Reservoir Fluid StudySTATOIL

15/8-1 Well DST 1CSleipner Field

NorwayRFL 830489

- 2 NOV. 18?3

Reservoir Fluid Analysis

7501 STEMMONS FREEWAY. BOX 47547. DALLAS. TEXAS 75247 • 214/631-8270

September 30, 1983CORE LABORATORIES, INC.

STATOILFORUSP. 0. Box 300N-4001 StavangerNorway

Attention: Mr. J. Grande

P. L. MosesManager

Reservoir Fluid Analysis

Subject: Reservoir Fluid Study15/8-1 Well OST 1CSleipner FieldNorwayRFL 830489

Gentlemen:

Samples of separator gas and liquid collected from the subject well byyour representatives on December 3, 1981, were forwarded to ourlaboratory for use in a reservoir fluid study. The results of thestudy are presented in this report.

The opening pressures of the separator gas cylinders and the saturationpressure of the separator liquid were measured at ambient, laboratorytemperature. These measurements were compared to the reported, samplingconditions to provide a quality control check. A summary of the samplesreceived in the laboratory may be found on page two.

The compositions of the separator gas samples were measured throughnonanes with decanes plus fractions by a combination of routine gas andtemperature-programmed chromatography. The results of these analysesmay be found on pages three and four. The composition of the separatorliquid was determined through hexanes by low-temperature, fractionaldistillation and gas chromatography. The heptanes plus fraction wasthen analyzed to an eicosanes plus fraction by temperature-programmedchromatography. These data are shown on pages fi ve and six.

The producing gas/liquid ratio was 7417 cubic feet of primary separatorgas at 14.73 psia and 60°F. per barre! of stock tank liquid. In thelaboratory, this was found to be equivalent to 3700 standard cubic feetof primary separator gas per barrel of primary separator liquid at 515psig and 88°F. The separator products were physically recombined tothe latter ratio. A portion of the recombined fluid was charged to ahigh pressure, windowed cell at reservoir temperature (275°F.). Vi sua!examination revealed that the fluid contained what appeared to be

STATOIL Page Two15/8-1 Well DST 1C

drilling mud (approximately 10 percent by vol urne). This contaminationwas traced to the separator liquid sample. Due to a shortage ofseparator liquid, it was necessary to reproduce the liquid in thelaboratory by flashing the contaminated, recombined fluid back througha separator operating at 515 psig and 88°F. The contaminant was thenallowed to precipitate from the liquid. The "clean" separator liquidwas then displaced into a mixing cyl inder and recombined with theseparator gas. The resulting fluid was used in the remainder of thestudy. The composition of the well stream, also shown on page f i ve,was calculated based on the measured compositions of the separatorproducts and the recombination ratio. Please note that the well streamcomposition differs from that reported via telex on September 2, 1983,which was calculated using the composition of the contaminated separatorliquid.

A portion of the recombined fluid was charged to a high pressure,windowed cell at reservoir temperature (275°F.). During a constantcomposition expansion at this temperature, a retrograde dew point wasobserved at 3678 psig which is significantly below the reportedreservoir pressure of 7711 psig. The pressure-volume relations arepresented on page seven.

A constant volume depletion at reservoir temperature was performed onthe fluid. Starting at saturation pressure, a sample of fluid wasexpanded to the first depletion pressure and equilibrated. Theresulting gas phase was displaced from the cell at constant pressureuntil original sample volume was obtained. The volume, deviationfactor and composition of the produced gas were determined. Theremaining system was then expanded to the second depletion pressure,the gas phase produced back to constant volume, and the produced gasanalyzed. This procedure was repeated until the reservoir pressurewas depleted to 700 psig. The 700 psig equilibrium liquid phase wasthen analyzed. A tabulation of these data may be found on page eight;graphic interpretations are provided on pages twelve and thirteen.

Flash calculations were performed to determine the recoverable tankliquid and separator gas as functions of reservoir pressure. A 100percent plant efficiency was assumed. The results of thesecalculations are shown on pages nine and ten.

During the depletion, retrograde liquid volume was measured visually.The maximum liquid volume observed was 7.2 percent of the hydrocarbonpore space. These data are presented in tabular and graphic formats onpages eleven and sixteen, respectively.

STATOIL Page Three15/8-1 Well OST 1C

Thank you for the opportunity to perform this study for STATOIL. Shouldyou have any questions concerning these data, or i f we may be of furtherservice, please do not hesitate to contact us.

Very t ru ly yours,

CORE LABORATORIES, INC.

Jp****+ >James R. PortnerArea ManagerReservoir Fluid Analysis

JRF:RSR:mc10 cc: Addressee

l cc: Core Laboratories U.K., Ltd.Howe Moss RoadKirkhill Industriel EstateDyce, AB2 OES Aberdeen ScotlandAttn: Mr. Les Sebborn

CORE LABORATORIES. INC.Reservoir Fluid Analysis

Page 1 of____Tj6_

File RFL 830489

Company STATOIL______________ Date Sampled December 3, 1981_____

Well 15/8-1 PST 1C___________ State_____________________

Field___Sleipner_________________ Country_____Norway

FORMATION CHARACTERISTICS

Formation Nåme ____________________Date First Well Completed ______^____________Original Reservoir Pressure PSIG @ Ft7Original Produced Gas/Liquid Ratio _ _ _ _ _ _ _ _ _ _ S C F / B b l

Production Rate ______ ________Bbls/DaySeparator Pressure and Temperature PSIG °F.Liquid Gravity at 60°F. _______________°API

Datum Ft. SubseaWELL CHARACTERISTICS——————————

Elevation __________________Ft.Total Depth ___________________Ft.Producing Interval _________________Ft.Tubing Size and Depth In. to ......_ .f**Open Flow Potential MMSUFTDayLast Reservoir Pressure 7711 PSIG @ Ft.

Date ______Reservoir Temperature 275 °F. @ Ft.Status of Well ____________________Pressure Gauge ____________________

SAMPLING CONDITTOH5——————————————Flowing Tubing Pressure 1860 PSIG @ 128°F.______Flowing Bottom Hole Pressure PSTGPrimary Separator Pressure 515 "PSIGPrimary Separator Temperature 88 °F.Secondary Separator Pressure __________________PSIGSecondary Separator Temperature ___________________°F.Field Stock Tank Liquid Gravity °API g 60°F.Primary Separator Gas Production Rate _____________MSCF/Day

Pressure Base 14.73 PST!———————————Temperature Base 60_______°F.Compressibility Factor (Fpv) ___________Gas Gravity (Laboratory) ___________Gas Gravity Factor (Fq)

Liquid Production Rate @ 60°F. _______________Bbls/DayPrimary Separator Gas/Stock Tank Liquid Ratio 7417 SCF/Bbl

or 134.88 Bbls/MMSCFSampled by ______________________

REMARKS:

Ihese analyses, opinicns or interpretations are based on observations and material supplied by the client to uhcm, and for trfiose exclusive arri oonfidentialuse, this report is ude. The intervretaticns or opinions expressed represent the best judgement of Ccre Laboratories, Inc. (all eirore and cmissionaexcepted)i but Core Laboratories, Inc. and its officers and enployees, assuae no responsibility and make no warrvuity or representations as to the produc-tivity, proper operation, or profitableness of any oil, gfts or other Bineral uell or sand in oonnectkn with riiich such report is used or re lied upcn.

CORE LABORATORIES. INC.Reservoir Fluid Analysis

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1C

SUMMARY OF SAMPLES RECEIVED IN LABORATORY

Separator Gas

Separator Conditions

Cylinder Pressure, Temperature,Number PSI6 °F.

Laboratory Opening Conditions

Pressure, Temperature,PSIG °F.

001-108001 -l 02

515*515**

8888

520540

7070

Separator Liquid

Separator Conditions

Cylinder Pressure, Temperature,Number PSIG °F.

Laboratory Bubble Point Pressure

Pressure, Temperature,PSIG °F.

001-1 515 88 513 71

*Cylinder tåg indicated sampling pressure = 560 psig.**Cylinder tåg indicated sampling pressure = 595 psig.

niese analyses, opinions or interpretations are based on observations and material supplied by the client to uhaa, and for «hose exclusive and confidentialuse, this report is nåde. Ihe interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omiesionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assune no responsibility and mate no warmnty or representations as to the produc-tivity, proper operaticn, or profitableness of any oil, gas or other mineral uell or sand in oonnection with viiich such report ia used or relied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analysis

Page 3 of 16

File RFL 830489

Wel! 15/8-1 PST 1C

HYDROCARBON ANALYSIS OF SEPARATOR GAS SAMPLE

Component Mol Percent 6PM

Hydrogen Sulfide 0.00Carbon Dioxide 9.43Nitrogen 3.02Methane 65.00Ethane 10.71 2.863Propane 8.75 2.407iso-Butane 1.23 0.402n-Butane 1.26 0.397iso-Pentane 0.28 0.102n-Pentane 0.17 0.062Hexanes 0.09 0.037Heptanes 0.04 0.016Octanes 0.02 0.009Nonanes Trace 0.000Decanes plus Trace 0.000

100.00 6.295

Calculated gas gravity (air = 1.000) = 0.843

Calculated gross heating value = 1176 BTU percubic foot of dry gas at 14.73 psia and 60°F.

Collected at 515 psig and 88°F.

Cy linde r: 001-108

Ihese analyses, opinions or interpretations are based on observations and naterial supplied by the client to (don, and for «tose exclusive and oonfidentialuse, this report is nåde. Ihe interpretatioro or opinions expressed represent -Q» best judgement of Core Laboratories, Inc. (all errors and onissionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assine no responsibility and make no worranty or representations as to the produc-t i vi ty, proper operation, or profitableness of any oil, gfts or other Bineral uell or sand in oonnecticn with which such report is used or reiied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analysis

Page 4 of- 16

File RFL 830489

Hell 15/8-1 PST 1C

HYDROCARBON ANALYSIS OF SEPARATOR GAS SAMPLE

Component Mol Percent GPM

Hydrogen Sulfide 0.00Carbon Dioxide 9.40Nitrogen 2.99Methane 64.93Ethane 10.70 2.860Propane 8.78 2.416iso-Butane 1.24 0.405n-Butane 1.29 0.407iso-Pentane 0.30 0.110n-Pentane 0.19 0.069Hexanes 0.11 0.045Heptanes 0.05 0.021Octanes 0.02 0.009Nonanes Trace 0.000Decanes plus Trace 0.000

100.00 6.342

Calculated gas gravity (air = 1.000) = 0.845

Calculated gross heating value = 1180 BTU percubic foot of dry gas at 14.73 psia and 60°F.

Collected at 515 psig and 88°F.

Cyl inder: 001-102

\s Ihese analyses, opinions or interpretations are based on observations and naterial supplied by the client to uttom, and for uhose exclusive and confidential\ use, this report is nåde. The interpretatiuns or opinions expressed represent the best judgement of Gåre Laboratories, Inc. (all errors and omissions

excepted); but Gane Laboratories, Inc. and its officers and enployees, assuoe no responsibility and nake no uarranty or representations as to the produe-tivity, proper operation, or profitableness of any oil, gas or other Bineral uell or sand in oonnection with uhich such report is used or relied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analysis

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HYDROCARBON ANALYSES OF SEPARATOR PRODUCTS AND CALCULATED WELL STREAM

ComponentSeparator Liquid,

Mol Percent

Hydrogen Sul f i deCarbon DioxideNitrogenMethaneEthanePropaneiso-Butanen-Butaneiso-Pentanen-PentaneHexanesHeptanesOctanesNonanesDecanes plus

Properti es of Heptanes plus

0.004.100.2413.6110.3822.926.479.144.353.754.844.225.373.207.41

100.00

AP I gravity @ 60°F. 38.5Density, Gm/Cc @ 60°F. 0.8315Molecular weight 135

Separator Gas,Mol Percent

0.009.402.99

64.9310.70

8.78

Well Stream

,24,29

0.300.190.110.050.02

TraceTrace

100.00

103

Mol Percent

0.008.092.3152.2610.6212.272.533.231.301.071.281.081.340.791.83

100.00

0.831135

6PM

2.8393.3750.8271.0180.4760.3870.5222.592*

12.036

Calculated separator gas gravity (air=1.000) = 0.845Calculated gross heating value for separator gas = 1180 BTUper cubic foot of dry gas @ 14.73 psia and 60°F.

Primary separator gas collected @ 515 psig and 88°F.Primary separator liquid collected @ 515 psig and 88°F.

Primary separator gas/separator liquid ratio = 3700 SCF/Bbl @ 88°F.Primary separator liquid/stock tank liquid ratio = 2.0046 Bbls @ 88°F./BblPrimary separator gas/well stream ratio = 753.11 MSCF/MMSCFStock tank liquid/well stream ratio = 101.54 Bbls/MMSCF

*6PM value for heptanes plus fraction

Ihese analyses, opinions or interpretations are based on observations and material supplied by the client to uhom, and for uhose exclusive and confidentialuse, this report is ude. The interpretations or opinions expressed represent the best judgeraent of Core Laboratories, Inc. (all errors and ontissionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assune no responsibility and nake no warranty or representatioris as to tite produc-tivity, proper operation, or profitableness of any oil, gas or other uLneral «all or sand in oomection with t*uch such report is used or reiied upon.

CORE LABORATORIES. INC.Reservoir Fluid Analysis

Page 6____of 16

File RFL 830489

Well 15/8-1 PST 1C

HYDROCARBON ANALYSIS OF SEPARATOR LIQUID HEPTANES PLUS FRACTION

Component Weight Percent Mol Percent

Propane 0.00 0.00Butanes 0.00 0.00Pentanes 0.00 0.00Hexanes 0.00 0.00Methyl-Cyclopentane 2.56 4.08Benzene 0.00 0.00Cyclohexane 4.08 6.51Heptanes 8.26 11.07Methyl-Cyclohexane 8.26 11.29Toluene 5.14 7.49Octanes 7.75 9.11Ethylbenzene 0.97 1.23Meta & Para Xylenes 6.26 7.92Orthoxylene 1.57 1.99Nonanes 5.44 5.69iso-Propyl Benzene 0.35 0.39n-Propyl Benzene 0.40 0.451,2,4 Trlmethylbenzene 2.32 2.59Decanes 7.40 6.98Undecanes 5.91 5.08Dodecanes 3.49 2.75Tridecanes 4.08 2.97Tetradecanes 3.91 2.65Pentadecanes 3.47 2.19Hexadecanes 2.62 1.55Heptadecanes 1.83 1.02Octadecanes 1.59 0.84Nonadecanes 1.33 0.67Eicosanes plus 11.01 3.49

100.00 100.00

Calculated average molecular welght = 134

These analyses, opiniøns or interpretations are based on observations and material supplied by the client to «hom, and for duse exclusive and oonfidentialuse, this report is nåde. The interpretatiuns or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errore and omissionsexcepted); but Con taboratories. Inc. and its officers and enployees, assune no responsibility and make no warrwnty or representations as to the produc-tivity, proper operation, or profitableness of any oil, gas or other mineral uell or sand in oonnecticn with vfiich such report is used or r-elied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analysis Page_

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DEPLETION STUDY AT 275°F.

Hydrocarbon Analyses of Produced Well Stream - Mol PercentReservoir Pressure - PSIG

Component

Carbon DioxideNitrogenMethaneEthaneP rop aneiso-Butanen-Butaneiso-Pentanen-PentaneHexanesHeptanes plus

Molecular weight of heptanesDensity of heptanes plus

Equilibrium gasTwo-phase

3678

8.102.3252.2910.6212.272.533.231.301.071.265.01

100.00

plus 1350.831

0.8420.842

3000

8.152.3453.5410.6612.202.493.101.240.991.174.12

100.00

1240.821

0.7970.788

2400

8.262.4054.2410.7312.132.453.081.210.981.103.42

100.00

1190.815

0.7920.768

1800

8.342.4554.6410.8112.152.443.071.200.981.062.86

100.00

1140.810

0.8140.770

1200

8.472.4354.3810.9312.372.493.221.200.971.052.49

100.00

1100.805

0.8620.779

700

8.402.3953.6311.0212.742.603.331.301.081.142.37

100.00

1090.804

0.9120.782

700*

2.060.208.474.329.262.924.352.822.605.0257.98100.00

1590.856

Well Stream produced-Cumulative percent of initial O 12.822 28.424 46.361 64.494

*Composition of 700 psig equilibrium liquid phase.

79.130

These analyses, opinions or interpretations are based on observations and material supplied by the client to uhon, and for Mhose exclusive and confidentialuse, this report is rasle. The interpretations or opinions expressed represent the best judgement of Gane Laboratories, Inc. (all errors and omissionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assume no responsibility and make no warranty or representations as to the produc-tivity, proper operation, or profitableness of any oil, gas'or other mineral Hell or sand in connection uith which such report is used or relied upcn.

CORE LABORATORIES. INC.Reservoir Fluid Analysis

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PRESSURE-VOLUME RELATIONS OF RESERVOIR FLUID AT 275°F.(Constant Composition Expansion)

Pressure,PSIG

80007711 Reservoir7500700065006000550050004500420040003900380037003678 Dew Point160035003350315029002600230018931620142812771152

RelativeVol urne

0.7316Pressure 0.7398

0.74600.76340.78100.80290.82920.86110.90140.93170.95490.96810.98180.99651.00001.01261.02971.05901.10581.17781.29371.45101.77682.09802.41422.73063.0621

Deviation Factor,Z

l,1.l,l,1.1.1.

(1).337.303.278.221,160,101.043

0.9850.9280.8960.8750.8640.8540.8440.842 (2)

(1) Gas expansion factor = 1.599 MSCF/Bbl(2) Gas expansion factor = 1.183 MSCF/Bbl

These analyses, opinians or interpretations are based on observations and nuterial supplied by the client to utan, and for whose exclusive and confidentialuse, this report is nåde. the interpretations or opinions expressed represent the best judgement of Gore Laboratories, Inc. (all errors and cniissiansexcepted); but Core Laboratories, Inc. and its officers and enployees, assune no responsibility and make no wan>inty or representations as to the produc-tivity, proper operation, or profitableness of any oil, gas or other mineral «all or sand in ccmection with which such report is used or relied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analysis Page

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CALCULATED CUMULATIVE RECOVERY DURING DEPLETION

Cumulative Recovery perMMSCF of Original Fluid

Well Stream - MSCF

Normal Temperature SeparationStock Tank Li qu i d - Barre! sPrimary Separator Gas-MSCFStock Tank Gas - MSCF

Total "Plant Products" inPrimary Separator Gas-Gallons——————————

PropaneButanes (total )Pentanes plus

Total "Plant Products" inStock Tank Gas - Gallons

PropaneButanes (total )Pentanes plus

Total "Plant Products" inWell Stream - Gallons

PropaneButanes (total)Pentanes plus

Primary separator at 515 psig and 88°F.; stock tank at 50°F.

Initialin Place

1000

92.99791.38120.02

23652115714227

4581116773336

2839337518453953

Reservoir Pressure -3678

0

000

00 ,00

0000

0000

3000

128.22

9.61104.7413.84

3122869831

521299241

365430230418

2400

284.24

19.47235.0829.39

70264622471

10827319890

813951506859

1800

463.61

29.16387.3746.24

11581073377120

168428316146

133115508231307

PSIG1200

644.94

37.89542.2363.32

16271518540170

227585441206

1861216811541724

700

791.30

44.93666.0378.26

20061882673211

279723551262

2292268014322067

These analyses, opinions or interpretations are based on observations and material supplied by the client to whctn, and for Mhose exclusive and oonfidentialuse, this report is nåde. the interpretations or opinions expressed represent the best judgeraent of Gåre Laboratories, Inc. (all errore and onisBionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assume no responsibility and make no warranty or representations as to the produc-tivity, proper operation, or profitableness of any oil, gas or other nineral well or sand in connection with uhich sudl report is used or relied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analysis

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CALCULATED INSTANTANEOUS RECOVERY DURING DEPLETION

Reservoir Pressure - PSI6

3678 3000 2400 1800 1200 700

Normal Temperature SeparationStock Tank Liquid Gravity, °API at 60°F.Separator Gas/Well Stream Ratio, MSCF/MMSCF

Prirnary Separator Gas OnlyPrimary Stage Separator and Stock Tank Gases 911.40

Separator Gas/Stock Tank Liquid Ratio, SCF/STBPrimary Separator Gas OnlyPrimary Stage Separator and Stock Tank Gases

56.1

791.38

85109801

59.5

816.91924.83

1089712336

62.0

835.36935.01

1322014797

64.5

849.06943.03

1572217462

66.7

854.00948.18

1772419679

68.1

845.86947.94

1759519718

GPM from Smooth Well Stream CompositionsEthane plus———————————————Propane plusButanes plusPentanes plus

12.0139.1735.7983.953

11.2568.4065.0503.259

10.8047.9354.5982.827

10.4987.6084.2652.500

10.4497.5274.1242.295

10.6997.7534.2482.349

TTiese analyses, opinions or interpretations are based on observations and material supplied by the client to whora, and for «hose exclusive and oonfidentialuse, this report is nåde. The interpretatians or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and onissionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assume no responsibility and nake no warranty or representations as to the produc-tivity, proper operation, or profitableness of any oil, gas or other mineral uell or sand in connection with **iich such report is used or relied upon.

CORE LABORATORIES, INC.Reservoir Fluid Analy sis

Page 11 of__]6_

Fl 1 e RFL 830489

Well 15/8-1 PST 1C

RETROGRADE CONDENSATION DURING GAS DEPLETION AT 275°F.

Pressure, Retrograde Liquid Volume,PSIG Percent of Hydrocarbon Pore Space

3678 Dew Point 0.0HOT 0.13500 0.23350 0.43150 0.73000 First Depletion Pressure 1.62400 5.71800 7.21200 7.1700 6.1O 3.7

Ihese analyses, opinions or interpretations are based on obseivatione and material supplied by the client to whctn, and for whose exclusive and confidenti*!use, this report is ude. lhe interpretatiuns or opinions expressed represent the best judgement of Gåre Laboratories, Inc. (all errors and omissionsexcepted); but Core Laboratories, Inc. and its officers and enployees, assune no responsibility and make no warranty or representations as to the praduc-tivilTV. MODCr oocr«tuvi. ar ranofi-fcahl«neaR of aiw oil. oaa on other« nitv^nil uøll nm umri in oormer-t-inn wi-hh t^ir-h m»nh

CORE LABORATORIES, INC.Petroleum Resenxnr Engineering

DALLAS, TEXAS

Pacjc* 12 nf 16Fiia RFL 830489

DEVIATION FACTOR OF GAS PHASE DURING DEPLETION

1.5

1.4

1.3

1.2

1.1QÉOO

1.0

0.9

0.8

0.7

0.6

0.5

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CORE LABORATORIES, INC.Petroleum Reservoir Engineering

DALLAS, TEXAS

PageFile_

13 «f 16RFL 830489

CUMULATIVE PRODUCED VOLUME DURING DEPLETION

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CORE LABORATORIES, INC.Petroleum Reservoir Engineering

DALLAS, TEXAS

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