COMPOSITIONAL DATA : GAS : GAS PROPERTIES Puffin Fm RFT ...

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TEST DATA FROM THE DISCOVERY WELL (Skua-2):DST 2, 1,852-1,855 m,Recovered 30 bbls of formation water.DST 1, 2,332-2,336.5 m,Flowed 43.3 o API oil at 450 bbls/daythrough a 6.4 mm choke at 630 psi.Bathurst Island Group (Late Maastrichtian)Bathurst Island Group (Santonian)APPRAISAL AND DEVELOPMENT DRILLING :Skua-1 was drilled inside structural closure but intersected the reservoir below the oil/water contact andwas plugged and abandoned. Minor oil shows were recorded in swc’s shot at the Miocene/Eoceneunconformity and in tight Palaeocene limestones.Skua-2 intersected the western bounding fault of the structure at 2,338 mKB and did not penetrate acomplete reservoir section. The well was subsequently plugged and abandoned due to poor flow rates.A residual oil column was identified between 1,853 mKB and 1,859 mKB in a Late Maastrichtian sandin Skua-2. Testing (DST 2) indicated the sand was water saturated. The Santonian oil saturated sandtested by DST 1 in the Skua-2 well is juxtaposed against the Plover Formation reservoir across thewestern bounding fault. The unit is thought to be draining oil across the fault from the Plover Formationbut due to poor reservoir quality, the Santonian sand acts as a natural choke to flow.Skua-3 was initially drilled vertically to test a series of shallow, stacked closures. Below 1,488 mKB, thewell was drilled directionally to intersect deeper closures in an optimal position. The well intersected a44.4 mTVT hydrocarbon column between 2,286.3 mTVDSS and 2,330.7 mTVDSS (35.8 mTVT of netpay) and was suspended as a potential oil producer. Skua-3, drilled in a crestal position, was the firstwell to test the Plover Formation reservoir proper. DST 2, taken over the interval 2,376-2,381 m, flowedoil at 5,477 bbls/day and gas at 240,665 m 3 /day.Skua-4, located 1.8 km northeast of Skua-3, was cased and suspended as a future oil producer.Skua-5 was an appraisal well designed to test the northeasterly extent of the field. The well tested asmall, deeper and separate oil and gas accumulation which was not thought to economically producible.The well was plugged and abandoned.Skua-6 was drilled as a flank appraisal well. The well was plugged and abandoned after encountering aresidual oil column down to 2,368 mSS in the Early Jurassic section.Skua-7 was plugged and abandoned after the Operator was unable to run 30” surface casing. The wellwas redrilled as Skua-7A.Skua-7A was drilled as production well on the northern culmination of the field. The well intersected a29 m oil column (12.9 m net pay) but the oil/water contact was obscured by a shaley interval. Oil wasrecorded down to 2,333 mSS. Skua-7A also intersected a 1 m oil column overlain by gas in a thin sandwithin the Puffin Formation (1,930 – 1,932.5 mKB).Skua-8 was completed as a future producer after intersecting a 51 m gross hydrocarbon column (4 m gascolumn, 47 m oil column).Skua-9 intersected a 50 mTVT gross hydrocarbon column (41.9 mTVT net pay) before the drill stringbecame irretrievably stuck at 2,534 mKB. The well was plugged back and kicked off at 2,074 mKB asSkua-9ST-1.Skua-9ST-1 was completed as a future producer after intersecting a 53 mTVT hydrocarbon column(46.5 m oil column, 6.5 m gas column) between 2,280 mTVDSS and 2,333 mTVDSS.
RESERVES:Initial Oil:20.5 MMbblsSource: Northern Territory Department of Business Industry and ResourceDevelopment, 1998.REMARKS:Fluid inclusion studies by O’Brien & others (1996) indicates a 10 m residual oil column below thepresent day OWC. This suggests appreciable quantities of oil (~ 20 million barrels) have leaked from theSkua structure, probably during the reactivation of bounding faults in the Tertiary.Production from the Skua oil field commenced 1991 via sub-sea completions connected to an FPSO.The field was producing oil at a rate of 1,900 bbls/day when production was shut in and the fielddecommissioned in January 1997.STRATIGRAPHY (Skua-2) :AGE UNIT FORMATION TOP(mKB)WOODBINE Undifferentiated 89.0TERTIARY GROUP Hibernia Formation 852.0Woodbine Beds 1393.0CRETACEOUS BATHURST ISLAND GP Undifferentiated 1844.0JURASSIC TROUGHTON GROUP Plover Formation 2338.0STRATIGRAPHY (Skua-9) :AGE UNIT FORMATION TOP(mSS)Barracouta/Oliver Fms 83.0TERTIARY WOODBINE Prion/Hibernia Fms 838.5GROUP Grebe Sandstone 1224.0Johnson Formation 1430.0CRETACEOUS BATHURST ISLAND GP Puffin/Fenelon Fms 1848.0JURASSIC TROUGHTON GROUP Plover Formation 2283.0
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COMPOSITIONAL DATA :GAS :GASPROPERT
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Accumulation Number: 10BONAPARTEORI
Page 6 and 7:
Accumulation Number: 11BUFFALOORIGI
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Accumulation Number: 12BULLERORIGIN
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REMARKS:Fluorescence recorded below
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124°58'125°00'125°02'Challis 11C
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Accumulation Number: 14CHALLISORIGI
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RFT 4, 1,392 m,Recovered 6.5 litres
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Accumulation Number: 15CHUDITCHORIG
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Accumulation Number: 16CORALLINAORI
Page 22 and 23:
Accumulation Number: 17CRUXORIGINAL
Page 24 and 25:
Accumulation Number: 18CURLEWORIGIN
Page 26 and 27:
TEST DATA FROM THE DISCOVERY WELL (
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125°18'1060125°20'10701070107011
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Accumulation Number: 20EAST SWANORI
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GAS SATURATION:33% (average, 2,695
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124°34' 124°36' 124°38'280012°1
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1250125°45'125°50'0 5 km11°15'Co
Page 39 and 40:
Accumulation Number: 23ELANGORIGINA
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126°32'126°34' 126°36' 126°38'1
Page 43 and 44:
Accumulation Number: 24EVANS SHOALO
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RFT 13, 3,678 m,Plover FormationRec
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1800127°30'2000127°40'19002000210
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COMPOSITIONAL DATA :GAS :GASPROPERT
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126°30'126°40'1050105010°50'1000
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STRATIGRAPHY (Flamingo-1) :AGE UNIT
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600129°15'129°30'129°45'11°45'N
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Accumulation Number: 28FOHNORIGINAL
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Accumulation Number: 29GARIMALAORIG
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Accumulation Number: 30HALCYONORIGI
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STRATIGRAPHY (Halcyon-1) :AGE UNIT
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124°58'125°00'Jabiru 1211°55'Jab
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Jabiru-4 intersected a 32.5 m gross
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STRATIGRAPHY (Jabiru-12) :AGE UNIT
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REMARKS:Jahal-1 was drilled to 3,30
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126°28'126°30'320010°50'3200Kaka
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Accumulation Number: 34KAKATUA NORT
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REMARKS:Kakatua North-1 was abandon
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1700129°00'1800129°05'1790129°10
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Accumulation Number: 36KELP DEEPORI
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STRATIGRAPHY (Krill-1) :AGE UNIT FO
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Accumulation Number: 40LESUEURORIGI
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TEST DATA FROM THE DISCOVERY WELL (
Page 89 and 90: Accumulation Number: 39LAMINARIAORI
Page 91 and 92: TEST DATA FROM THE DISCOVERY WELL (
Page 93 and 94: Accumulation Number: 41LEEUWINORIGI
Page 95 and 96: STRATIGRAPHY (Leeuwin-1) :AGE UNIT
Page 97 and 98: 1400125°35'125°40'145014201450140
Page 99 and 100: Accumulation Number: 43LOXTON SHOAL
Page 101 and 102: RESERVES:Gas:Condensate:9.56 TCF (i
Page 103 and 104: RFT 8, 3,724.9 m,Recovered 0.03 m 3
Page 105 and 106: Accumulation Number: 45MARETORIGINA
Page 107 and 108: REMARKS:A 3.5 m gross hydrocarbon c
Page 109 and 110: 124°31'124°33'12°40'275027002700
Page 111 and 112: STRATIGRAPHY (Montara-1) :AGE UNIT
Page 113 and 114: 125°00'125°05'350032500 5 kmConto
Page 115 and 116: STRATIGRAPHY (Oliver-1) :AGE UNIT F
Page 117 and 118: MDT, Run 1, 2,600.5 mRecovered 21 l
Page 119 and 120: 125°02'00.5 km1650Contour Interval
Page 121 and 122: Accumulation Number: 50PENGUINORIGI
Page 123 and 124: RFT 5, 2,535 m,Recovered 3.6 m 3 of
Page 125 and 126: 128°20'WANT128°30'425012°40'0 10
Page 127 and 128: COMPOSITIONAL DATA :GAS :GASPROPERT
Page 129 and 130: Accumulation Number: 53PUFFINORIGIN
Page 131 and 132: APPRAISAL AND DEVELOPMENT DRILLING
Page 133 and 134: Accumulation Number: 54RAMBLERORIGI
Page 137 and 138: STRATIGRAPHY (Saratoga-1) :AGE UNIT
Page 139: 124°24'124°25'124°26'124°27'GOC
Page 143 and 144: 17501750127°45' 128°00' 128°15'1
Page 145 and 146: Accumulation Number: 58SUNSETORIGIN
Page 149 and 150: Accumulation Number: 59SWANORIGINAL
Page 153 and 154: Accumulation Number: 60TAHBILKORIGI
Page 155 and 156: NET PAY:60.7 mNET TO GROSS RATIO: 8
Page 157 and 158: 16001600124°52'124°52'124°54'165
Page 159 and 160: COMPOSITIONAL DATA CONTD :GAS :GASP
Page 163 and 164: Accumulation Number: 63TERNORIGINAL
Page 165 and 166: PERMEABILITY:PETROLEUM BEARING UNIT
Page 167 and 168: Accumulation Number: 64TROUBADOUROR
Page 169 and 170: FIT 3, 2,286 m,Recovered 0.45 m 3 o
Page 171 and 172: Accumulation Number: 65TURTLEORIGIN
Page 173 and 174: PETROLEUM BEARING UNIT No.2:CONTENT
Page 175 and 176: RFT 4, 1,624.6 m,Recovered 1-2 cc o
Page 177 and 178: Accumulation Number: 66VIENTAORIGIN
Page 181 and 182: PETROLEUM BEARING UNIT No.2: Langfi
Page 184 and 185: 123° 124° 125° 126° 127° 128°
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COMPOSITIONAL DATA : GAS : GAS PROPERTIES Puffin Fm RFT ...

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