading sensors (Gyro) 3 2DP-UPS 3 2IAS SystemComms systemsNo controllers ornetwork alarms3 systemperformance limitationAny failure or loss <strong>of</strong>performance in anysystemLoss <strong>of</strong> one networkor one <strong>of</strong> redundantcontrollers/servers1 system notoperating>70% or loss <strong>of</strong> onepower station +Consequence alarmConsequence alarmSituation specificSituation specific2 (situation specific) If threat to position1 or loss <strong>of</strong> failure <strong>of</strong>backup controller1 or loss <strong>of</strong> backupwind sensor (stb.aft)1 or loss <strong>of</strong> backupMRU (No. 1)2 or loss <strong>of</strong> backupgyro (No.1)2 or loss <strong>of</strong> backupUPS (No.1)Loss <strong>of</strong> 2 <strong>of</strong> <strong>the</strong>redundant controllers/server in any systemSituation specificLoss <strong>of</strong> all system orunable to maintainpositionIf threat to positionIf threat to positionIf threat to positionIf threat to positionIf threat to positionSituation specificRiser limitation UFJ 0-1.5 deg 2 deg Situation specific Situation specificRiser limitation LFJ 0-1.5 deg 2 deg > 2 deg 4 degWind speed (10m/10s) 0-20 m/s 20 m/s Situation specific Situation specificWind direction Situation specific Situation specific Situation specific Situation specificSign. waveheight 0-4 m 5 m Situation specific Situation specificRiser twist+/- 17 deg fromBOP landoutSlip ring / Slip joint Fully operable Any failure or problemAction requiredNormal status>17 deg advice <strong>Statoil</strong> Situation specific Situation specificAdvise Master, Driller,Toolpusher, <strong>Statoil</strong>Rep.Issue alarm andfollow proceduresIssue alarm andfollow proceduresNotify OIM immediately (Y/N) Yes Yes YesNotify <strong>Statoil</strong> immediately (Y/N) Normal condition Yes Yes YesValidity area: Page 32 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Note: All distances included above are in metres. Figures do not relate to <strong>the</strong> geographical wellposition, but to <strong>the</strong> ZAP position (Zero Angle Position). This position is chosen and adjusted by <strong>the</strong>DP Operator in order to reduce wear on <strong>the</strong> BOP and tree when running equipment into <strong>the</strong> well. Allnoted figures are <strong>the</strong>refore from Start (ZAP) position, whichever that position is at a given time.Note: This WSOG is valid inside 100 metres from <strong>the</strong> wellhead / spudding or subsea facility positionWell Escape way: Clear escape route 50 m direction ____ degreesSigned on behalf <strong>of</strong> Contractor: ___________Signed on behalf <strong>of</strong> <strong>Statoil</strong>: ____________General NotesLimits are maximum figures and are used as guidelines. Any action may be initiated PRIOR toreaching limits at <strong>the</strong> discretion <strong>of</strong> <strong>the</strong> relevant Supervisory staff. These figures are general and shouldbe corrected jointly (<strong>Statoil</strong> and contractor) in <strong>the</strong> earliest stages <strong>of</strong> operations in <strong>the</strong> light <strong>of</strong>experience <strong>of</strong> an individual units performance. The WSOG shall for <strong>the</strong> basis <strong>of</strong> <strong>the</strong> units Alertingstrategy and is designed to be iterative in <strong>the</strong> light <strong>of</strong> operational experience.Note 1Any situation where loss <strong>of</strong> position is occurring or potential for loss <strong>of</strong> position exists shall require <strong>the</strong>DPO to issue <strong>the</strong> warning alert most appropriate under <strong>the</strong> circumstances. The vessels INTACT (Allthrusters & all available power online) DP Capability Plot shall be used to define <strong>the</strong> Yellow Alertcircle. The example below shows an actual test footprint in <strong>the</strong> intact (all thrusters) case during <strong>the</strong>maximum working conditions (H s 6.7m). Wherever footprints exceed this level <strong>the</strong>n by definition anAlert condition exists.Validity area: Page 33 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002CLASS 3 DP SEMIMAX FOOTPRINT Hs 6.7mAPPROX 10mINTACT DP THRUST CASE10 metresFOR INFORMATION ONLYNote 2The 5 minute average heading deviation (from setpoint) limits are designed to ensure that alertingoccurs whenever any heading instability is experienced. The Advisory Condition (informative fordriller, Master, <strong>Statoil</strong>) should be made when heading instability) is seen. Heading setpoint error canbe viewed using trend pages installed in s<strong>of</strong>tware in <strong>the</strong> DP Control system. Notwithstanding <strong>the</strong>above note, <strong>the</strong> DP Operator should issue a cautionary yellow alert if heading instability becomes suchthat a threat to <strong>the</strong> unit’s position exists.Validity area: Page 34 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20025.12 Well Specific Operating Guidelines (WSOG) Form (Blank)Well Specific Operating Guidelines (WSOG) Category A, B, C, DUnit/Vessel: Deepwater X Well: SAMPLE Operator: STATOILCondition Green Advisory Yellow RedANY DP INCIDENTBLACK-OUT <strong>of</strong> ALL HVNETWORKSDRIVE OFF Incident orDRIFT OFF Incident orFORCE OFF IncidentUnit <strong>of</strong>fset deviation fromstart pointWaterdepth: ___ metresINTACT DPSYSTEMDP position footprintDP heading footprintPower consumption eachnetwork (__ split configuration)Thrust consumption each onlineunit.Position reference availableDP control system (includingIAS- DP controllers)Wind sensorsMotion sensors (MRU)Heading sensors (Gyro)DP-UPSIAS SystemComms systemsRiser limitation UFJRiser limitation LFJWind speed (10m/10s)Wind directionSign. waveheightRiser twistSlip ring / Slip jointAction requiredNormal statusAdvise Master, Driller,Toolpusher, <strong>Statoil</strong>Rep.Issue alarm andfollow proceduresIssue alarm andfollow proceduresNotify OIM immediately (Y/N)Notify <strong>Statoil</strong> immediately (Y/N)Note: This WSOG is valid inside 100 metres from <strong>the</strong> wellhead / spudding or subsea facility positionWell Escape way: Clear escape route xxx m direction ____ degreesSigned on behalf <strong>of</strong> Contractor:Signed on behalf <strong>of</strong> <strong>Statoil</strong>:Validity area: Page 35 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20026 Well Testing6.1 GeneralThe WSOG protocol defined herein shall be used in a DP operational HAZOP during <strong>the</strong> planning <strong>of</strong>welltest operations from any dynamically positioned unit. The WSOG used for standard E or Pdrilling operations may be used and amended with standing instructions. Standing instructions whichare agreed at <strong>the</strong> operational HAZOP may include, but not be limited to:-1. DST WSOG to be initiated at time <strong>of</strong> start <strong>of</strong> running subsea test tree to allow green operatingstatus to be revised and unit reconfigured2. No OSV operations as a result <strong>of</strong> increased risk <strong>of</strong> acoustic reference system interference3. No routine helicopter operations as a result <strong>of</strong> increased risk <strong>of</strong> loss <strong>of</strong> position in <strong>the</strong> event <strong>of</strong>wind sensor disturbance.4. Additional or revised wea<strong>the</strong>r limitations as required dependant on <strong>the</strong> nature <strong>of</strong> <strong>the</strong> welltest.5. Restrictions in ROV operations if required.A separate well test WSOG should be produced from a DP operational HAZOP early in <strong>the</strong> planningphase. Additional guidance notes for event alert handling between <strong>the</strong> DPO, driller and welltestSupervisor will require to be established. Onboard training in <strong>the</strong> agreed welltest WSOG is an areawhere additional risk reducing measures may exist.7 References7.1 GeneralApplicability <strong>of</strong> Coastal state regulations are defined in NORSOK J-003, Marine Operations and shallbe read as follows:• Flag state and classification Rules apply to <strong>the</strong> vessels hull, stability, machinery, mooring and o<strong>the</strong>rmarine systems.• Coastal state regulations, such as NPD regulations, apply to drilling and well systems, <strong>the</strong> relatedwork environment, and general management systems.7.2 Regulatory acts and regulationsRelevant regulations stipulated by <strong>the</strong> Norwegian Petroleum Directorate and <strong>the</strong> Norwegian MaritimeDirectorate (for Norwegian flagged vessels and vessels carrying an NMD Letter <strong>of</strong> Compliance) apply.Validity area: Page 36 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Norwegian RegulationsAuthorityNMDNMDNVEStandardRegulations for Mobile Offshore Units, laid down by <strong>the</strong> NorwegianMaritime Directorate (NMD)Norwegian Ship Control Rules, issued by NMDFEA-M1990: Regulations for Electrical Installations - MaritimeInstallations.International Regulations, Codes and StandardsAuthorityStandardSOLAS-74/78 International Convention for Safety <strong>of</strong> Life at Sea (SOLAS) 1974,modified by <strong>the</strong> protocol <strong>of</strong> 1978MODU CODE Code for <strong>the</strong> Construction and Equipment <strong>of</strong> Mobile Offshore DrillingUnits. International Maritime Organisation (IMO) Resolutions A.649(16). Refer to §4.12 <strong>Dynamic</strong> <strong>Positioning</strong> systems.IMO MSC Circ. 645 Guidelines for <strong>the</strong> Design and Operation <strong>of</strong> <strong>Dynamic</strong>ally PositionedVesselsIMO MSC Circ. 738 The Training & Experience <strong>of</strong> Key DP PersonnelMARPOL 73/78 International Convention for <strong>the</strong> Prevention <strong>of</strong> Pollution from Ships1973, as modified <strong>the</strong> by Protocol <strong>of</strong> 1978IMO A.469 (XII) Guidelines for <strong>the</strong> Design and Construction <strong>of</strong> Offshore Supply VesselsLoad Lines 1966 International Conference on Load Lines, 1966Tonnage 1969 International Conference on Tonnage Measurement <strong>of</strong> Ships, 1969COLREGConvention on <strong>the</strong> International Regulations for Preventing Collisions atSea, 1972IMO A.680 (17) IMO Guidelines on Management for <strong>the</strong> Safe Operation <strong>of</strong> Ships and forPollution PreventionSTCWInternational Convention on Standards <strong>of</strong> Training, Certification andWatchkeeping for Seafarers, 1978IMO A.481 (XII) Principles <strong>of</strong> Safe ManningIMO A.538 (13) Maritime Safety Training <strong>of</strong> Personnel on Mobile Offshore Units7.3 Standards and specificationsThe guidelines contained in IMO MSC / Circ. 645, Guidelines for Vessels with <strong>Dynamic</strong> <strong>Positioning</strong>Systems and IMCA (International Marine Contractors Association) Guidelines for <strong>the</strong> Design andOperation <strong>of</strong> <strong>Dynamic</strong>ally Positioned Vessels (Report GM-1611/01-0189-650 as amended) areadopted. These requirements are designed to ensure that adequate equipment is always available andthat safety benefits <strong>of</strong> duplicate or triplicate equipment are maximised during operations involving <strong>the</strong>highest level <strong>of</strong> risk. The standards <strong>of</strong> training and certification for DP operations shall be derivedfrom <strong>the</strong> IMCA <strong>document</strong> “The Training & Experience <strong>of</strong> Key DP personnel” Ref M117, Jan 1996) aswell as IMO MSC. Circ 738.Wherever any relevant flag state, national or international regulations are updated an amendment <strong>of</strong><strong>the</strong>se requirements may be made based on <strong>the</strong> nature <strong>of</strong> <strong>the</strong> changes.The broad requirement is that any unit must always operate in <strong>the</strong> safest mode possible however, notall DP related equipment must be available all <strong>the</strong> time for all operations. These requirements seek tocontrol risk by defining safe limits prior to <strong>the</strong> commencement <strong>of</strong> DP drilling operations.Validity area: Page 37 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore
<strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>DP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002These requirements reflect <strong>the</strong> current legislative requirements and guidance available for operations inareas where <strong>the</strong> Norwegian national legislative framework applies. The minimum consequence classacceptable shall be determined on a well or contract specific basis but shall not be less than IMOEquipment Class 2 for any given vessel or unit irrespective <strong>of</strong> geographical location.In any location world-wide where no DP related national legislation is enforced, <strong>the</strong> most currentedition <strong>of</strong> IMCA’s Guidelines for <strong>the</strong> Design and Operation <strong>of</strong> <strong>Dynamic</strong>ally Positioned Vessels (Jan00 - Report GM-1611/01-0189-650 as revised) shall apply. The guideline for drilling units to beequipped and operated with a minimum <strong>of</strong> Consequence Class 2 shall be a <strong>Statoil</strong> requirement.<strong>Statoil</strong>’s requirements for Class 3 operations world-wide, in locations o<strong>the</strong>r than those on <strong>the</strong>Norwegian Continental Shelf shall be made on an individual well, area or unit basis.No part <strong>of</strong> <strong>the</strong>se requirements detract from or diminish <strong>the</strong> significance <strong>of</strong> any Norwegian Maritime orPetroleum Directorate standards in force when operating a vessel or unit on <strong>the</strong> Norwegian ContinentalShelf.Using <strong>the</strong> protocols outlined in this <strong>document</strong>, vessel or unit operators shall be requested to provetechnical integrity for <strong>the</strong> positioning equipment as well as competence in operational management.The NORSOK standard defines <strong>the</strong> basic requirements to vessels performing marine operations, to <strong>the</strong>planning, execution and work associated with such operations on <strong>the</strong> Norwegian Continental Shelf.The detail <strong>of</strong> relevant standard contained in J-003 Rev 2 Marine Operations have been included herein.The following standards and specifications with <strong>the</strong>ir respective normative references apply:NORSOK D001NORSOK D002NORSOK D010NORSOK J003Drilling facilitiesSystem requirements well intervention equipmentDrilling and well operationsMarine operationsDP Audit standards are adopted. <strong>Statoil</strong> adopt and conform to <strong>the</strong> 1993 UKOOA <strong>document</strong>“Guidelines for Auditing Vessels with <strong>Dynamic</strong> <strong>Positioning</strong> Systems” (112 UKOOA). The UKOOA<strong>document</strong> provides guidance on <strong>the</strong> qualifications / experience required <strong>of</strong> a Competent Auditor aswell as notes on trials requirements.7.4 <strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>ationThe following <strong>Statoil</strong> <strong>governing</strong> <strong>document</strong>ation apply:“Drilling, Well & Production Activities” (AR03) (<strong>Statoil</strong> Group/All locations/On- and <strong>of</strong>fshore)“Marine Operations” (AR08) (<strong>Statoil</strong> Group/All locations/On- and <strong>of</strong>fshore)“Dispensations to and improvements <strong>of</strong> <strong>governing</strong> <strong>document</strong>s” (WR0011) (<strong>Statoil</strong> Group/Alllocations/On- and <strong>of</strong>fshore)Validity area: Page 38 <strong>of</strong> 38<strong>Statoil</strong> Group / All locations / On- and <strong>of</strong>fshore