Statoil governing document - Dynamic Positioning Committee of the ...

Author’s Name Name of the Paper SessionPDynamicPositioningCommitteeMarine Technology SocietyDYNAMIC POSITIONING CONFERENCESeptember 17-18, 2002IntroductionDP Requirements for Drilling andIntervention UnitsBjørn AbrahamsenStatoil (Stavanger)

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical RequirementsTR1029, Version 1, Valid from 01.09.2002Validity area:Statoil Group / All locations / On- and offshoreSignatures 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 Statoil DP Policy (Categories A, B, C & D).....................................................................................265.6 Statoil 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 Statoil governing documentation ......................................................................................................38

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20021 IntroductionThis document lists the types of 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 of 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 Statoil world-wide.All requirements documented herein are based on existing good practice and serve to strengthenStatoil’s existing quality management regime.1.1 ObjectiveThe purpose of this document is to define the minimum requirements for vessels and / or units to becontracted for the purpose of carrying out drilling, well testing and / or well intervention operationsusing dynamic positioning only.1.2 Validity areaStatoil group. These requirements are valid on a world-wide basis. Guidance notes and explanationare given whenever additional requirements to meet the Norwegian operating regime are made.Any DP drilling or intervention unit shall be certified as a marine offshore unit and shall be operated inaccordance with relevant national or flag state regulations during transit. In terms of operational DPsafety, the transition to Statoil’s requirements shall be made when the vessel begins deployingpositioning equipment and commences field arrival DP trials at a given location.1.3 Warrant“Drilling, Well & Production Activities” (AR03) (Statoil Group/All locations/On- and offshore)1.4 Document replacesWR0581.1.5 Publishing and follow-upF&T BRT is responsible for publishing and follow-up of this document.1.6 DefinitionsThe following definitions and abbreviations apply:-Validity area: Page 3 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002TermContractorVesselForeign FlagvesselColumnStabilised UnitDNVABSLloydsBVDPIMOIMCAIADCNMDNPDDefinitionVessel owner, operator or charterer responsible for execution of the workCommon term including ships, barges, column stabilised units, selfelevating units and other floating units with or without own propulsion,which are subject to registration and classification according to national orinternational maritime regulations.Vessel with Flag state other than Norwegian.Unit with the main deck connected to underwater hull by columns orcaissons.Det Norske VeritasAmerican Bureau of ShippingLloyds Register of ShippingBureau VeritasDynamic PositioningInternational Maritime OrganisationInternational Marine Contractors AssociationInternational Association of Drilling ContractorsNorwegian Maritime DirectorateNorwegian Petroleum DirectorateFurther 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 Statoil,it shall be capable of performing the following:-• Positioning in up to contracted water depth within Statoil’s performance requirements foraccuracy. This includes minimum levels of ‘DP Capability’ as defined herein for both monohulland semisubmersible units.• Locating / spudding in and positioning over a well within Statoil’s maximum time scale andaccuracy criteria.• Monitoring both well and drilling unit’s positions throughout the drilling programme withoutexception.• Monitoring any riser performance using the equipment specifications herein.• Continuous operation. I.e. sufficient redundancy in equipment to meet Statoil’s uptimeexpectations.• Operational management to a level of competence that complements Statoil’s safety goals laid outherein. This includes areas that are part of 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 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the nature of the work, type ofunit and waterdepth. A categorisation scheme differentiating the different types of tasks is used thedefine applicability of the 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 document, tables and additional notes are used to show the applicabilityof the various requirements within the four Categories.Each planned operation is assessed against all relevant legislation and industry guidelines. Therelevant Class of operation shall be in force at all times during the particular operation. Thisrequirement is central to Statoil’s policy of continual focus on the safety of any DP drilling orintervention operations.Validity area: Page 5 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002The following table of Classification shall apply for the planning of 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, thenNormal operating mode shall be Class 3 forall operations irrespective of location* Where no National / local legislation is in force, latest edition of IMCA Guidelines shall beminimum Statoil world-wide requirement.These requirements point to the following and hold distinct safety advantages for both Statoil andpotential contractors.The issue of different levels of equipment specification prescribed by IMO, NMD, Class or industrialguidelines is avoided. When operating for Statoil, these levels of equipment shall be the starting pointand effective reporting of 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 the form of a review of all documentation requested in Table 1. Aprospective Contractor will be requested to provide as much of the information requested as possiblein order that a review may be made of the unit’s technical integrity. An overall assessment of the typeand quality of documentation submitted shall be performed in order to verify the unit’s level ofpreparation for the proposed program.The review process shall allow Statoil to conduct an operational verification program against bothinternational best practice as well as technical minimum and site specific requirements.From the outset of the review process, the onus shall be placed on the contractor to prove it’s stationkeeping case. The documentation table (Table 1) includes explanatory notes in order to clarify thestandards expected. The Statoil Verification Model is illustrated in the diagram overleaf:-DP Drilling & Intervention Units Verification Model SchematicValidity area: Page 6 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 documentation. Type, year fitted, software versions a a a aFull details including year fitted, software upgrade history, history ofreference system interfacing and present spread. One line diagramincluding details of power supplies and upgrade history2Satellite based position references one line diagram and maintenancedocumentation, type, software versions, maintenance recordsa a a aAs stated. Details of systems proposed on site should also besubmitted. Detailed performance analysis of diff links in use should beavailable to support coverage3 Hydroacoustic position references one line diagram and documentation a a a aOne line diagrams, details of beacons proposed, battery types andstatus. Copy of beacon log and maintenance records for previousperiod on DP.4 Other reference systems (i.e. Tautwire) one line diagram and documentation a a a aAny other relevant position reference system material5Independent FMEA Study of complete unit including control, engineering andelectrical subsystemsa a a aHard copy of FMEA (latest version) should be submitted along withdescription of action list closeout response. This will be reviewed indetail.As a minimum, the vessel FMEA must meet IMCA & CEI/IEC 812 (85)standards and include failure mode proving analysis of:-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 document and closeout response requiredValidity area: Page 8 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the Vessel FMEA required inpart 57 FMEA Proving trials report a a a aAs a minimum, the vessel FMEA Proving trials must meet IMCAstandards and include cause and effect proving analysis of:-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 document and closeout response required8 Annual DP trials for previous years on DP a a a aAnnual DP trials shall include tests which prove the failure modes inthe 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 document and closeout response requiredValidity area: Page 9 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 off and drive off 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 theoretical 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 the unit is able tooperate without ALL thrust units online (6 of 8 for example) then thefailed 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 documentation a a a aHardcopy of Class Notation, expiry date and details of any outstandingConditions of 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 documentation 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 the equipmentused at the specific well.16 DP Incident reports and changes made as a result of cause analysis a a a aHard copies of all Yellow and Red Alert or other Incidents reportedduring DP operations shall be provided. Incident reporting shall includethe following1. Details of instances and duration of DGPS (or diff. correctionlosses)2. Details of instances and duration of 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 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of IN COMMAND DP control system alarm printout for last 7 days ofcontinuous DP operations to establish correct online recordinga a a aDetails of alarm and response definitions. The data requested in the blank18 Operational Limits Form should be completed on an individual well / locationbasis.a a a a19DP additional documentation, for example any upgrade of station keepingsystems in the 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 of all assigned DP Operators certificates and merchant marinelicencesa a a a23 Schedule of all assigned Marine Engineers merchant marine licences. a a a a24 Copies of all additional DP training certification. I.e. simulator training a a a a25 Details of marine and engineering crews record of DP hours a a a a26Maintenance schedules covering well program period for equipment such asgenerators and thrusters.a a a aIt shall be the Contractors responsibility to inform Statoil of impendingmaintenance which will require any equipment to be unavailableincluding: Generation, thrusters, DP systems, cooling systems, Fuelpumps, lube pumps, reference systems, UPS’s.27DP Guidance documentation (Table 2 contains details of expecteddocumentation to be held at DP Control location- existence to be verified).a a a aThe unit shall be provided with the guidance documentation listed inTable 2. There is no requirement to submit such guidance, theexistence of documentation will be verified during the field arrival trialsprogress. Documentation requirements include, but shall not be limitedto those included in Table 2.28Outline of onboard vessel familiarisation and specific training required fornew key DP personnel. IMCA Guidelines Ref. 2a a a aSchedule of 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 of the DP,engineering and electrical departments. Evidence of combined drilling/ DP & engineering drills which simulate yellow and red alert conditionsshall be provided. Where no National or Contractor generatedstandards are made, the standards applicable on the Norwegian Shelfshould be followed and documented as far as practicable.29Details of methods employed and fields recorded in dynamic positioningsystems datalogging facilitya a a aCopies of Class 3 checklist and details of 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 documentation for Drilling & Intervention UnitsValidity area: Page 11 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of Key DP Personnel - MSC Circ 738 IMCA Jan 96Rev 5GM-1611/01-0189-650, The guidelines for the design and operation ofdynamically positioned vessels IMCA99Ref. 4: 119 Engine Room Fires on DP vessels IMCA Aug 97Ref. 5: 105 Failure modes of the Artemis position reference system IMCA (if fitted) Jul 92118 Failure modes of the Artemis positioning reference system IMCA (if fitted) May 94Ref. 6: 128/ QRA for the use of a dual DGPS system for dynamic positioning IMCA Feb 95141 Guidelines of the use of DGPS as a position reference in DP control systems IMCA Oct 97Ref. 7: 145 Review of three dual hydro acoustic position reference systems for deep waterdrilling IMCARef. 9: 125 Safety interface document for a DP vessel working near an offshore platform.IMCAApr 98July 97Ref. 11 126 Reliability of electrical systems on DP vessels IMCA Feb 95IMCAS&L005Application of UK Safety Case Legislation to Specialist Vessels – Well ServicingNote 1Oct 00VarProceedings of 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 Dynamic Positioning 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 documentation requirementsValidity area: Page 12 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002The unit shall be fitted with sufficient levels and types of equipment in order to safely conduct theproposed program. An assessment of the suitability of the unit for the proposed workscope will beundertaken when submission of relevant documentation has taken place.The number, type and performance requirements of each part of the vessels station keeping system aredefined in the operational requirements section.Deficiencies in documentation should not preclude the use of an individual unit, although Statoil maymake recommendations prior to engaging in operations. The vessel’s Alert procedure is an example ofwhere changes may require to be made in order to satisfy Statoil’s requirements. It is expected that aprospective unit will have an alerting system which can function in the 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 the 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 of 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 theGreen Status using DP Consequence Analysis ON without alarms for more than brief and isolatedperiods with heading is optimised into the prevailing environment.DP Capability plots using the IMCA standard format shall be produced which verify that therequirements 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 the following minimum operational footprints.Validity area: Page 13 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of 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 theGreen Status using DP Consequence Analysis ON without alarms for more than brief and isolatedperiods with heading is optimised into the prevailing environment.DP Capability plots using the IMCA standard format shall be produced which verify that therequirements 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 the ability of the unit to hold station in certain environmental envelopes.Because monohull DP capability profiles differ from that of semisubmersible, requirements must beplaced in order that the unit has sufficient holding capability to withstand changes in resultantenvironmental loads. When considering a monohull vessel’s capability a sector of 60° (arc overhorizon of +/-30° either side of the vessel head) is used. Statoil’s minimum levels of 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 of 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 of 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 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 theGreen Status using DP Consequence Analysis ON without alarms for more than brief and isolatedperiods with heading is optimised into the prevailing environment.An important factor for monohull operations is the requirement of a minimum level of DP Capabilitywithin a 60° sector around the head. Minimum requirements will ensure that the vessel has sufficientcapability over this arc to react to changes in environmental conditions and be able to be maintained inthe optimum heading. Semisubmersible requirements are also included in Table 5.To illustrate the requirement, the following monohull unit’s 1500m drilling DP Capability plot showscapability which complies with Statoil’s minimum criteria.Validity area: Page 15 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.20023.6 Reference System RequirementsIn accordance with industry guidelines, Statoil require that at all times 3 independent positionreference systems shall be in use and actively selected at the main DP Control location. Thisrequirement is made for any operation irrespective of Class of operation. Any condition where anoperator cannot maintain 3 reference systems online (within performance criteria stipulated) shall beimmediately reported to the Statoil representative. The use of a Yellow or Red Alert may be requireddepending on the circumstances of the situation.The number, type and availability of effective position reference systems is an important factor in theprovision of safe DP operations. For this reason, strict adherence to these requirements shall befollowed. Table 6 below is used to add further clarity to the 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 of Minimum Statoil Position Reference RequirementsAny DP unit undertaking drilling or intervention operations in waterdepth

Statoil governing documentDP 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 of reception of Differential Corrections.Sources must use separate Communications systems if satellite based. Oneradio based differential link must also be provided to augment Inmarsat orother satellite based differential links.Minimum fed with 3 separate means of reception of Differential Corrections.Sources must use separate Communications systems if satellite based. Oneradio based differential link must also be provided to augment Inmarsat orother satellite based differential links.Table 7 DGPS Differential corrections requirementsThere shall be provided 2 separate DGPS input buttons at the main DP Control system. When 2 inputsfor DGPS are used online, the differential corrections in use shall be separately provided. The Masteris responsible for ensuring requirements for reference system redundancy are met at all times and thatthe Statoil representative is informed immediately upon any degradation.In order for a particular position reference sensor to be considered effective, the device must becapable of providing sufficient positional accuracy and repeatability during trials. Performance testsshall require that each vessel position sensor be tested online as a single input to the active DP ControlSystem.3.7 Additional Equipment RequirementsStatoil 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 of sea or current exist in a givengeographical location.Where a requirement for real-time recording of sea height and water column current is made at thewell planning stage, the equipment fitted and data recorded shall be of a type accepted by Statoil.Verification of the systems, displays and data recording methods shall be made at the field arrivalstage as part of location set-up trials.3.8 Technology Development Requirements (Categories A, B, C & D)Statoil have adopted requirements for logging vessel operational data. Any contracted vessel or unitshould have the ability to log information in an electronic format. This information must be logged insuch a way that it can provide post event analysis of any station keeping incident and be used inconjunction with Statoil’s continued technology development purposes.The ability to record vessel, ocean, environmental and riser performance data forms the cornerstone ofStatoil’s continuing process of development and should be understood at the earliest stage by anycontractor.The requirements for datalogging contained in this section shall be made by Statoil on an individualwell or field location basis. The Contractor is responsible for listing all fields which can be logged aspart of the information requested at the pre-hire stage. This will be assessed against the itemscontained in Table 8. Upon request, each contractor shall provide electronic logging of ALL itemscontained in Table 8.Validity area: Page 18 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the electronic data will take.The system should be capable of providing at least 7 days of previous data at any given time. Thisdata must be available in a simple manner without the requirement for time consuming analysis or dataacquisition. During a drilling or intervention program, the unit’s historical data should be submitted tothe onboard Statoil representative weekly in either CD or diskette formats.This data will be used primarily by Statoil’s development department.Information shall required to be electronically logged:-Item Required weekly electronic log of 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 of 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 Statoil requirements for electronic dataloggingThe logging process and tests of the accuracy and validity of the data being recorded will be includedas part of the field arrival test procedure to be witnessed by Statoil. The nature of modern controlsystems fitted to the latest drilling units allows this data to be easily collected.3.9 Annual TrialsIn accordance with safe industry practice, where no acceptably documented Annual or FMEA ProvingTrials have been completed within 1 year of the arrival at the field location, Statoil 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 the response of 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 the anniversary date of previous trials. This trial shall form thebasis of risk identification and reduction potential.For all vessels or units intended to carry out drilling and / or intervention operations in the NWEuropean area the current edition of the UKOOA Guidelines “Auditing vessels with dynamicpositioning systems” Ref. Issue 2, September 1993 shall be the required standard. It shall be thecontractors responsibility to independently verify trials and report non-conformances. All reports shallbe made available to Statoil upon request.Validity area: Page 19 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002For all other operations world-wide, in accordance with IMO Circ MSC 645 §5.1.2 the owner of thevessel / unit is entrusted to carry out Annual DP trials in accordance with a program accepted by thevessel’s Flag state administration. A Flag State approved trials program shall be submitted to Statoil.Where no acceptably documented DP performance trials have been completed within 1 year of thearrival of the field location, Statoil 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 the vessels positioning equipment spread and no performanceanalysis has been performed. Examples of the format of DP performance trials accepted by Statoil areavailable upon request. The purpose of 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 transferStatoil require that contractors are pro-active in the development and maintenance of good stationkeeping practices on their vessels and units. Contractors are encouraged to use the methods detailedbelow to allow effective experience transfer of operational knowledge:-• Effective incident reporting, investigation and closeout.• Membership and active participation of a recognised industry body such as IMCA, theInternational Marine Contractors Association.• Participation in performance indication and improvement schemes such as the IMCA Incidentreporting scheme through a competent person in the marine management structure.• Use of operational personnel in risk identification and assessment practices. Operational personnelassigned to a given vessel / unit shall take part in the WSOG limit setting exercise.4 Field arrival requirements4.1 Arrival TrialsTable 1 requires that previously documented DP Trials be submitted at the pre-hire phase. In order tosatisfy Statoil’s additional requirements, field arrival trials shall be performed. These shall form partof standard operating procedures for any unit. In order to correctly verify the performancerequirements, the formal field arrival trials checklist shall include the following:-ItemAll DP Control systemsAll Reference systems 1Environmental systems including gyro, windand motion sensorsEngineering systemsElectrical systemsUPS checksCommunications systemsVentilation systemsAlarm systemsRiser sensorsWeather forecasting processesDataloggingAlarm recordingRequirementsCheck all operational andGREEN Status requirementsfor number, type andperformance standards arefully achievedCheck forecasts availableCheck parameters as per Statoils data recording criteriaCheck DP and ECR alarm printersValidity area: Page 20 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Table 9 Contents of field arrival checklist requirementsNote 1 Performance trials to verify the 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 the guidelines contained herein. Examples of 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 of set-up.Each satellite based sensor’s accuracy and repeatability meets minimum requirements at a given siteupon completion of set-up.Each additional reference system (i.e. tautwires, where fitted) provides adequate levels of performance.Check the correct functioning of alerting systems and communications systems.The field arrival process is designed to ensure that all the equipment fitted is both operational and fitfor purpose. Special attention may be paid to the performance of certain systems at a given location.This requirement is made in order to give Statoil sufficient confidence that the equipment has been setupcorrectly and that maximum performance possible is achieved prior to commencement ofoperations.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 the information contained in thewell program which will indicate the 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 thevessel set-up on location. Copies of the field arrivals and periodic checklists will be made available atthe pre-hire phase. These should be completed formally and any deficiencies reported to Statoil.Statoil may witness field arrival trials and verify compliance against these requirements. Statoil maymake recommendations for any items inclusion in the test programme where safety of the 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 the DP Control location.The lights shall be as follows:-¨• Steady green light to indicate vessel under automatic DP control, normal operational status andconfirming the Alert System is functional.• Flashing yellow light to indicate degraded DP control.• Flashing red light to indicate DP emergency.Hardcopy printouts of all Alert status changes between Green, Yellow and Red shall be provided bythe Online DP Control systemAll alert systems shall be tested twice daily and records maintained. Checks shall also include use ofinternal telephone and talkback systemsValidity area: Page 21 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the main DP Control location and thedriller’s / well operations console.5.2 DP Alerts (Category A)Well servicing / intervention operations in Category A shall make use of the standard Alerting regimeas described in §5.1. Alert lights / sirens shall be located in the 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 the Statoil Representative immediately5.3 DP Alerts (Categories B, C & D)Definitions of the various alerts applicable to Category B, C & D operations are contained herein. It isvital that the alert systems are effectively used throughout any drilling or intervention operations. Acontractor should assess its procedures against these requirements.A system of lights and audible alarms should be used in a similar manner to other DP operations withaudible and visual indication in the following locations. Alerts shall be initiated at the Main DPControl location.Alert lights / sirens shall be located in the 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 of Categories B, C or D an additional status entitled Advisory Condition is used as apre-warning of changes in unit performance which have the potential for leading to higher alertconditions. The principle of safe and controlled operations suspension is encompassed in the overallphilosophy.Validity area: Page 22 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 thesea bed in normal operational status when the 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 the maximum thrust and powerthat would be needed after the worst case single failure to avoid exceeding the critical excursion.Vessel’s indicated position and heading are within predetermined limits.Negligible risk of collision exists from other vessels.Recipients of Green ConditionGreen condition lighting at strategic locations around unit, no furthercommunications other than routine necessary.Advisory ConditionThe Advisory Status conditions are defined in the Well Specific Operating Guidelines Form (WSOG)included in this document. The purpose of this condition is to provide early warning of any changesoccurring which may lead to a heading or position problem and / or deteriorating weather conditions.The condition is designed in order that supervisory staff can assess any failure or loss of performanceagainst current and planned operations in order to make prudent changes to planned operations. Use ofthe Advisory condition should be maximised: the conditions which apply are predefined by Statoil.The basic requirement is that where any DP related equipment fitted to a given unit fails or suffersperformance loss, the event shall be reported to Supervisory Staff.Recipients of Advisory Condition StatusDuty Senior DPO, Duty driller, Duty Marine Engineer, Master, DutyStatoil Representative, Duty well test Supt. (if appl.)Validity area: Page 23 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of the following conditions applies:A failure in a sub-system has occurred leaving the DP system in an operational state (possibly afterreconfiguration) but with no suitable backup available, so that an additional fault would cause a loss ofposition.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 of collision exists from another vessel.Approaching weather conditions are judged to be beyond present DP capability after allowing forworst case single failure.RedRecipients of Yellow AlertYellow Alert lighting and audible alerting. Duty Senior DPO, Duty driller,Duty Marine Engineer, Master, Duty Statoil Representative, Duty well testSupervisor (if applicable)Emergency Status (Red Alert). A vessel can be defined as in "Emergency Status" if any of thefollowing conditions apply:System failure results in an inability to maintain position or heading control.Any external condition exists, including imminent collision, preventing the vessel maintainingposition.There is no time available for position recovery.Recipients of Red AlertRed Alert lighting and audible alerting. Duty Senior DPO, Duty driller,Duty Marine Engineer, Master, Duty Statoil Representative, Duty welltest Supervisor (if applicable)Validity area: Page 24 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the alert levels initiated by the DP Operator:Status NameGreen StatusAdvisory ConditionYellow AlertRed AlertActions / NotesNo action. Operations progress. Routinecommunications. Standard communicationsroutines apply.Informative status prior to issue of alarms. Usedby operational personnel to inform supervisors ofcertain changes taking place in the DP operation.The Advisory Condition has no lights or bells, ismerely a status condition achieved through use ofinternal 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 furtheraction is necessary or if operations can continue.Emergency status; Emergency disconnectsequence to be initiated. All necessary actionsrequired to prevent loss of life or damage toequipment or the environment shall be taken.Table 10 Statoil DP Drilling Status Definitions5.4 Incident PrioritiesIn general, the longer time available to a driller, the greater the level of preparation that can be made toeffect well control measures and secure the well. An accurate and clear transmission of facts isrequired between the DP Operator and the driller during any use of any alert condition.Where a DP Operator is in any doubt whatsoever as to the vessel’s position or station keepingperformance, he should, in the first instance use the YELLOW alert. The contractor must be awarethat the Advisory and Yellow Alert processes should be maximised in attempts to reduce thepossibility of immediate (Red) Alert situations. Conversely, if a situation exists where loss of positionor heading is occurring and cannot be checked, immediate Red Alert should be initiated in order tomaximise the time available to the driller and possibility of successful disconnection.Priorities should be clearly established for dealing with a DP problem. The authority of the Master andDrilling Supervisor (Contractors) are of fundamental importance at such times (N.B. A red alert willonly involve the Master and / or drilling supervisor if they are present at the DP control or drillfloorwhen alert is issued). They should co-operate closely on these priorities so that there is no room fordoubt or dissension and that the senior DP Operator and driller on duty at the time of an emergency actto the same priorities without undue hesitation. Priorities should take into account that: the safety oflife is the first priority, - The Master has ultimate authority to assess and decide on courses of action inthis respect, but the advice of the Drilling Supervisor (Contractors) must be taken into account.As a guideline, the following information shall be assessed jointly by the Statoil Representative andthe unit’s Master / Drilling Supervisor during any Advisory Condition.• Any position or heading performance loss as a result of alert cause• Weather conditions at time of alert• Drilling operation in progress at time of alertValidity area: Page 25 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of alert• Assessment of additional weather forecasts which may be required• Time required to reach a safe situationAdditionally, for well intervention / testing operations:-• Well parameters• Equipment design limits• Consequences of failure5.5 Statoil DP Policy (Categories A, B, C & D)Where additional systems are fitted, for example a Class 3 certified unit, the policy is that any suchequipment shall be available at all times irrespective of class of operation. This policy realises thatwhen operating where full NMD Class 3 is not necessarily required, the related equipment shouldremain online and in use. This policy will reduce the need for procedural changes when conductingdrilling operations with differing legislative requirements.Where any requirements cannot be achieved in full it shall be the contractors responsibility todocument that an equivalent level of safety, operability and redundancy is achieved using appropriatetechniques such as risk analysis.It shall be the contractors responsibility to inform Statoil of maintenance schedules relating to all DPassociated equipment in order that prior planning can be made. The purpose of this requirement is thatcertain equipment may be taken offline during periods of lowest risk activities such as running riserwhere no subsea connection has been made.5.6 Statoil DP Policy (Categories B, C & D)Where any contracted DP drilling unit has been assigned Consequence Class 3, this mode of operationshall be the standard or ‘normal’ operating mode at all times. This follows Statoil’s policy ofoperating the unit in the safest mode possible. The requirements outlined for the definition and use of“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 the unitsoverall station keeping capability. By the adoption of this policy, Statoil will have in place a system ofcontinual risk assessment. This process includes both equipment breakdown and equipmentperformance deficiencies as identified in the WSOG (Well Specific Operating Guidelines) Form.Where, due to the nature of the drilling operation proposed or geographical location, a drilling unitcertified to Consequence Class 2 is contracted, the risk control process outlined shall be adopted asclosely as possible. The process of identification and use of green, advisory, yellow and red limitsshall be carried out prior to the commencement of operations.Statoil’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, thetransition 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 of it’s Class 2 and 3 set-up at the pre-hire stage. This should clearly document actionsrequired for the transition between Class 2 and 3 including copies of checklists in use on an individualunit.Validity area: Page 26 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002It shall be the Contractors responsibility to inform Statoil of all maintenance being carried out at anygiven time in order that this information is available when planning future well activities. Thisrequirement does not alter the necessity to make use of the Advisory Condition where any failure ofloss of performance has, or is occurring.5.7 Reporting (Categories A, B, C & D)No part of the 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 of position is the outcome or possible outcome, nothing inthese requirements shall change the overriding responsibility of the operational personnel to takewhatever action is then required. Immediate use of either Yellow or Red shall be made where theimmediacy of the 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 of performance in any system where that system cannotbe selected as an effective position measuring device into thecontrol 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 the contractor shall provide details of the 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 of the WSOG form is recommended for this purpose.Any unexpected failure of any DP related system shall be logged in a DP status report in order thatperformance data can be collected for Statoil’s incident research requirements. This requirement isirrespective of 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 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 Statoil Representative within a reasonable timeframe and in no cases more than 15 minutesafter any failure or occurrence. A system should be in place where the DP Operator is aware offailures in any engineering systems and that no failure or equipment (and / or redundant equipment)goes unreported. Additionally, any loss of redundancy or any Yellow or Red Alert condition shall bereported - post event, using the standard IMCA Incident Report Form or equivalent which shall bemade available to Statoil upon completion Ref. §5.9 Management.Although it shall be the contractors responsibility to complete and promulgate DP Incident reports, theStatoil Representative onboard will take an active roll in ensuring full compliance with theserequirements.A program of alert drills shall to be undertaken, aimed at training and maintaining a competent team tocope with emergencies. Where well control drills are required, the DP, engineering and electricaldepartments shall be included. Realistic drills which familiarise operators in the use of the variousalerts shall be conducted and documented. These drills shall be inclusive of all personnel havinginvolvement in an actual alert condition.Statoil reserve the right to request suspension of operations and preparations for disconnection in anysituation where the Senior onboard Representative feels that continued operations may represent actualor potential danger to personnel, equipment or the environment.5.8 Reporting (Categories A, B, C & D)An equipment failure or performance failure shall be reported in the manner described. Statoil shall beinformed immediately when any equipment failure takes place even if the failure has no immediateeffect on position or heading control. For operations in operations in Categories B, C & D, theAdvisory Condition shall be used. The Advisory Alert conditions shall be included in the WellSpecific Operating Guidelines Form (WSOG) which shall be completed, agreed and signed off byStatoil and the contractor prior to operations commencement.The nature of any failure, it’s immediate effect, and it’s effect on forthcoming operations will beestablished by both Statoil and the Contractor’s senior onboard Representative. The informationprovided in the 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 of the situation which shall beentitled an SJA or Safe Job Analysis. Details of such systems and examples of the documentationshall be provided to Statoil 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 the SMS operating on board the ship contains a clearstatement emphasising the Master's authority. The Company shall establish in the SMS that the Masterhas the overriding authority and the responsibility to make decisions with respect to safety andpollution prevention and to request the 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 the Master, the onboardStatoil Representative and the nominated person within the contractors management.Each Yellow or Red Alert incident analysis Report shall include the following information:-Validity area: Page 28 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002INFORMATION REQUIREDEvent timetable in detailWeather conditions during IncidentPosition (initial and final)Heading (initial and final)Summary of eventsSummary of 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 Statoil. Reports shall be supplemented by electronic data which shall bemade available to Statoil upon request.5.10 Well Specific Operating Guidelines (WSOG)The Well Specific Operating Guidelines (WSOG) Form lists guidelines for the issue of the 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 the contractor and agreed upon prior tothe commencement of any drilling and / or intervention programme in categories B, C or D. CategoryA operations are also recommended to use the 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 the limit setting exercise forthe drift / drive and force off cases. The table below shows Category versus waterdepth and includesdistances for the 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 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 offset limits appliedduring BOP connected drilling operations ARE constrained by available stroke length of thetop drill string compensator. A full assessment of the time requirements and hence Advisory,Yellow and Red limiting offset distances is required in these operations.ADDITIONAL NOTES: All heavy intervention and drilling / completion operations. A completeassessment of the site, vessel, equipment, downhole tool characteristics, potential and effectof loss of position shall be made in order to assess the 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 of 38Statoil Group / All locations / On- and offshore980

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Example of estimating safe disconnect time :Using the figure above, for a Category “D” Drilling operation planned at 380m MSL waterdepth. Avertical line is drawn onto the diagram above.Well using the 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 theoretical). In a linear system, this corresponds to a horizontal distance of 53mfrom Zero Angle position (if well centre). In all circumstances, the time to disconnect shall be verifiedas being LESS than the time required to exceed a 53m offset from initial position. Scenarios to beassessed shall include a full 100% drive-off away from environment with all thrusters online, and a fullblack-out drift-off scenario. Time and distance shall be assessed with full regard to the followingvariables :• Physical limitations of 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 the drilling program• Riser and rig motions in deteriorating environmental conditions• Time requirements to disconnect BOP for each part of the well programDistances will not be linear as waterdepth increases therefore these notes shall be used as guidanceonly.Validity area: Page 31 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of ALL HVNETWORKSDRIVE OFF Incident orDRIFT OFF Incident orFORCE OFF IncidentUnit offset 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 of 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 ofperformance in anysystemLoss of one networkor one of redundantcontrollers/servers1 system notoperating>70% or loss of onepower station +Consequence alarmConsequence alarmSituation specificSituation specific2 (situation specific) If threat to position1 or loss of failure ofbackup controller1 or loss of backupwind sensor (stb.aft)1 or loss of backupMRU (No. 1)2 or loss of backupgyro (No.1)2 or loss of backupUPS (No.1)Loss of 2 of theredundant controllers/server in any systemSituation specificLoss of 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 Statoil Situation specific Situation specificAdvise Master, Driller,Toolpusher, StatoilRep.Issue alarm andfollow proceduresIssue alarm andfollow proceduresNotify OIM immediately (Y/N) Yes Yes YesNotify Statoil immediately (Y/N) Normal condition Yes Yes YesValidity area: Page 32 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the geographical wellposition, but to the ZAP position (Zero Angle Position). This position is chosen and adjusted by theDP Operator in order to reduce wear on the BOP and tree when running equipment into the well. Allnoted figures are therefore from Start (ZAP) position, whichever that position is at a given time.Note: This WSOG is valid inside 100 metres from the wellhead / spudding or subsea facility positionWell Escape way: Clear escape route 50 m direction ____ degreesSigned on behalf of Contractor: ___________Signed on behalf of Statoil: ____________General NotesLimits are maximum figures and are used as guidelines. Any action may be initiated PRIOR toreaching limits at the discretion of the relevant Supervisory staff. These figures are general and shouldbe corrected jointly (Statoil and contractor) in the earliest stages of operations in the light ofexperience of an individual units performance. The WSOG shall for the basis of the units Alertingstrategy and is designed to be iterative in the light of operational experience.Note 1Any situation where loss of position is occurring or potential for loss of position exists shall require theDPO to issue the warning alert most appropriate under the circumstances. The vessels INTACT (Allthrusters & all available power online) DP Capability Plot shall be used to define the Yellow Alertcircle. The example below shows an actual test footprint in the intact (all thrusters) case during themaximum working conditions (H s 6.7m). Wherever footprints exceed this level then by definition anAlert condition exists.Validity area: Page 33 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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, Statoil) should be made when heading instability) is seen. Heading setpoint error canbe viewed using trend pages installed in software in the DP Control system. Notwithstanding theabove note, the DP Operator should issue a cautionary yellow alert if heading instability becomes suchthat a threat to the unit’s position exists.Validity area: Page 34 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 of ALL HVNETWORKSDRIVE OFF Incident orDRIFT OFF Incident orFORCE OFF IncidentUnit offset 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, StatoilRep.Issue alarm andfollow proceduresIssue alarm andfollow proceduresNotify OIM immediately (Y/N)Notify Statoil immediately (Y/N)Note: This WSOG is valid inside 100 metres from the wellhead / spudding or subsea facility positionWell Escape way: Clear escape route xxx m direction ____ degreesSigned on behalf of Contractor:Signed on behalf of Statoil:Validity area: Page 35 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP 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 the planning ofwelltest 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 the operational HAZOP may include, but not be limited to:-1. DST WSOG to be initiated at time of start of running subsea test tree to allow green operatingstatus to be revised and unit reconfigured2. No OSV operations as a result of increased risk of acoustic reference system interference3. No routine helicopter operations as a result of increased risk of loss of position in the event ofwind sensor disturbance.4. Additional or revised weather limitations as required dependant on the nature of the welltest.5. Restrictions in ROV operations if required.A separate well test WSOG should be produced from a DP operational HAZOP early in the planningphase. Additional guidance notes for event alert handling between the DPO, driller and welltestSupervisor will require to be established. Onboard training in the agreed welltest WSOG is an areawhere additional risk reducing measures may exist.7 References7.1 GeneralApplicability of Coastal state regulations are defined in NORSOK J-003, Marine Operations and shallbe read as follows:• Flag state and classification Rules apply to the vessels hull, stability, machinery, mooring and othermarine systems.• Coastal state regulations, such as NPD regulations, apply to drilling and well systems, the relatedwork environment, and general management systems.7.2 Regulatory acts and regulationsRelevant regulations stipulated by the Norwegian Petroleum Directorate and the Norwegian MaritimeDirectorate (for Norwegian flagged vessels and vessels carrying an NMD Letter of Compliance) apply.Validity area: Page 36 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002Norwegian RegulationsAuthorityNMDNMDNVEStandardRegulations for Mobile Offshore Units, laid down by the 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 of Life at Sea (SOLAS) 1974,modified by the protocol of 1978MODU CODE Code for the Construction and Equipment of Mobile Offshore DrillingUnits. International Maritime Organisation (IMO) Resolutions A.649(16). Refer to §4.12 Dynamic Positioning systems.IMO MSC Circ. 645 Guidelines for the Design and Operation of Dynamically PositionedVesselsIMO MSC Circ. 738 The Training & Experience of Key DP PersonnelMARPOL 73/78 International Convention for the Prevention of Pollution from Ships1973, as modified the by Protocol of 1978IMO A.469 (XII) Guidelines for the Design and Construction of Offshore Supply VesselsLoad Lines 1966 International Conference on Load Lines, 1966Tonnage 1969 International Conference on Tonnage Measurement of Ships, 1969COLREGConvention on the International Regulations for Preventing Collisions atSea, 1972IMO A.680 (17) IMO Guidelines on Management for the Safe Operation of Ships and forPollution PreventionSTCWInternational Convention on Standards of Training, Certification andWatchkeeping for Seafarers, 1978IMO A.481 (XII) Principles of Safe ManningIMO A.538 (13) Maritime Safety Training of Personnel on Mobile Offshore Units7.3 Standards and specificationsThe guidelines contained in IMO MSC / Circ. 645, Guidelines for Vessels with Dynamic PositioningSystems and IMCA (International Marine Contractors Association) Guidelines for the Design andOperation of Dynamically 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 of duplicate or triplicate equipment are maximised during operations involving thehighest level of risk. The standards of training and certification for DP operations shall be derivedfrom the IMCA document “The Training & Experience of 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 ofthese requirements may be made based on the nature of the changes.The broad requirement is that any unit must always operate in the safest mode possible however, notall DP related equipment must be available all the time for all operations. These requirements seek tocontrol risk by defining safe limits prior to the commencement of DP drilling operations.Validity area: Page 37 of 38Statoil Group / All locations / On- and offshore

Statoil governing documentDP Requirements for Drilling and Intervention UnitsTechnical Requirements TR1029, Version 1, Valid from 01.09.2002These requirements reflect the current legislative requirements and guidance available for operations inareas where the 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 of geographical location.In any location world-wide where no DP related national legislation is enforced, the most currentedition of IMCA’s Guidelines for the Design and Operation of Dynamically 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 of Consequence Class 2 shall be a Statoil requirement.Statoil’s requirements for Class 3 operations world-wide, in locations other than those on theNorwegian Continental Shelf shall be made on an individual well, area or unit basis.No part of these requirements detract from or diminish the significance of any Norwegian Maritime orPetroleum Directorate standards in force when operating a vessel or unit on the Norwegian ContinentalShelf.Using the protocols outlined in this document, vessel or unit operators shall be requested to provetechnical integrity for the positioning equipment as well as competence in operational management.The NORSOK standard defines the basic requirements to vessels performing marine operations, to theplanning, execution and work associated with such operations on the Norwegian Continental Shelf.The detail of relevant standard contained in J-003 Rev 2 Marine Operations have been included herein.The following standards and specifications with their respective normative references apply:NORSOK D001NORSOK D002NORSOK D010NORSOK J003Drilling facilitiesSystem requirements well intervention equipmentDrilling and well operationsMarine operationsDP Audit standards are adopted. Statoil adopt and conform to the 1993 UKOOA document“Guidelines for Auditing Vessels with Dynamic Positioning Systems” (112 UKOOA). The UKOOAdocument provides guidance on the qualifications / experience required of a Competent Auditor aswell as notes on trials requirements.7.4 Statoil governing documentationThe following Statoil governing documentation apply:“Drilling, Well & Production Activities” (AR03) (Statoil Group/All locations/On- and offshore)“Marine Operations” (AR08) (Statoil Group/All locations/On- and offshore)“Dispensations to and improvements of governing documents” (WR0011) (Statoil Group/Alllocations/On- and offshore)Validity area: Page 38 of 38Statoil Group / All locations / On- and offshore