Deep Panuke Project Description - Encana

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These subsea structures may be fastened to the seabed via four piles ranging in size from 610 mm [24inch] to 910 mm [36 inch] driven approximately 8 to 12 m below seabed. These piles would be drivenwith an IHC S-90 (or equivalent) hammer which has a maximum energy output of 89,000 Newtonmeters(66,000 foot-pounds). The actual pile driving duration is estimated to be 0.5 to 1 hours basedupon the previous experience of driving the Panuke platform docking piles.Although the total number of piles has increased for the revised Project design basis, the diameter andlength of the piles is smaller requiring an overall shorter duration of the activity with a lower energyhammer. As a result, the potential pile driving requirements associated with the 2006 Project basis isless than the Project basis approved in the 2002 CSR; refer to Table 2.3 for comparison.2.3.7 Onshore Facilities and Pipeline (M&NP Option Only)Onshore pipeline installation activities as presented in the original CSR have not changed; therefore,these activities are not addressed in this section as there is no need to re-state.2.3.8 Development Well ConstructionDevelopment wells will include five to eight production wells and one injection well, all of which willbe subsea. A jack-up drilling unit will be used to complete the existing wells and to drill the subseawells. A jack-up drilling unit is a MODU that has legs that can be jacked up or down. Once towed to thesite, the legs are jacked down until they are in contact with the seafloor, then the rig platform is elevateduntil it is approximately 25 m above the water surface. The jack-up drilling unit will remain on locationduring drilling and completion operations and then be removed. Well construction activities areexpected to take approximately 430 days (five new drill wells at 60 days each plus four re-entry wells at32 days each) in total to complete.The normal drilling program for all Deep Panuke wells involves conventional hole and casing/pipesizes. All casing designs are based on CNSOPB Offshore Petroleum Drilling Regulations.Deep Panuke Volume 4 (Environmental Assessment Report)• November 2006 2-22
Table 2.3Pile Driving DetailsProject Design Basis of 2002 Approved 2002 CSRWellhead PlatformProductionPlatformUtilities andQuarters PlatformNo.PilesSize [mm (in)]4 2100 (84) 61842100(84)2100(84)SSIV Skid 1 4 610-910 (24-36) 8 - 12Revised Project BasisNo.PilesSize [mm (in)]WellheadProtection (x9) 36 24 - 36 8 - 12Penetration[m] Hammer Size Max. Energy ]N.m (ft. lbs)] Actual Driving Duration/PileMenck MHU-1700(or equivalents)68 Same as WHP65 Same as WHPIHC S-90(or equivalents)1,699,000(1,253,000)1,699,000(1,253,000)1,699,000(1,253,000)89,000(66,000)ActualDrivingDuration4 to 6 hr 16hr - 24hr4 to 6 hr 32hr - 48hr4 to 6 hr 16hr - 24hr0.5hr - 1hrEstimated Total Duration 2 (Menck MHU-1700)Estimated Total Duration 3 (IHC S-90)Penetration[m] Hammer Size Max. Energy [N.m (ft. lbs)] Actual Driving Duration/pileIHC S-90(or equivalents)Hot Tap 4 24 - 36 8 - 12 Same as WellheadTie-in 4 24 - 36 8 - 12 Same as WellheadSSIV Skid 1 4 24 - 36 8 - 12 Same as Wellhead2hr - 4hr64hr - 96hr2.7 d – 4 d2hr - 4hrActualDrivingDuration89,000(66,000) 0.5hr - 1hr 18hr - 36hr89,000(66,000) 0.5hr - 1hr 2hr - 4hr89,000(66,000) 0.5hr - 1hr 2hr - 4hr89,000(66,000) 0.5hr - 1hr 2hr - 4hr1 May not be required since in Platform/MOPU Safety Zone2 Approximately 40 to 45% of the duration is under water hammer activities3 All the duration is underwater hammer activitiesEstimated Total Duration 3 (IHC S-90)24hr - 48hr1d - 2dDeep Panuke Volume 4 (Environmental Assessment Report)• November 2006 2-23
Page 1 and 2: 2 PROJECT DESCRIPTIONThis section p
Page 3 and 4: Potential Radioactive Components: T
Page 5 and 6: 2.2.2 Subsea Wells and FlowlinesThe
Page 10 and 11: 2.2.3.1 M&NP OptionThe proposed pip
Page 12 and 13: The onshore portion of the pipeline
Page 14 and 15: 2.3 Construction and Installation2.
Page 16 and 17: 2.3.2 Export PipelineA proposed pip
Page 18 and 19: A dedicated subsea umbilical will b
Page 20 and 21: Table 2.2 Construction MethodsCateg
Page 24 and 25: For the new production and injectio
Page 26 and 27: Figure 2.8Typical Production Well S
Page 28 and 29: 2.3.8.1 Drilling Fluid ProgramWater
Page 30 and 31: Table 2.4 Hydrostatic Fluid Dischar
Page 32 and 33: Acid GasInjectionFeed GasCompressio
Page 34 and 35: Although the M&NP Option is the onl
Page 36 and 37: Spent TEG has no measurable H 2 S a
Page 38 and 39: Table 2.7 Water CompositionComponen
Page 40 and 41: 2.4.2 Utilities2.4.2.1 Electrical P
Page 42 and 43: will be designed considering emerge
Page 44 and 45: zones over the pipeline although th
Page 46 and 47: 2.7 Emissions and DischargesEnCana
Page 48 and 49: Table 2.8 Routine Project Emissions
Page 50 and 51: 2.7.1.1 Air PollutantsThe following
Page 52 and 53: esult in eye irritation, respirator
Page 54 and 55: Typically, a re-entry and completio
Page 56 and 57: 2.7.5.3 Deck DrainageDuring constru
Page 58 and 59: 2.9.2 Pipeline Leak PreventionThe p
Page 60 and 61: 2.9.5 Subsea Protection StructuresT
Page 62 and 63: • consider concept alternatives f
Page 64 and 65: Table 2.10Centre Substructure Type
Page 66 and 67: is much more weather-dependent than
Page 68 and 69: Table 2.11 Processing Location Alte
Page 70 and 71: After carefully considering the con
Page 72 and 73:
Flaring acid gas consists of direct
Page 74 and 75:
Table 2.13Produced Water Disposal A
Page 76 and 77:
Therefore, injection into an annula
Page 78 and 79:
Use of a dedicated condensate pipel
Page 80 and 81:
is taken offshore on a special lay
Page 82:
Table 2.15Acid Gas Injection Locati
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Deep Panuke Project Description - Encana

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