white rose oilfield development application - Husky Energy

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4.2.1.3 West Avalon PoolOnly one well, J-49, has been drilled in the West Avalon Pool. The pool is expected to have an averagegas column thickness of 122 m and an oil column of 59 m. The OGIP for the pool is estimated to bebetween 23 and 37 billion m 3 . The OOIP is estimated to be between 32 and 42 million m 3 , with provenplus probable (P50) volumes of 37 million m 3 . On this basis, the pool is expected to containapproximately 35 percent OGIP and 20 percent of the OOIP in the Avalon Formation.This pool is also expected to be of poorer reservoir quality than the South Avalon Pool, with an averagepermeability in the order of 90 mD.4.2.2 Reservoir Exploitation4.2.2.1 Reservoir Simulation Model – South Avalon PoolA three-dimensional reservoir model was developed for the South Avalon Pool to evaluate depletionoptions for the pool. For reference case reservoir performance determinations, all faults were assumedto be sealing.A waterflood scheme was used for the reference case development. Several model runs were made todetermine the horizontal well locations that would result in optimum recoveries from the model. A totalof 10 production wells and seven water injection wells were required to optimize reservoir performancein the model. Horizontal water injection wells were placed well below the oil-water contact to ensuredispersion of the injection water. The location of the horizontal oil producers was based on optimizingrecoveries, while maximizing the time to water and/or gas break through.The recovery for the South Avalon Pool was approximately 39 percent. On a fault block by block basis,recoveries varied from 29 to 50 percent.A fundamental assumption for the waterflood development case is excess produced gas is conserved byreinjecting it into another pool in the White Rose field. Current plans are to drill the first gas injector inthe North Avalon Pool in the N-22 area. After some reservoir response is seen, a decision will be madeas to the number, timing and location for additional gas injectors, if they are required. Areas forpotential future gas injector locations include the North Avalon Pool, the West Avalon Pool and thesouth end of the Terrace block in the South Avalon Pool.White Rose DA Project Summary • January 2001 Page 50
4.2.2.2 Alternative Development OptionsThree other development options were evaluated for the South Avalon Pool. They were:• reinjecting all excess produced gas (net of fuel requirements) into the southern portion of the SouthAvalon Pool;• reinjecting excess produced gas (net of fuel requirements) into fault blocks across the field; and• reinjecting only a portion of produced gas cap gas to maintain original gas-oil contacts.In cases where all produced gas is reinjected into the producing pool, recoveries are reducedsignificantly. For the partial reinjection cases, recoveries are not affected as significantly, but additionalgas injection wells would be required as there would be gas injection both within and outside the pool.In all cases, reinjection of gas into the pool increases gas handling requirements due to earlier and moresignificant breakthrough volumes. The increased gas production rates would increase gas compressionrequirements and reduce project economics.The water injection reference case maximizes recoveries and minimizes gas handling requirements.Water handling and total fluid requirements are larger in the reference case, but can be managed muchmore easily than large gas volumes.4.2.2.3 Reference Case Development SensitivitiesTwo types of sensitivities were evaluated with the models. The first type were controllable areasdealing with facility and well constraints. Sensitivities were run to examine the impact of facility oilhandling capacities, gas handling capacities, bottomhole producing pressure constraints and horizontalversus vertical or highly deviated wells will have on field production performance and recovery factors.The second type were uncontrollable areas dealing with uncertainties in reservoir quality andperformance and included:• reduced vertical permeabilities;• permeability barriers;• reduced permeability in the water leg;• non-sealing faults;• sealing sub-seismic faults; and• faults acting as flow conduits.The above sensitivities, with the exception of non-sealing faults, had a negative impact on recoveries.White Rose DA Project Summary • January 2001 Page 51
Page 1 and 2:
WHITE ROSE OILFIELDDEVELOPMENT APPL
Page 3:
TABLE OF CONTENTSPage No.1 INTRODUC
Page 6 and 7: 7.1.5 Command Structure............
Page 8 and 9: Figure 1.1-1White Rose LocationWhit
Page 10 and 11: There will be three to four drill c
Page 12 and 13: 1.2.1 Exploration HistoryThe first
Page 14 and 15: Figure 1.2-2Depletion Schedule for
Page 16 and 17: Figure 1.2-3United States Import Re
Page 18 and 19: Figure 1.2-4Selected Natural Gas Pr
Page 20 and 21: Figure 1.2-6Gas Infrastructure Inve
Page 22 and 23: Figure 1.2-7Model for Gas Developme
Page 24 and 25: These remaining five options (steel
Page 26 and 27: Figure 1.3-2Relative Technical Risk
Page 28 and 29: In addition, the steel FPSO will:
Page 30 and 31: This system was evaluated as fourth
Page 32 and 33: Figure 1.4-1Project Development Sch
Page 34 and 35: 2.1 Regulatory RequirementsThe star
Page 36 and 37: • project summary booklet, which
Page 38 and 39: The first series of open houses fea
Page 40 and 41: 2.6 Media BriefingsHusky Oil repres
Page 42 and 43: 3 CANADA-NEWFOUNDLAND BENEFITS PLAN
Page 44 and 45: 3.1.2 Canada-Newfoundland Benefit C
Page 46 and 47: The subsea contract package will co
Page 48 and 49: 3.1.3.6 Monitoring and ReportingHus
Page 50 and 51: • The operations/production phase
Page 52 and 53: • Husky Oil’s preferred develop
Page 54 and 55: 4.1.2 White Rose Structural Geology
Page 58 and 59: Reducing oil handling capacities ha
Page 60 and 61: 4.2.2.7 Reservoir ManagementReservo
Page 62 and 63: Side scan sonar images of the White
Page 64 and 65: Generators will be sized to meet th
Page 66 and 67: 4.5.3 Marine Support VesselsHusky O
Page 68 and 69: The offshore organization will cons
Page 70 and 71: Husky Oil promotes safe operations
Page 72 and 73: Table 4.8-3Capital and Operating Co
Page 74 and 75: 5 ENVIRONMENTAL IMPACT STATEMENTThe
Page 76 and 77: The principal origins of the iceber
Page 78 and 79: white hake and winter flounder. The
Page 80 and 81: Produced water, although treated pr
Page 82 and 83: opportunity for interaction with bi
Page 84 and 85: The effects of project development,
Page 86 and 87: Additional mitigation measures for
Page 88 and 89: In summary, after mitigation measur
Page 90 and 91: 6 SOCIO-ECONOMIC IMPACT STATEMENTTh
Page 92 and 93: 6.1.2.1 EducationIn recent years, t
Page 94 and 95: 6.1.3.1 HousingThe number of dwelli
Page 96 and 97: Figure 6.1-1NAFO Divisions on the G
Page 98: During the development phase of the
Page 101 and 102: 6.2.3 Community Physical Infrastruc
Page 103 and 104: damage or foul gear. Any damage to
Page 105 and 106: have medical programs for their ope
Page 107 and 108:
7 SAFETY PLAN AND CONCEPT SAFETY AN
Page 109 and 110:
Hazard prevention, detection and mi
Page 111 and 112:
7.1.5 Command StructureThe command
Page 113 and 114:
7.2.1 Major Hazard IdentificationTh
Page 115 and 116:
8 REFERENCESJWEL (Jacques Whitford
Page 117 and 118:
Adams Pearson Associates Limited. 1
Page 119 and 120:
Hycal Energy Research Laboratories
Page 121:
Schlumberger. 2000. Husky Oil et al
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