white rose oilfield development application - Husky Energy

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4.1.2 White Rose Structural GeologyThree episodes of rifting affected the White Rose area. During the first rifting phase, thick Osprey/Argosalt beds were deposited. This salt was tectonically mobilized during the second rifting stage formingelongated salt walls parallel with the emerging Central Ridge. Major north-south and northeastsouthwestfaults dissect the sediments deposited above the northerly plunging salt wall, including thesource rocks. The third rifting stage had a pronounced influence on the area as the salt ridge wasdivided by salt withdrawal into a major ridge (Amethyst) and a northerly circular dome in which theoverlying racks have been ruptured (White Rose).Three intersecting fault systems oriented northeast-southwest, north-northwest south-southwest andnorth-south, divide the area. A few major faults (for example, the West Amethyst, Central and Twinfaults), together with a low structural trend oriented north-northeast south-southwest, segment the areainto three pools (Figure 1.2-1). The pools are:• the South Avalon Pool (E-09, L-08, A-17, H-20 and environs), which occupies an area ofapproximately 18 km 2 located east of the Amethyst Ridge and Central Fault; the pool isgeologically complex, and limited by the East Amethyst Central and Twin faults;• the West Avalon Pool (J-49 field and environs) encompasses a 16 km² area and is confined betweenthe West Amethyst, Central and North J-49 faults and the crestal erosional edge; and• the North Avalon Pool (N-30, N-22 and environs) occupies an area of about 10 km²; it is boundedby the Central Fault, White Rose dome erosional edge, Trave Fault and southeastern end of theTrave Syncline.4.2 Reservoir Engineering4.2.1 Reservoir Quality and In Place Resource AssessmentsTwenty-five drill stem tests have been carried out in the White Rose field to assist in evaluatingreservoir production capabilities and determine fluid properties. Results indicate that each of the threeAvalon pools has an oil leg with an associated gas cap and underlying water. The oil-water and gas-oilcontacts are different for each pool, confirming that there are sealing faults in the field. The oil is atypical Jeanne d’Arc Basin waxy crude with an average quality of approximately 30° API. Thereservoirs have fine to very fine sandstone with a relatively low average permeability in the order of100 milliDarcies (mD). In addition, there are several calcite-cemented zones that may hinderproduction.White Rose DA Project Summary • January 2001 Page 48
4.2.1.1 South Avalon PoolThe South Avalon Pool has been delineated by four wells (E-09, L-08, A-17 and H-20). The pool has a117 m oil leg and contains approximately 65 percent of the original oil in place (OOIP) in the field. Thepool is expected to contain between 114 and 138 million m 3 of oil, with proven plus probable (P50)volumes of 126 million m 3 .The gas cap in the pool has an average thickness of 81 m and is expected to contain between 8.2 and15.5 billion m 3 of the original gas in place (OGIP).The above volumes do not include the results of the recently drilled H-20 well, which are currentlybeing evaluated. It is expected that the results of this well will only marginally reduce the in placevolumes.This pool has better reservoir quality than the other pools, with an estimated average permeability ofapproximately 127 mD. Due to the low permeability and the proximity of the gas cap, horizontal<strong>development</strong> wells will be required to ensure adequate production rates and maximum oil recoveries.With horizontal well lengths in the order of 2,000 m, a typical production well in the pool shouldinitially be capable of producing 3,600 m 3 of oil per day.4.2.1.2 North Avalon PoolTwo wells, N-22 and N-30, have been drilled in the North Avalon Pool. Both of the wells encounteredand tested gas. The average gas column thickness for the pool is expected to be approximately 177 mand contain between 41 and 54 billion m 3 of the OGIP. This represents approximately 50 percent of thegas in the Avalon Formation.The N-30 well encountered 15 m of oil at the bottom of the Avalon Formation. Extrapolating to thecommon water gradient in the field, the pool is expected to have a 56-m oil column. The OOIP for thepool is estimated to be between 25 and 32 million m 3 . Proven plus probable (P50) volumes areestimated to be 29 million m 3 or approximately 15 percent of the oil in place in the field.On average, the North Avalon pool is expected to be of poorer reservoir quality than the South AvalonPool, with an average permeability in the order of 95 mD.White Rose DA Project Summary • January 2001 Page 49
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 56 and 57: 4.2.1.3 West Avalon PoolOnly one we
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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