CORE LABORATORIES
tillitiabl
AUG 5 1999
RzczIvFn
Core Laboratories Reservoir Fluids Report - Calgary
Oirausta-Ifewtrou.adita4,01
otrrib04-•
for
Hibernia Management & Development Company Ltd.
HMDC Hibernia B16-3
Number Of Pages ( including cover page): 8
File Number: 52134-98-1526/52143-98-0018
Date: July 23, 1999
/
Report Distribution: John Andrews, HMDC (St. John's) - 3 ,copies \
4;
11) .
APPROVED BY:
0
Eric MacDonald, B.Sc.
Technical Specialist, Non-Routine R ery i ' Fluids
Phone # 250-4082
Please contact the above person should there be any questions concerning the
contents of this report. Atmospheric samples will be kept a maximum of 30 days.
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the
client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed
represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas,
coal or other mineral, proper well or sand in connection with which such report is used or relied upon for any reason
whatsoever.
CA-300149-ALL/02
INV-021373
iii
Release Date 04/29/1998
Registered 04/27/2010
Core Laboratories Lanaua
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000, Fax (403) 250-5120
COHLAB
COMPANY
SAMPLE ID
PROJECT
CORE LABORATORIES
Hibernia Management and Development
HMDC Hibernia B16-3
Various Analysis
PAGE 1 of 7
FILE 52134-98-1526
DATE 99-07-22
Scope of the Work
To provide analysis of a crude oil by gas chromatography (GC) to C3G+ and to determine
the sulfur content, acid number, pour point, cloud point and wax content of the sample
listed below. Also, to analyze the sample for saturate, aromatic, resin and asphaltene
fractions and to determine the elemental composition. Wax isolated from the sample is to
be analyzed by GC to C1o„.
Samples Received and Description
Sample #1:
HMDC Hibernia B16-3
Description:
Oil
Location:
Bottomhole SRS, depth 4085.0 mRT
Date Sampled: 98-02-27
Date Received: 98-03-12
Date Analyzed: 99-06-22
Results
A. Physical Properties
Wax Content
8.5 Wt.%
Total Sulfur
4.6 g/kg
Acid Number
0.10 mg KOH/g
Pour Point
3 °C
Cloud Point by Viscosity Deflection
32 +/- 2 °C
Viscosity at 15°C
62.72 cSt.
Viscosity at 20°C
34.17 cSt.
Viscosity at 30°C
14.56 cSt.
Viscosity at 40°C
8.538 cSt.
Viscosity at 50°C
5.969 cSt.
Viscosity at 60°C
4.553 cSt.
In general, the point of inflection when the above listed viscosity measurements are
plotted on ASTM D-341 graph paper indicates the onset of wax crystallization, or cloud
point. Cloud point by viscosity deflection assumes sufficient wax crystals form to initiate
a change in the physical properties (namely viscosity) of the fluid. See page 2 for a plot
of the viscosity data.
B. C1 Chromatogram On Organic Fraction
A wax fraction was recovered from the oil sample using UOP-46 method. In general, the
UOP-46 method collects wax precipitated at -30°C. This wax fraction was then dissolved
in CS2, which is a strong organic solvent and the CS2 soluble fraction of the sample was
analyzed using a gas chromatograph. The results are presented in tabular format on page
3, and in graphical format on page 4 of this report.
The wax in this sample is relatively light in nature with a carbon range of C20 — C40.
File:
DRAB
521 34-1 998-1 526
Page No: 2
Company Name:
Hibernia Management and Development
Well Name:
Hibernia B16-3
Location:
Sampled From:
Bottomhole SRS
Sampling Date:
VISCOSITY - TEMPERATURE CHART
KINEMATIC VISCOSITY (mm2/s)
500
300
200
80
60
40
30
20
10
8
7
6
5
5.
15.
25.
35.
45.
55.
TEMPERATURE (Degrees Celsius)
65.
75.
CORELAB
COMPANY
SAMPLE ID
PROJECT
CORE LABORATORIES
Hibernia Management and Development
HMDC Hibernia B16-3
Various Analysis
PAGE 3 of 7
FILE 52134-98-1526
DATE 1999-07-01
C60+ Tabular Results
Component
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
C31
C32
C33
C34
C35
Weight %
0.03
0.15
0.29
0.34
0.53
0.52
0.54
0.85
1.87
3.85
6.49
7.77
8.57
8.54
8.41
7.69
7.51
6.69
5.81
4.99
3.72
3.06
2.02
1.55
1.23
1.04
Component
C36
C37
C38
C39
C40
C41
C42
C43
C44
C45
C46
C47
C48
C49
C50
C51
C52
C53
C54
C55
C56
C57
C58
C59
C60
Weight %
0.96
0.95
0.77
0.86
0.61
0.42
0.31
0.23
0.16
0.13
0.10
0.08
0.08
0.07
0.08
0.05
0.04
0.02
0.01
0.01
0.00
0.00
0.00
0.00
0.00
COHLAB
COMPANY
SAMPLE ID
PROJECT
CORE LABORATORIES
Hibernia Management and Development
HMDC Hibernia B16-3
Various Analyses
PAGE
FILE
DATE
4 of 7
52134-98-1526
1999-07-01
7.04_
6.80
6.55__
6.31
6.07
IL
5 82
minu tes
1
1
1
5.62
11.25
16.87
SAMPLE: UOP WAX
22.50
28.12
33.75
39.37
45.00
COREL
COMPANY
SAMPLE ID
PROJECT
B
CORE LABORATORIES
Hibernia Management and Development
HMDC Hibernia B16-3
Various Analysis
PAGE 5 of 7
FILE 52134-98-1526
DATE 1999-07-01
C. SARA Analysis
Percent Oil - Carbon Number 14 and less
38.82 Wt.%
Percent Oil - Carbon Number 15 and greater
61.18 Wt.%
All of the analysis below are based on the C15+ fraction of the sample.
Percent Hydrocarbons (Saturates & Aromatics)
87.37 Wt.%
Percent Non-Hydrocarbons (Asphaltenes & Resins)
12.63 Wt.%
Saturate to Aromatic Ratio
1.34
Saturate Fraction
50.00 Wt.%
Aromatic Fraction
37.37 Wt.%
Resin Fraction
11.29 Wt.%
Asphaltene Fraction
1.34 Wt.%
D. Elemental Analysis
The sample was sent for elemental analysis according to ASTM D-5291 methodology.
The composition was determined as:
Carbon - C
85.15 %
Hydrogen - H
12.36 %
Nitrogen - N
0.45 %
E. Hydrocarbon Liquid Analysis
Refer to pages 6 and 7 for the results of the C30, analysis by gas chromatography.
(FAB
HYDROCARBON LIQUID ANALYSIS
069 - 11
52134-1998-1526
CONTAINER IDENTITY
LABORATORY NUMBER
Hibernia Management and Development
6
OPERATOR
PAGE
Hibernia B16-3
LOCATION
WELL OR SAMPLE LOCATION
KB ELEV (m)
GR ELEV (m)
Hibernia
FIELD OR AREA
POOL OR ZONE
TEST TYPE AND NO.
SAMPLER
TEST RECOVERY
Bottomhole SRS
oc
POINT OF SAMPLE
AMT. AND TYPE CUSHION
PUMPING
FLOWING
WATER
red
GAS LIFT
OIL
MUD RESISTIVITY
SWAB
red
GAS
red
TEST INTERVAL (meters)
a
SEPARATOR
°C
a
CONTAINER
WHEN SAMPLED
RESERVOIR
°C
CONTAINER
WHEN RECEIVED
SEPARATOR
Temperatures, °C
Pressures, kPa (gauge)
1998 05 27
DATE SAMPLED (Y/M/D)
COMPONENT
MOLE
FRACTION
1999 05 21
1999 07 22
TE
DATE RECEIVED (Y/WD)
DATE ANALYZED (Y/WD)
ANALYST
MASS
FRACTION
LIQUID
-UT%
FigC
SIGNATURE
OBSERVED PROPERTIES OF C6+ RESIDUE (15/15°C)
mUm'
867.8 kgirn.
N2
0.0000
0.0000
0.0000
0.0
CO 2
0.0000
0.0000
0.0000
0.0
H2 S
0.0000
0.0000
0.0000
0.0
C1
0.0000
0.0000
0.0000
0.0
0
0.0000
0.0000
0.0000
0.0
0.0004
0.0001
0.0001
1.5
0
2
3
0.0005
0.0001
0.0002
2.2
C4
0.0030
0.0007
0.0011
12.6
iC 5
0.0053
0.0016
0.0022
25.9
C5
0.0108
0.0032
0.0044
52.2
0
0.9800
0.9943
0.9920
11,868.1
1.0000
1.0000
1.0000
11,962.5
Total
0.8686
31.6
RELATIVE DENSITY
API © 15.5 °C
248
RELATIVE MOLECULAR MASS
CALCULATED PROPERTIES OF TOTAL SAMPLE (15/15°C)
865.8 kg/m'
iC 4
6+
DENSITY
DENSITY
0.8666
31.9
RELATIVE DENSITY
API © 15.5 °C
244.90
RELATIVE MOLECULAR MASS
REMARKS:
NOTE: All Properties have been calculated utilizing GPA 214548 physical constants.
DRAB
HYDROCARBON LIQUID ANALYSIS
Operator:
Hibernia Management and Development
Page: 7
Well:
Hibernia B16-3
File: 52134-1998-1526-11-069
Sample Point: Bottomhole SRS
Date: 1999 06 04
Analysis of C 6+ Fraction
Boiling Point:
Range (° C)
Component
36.1- 68.9
68.9- 98.3
98.3-125.6
125.6-150.6
150.6-173.9
173.9-196.1
196.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.6-287.8
287.8-302.8
302.8-317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
380.0-391.1
391.1-401.7
401.7-412.2
412.2-422.2
422.2-431.7
431.7-441.1
441.1 PLUS
Hexanes
Heptanes
Octanes
Nonanes
Decanes
Undecanes
Dodecanes
Tridecanes
Tetradecanes
Pentadecanes
Hexadecanes
Heptadecanes
Octadecanes
Nonadecanes
Eicosanes
Heneicosanes
Docosanes
Tricosanes
Tetracosanes
Pentacosanes
Hexacosanes
Heptacosanes
Octacosanes
Nonacosanes
Triacontanes Plus
80.0
110.6
136.1-138.9
144.4
168.9
48.9
72.2
81.1
101.1
Carbon
Number
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
C30+
0.0201
0.0428
0.0687
0.0612
0.0676
0.0563
0.0551
0.0462
0.0433
0.0378
0.0352
0.0305
0.0263
0.0237
0.0212
0.0192
0.0165
0.0156
0.0139
0.0134
0.0117
0.0115
0.0100
0.0106
0.1407
0.0071
0.0175
0.0320
0.0320
0.0393
0.0359
0.0383
0.0347
0.0351
0.0328
0.0325
0.0299
0.0272
0.0260
0.0245
0.0233
0.0209
0.0207
0.0193
0.0194
0.0175
0.0178
0.0161
0.0176
0.3449
0.0083
0.0199
0.0355
0.0348
0.0420
0.0378
0.0399
0.0358
0.0358
0.0333
0.0328
0.0301
0.0272
0.0258
0.0242
0.0229
0.0205
0.0202
0.0187
0.0187
0.0169
0.0172
0.0155
0.0170
0.3308
Benzene
Toluene
Ethylbenzene, p + m-Xylene
o-Xylene
1,2,4 Trimethylbenzene
C6H6
C7H8
C8H10
C8H10
C9H12
0.0016
0.0106
0.0147
0.0085
0.0045
0.0005
0.0040
0.0064
0.0037
0.0022
0.0004
0.0036
0.0058
0.0033
0.0020
Cyclopentane
Methylcyclopentane
Cyclohexane
Methylcyclohexane
TOTAL
C5H10
C6H12
C6H12
C7H14
0.0018
0.0061
0.0127
0.0204
0.9800
0.0005
0.0021
0.0044
0.0082
0.9943
0.0005
0.0022
0.0044
0.0082
0.9920
C6
C7
C5
C9
Cio
Cii
012
013
014
C15
C16
C17
C18
C19
C20
021
C22
C23
0 24
C25
C26
027
0 28
029
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
0.9581
0.9867
0.9832
252
0.8705
869.8
sue #:......
toiRiala :
CANADA-INIE\WOUNDIAND
PROMO* Of.. Off5140RE PETROvEUM BOARD
APR 29 1998
RECEIVED
Canada-Newfoundland
refratetrr Petroleum Pm,*
Reservoir Fluid Analysis
for
Hibernia Management and
Development Company Ltd.
HMDC Hibernia B16-3
Sample Date: Feb-08-98
Sampling Depth: 3 938 m MD
File Number: 52134-98-2063 (Calgary)
File Number: 52143-98-0027 (Newfoundland)
April 22nd, 1998
A product of
Core Laboratories Canada Ltd.
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core Laboratories Canada Ltd. assumes no responsibility and makes no Warranh,
-representations, expressed or implied, as to the productivity, proper operatic -mineral, proper well or sand in connection with which such report is used o
INV-021460
1
Release :
a l I
0429/1998
CA-300149-ALL/02
111'1111111e)11111,10
CORV
CORE LABORATORIES
April 22nd, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
Al C 6K3
Attention:
Mr. John Andrews
Subject:
Reservoir Fluid Analysis
HMDC Hibernia B16-3
Sample Date: Feb-08-98
Sample Depth: 3 938 m MD
File Number: 52134-98-2063 (Calgary)
File Number: 52143-98-0027 (Newfoundland)
Gentlemen:
A subsurface sample (MDT Tool) of reservoir fluid was collected from the subject well by a
representative of Schlumberger on February 8th, 1998. The sample was then submitted to our
Calgary laboratory for analysis.
Initially, the pressure in the MDT tool was raised, using water as a hydraulic fluid on the
piston side, to a working pressure of 48 263 kPa (gauge). The tool was agitated in order to
redissolve any liberated gas into the oil phase. Once the reservoir fluid in the sampler was
confirmed to be in single-phase, an aliquot was transferred, at 48 263 kPa (gauge), to an
evacuated, high-pressure, stainless steel, windowed cell for a reservoir temperature, saturation
pressure measurement. The remainder of the sample from this tool was then transferred to a
high-pressure, stainless steel cylinder.
As stated above, the saturation pressure measurement was carried out using a high-pressure,
windowed cell. After an aliquot of sample was transferred to the cell, the contents of the cell
were stabilized at the working pressure and reservoir temperature. The pressure in the cell
was then lowered by increasing the effective internal volume of the cell, through hydraulic
fluid withdrawal, until free gas was noticed through the window portion of the cell. The
pressure at which the first bubble of gas was noticed was defined as the saturation
(bubblepoint) pressure of the fluid. The fluid in the cell was returned to a single-phase state
and the process repeated to confirm the saturation pressure.
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000, Fax (403) 250-5120
.../2
2
The saturation pressure was reported and as instructed, a four-stage separator test and a
compositional analysis (C30+) were conducted on the subsurface sample. The conditions for
the separator test were supplied by Mr. John Andrews of Hibernia Management and
Development Company Ltd.
It should be noted that the data contained in the following report, although final for this issue,
maybe be refined once complete reservoir fluid studies have been conducted. The adjustments
or refinements would be as a result of more accurate and comprehensive measurements
required during the reservoir fluid studies. The changes, if any, would probably be within
±2% of the reported values.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LABORATORIES CANADA LTD.
Al Kassam
PVT - Technical Specialist
ak
enclosure
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3; Feb-8-98, 3 938 m MD
52134-98-2063
SUMMARY OF SATURATION PRESSURE DATA
Well
B16-3
Sampling
Sampling
Reservoir
Reservoir
Date
Depth
m MD
Temperature
°C
Pressure
Pressure *
kPa (absolute)
kPa (gauge)
3 938
95.6
39 487
34 922
Feb-08-98
Saturation
* Bubblepoint pressure (visually measured in a high-pressure, windowed cell).
Page 1
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3; Feb-8-98, 3 938 m MD
52134-98-2063
SEPARATOR TEST OF RESERVOIR FLUID SAMPLE
Separator
Pressure
kPa
(Gauge)
Separator
Temperature
°C
34 922
Gas/Oil
Ratio
(m3/m3)
(A)
Gas/Oil
Ratio
(m3/STm3)
(B)
75.0
184.1
73.0
Stock Tank
Oil Gravity
@ 15.6 °C
(°API)
Formation
Volume
Factor
(C)
Separator
Volume
Factor
(D)
Specific
Gravity of
Liberated
Gas (E)
213.8
1.162
0.723
16.6
18.5
1.111
0.843
92.0
12.7
13.9
1.088
1.243
45.0
0.4
0.4
1.027
N/M
Total
246.6
95.6
to
4 137
to
1 138
to
109
to
0
37.6
1.720
Sample Depth: 3 938 m MD
Date Sampled: Feb-08-98
Schlumberger
Sampled by:
N/M - not measured due to insufficient liberated gas.
(A) Cubic metres of gas 101.325 kPa (absolute) and 15.0 °C per cubic metre of oil indicated pressure and temperature.
(B) Cubic metres of gas 101.325 kPa (absolute) and 15.0 °C per cubic metre of stock tank oil 10 15.0 °C.
(C) Cubic metres of saturated oil @ 34 922 kPa (gauge) and 95.6 °C per cubic metre of stock tank oil t 15.0 °C.
(D) Cubic metres of oil indicated pressure and temperature per cubic metre of stock tank oil i@ 15.0 °C.
(E) Air = 1.000.
Page 2
Core Laboratories Canada Ltd.
ICE
CRELAB
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
685
52134-98- 2063
CONTAINER IDENTITY
LABORATORY NUMBER
Hihernia Management and Development
3
OPERATOR
PAGE
HMDC Hihernia B I6-3
LOCATION
WELL OR SAMPLE LOCATION
Hibernia
KB ELEV (m)
Hihernia
FIELD OR AREA
POOL OR ZONE
TEST TYPE & NO
GR ELF`•
Schlumberger
SAMPLER
TEST RECOVERY
Reservoir Fluid (MDT Sample)
°C
POINT OF SAMPLE
AMT & TYPE CUSHION
PUMPING
3938.() -
FLOWING
WATER
m3/d
MUD RESISTIVITY
GAS LIFT
OIL
SWAB
m3/d
GAS
m3/d
TEST INTERVAL (meters)
34922
SEPARATOR
@
RESERVOIR
95.6
@ °C
CONTAINER
WHEN SAMPLED
CONTAINER
WHEN RECEIVED
SEPARATOR
Pressures, kPa (gauge)
98 02 08
98 02 13
DATE SAMPLED (Y'M/D)
Temperatures, °C
98 02 25
DATE RECEIVED (Y/M/D)
RS/TE
DATE ANALYZED (Y/M/D)
ANALYST
OBSERVED PROPERTIES OF Cs. RESIDUE (15/1 5°C)
LIQUID
COMPONENT
MOLE
MASS
VOLUME
FRACTION
FRACTION
FRACTION
mL/m3
849.0
kg/m3
DENSITY
N2
Trace
Trace
Trace
Trace
CO,
0.0051
0.0031
0.0024
11.5
H2S
0.000(1
0.0000
0.0000
0.0
C1
0.5872
0.1311
0.2817
1328.1
C2
0.0620
0.0260
0.0467
220.4
C-1
0.0480
0.0295
0.0374
176.5
0.0085
0.0069
0.0079
37.1
C4
0.0253
0.0205
0.0226
106.5
iC5
0.0101
0.0101
0.0105
49.4
C.5
0.0157
0.0158
0.0161
75.9
C6+
0.2381
0.7570
0.5747
2709.0
Total
1.0000
1.0000
1.0000
4714.4
IC4
SIGNATURE
0.8498
RELATIVE DENSITY
35.2
API @ 15.5° C
228
RELATIVE MOLECULAR MASS
CALCULATED PROPERTIES OF TOTAL SAMPLE (15/1 5°C)
644.4
DENSITY
kq/m3
0.6450
RELATIVE DENSITY
88.1
API @ 15 5° C
71.84
RELATIVE MOLECULAR MASS
REMARKS:
Refer to page 4 for the extended analysis of
hexanes plus.
NOTE:
All Properties have been calculated utilizing GPA 2145.88 physical constants.
WREN
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
Operator:
Well:
Sample Point:
Hibernia Management and Development
HMDC Hibernia B16-3
Reservoir Fluid (MDT Sample)
Page:
File:
Date:
4
52134-98- 2063
98 02 25
Analysis of C6+ Fraction
Boiling Point:
Range (°C)
Component
36.1- 68.9
68.9- 98.3
98.3-125.6
125.6-150.6
150.6-173.9
173.9-196.1
196.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.6-287.8
287.8-302.8
302.8-317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
380.0-391.1
391.1-401.7
401.7-412.2
412.2-422.2
422.2-431.7
431.7-441.1
441.1 PLUS
Hexanes
Heptanes
Octanes
Nonanes
Decanes
Undecanes
Dodecanes
Tridecanes
Tetradecanes
Pentadecanes
Hexadecanes
Heptadecanes
Octadecanes
Nonadecanes
Eicosanes
Heneicosanes
Docosanes
Tricosanes
Tetracosanes
Pentacosanes
Hexacosanes
Heptacosancs
Octacosanes
Nonacosanes
Triacontanes Plus
80.0
110.6
136.1-138.9
144.4
168.9
48.9
72.2
81.1
101.1
Carbon
Number
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
C6
C7
C28
C29
C30+
0.0168
0.0149
0.0157
0.0127
0.0135
0.0135
0.0132
0.0102
0.0097
0.0088
0.0081
0.0066
0.0054
0.0052
0.0047
0.0042
0.0034
0.0033
0.0029
0.0028
0.0023
0.0023
0.0019
0.0020
0.0228
0.0215
0.0221
0.0266
0.0241
0.0284
0.0314
0.0334
0.0278
0.0285
0.0276
0.0272
0.0235
0.0203
0.0207
0.0197
0.0184
0.0156
0.0158
0.0145
0.0146
0.0125
0.0129
0.0111
0.0120
0.2040
0.0191
0.0190
0.0223
0.0197
0.0229
0.0249
0.0262
0.0216
0.0219
0.0211
0.0207
0.0178
0.0153
0.0155
0.0147
0.0137
0.0116
0.0117
0.0106
0.0106
0.0091
0.0094
0.0080
0.0087
0.1475
Benzene
Toluene
Ethylbenzene, p + m-Xylene
o-Xylene
1,2,4 Trimethylbenzene
C6H6
C7H8
C81-110
C81-110
C91-112
0.0024
0.0044
0.0040
0.0022
0.0011
0.0028
0.0061
0.0063
0.0034
0.0019
0.0019
0.0041
0.0043
0.0023
0.0013
Cyclopentane
Methylcyclopentane
Cyclohexane
Methylcyclohexane
TOTAL
C51-110
C6111 2
C61412
C71-114
0.0020
0.0047
0.0044
0.0060
0.2381
0.0021
0.0059
0.0055
0.0088
0.7570
0.0017
0.0047
0.0041
0.0067
0.5747
C5
C9
Cm
C11
C12
C11
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
0.2193
0.7334
0.5539
241
0.8571
856.3
MOPDXV Oft CP.OPDP.-NE\111i-OUNOLP.NO
OfFS-PR PEIROt.EUM 5000
Wulf 34.6P6-;mm,
JUL 6 1998
cassa-rfewromenne
Offsibent PitIVOSten Dessmi
Reservoir Fluid Analysis
for
Hibernia Management and
Development Company Ltd.
HMDC Hibernia B16-3
Sample Date: Feb-27-98
Sampling Depth: 3 950 m RT
CONF1
TIAL
File Number: 5213498-2057 (Calgary)
File Number: 52143-98-0029 (Newfoundland)
June 24th, 1998
A product of
Core Laboratories Canada Ltd.
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core Laboratories Canada Ltd. assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other
mineral, proper well or sand in connection with which such report is used or rel
INV-021462
CA-300149-ALL/02
11111111111111111111111.1 1 1 1 1 1 1 1 1 1 1
Release Date 04/ 29/1998
Registered 04/27/2010
av
AB
CORE LABORATORIES
June 24th, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
Al C 6K3
Attention:
Mr. John Andrews
Subject:
Reservoir Fluid Analysis
HMDC Hibernia B16-3
Sample Date: Feb-27-98
Sample Depth: 3 950 m RT
File Number: 52134-98-2057 (Calgary)
File Number: 52143-98-0029 (Newfoundland)
Gentlemen:
Subsurface samples (SRS Tool) of reservoir fluid were collected from the subject well by a
representative of Oilphase on February 27th, 1998. The samples were then submitted to Core
Laboratories for analysis.
Initially, the pressure in the SRS tools was raised, using water as a hydraulic fluid on the
piston side, to a working pressure of 48 263 kPa (gauge). The tools were agitated and heated
in order to redissolve any liberated gas into the oil phase. Once the reservoir fluid in the
samplers were confirmed to be in single-phase, they were individually transferred, at 48 263
kPa (gauge), to high-pressure, stainless steel, piston cylinders. These piston cylinders were
then shipped from our Newfoundland facility to our Calgary location for analysis. A process
similar to the above was employed in order to transfer an aliquot of each sample into the
windowed cell for a reservoir temperature, saturation pressure measurement. The remainder
of the sample from each of the piston cylinders was then transferred to a high-pressure,
stainless steel cylinder.
As stated above, the saturation pressure measurements were carried out using a high-pressure,
windowed cell. After an aliquot of each sample was individually transferred to the cell, the
contents of the cell were stabilized at the working pressure and reservoir temperature. The
pressure in the cell was then lowered by increasing the effective internal volume of the cell,
through hydraulic fluid withdrawal, until free gas was noticed through the window portion of
the cell. The pressure at which the first bubble of gas was noticed was defined as the
saturation (bubblepoint) pressure of the fluid. The fluid in the cell was returned to a singlephase state and the process repeated to confirm the saturation pressure.
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000, Fax (403) 250-5120
.12
2
The saturation pressures were reported and as instructed, the pressure-volume relations at the
reported reservoir temperature of 95.2 °C, a four-stage separator test and a compositional
analysis (C30+) were conducted on the selected subsurface sample. The conditions for the
separator test were supplied by Mr. John Andrews of Hibernia Management and Development
Company Ltd.
It should be noted that the data contained in the following report, although final for this issue,
maybe be refined once complete reservoir fluid studies have been conducted. The adjustments
or refinements would be as a result of more accurate and comprehensive measurements
required during the reservoir fluid studies. The changes, if any, would probably be within
±2% of the reported values.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LABORATORIES CANADA LTD.
Al Kassam
PVT - Technical Specialist
ak
enclosure
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3; Feb-27-98, 3 950 m RT
52134-98-2057
SUMMARY OF SATURATION PRESSURE DATA
Sample
Number
•
Sampling
Date
Well
Sampling
Depth
Reservoir
Temperature
Reservoir
Pressure
Saturation
Pressure *
m RT
°C
kPa (gauge)
kPa (gauge)
1 **
B16-3
Feb-27-98
3 950
95.2
38 786
36 466
2
B16-3
Feb-27-98
3 950
95.2
38 786
36 887
Bubblepoint pressure (visually measured in a high-pressure, windowed cell).
•• This sample was used for analysis.
Page 1
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Feb-27-98, 3 950 m RT)
52134-98-2057
VOLUMETRIC DATA
(at 95.2 °C)
Saturation Pressure (Psat)
36 466 kPa(g)
Thermal Exp. @ 41 369 kPa(g)
1.10445 V at 95.2 °C / V at 15.0 °C
AVERAGE SINGLE-PHASE COMPRESSIBILITIES
Single-Phase
41 369
38 611
Pressure Range
Compressibility
kPa(g)
v/v/kPa
to
38 611
24.89 E -7
37 921
to
to
37 232
to
37 921
37 232
36 466
27.06 E -7
28.02 E -7
29.08 E -7
Page 2
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 1316-3 (Feb-27-98, 3 950 m RT)
52134-98-2057
PRESSURE-VOLUME RELATIONS
(at 95.2 °C)
Pressure
Relative
Y-Function (B)
kPa(g)
Volume (A)
kg/m3
41 369
0.9872
38 611
0.9940
37 921
0.9959
37 232
0.9978
b»36 466
1.0000
35 515
1.0056
34 791
1.0102
4.720
31 447
1.0359
4.436
27 882
1.0742
4.132
24 173
1.1327
3.816
4.782
20 857
1.2107
3.534
17 795
1.3187
3.274
15 182
1.4564
3.051
12 686
1.6551
2.839
11 845
1.7448
2.767
(A) Relative Volume: VNsat or volume at indicated pressure per volume at saturation pressure.
(B) Where: Y-Function (Psat - P) / [ (Pabs) (VNsat - 1) ]
Page 3
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 616-3; Feb-27-98, 3 950 m RT
52134-98-2057
SEPARATOR TEST OF RESERVOIR FLUID SAMPLE
Separator
Pressure
kPa
(Gauge)
Separator
Temperature
°C
36 466
Gas/Oil
Ratio
(m3/m3)
(A)
Gas/Oil
Ratio
(m3/STm3)
(B)
75.0
192.5
73.0
Stock Tank
Oil Gravity
@ 15.6 °C
(°API)
Formation
Volume
Factor
(C)
Separator
Volume
Factor
(D)
Specific
Gravity of
Liberated
Gas (E)
223.7
1.162
0.704
17.1
18.9
1.100
0.913
92.0
12.8
13.9
1.085
1.314
45.0
0.1
0.1
1.027
N/M
Total
256.6
95.2
to
4 137
to
1 138
to
109
to
0
36.4
1.737
Sample Depth: 3 950 m RT
Date Sampled: Feb-27-98
Sampled by:
Oilphase
N/M - not measured due to insufficient liberated gas.
(A) Cubic metres of gas @ 101.325 kPa (absolute) and 15.0 °C per cubic metre of oil @ indicated pressure and temperature.
(B) Cubic metres of gas 101.325 kPa (absolute) and 15.0 °C per cubic metre of stock tank oil 15.0 °C.
(C) Cubic metres of saturated oil 36 466 kPa (gauge) and 95.2 °C per cubic metre of stock tank oil 15.0 °C.
(D) Cubic metres of oil indicated pressure and temperature per cubic metre of stock tank oil 15.0 °C.
(E) Air = 1.000.
Page 4
Core Laboratories Canada Ltd.
CORELAB
OVA
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
P12
52134-98- 2057
CONTAINER IDENTITY
LABORATORY NUMBER
Hihernia Management and Development
5
OPERATOR
PAGE
HMDC Hihernia B16-3
LOCATION
WELL OR SAMPLE LOCATION
KB ELEV (m)
Hihernia
GR ELEV (m)
Oilphase
FIELD OR AREA
POOL OR ZONE
TEST TYPE & NO.
SAMPLER
TEST RECOVERY
Reservoir Fluid (SRS Sample)
°C
POINT OF SAMPLE
AMT & TYPE CUSHION
PUMPING
3950 -
FLOWING
WATER
mi
ld
MUD RESISTIVITY
GAS LIFT
OIL
SWAB
mi
ld
GAS
m3/d
TEST INTERVAL (meters)
36466
SEPARATOR
@ °C
95.2
@ °C
CONTAINER
WHEN SAMPLED
RESERVOIR
CONTAINER
WHEN RECEIVED
SEPARATOR
Pressures, kPa (gauge)
98 02 27
98 03 12
DATE SAMPLED (Y/MID)
Temperatures, °C
98 03 26
DATE RECEIVED (Y/M/D)
RS/TE
DATE ANALYZED (Y/M/D)
ANALYST
OBSERVED PROPERTIES OF Ce, RESIDUE (15/15°C)
LIQUID
COMPONENT
MOLE
MASS
VOLUME
FRACTION
FRACTION
FRACTION
SIGNATURE
mUm3
856.9
kg/m3
N,
Trace
Trace
Trace
Trace
CO2
0.0075
0.0045
0.0036
17.0
H2S
0.0000
0.0000
0.0000
0.0
C1
0.5893
0.1302
0.2821
1332.8
C2
0.0623
0.0258
0.0469
221.5
C3
0.0482
0.0293
0.0375
177.2
iC4
0.0081
0.0065
0.0075
35.4
C4
0.0230
0.0184
0.0205
96.8
iCs
0.0086
0.0085
0.0089
42.0
Cs
0.0130
0.0129
0.0133
62.9
C6+
0.2400
0.7639
0.5797
2738.6
Total
1.0000
1.0000
1.0000
4724.1
0.8577
RELATIVE DENSITY
DENSITY
33.6
API @ 15.5° C
231
RELATIVE MOLECULAR MASS
CALCULATED PROPERTIES OF TOTAL SAMPLE (15/15°C)
650.3
DENSITY
kg/m3
0.6509
RELATIVE DENSITY
86.1
API @ 15.5° C
72.64
RELATIVE MOLECULAR MASS
REMARKS:
Refer to page 6 for the extended analysis of
hexanes plus.
NOTE: All Properties have been calculated utilizing GPA 2145.88 physical constants.
MAE
NUMB
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
Operator:
Well:
Sample Point:
Hibernia Management and Development
HMDC Hibernia B16-3
Reservoir Fluid (SRS Sample)
Page:
File:
Date:
6
52134-98-2057
98 03 26
Analysis of C6, Fraction
Boiling Point:
Range (°C)
Component
36.1- 68.9
68.9- 98.3
98.3-125.6
125.6-150.6
150.6-173.9
173.9-196.1
196.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.6-287.8
287.8-302.8
302.8-317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
380.0-391.1
391.1-401.7
401.7-412.2
412.2-422.2
422.2-431.7
431.7-441.1
441.1 PLUS
Hexanes
Heptanes
Octanes
Nonanes
Decanes
Undecanes
Dodecanes
Tridecanes
Tetradecanes
Pentadecanes
Hexadecanes
Heptadecanes
Octadecanes
Nonadecanes
Eicosanes
Heneicosanes
Docosanes
Tricosanes
Tetracosanes
Pentacosanes
Hexacosanes
Heptacosanes
Octacosanes
Nonacosanes
Triacontanes Plus
80.0
110.6
136.1-138.9
144.4
168.9
48.9
72.2
81.1
101.1
Carbon
Number
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
C6
C7
C8
C9
C28
C29
C30+
0.0158
0.0143
0.0154
0.0125
0.0130
0.0120
0.0117
0.0099
0.0093
0.0082
0.0077
0.0067
0.0056
0.0052
0.0046
0.0042
0.0036
0.0034
0.0030
0.0029
0.0025
0.0024
0.0021
0.0022
0.0302
0.0189
0.0199
0.0244
0.0224
0.0257
0.0261
0.0277
0.0253
0.0257
0.0244
0.0241
0.0223
0.0197
0.0193
0.0180
0.0173
0.0155
0.0153
0.0141
0.0142
0.0127
0.0127
0.0115
0.0125
0.2532
0.0169
0.0172
0.0206
0.0184
0.0209
0.0208
0.0219
0.0198
0.0199
0.0187
0.0184
0.0170
0.0149
0.0145
0.0134
0.0129
0.0115
0.0114
0.0104
0.0105
0.0093
0.0093
0.0083
0.0090
0.1840
Benzene
Toluene
Ethylbenzene, p + m-Xylene
o-Xylene
1,2,4 Trimethylbenzene
C6H6
C7H8
C8H10
C8H10
C9H12
0.0024
0.0045
0.0040
0.0023
0.0013
0.0027
0.0057
0.0060
0.0034
0.0022
0.0018
0.0039
0.0041
0.0023
0.0015
Cyclopentane
Methylcyclopentane
Cyclohexane
Methylcyclohexane
TOTAL
C5H10
C6H II 2
C6H12
C7H14
0.0020
0.0044
0.0044
0.0063
0.2400
0.0020
0.0052
0.0052
0.0086
0.7639
0.0016
0.0041
0.0039
0.0066
0.5797
C1 0
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
0.2222
0.7430
0.5612
243
0.8644
863.6
NDI.
ONDA-Nt\NVOOEU
C9ffStAORE PEIRCANk WOOD,
File #:
Tnitials
ISOY
APR 29 1998
RECEIVED
Canada-Newfoundland
oirtrainr. Petrolomm Dame
Reservoir Fluid Analysis
for
Hibernia Management and
Development Company Ltd.
HMDC Hibernia B16-3
Sample Date: Feb-08-98
Sampling Depth: 3 990 m MD
Sample #1
File Num e
98-2061 (Calgary)
File Number: 52143-98-0025 (Newfoundland)
April 22nd, 1998
A product of
Core Laboratories Canada Ltd.
CA-300149-ALL/02
INV-021464
1111
II 111 11 1 1 11 1111
Registered 04/27/2010
Release Date 04/29/1998
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core Laboratories Canada Ltd. assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other
mineral, proper well or sand in connection with which such report is used or relied upon for any reason whatsoever.
Core Laboratories
COIELAB
CORE LABORATORIES
April 22nd, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
Al C 6K3
Attention:
Mr. John Andrews
Subject:
Reservoir Fluid Analysis
HMDC Hibernia B16-3
Sample Date: Feb-08-98
Sample Depth: 3 990 m MD
Sample #1
File Number: 52134-98-2061 (Calgary)
File Number: 52143-98-0025 (Newfoundland)
Gentlemen:
A subsurface sample (MDT Tool) of reservoir fluid was collected from the subject well by a
representative of Schlumberger on February 8th, 1998. The sample was then submitted to our
Calgary laboratory for analysis.
Initially, the pressure in the MDT tool was raised, using water as a hydraulic fluid on the
piston side, to a working pressure of 48 263 kPa (gauge). The tool was agitated in order to
redissolve any liberated gas into the oil phase. Once the reservoir fluid in the sampler was
confirmed to be in single-phase, an aliquot was transferred, at 48 263 kPa (gauge), to an
evacuated, high-pressure, stainless steel, windowed cell for a reservoir temperature, saturation
pressure measurement. The remainder of the sample from this tool was then transferred to a
high-pressure, stainless steel cylinder.
As stated above, the saturation pressure measurement was carried out using a high-pressure,
windowed cell. After an aliquot of sample was transferred to the cell, the contents of the cell
were stabilized at the working pressure and reservoir temperature. The pressure in the cell
was then lowered by increasing the effective internal volume of the cell, through hydraulic
fluid withdrawal, until free gas was noticed through the window portion of the cell. The
pressure at which the first bubble of gas was noticed was defined as the saturation
(bubblepoint) pressure of the fluid. The fluid in the cell was returned to a single-phase state
and the process repeated to confirm the saturation pressure.
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000, Fax (403) 250-5120
/2
-2
The transfer to a high-pressure, windowed cell was repeated after heating the storage cylinder
in order to redissolve the paraffinic compounds that may have precipitated out. The
saturation pressure measurement was then also repeated.
The saturation pressures were reported and as instructed, a four-stage separator test and a
compositional analysis (C30+) were conducted on the subsurface sample. The conditions for
the separator test were supplied by Mr. John Andrews of Hibernia Management and
Development Company Ltd.
It should be noted that the data contained in the following report, although final for this issue,
maybe be refined once complete reservoir fluid studies have been conducted. The adjustments
or refinements would be as a result of more accurate and comprehensive measurements
required during the reservoir fluid studies. The changes, if any, would probably be within
±2% of the reported values.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LABORATORIES CANADA LTD.
Al Kassam
PVT - Technical Specialist
ak
enclosure
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3; Feb-8-98, 3 990 m MD (Sample #1)
52134-98-2061
SUMMARY OF SATURATION PRESSURE DATA
Well
Sampling
Date
Sampling
Depth
Reservoir
Temperature
Reservoir
Pressure
Saturation
Pressure *
m MD
°C
kPa (absolute)
kPa (gauge)
B16-3
Feb-08-98
3 990
96.7
39 777
36 680
B16-3
Feb-08-98
3 990
96.7
39 777
36 666 '
Bubblepoint pressure (visually measured in a high-pressure, windowed cell).
' Saturation pressure measurement after heating storage cylinder.
Page 1
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3; Feb-8-98, 3 990 m MD (Sample #1)
52134-98-2061
SEPARATOR TEST OF RESERVOIR FLUID SAMPLE
Separator
Separator
Gas/Oil
Gas/Oil
Stock Tank
Formation
Separator
Specific
Pressure
Temperature
Ratio
Ratio
Oil Gravity
Volume
Volume
Gravity of
kPa
°C
(m3/m3)
(m3/STm3)
@ 15.6 °C
Factor
Factor
Liberated
(A)
(B)
(*API)
(C)
(D)
Gas (E)
75.0
217.1
253.9
1.169
0.706
73.0
17.2
19.1
1.110
0.815
92.0
12.0
13.1
1.092
1.227
45.0
0.1
0.1
1.027
N/M
Total
286.2
(Gauge)
36 680
96.7
to
4 137
to
1 138
to
109
to
0
38.2
1.832
Sample Depth: 3 990 m MD
Date Sampled: Feb-08-98
Sampled by:
Schlumberger
N/M - not measured due to insufficient liberated gas.
(A) Cubic metres of gas
101.325 kPa (absolute) and 15.0 °C per cubic metre of oil
indicated pressure and temperature.
15.0 °C.
101.325 kPa (absolute) and 15.0 °C per cubic metre of stock tank oil
(B) Cubic metres of gas
15.0 °C.
(C) Cubic metres of saturated oil @ 36 680 kPa (gauge) and 96.7 °C per cubic metre of stock tank oil
(D) Cubic metres of oil
indicated pressure and temperature per cubic metre of stock tank oil
15.0 °C.
(E) Air = 1.000.
Page 2
Core Laboratories Canada Ltd.
CRELAB
COHLA
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
682
52134-98-2061
CONTAINER IDENTITY
LABORATORY NUMBER
Hibernia Management and Development
3
OPERATOR
PAGE
HMDC Hibernia BI6-3
LOCATION
WELL OR SAMPLE LOCATION
Hibernia
KB ELEV (m)
Hibernia
FIELD OR AREA
POOL OR ZONE
TEST TYPE & NO
GR ELEV Im)
Schlumberger
SAMPLER
TEST RECOVERY
Reservoir Fluid (MDT Sample #1)
@
POINT OF SAMPLE
AMT & TYPE CUSHION
PUMPING
3990.0 -
FLOWING
WATER
m3id
MUD RESISTIVITY
GAS LIFT
OIL
SWAB
m3id
GAS
m3/d
TEST INTERVAL (meters)
@
36680
SEPARATOR
°c
CONTAINER
WHEN SAMPLED
RESERVOIR
96.7
CONTAINER
WHEN RECEIVED
SEPARATOR
Pressures, kPa (gauge)
98 02 08
98 02 13
DATE SAMPLED (Y/M/D)
Temperatures, "C
98 03 02
DATE RECEIVED (Y/M/D)
RS/TE
DATE ANALYZED Y/M/D)
ANALYST
OBSERVED PROPERTIES OFC6. RESIDUE (15/15°C)
LIQUID
COMPONENT
MOLE
MASS
VOLUME
FRACTION
FRACTION
FRACTION
SIGNATURE
mL/m3
847.3
kg/m3
DENSITY
N2
Trace
Trace
Trace
Trace
CO2
0.0066
0.0042
0.0032
14.9
H2S
0.0000
0.0000
0.0000
0.0
C1
0.5993
0.1389
0.2945
1355.4
C-,
0.0628
0.0273
0.0485
223.2
Cl
0.0485
0.0309
0.0387
178.3
iC4
0.0082
0.0069
0.0078
35.8
C4
0.0235
0.0197
0.0215
98.9
iC5
0.0089
0.0093
0.0095
43.5
C5
0.0135
0.0141
0.0142
65.3
C6+
0.2287
0.7487
0.5621
2587.3
Total
1.0000
1.0000
1.0000
4602.7
0.8480
RELATIVE DENSITY
35.5
API @ 15 5° C
227
RELATIVE MOLECULAR MASS
CALCULATED PROPERTIES OF TOTAL SAMPLE (15/15°C)
636.1
DENSITY
kg/m3
0.6366
RELATIVE DENSITY
91.0
API @ 15 5° C
69.22
RELATIVE MOLECULAR MASS
REMARKS:
Refer to page 4 for the extended analysis of
hexanes plus.
NOTE:
All Properties have been calculated utilizing GPA 2145-88 physical constants.
CRAB
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
Operator:
Hibernia Management and Development
Well:
HMDC Hibernia B16-3
Sample Point: Reservoir Fluid (MDT Sample #1)
Page: 4
File:
52134-98- 2061
Date: 98 03 02
Analysis of C6, Fraction
Boiling Point:
Range (°C)
Component
36.1- 68.9
68.9- 98.3
98.3-125.6
125.6-150.6
150.6-173.9
173.9-196.1
196.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.6-287.8
287.8-302.8
302.8-317.2
317.2:330.0
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
380.0-391.1
391.1-401.7
401.7-412.2
412.2-422.2
422.2-431.7
431.7-441.1
441.1 PLUS
Hexanes
Heptanes
Octanes
Nonanes
Decanes
Undecanes
Dodecanes
Tridecanes
Tetradecanes
Pentadecanes
Hexadecanes
Heptadecanes
Octadecanes
Nonadecanes
Eicosanes
Heneicosanes
Docosanes
Tricosanes
Tetracosanes
Pentacosanes
Hexacosanes
Heptacosanes
Octacosanes
Nonacosanes
Triacontanes Plus
80.0
110.6
136.1-138.9
144.4
168.9
Benzene
Toluene
Ethylbenzene. p + m-Xylene
o-Xylene
1.2,4 Trimethylbcnzene
C6H6
C7H5
C8Hio
C81-110
48.9
72.2
81.1
101.1
Cyclopentane
Methylcyclopentane
Cyclohexane
Methylcyclohexane
TOTAL
C51-110
C6H12
C6H12
C71114
Carbon
Number
Mole
Fraction
C6
C7
0.0162
C8
C9
C10
CH
C12
C13
CI 4
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30.4.
C9H12
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
Fraction
Liq. Vol.
Fraction
0.0187
0.0134
0.0134
0.0117
0.0117
0.0089
0.0086
0.0079
0.0073
0.0060
0.0048
0.0048
0.0043
0.0038
0.0031
0.0030
0.0027
0.0026
0.0022
0.0021
0.0018
0.0019
0.0213
0.0217
0.0229
0.0332
0.0268
0.0296
0.0285
0.0311
0.0257
0.0267
0.0260
0.0256
0.0223
0.0192
0.0199
0.0188
0.0174
0.0149
0.0150
0.0141
0.0142
0.0125
0.0124
0.0109
0.0120
0.2019
0.0191
0.0194
0.0274
0.0217
0.0236
0.0224
0.0241
0.0197
0.0202
0.0197
0.0193
0.0167
0.0143
0.0147
0.0139
0.0128
0.0109
0.0110
0.0102
0.0102
0.0090
0.0089
0.0079
0.0085
0.1440
0.0025
0.0044
0.0040
0.0023
0.0012
0.0031
0.0063
0.0066
0.0037
0.0022
0.0020
0.0042
0.0044
0.0025
0.0015
0.0021
0.0046
0.0045
0.0062
0.2287
0.0022
0.0060
0.0059
0.0094
0.7487
0.0017
0.0047
0.0044
0.0071
0.5621
0.0147
Mass
0.2104
0.7248
0.5413
239
0.8554
854.7
B
CORE LABORATORIES
Of:
...•._---~ov 24 \998
RECEIVED
CIaMda·Newfoun4lJanll
,.",.,._
Reservoir Fluid Analysis
for
fIIIItroft....
--
Hibernia Management and
Development Company Ltd.
HMDC Hibernia 816-3
Subsurface SRS Sample #682
Sample Date: Feb-08-98
Sampling Depth: 3 990.0 m MD
Release~:
__~A~P~R..:.2~S}
__1:.:99:.;.8
File Number: 5213+98-2061 (Calgary)
File Number: 52143-98-0025 (Newfoundland)
November 12th, 1998
A product of
Core Laboratories Canada Ltd.
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core laboratories Canada Ltd. assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other
mineral, proper well or sand in connection with which such report is used or relied upon for any reason whatsoever.
Core laboratories
Canada ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250-5120
_
CORE LABORATORIES
November 12th, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
AIC 6K3
Attention:
Mr. John Andrews
Subject:
Reservoir Fluid Study (Subsurface Sample)
HMDC Hibernia BI6-3
Sample Date: Feb-08-98
File Number: 52134-98-2061(Calgary)
File Number: 52143-98-0025 (Newfoundland)
Gentlemen:
Subsurface samples were collected from the subject well by a representative of Schlumberger
on February 8th, 1998. The samples were then submitted to our Calgary laboratory for use in
a reservoir fluid study.
Upon arrival, a visual saturation pressure was measured, a
compositional analysis was conducted, a four-stage separator test conducted, and the results
reported to Mr. John Andrews.
It was then requested that a complete reservoir fluid study be conducted on this sample. The
enclosed report contains a brief description of the tests & the expreimental procedures that
were followed in the laboratory, the laboratory results in tabular and graphical formats, the
compositional data, and concludung remarks.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LABORATORIES CANADA LTD.
~~'>--
Dawson Milbury
r
~&/k
,-....., -
PVT Co-ordinator
\dm
enclosure
Core Laboratories
Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250·5120
TABLE OF CONTENTS
ITEM
PAGE
1. Summary ofPVT Data
1
2. Project Objective & Scope
2
3. Analytical Summary
3-7
4. Conclusions & Observations
8
5. Tabular Data
A. Pressure-Volume Relations
9,10
B. Differential Vaporization
11,12
C. Reservoir Fluid Viscosity
13
D. Separator Test of Reservoir Fluid
14
6. Compositional Data
A. Reservoir Fluid
15,16
7. Illustrations
A. Relative Volume
17
B. Oil Density
18
C. Relative Oil Volume
19
D. Solution and Liberated Gas-Oil Ratios
20
E. Gas Deviation (Z) Factor
21
F. Gas Formation Volume Factor & Gas Viscosity
22
G. Oil Viscosity
23
8. Data Adjustment
A. Introduction to Data Adjustment
24-26
B. Adjusted Data
27
C. Adjusted Solution Gas-Oil Ratios (Illustration)
28
D. Adjusted Formation Volume Factors (Illustration)
29
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MOT sample #682 ; Feb-08-98, 3990.0m MO)
52134-98-2061-1
SUMMARY OF PVT DATA
Reported Reservoir Conditions
Current Reservoir Pressure
.
39676
kPa(g)
Reservoir Temperature
.
96.7
·C
Saturation
Pressure-Volume
Relations
.
36501
kPa(g)
.
28.11
E-7 vlv/kPa ( 41 369 to 36 501 kPa(g»
.
1.11289
V at 96.7·C I V at 15.0·C
Pressure
Avg. Single-Phase
Compressibility
Thermal Exp. @ 41 369 kPa(g)
Differential Vaporization
Data
( at 36 501 kPa(g) and 96.7 °C )
Solution Gas/Oil Ratio
.
Relative Oil Volume
.
Density of Reservoir Fluid
.
338.5
~ I ~ of residual oil at 15.0·C
2.059
~ I ~ of residual oil at 15.0 ·C
603.5
kgl~
Reservoir Fluid Viscosity
0.297 mPa's at 36 501 kPa(g) and 96.7 °C
Separator Test Results
Primary Separator Conditions
Formation
Total Solution
Tank Oil Gravity
Volume Factor
GaS/Oil Ratio
( °API at 15.6 °C )
kPa(g)
°C
(A)
(6)
4137
75.0
1.851
286.2
38.2
(A) Cubic metres of saturated oil per cubic metre of stock tank oil at 15.0 ·C.
(B) Total standard cubic metres of gas per cubic metre of stock tank oil at 15.0 ·C.
Page 1
Core laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-J (Subsurface MDT Sample #682; Feb-08-98, J 990.0 m MD)
52134-98-2061
PROJECT OBJECTIVE & SCOPE
The objective of the reservoir fluid study is to determine the PVT properties of the reservoir fluid
from the Hibernia B16-3 well (sampled Feb-08-98, sample depth - 3 990.0m MD).
The scope of the study entails the following tests; pressure-volume
relations,
differential
vaporization, viscosity measurements, multi-stage separator test and compositional analysis.
Page 2
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface MDT Sample #682; Feb-08-98, 3 990.0 m MD)
52134-98-2061
ANALYTICAL
SUMMARY
Sample Transfer & Preparation
Subsurface samples of reservoir fluid were collected from the subject well by Schlumberger.
The
samples were transferred, monophasically, to a piston-type cylinder at our Mt. Pearl facility, and
shipped to Calgary. Upon arrival, the samples were heated to a temperature well above reservoir
temperature, and transferred to a high pressure, stainless steel storage cylinder.
The saturation
pressure of the samples, at reservoir temperature, was measured and reported to Mr. John
Andrews. One sample, MDT # 682, was selected for a full PVT study.
PVT Experiments
A. Pressure- Volume Relations Test
A measured aliquot of the reservoir fluid is transferred, under pressure, to a high-pressure,
windowed cell and stabilized at a working pressure significantly above the reservoir pressure. The
cell is then heated to the reported reservoir temperature of 96.7 °C and again stabilized at the
working pressure.
The cell pressure is lowered by withdrawing the inert hydraulic fluid.
Reservoir fluid volumes in the cell are determined at several pressure increments both above and
below the saturation pressure. The saturation pressure (bubblepoint) itself is confirmed by visual
observation through the cell window and is repeated twice.
The results of this test are reported in the form of a ratio of reservoir fluid volume at any pressure
to the reservoir fluid volume at saturation conditions (relative volume or VNsat).
The relative
volume data is then used to calculate single-phase oil compressibilities and densities.
The data from this test is tabulated on pages 9 & 10 and illustrated on page 17 of this report.
Page 3
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia BI6-3 (Subsurface MDT Sample #682; Feb-08-98, 3 990.0 m MD)
52134-98-2061
Analytical Summary ..... continued
B. Differential Vaporization
At the completion of the pressure-volume relations test, the reservoir fluid is put into single phase
and stabilized at the working pressure and reservoir temperature.
The pressure in the cell is then
lowered, through hydraulic fluid withdrawal, to a predetermined pressure below the saturation
pressure.
The gas and oil phase portions of the system are allowed to separate and establish
equilibrium.
Once equilibrium is reached, the liberated gas is removed, at constant pressure,
quantified and its relative density to air measured. The volume of oil remaining in the cell is also
determined.
The pressure is reduced again and the procedure repeated until the final pressure
(atmospheric) is reached.
The stepwise pressure reduction allows for the examination of two-phase properties as a function
of pressure depletion during primary production.
Specifically, the liberated gas relative density,
gas deviation (Z) factor, gas formation volume factor, solution gas-oil ratio, oil formation volume
factor and oil phase density are determined at each pressure stage.
The data generated from the differential vaporization test is tabulated on pages 11 & 12 and
illustrated on pages 18 through 22 of this report.
C. Reservoir Fluid Viscosity
An aliquot of the reservoir fluid from the first cylinder is transferred, in single phase, to a rolling
ball viscometer that is preheated to the reservoir temperature. In this instrument, the roll time of a
steel ball is measured and converted to a viscosity value through calibration factors for a given
stainless steel barrel placed in the viscometer. The measurement is started at a pressure above the
reservoir pressure and is lowered through a relief valve to the next required pressure level. For
pre
Page 4
Core Laboratories canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface MDT Sample #682; Feb-08-98. 3 990.0 m MD)
52134-98-2061
Analytical Summary ..... continued
pressures below the saturation pressure, the liberated gas is isolated from the oil phase in such a
way as to allow only the oil to fill the measuring chamber (barrel). The same pressure levels used
in the pressure-volume relations and differential vaporization tests are selected such that the oil
density values from these tests can be directly used to convert roll times to viscosity values.
The viscosity of the liberated gas at each pressure level below the saturation
pressure
IS
calculated, based on a correlation by Lee, Eakin & Gonzalez, using the liberated gas properties
determined in the differential vaporization test.
The viscosity data is tabulated on page 13 and illustrated on pages 22 & 23 of this report.
D. Separator Test
A measured aliquot of the reservoir fluid is transferred to a scale separator and flashed at
conditions supplied by Mr. John Andrews of Hibernia Management and Development Company
Ltd. Specifically, flash to high stage separator conditions of 4240 kPa (absolute) & 75.0 °C, then
to medium stage separator conditions of 1 240 kPa (absolute) & 73.0 °C, then to low stage
separator conditions of 210 kPa (absolute) & 92.0 °C and finally to stock tank conditions and
45.0 °C. At each stage, the liberated gas is removed and quantified after equilibrium has been
reached. The volume of liquid remaining is then determined. This data is presented in the form of
solution gas-liquid ratios (total and individual stage), formation volume factor, stock tank liquid
gravity and liberated gas relative densities. The solution gas-oil ratio and the formation volume
factor from this test are adjusted, as documented in the Data Adjustment section of this report,
using data from the pressure-volume relations and differential vaporization tests.
Page 5
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface MDT Sample #682; Feb-08-98t 3 990.0 m MD)
52134-98-2061
Analytical Summary ..... continued
The results from the separator test can be found on page 14 of this report.
E. Reservoir Fluid Composition
The composition of the reservoir fluid is determined by high temperature flash. In this process, an
aliquot of reservoir fluid is flashed to atmospheric pressure at a controlled rate and elevated
temperature.
The evolved gas is collected, quantified and analyzed.
quantified and analyzed.
The residual oil is also
The reservoir fluid composition is arrived at by mathematically
recombining the individual flashed gas and residual oil compositions.
The flashed gas analysis is performed on the lIP 6890 gas chromatograph.
employed in this technology.
Three columns are
One column is used to detect oxygen and nitrogen.
The second
column detects carbon dioxide, hydrogen sulphide and light hydrocarbons to propane.
The third
column identifies the remainder of the hydrocarbons in the flashed gas (i.e.; butanes to extinction).
Helium is used as the carrier gas in all three columns. The residual oil is analyzed by capillary
chromatography which adheres to the ASTM simulated distillation method.
In this method, a
multi-component internal standard is used to compensate for column losses.
The resulting reservoir fluid composition is detailed on pages 15 and 16 of this report.
Page 6
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface MDT Sample #682; Feb-08-98, 3 990.0 m MD)
52134-98-2061
Analytical Summary ..... continued
General
A. illustrations
Where applicable, analytical expressions best representing the PVT data reported
and the
corresponding statistical summaries have been provided. Refer to pages 17 to 23 of this report.
B. Data Adjustment
The total solution gas-oil ratio and the formation volume factor from the multi-stage separator
test have been adjusted such that this data can be used directly in volumetric and material balance
calculations.
Complete documentation is provided on pages 24 to 26.
The adjusted data is
tabulated on page 27 and is illustrated on pages 28 & 29 of this report.
Page 7
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface MDT Sample #682; Feb-08-98, 3 990.0 m MD)
52134-98-2061
CONCLUSIONS & OBSERVATIONS
Based on the information received from Hibernia Management and Development Company Ltd.,
the data contained in this report and the observations made during the course of this study, the
following can be concluded.
1.
The saturation (bubblepoint) pressure of the bottomhole sample used in this study was
determined to be 36 501 kPa (gauge) at the reported reservoir temperature of 96.7 "C.
The
reported reservoir pressure was 39777 kPa (absolute).
2. The reservoir fluid exhibited the behaviour of a slightly volatile, medium gravity oil system.
There was no visual evidence of any unusual or uncommon occurrences during the course of this
study.
3. The adjusted data should be used in volumetric and material balance calculations.
4. Core Laboratories can recommend and perform additional tests to further define or characterize
the reservoir.
Page 8
Core Laboratories Canada Ltd.
TABULAR DATA
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMOC Hibernia 816-3 (Subsurface MDT sample #682 ; Feb-08-98, 3990.0m MO)
52134-98-2061-1
VOLUMETRIC
DATA
(at 96.7 ·C)
Saturation Pressure (Psat)
Density at Psat
Thermal Exp. @ 41 369 kPa(g)
.
.
.
AVERAGE SINGLE-PHASE
41369
38611
37921
37232
36542
36 501 kPa(g)
603.5 kg/m3
1.11289 Vat 96.7·C I Vat 15.0·C
COMPRESSIBILITIES
Pressure Range
Single-Phase
Compressibility
kPa(g)
vlvlkPa
to
to
to
to
to
38611
37921
37232
36 542
36501
Page 9
27.08 E-7
29.09 E-7
30.00 E-7
31.02 E-7
31.83 E-7
Core laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMOC Hibernia 816-3 (Subsurface MDT sample #682; Feb.Q8-98, 3990.0m MO)
52134-98-2061-1
PRESSURE-VOLUME RELATIONS
(at 96.7 ·C)
Pressure
kPa(g)
41369
38611
37921
37232
36 542
b»36501
36115
35770
35432
34639
31771
27745
23725
20222
17 071
14431
11942
10473
Relative
Volume (A)
V-Function
Density
(8)
kgl~
611.9
607.3
606.1
604.9
603.6
603.5
0.9863
0.9937
0.9957
0.9977
0.9999
1.0000
1.0024
1.0045
1.0068
1.0122
1.0356
1.0816
1.1516
1.2456
1.3754
1.5412
1.7810
1.9862
4.508
4.481
4.455
4.393
4.168
3.851
3.536
3.261
3.014
2.806
2.611
2.496
(A) Relative Volume: VNsat or volume at indicated pressure per volume at saturation pressure.
(8) Where: V-Function=
(Psat- P)
(Pabs) • (VNsat. - 1)
Page 10
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682; Feb-08-98, 3990.0m MD)
52134-98-2061-1
DIFFERENTIAL VAPORIZATION
(at 96.7 ·C)
Oil Properties
Oil
Relative
Relative
Solution
Liberated
Pressure
Density
Oil
Total
GaS/Oil
Gas/Oil
kPa(g)
kgI~
Volume
Volume
Ratio
Ratio
Bod (A)
Btd (B)
Rsd (C)
Rid
2.059
1.945
1.841
1.694
1.583
1.500
1.430
2.059
2.092
2.132
2.242
2.452
338.5
299.6
263.0
209.4
0.0
38.9
75.5
129.1
172.6
208.0
238.8
268.3
300.5
318.0
338.5
b»36 501
34129
31544
26890
22063
17237
12445
7584
2758
876
0
603.5
615.5
627.6
647.3
664.9
680.0
693.4
707.5
729.8
750.4
788.0
Gravity
of Residual
Oil
=
Density
of Residual
Oil
=
1.359
1.266
1.204
1.076
2.839
3.588
5.427
14.011
41.744
165.9
130.5
99.7
70.2
38.0
20.5
0.0
35.2 ·API at 15.6 ·C
848.4 kglm3 at 15.0·C
(A) Cubic metre of oil at indicated pressure and temperature per cubic metre of residual oil at 15.0 ·C.
(B) Cubic metres of oil plus liberated gas at indicated pressure and temperature per cubic metre of residual oil at 15.0 ·C.
(C) Cubic metres of gas at 101.325 kPa(a) and 15.0 ·C per cubic metre of residual oil at 15.0 ·C.
Page 11
Core laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682; Feb-08-98, 3990.0m MD)
52134-98-2061-1
DIFFERENTIAL VAPORIZATION
(at 96.7 ·C)
Gas Properties
Pressure
kPa(g)
b»36501
34129
31544
26890
22063
17237
12445
7584
2758
876
0
Incremental
Gas
Relative
Density
Cumulative
Gas
Relative
Density
(A)
(A)
0.950
0.924
0.876
0.830
0.790
0.765
0.775
0.917
1.155
2.072
0.950
0.937
0.912
0.891
0.874
0.860
0.851
0.858
0.874
0.947
Incremental
Deviation
Factor
Z
0.991
0.939
0.882
0.858
0.858
0.872
0.896
0.933
0.958
Gas
Formation
Volume
Factor
Gas
Expansion
Factor
Bg (8)
1/8g (C)
0.00377
0.00386
0.00425
0.00503
0.00644
0.00904
0.01516
0.04241
0.12749
265.57
259.20
235.44
198.62
155.39
110.64
65.96
23.58
7.84
(A) Air = 1.000
(8) Cubic metresof gas at indicatedpressureandtemperaturepercubic metreat 101.325kPa(a)and 15.0 ·C.
(C) Cubic metresof gas at 101.325kPa(a)and 15.0·C per cubic metreat indicatedpressureandtemperature.
Page12
Core laboratories Canadaltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface MDT sample #682; Feb-48-98, 3990.0m MD)
52134-98-2061-1
RESERVOIR FLUID VISCOSITY
(at 96.7 ·C)
Oil
Gas
Oil/Gas
Pressure
Viscosity
Viscosity *
Viscosity
kPa(g)
mPa·s
mPa·s
Ratio
41369
0.315
38611
0.305
37921
0.302
37232
0.299
36542
0.297
b»36 501
0.297
34129
0.295
0.0378
31544
0.313
0.0353
7.80
8.89
26890
0.389
0.0296
13.15
22063
0.512
0.0240
21.33
17 237
0.669
0.0198
33.86
12445
0.853
0.0168
50.65
7584
1.068
0.0147
72.52
2758
1.332
0.0127
104.54
876
1.472
0.0114
129.12
0
1.580
• Gas VIscosity data calculated from correlation of Lee A.L., Gonzalez M.H., and Eakin B.E., "The
VISCOSity of Natural Gases", Journal of Petroleum Technology, August, 1966, pp. 997-1000.
Page 13
Core Laboratories Canada Ltd.
COMPOSITIONAL DATA
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
52134-98-2061
682
LABORATORY NUMBER
CONTAINER IDENTITY
Hibernia
Management
15
and Development
PAGE
OPERATOR
B16-3
HMDC Hibernia
WELL OR SAMPLE LOCATION
LOCATION
Hibernia
KB ELEV. 1m)
Hihernia
FIELD OR AREA
Reservoir
SAMPLER
POOL OR ZONE
TEST TYPE & NO.
GR ELEV. (m)
Schlumberger
TEST RECOVERY
Fluid (MDT Sample # I)
@
AMT. & TYPE CUSHION
POINT OF SAMPLE
PUMPING
:\IJIJO.O -
GAS LIFT
FLOWING
~O~IL
WATER
SWAB
~G~AS~
~m~3~/d_
~m3~/d~
TEST INTERVAL (melers)
@
36680
SEPARATOR
"C
CONTAINER
WHEN SAMPLED
RESERVOIR
CONTAINER
WHEN RECEIVED
I --=-
9802
DATE SAMPLED (Y/M/D)
13
Temperatures,
980302
DATE RECEIVED (Y/MtO)
MOLE
MASS
VOLUME
FRACTION
FRACTION
FRACTION
"C
RS/TE
DATE ANALYZED (Y/M/D)
SIGNATURE
ANALYST
OBSERVED
LIQUID
COMPONENT
96.7
LPARATOR
Pressures, kPa (gauge)
9t< 02 08
PROPERTIES OFCs.
RESIDUE (1511S"C)
mUm3
847.3
kg/m3
DENSITY
N2
Trace
Trace
Trace
CO2
0.0066
().OO42
0.0032
14.9
H2S
O.O()()()
0.0000
0.0000
OJ)
C1
0.5993
0.1389
0.2945
1355.4
C2
OJ)628
0.0273
0.0485
223.2
C~
OJl485
0.0309
0.0387
178.3
35.5
0.8480
API @lS.S0C
RELATIVE DENSITY
Trace
iC~
O.OOX2
0.0069
0.0078
35.8
C4
0.0235
0.0197
0.0215
98.9
iC5
(l.()OH9
O.O()93
0.0095
43.5
C5
0.0135
0.0141
0.0142
65.3
Cc,+
O.22H7
O.74X7
0.5621
2587.3
Total
I.()()OO
1.0000
1.0000
4602.7
227
RELATIVE MOLECULAR MASS
CALCULATED PROPERTIES OF TOTAL SAMPLE (1511S"C)
636.1
DENSITY
kg/m3
91.0
0.6366
API @lS.S0C
RELATIVE DENSITY
69.22
RELATIVE MOLECULAR MASS
REMARKS:
Refer to page 16 for the extended
hexanes plus.
NOTE:
"C
MUD RESISTIVITY
analysis
of
All Proper1le8 •• va been calcUlalad U1IllzIng GPA 2145-88 phyelcal co_
HYDROCARBON
Operator:
Well:
Sample Point:
LIQUID ANALYSIS
Page:
File:
Date:
Hibernia Management and Development
HMDC Hibernia B10-3
Reservoir Fluid (MDT Sample #1)
16
52l34-98-2061
980302
Analysis of C6+ Fraction
Boiling Point:
Range (0C)
Component
Carbon
Number
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
0.0162
0.0147
0.0187
0.0134
0.0134
0.01l7
0.0117
0.0089
0.0086
0.0079
0.0073
0.0060
0.0048
0.0048
0.0043
0.0038
0.0031
0.0030
0.0027
(l.O026
0'(lO22
0.0021
0.0018
0.0019
0.0213
0.0217
0.0229
0.0332
0.0268
0.0296
0.0285
0.0311
0.0257
0.0267
0.0260
0.0256
0.0223
0.0192
0.0199
0.0188
0.0174
0.0149
0.0150
0.0141
0.0142
0.0125
0.0124
0.0109
0.0120
0.2019
0.0191
0.0194
0.0274
0.0217
0.0236
0.0224
0.0241
0.0197
0.0202
0.0197
0.0193
0.0167
0.0143
0.0147
0.0139
0.0128
0.0109
0.0110
0.0102
0.0102
0.0090
0.0089
0.0079
0.0085
0.1440
36.1- 68.9
6R.9- 98.3
9R.3-125.6
125.6-150.6
150.6-173.9
173.9-196.1
196.1-215.0
215.0-235.0
235J)-252.2
252.2-270.6
270.6-287.8
287.8-302.8
302.8-317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
380.0- 391.1
391.1-40 I.7
401.7-412.2
412.2-422.2
422.2-43 I.7
43 I.7 -441.1
441.1 PLUS
Hcxanes
Hcpianes
Octanes
Nonancs
Decancs
Undccancs
Dodecanes
Tridccanes
Tctradccancs
Nonacosanes
Triacontanes Plus
C6
C7
Cs
C9
CIO
CII
CI2
CI3
CI4
CI5
CI6
Cl7
CI8
CI9
C20
C21
C22
C23
C24
C25
C26
C27
C2S
C29
C30+
80.0
110.6
136.1-138.9
144.4
168.9
Benzene
Toluene
Ethylbenzene. p + m-Xylene
o-Xylene
1.2.4 Trimethylbenzene
C6H6
C7HS
CsHlO
CSHIO
C9HI2
0.0025
0.0044
0.0040
0.0023
0.0012
0.0031
0.0063
0.0066
0.0037
0.0022
0.0020
0.0042
0.0044
0.0025
0.0015
48.9
72.2
81.1
I()1.1
Cyclopentane
Mcthylcyclopentane
CSHIO
C6HI2
C6HI2
C7H14
0.0021
0.0046
0.0045
0.0062
0.2287
0.0022
0.0060
0.0059
0.0094
0.7487
0.0017
0.0047
0.0044
0.0071
0.5621
Pcntadccanes
Hexadccancs
Heptadccanes
Octadccanes
Nonadecanes
Eicosancs
Heneicosancs
Docosancs
Tricosanes
Tctracosanes
Pentacosanes
Hcxacosancs
Hcptacosanes
Octacosanes
Cyclohcxane
Methylcyclohexane
TOTAL
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction ofC7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
0.2104
0.7248
0.5413
239
0.8554
854.7
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682; Feb-08-98, 3990.0m MD)
52134-98-2061-1
SEPARATOR TEST OF SEPARATOR FLUID
Flash
Gas/Oil
Gas/Oil
Stock Tank
Formation
Separator
Specific
Conditions
Ratio
Ratio
Oil Gravity
Volume
Volume
Gravity
of
Density
(~/~)
(~/ST~)
at 15.6 ·C
Factor
Factor
Flashed
Gas
(kgl~
(A)
(8)
('API)
Sofb (C)
(0)
kPa(g)
I
·C
Oil Phase
)
( Air=1.000 )
589.7 .•
36501
96.7
4137
75.0
217.1
253.9
1.169
0.706
745.8
1 138
73.0
17.2
19.1
1.110
0.815
768.7
109
92.0
12.0
13.1
1.092
1.227
762.9
0
45.0
0.1
0.1
Rsfb
38.2
1.851
1.027
811.0
= 286.2
• Calculated by material balance of separator test voIumetrlcs.
(A) Cubic metres of gas at 101.325 kPa(a) and 15.0 'C per cubic metre of oil at indicated pressure and temperature.
(8) Cubic metres of gas at 101.325 kPa(a) and 15.0 'C per cubic metre of stock tank oil at 15.0 ·C.
(C) Cubic metres of saturated oil at 36 501 kPa(g) and 96.7·C per cubic metre of stock tank oil at 15.0 ·C.
(0) Cubic metres of oil at indicated pressure and temperature per cubic metre of stock tank oil at 15.0 ·C.
Page 14
Core Laboratories Canada Ltd.
ILLUSTRATIONS
Core Laboratories Canada Ltd.
Hibernia Managament and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDTsample #682; Feb-08-98, 3 990.0m MD)
62134-98-2061-1
RELATIVE VOLUME
(VNs)
1.015
2.1
~
•• 1.9
E
..-
1.010
\
\
\
~1.7
I [ Saturation pressur~]
36 501 kPa (gauge)
w
~1.5
1.005
4,
"E
I'I-
E
w
1.000
:2
~
..I
0
>
1=1.3
1
0.995
~
W
~
-,
-... i"'--
1•1
0.9
0
10
20
30
40
PRESSURE:MPa (gauge)
<.
w
i:!
to-
~
-.
Relative Volume}
Below Bubt:Aepoint
0.990
~
0.985
0.980
38.0
38.0
40.0
42.0
44.0
PRESSURE: MPa (gauge)
Analytical Expression
(above bubblepolnt)
1.2939Eoo - 7.6664E-01 * (Xd)O.5+4.7273E-01 * (Xd)O.75- 1.9392E-01 (Log)(Xd)o.995
where; Xd is defined as ( P 1 Psat )
Statistical Summary
r squared:
Confidence Interval (+1-):
Confidence:
Legend
•
0.999990
0.00003
99%
Page 17
Laboratory Data
Confidence Umits
Analytical expresSion
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMOC Hibernia B16-3 (Subsurface MOT sample #682; Feb-08-98, 3 990.0m MO)
62134-98-2061-1
OIL DENSITY
850
800
..,
~
750
~at
~
36.0
in
z
38.0
PRESSURE:
40.0
42.0
MPa (gauge)
W
Q
....•
(5
700
Saturation Pressure
36 501 kPa (gauge)
650
600
o
9
27
18
PRESSURE:
36
45
MPa (gauge)
Analytical Expression (below bubblepolntl
7.8803E+02 - 2.9057E+02 * (Xd)0.5 + 3.2160E02 * (Xd) 1.0_2.1557E+02 * (Xd) 1.7
where; Xd is defined as ( P 1 Psat )
Statistical Summary
r squared:
Confidence Interval (+1-):
Confidence:
Legend
0.999867
0.644
99%
Cf)
Page 18
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682; Feb-08-98, 3 990.0m MD)
62134-98-2061-1
RELATIVE OIL VOLUME (VNr)
2.5
•• 2.08
E
..-
2.3 -f-
C
,<,
E2.07
Single-Phase ~
Relative Oil Volume
~
~2.06
:>
r-,
~2.05
..,
..,-
E
E
;.:.
2.1
- f- ~52.04
~
(i)
I'e
~2.03
•..
~
[saturation pressureJ
36 501 kPa (gauge)
1.9
w
35.0
--
37.0
41.0
39.0
PRESSURE:
43.0
MPa (gauge)
:E
::::»
-'0
>
-'0 1.7
V
w
>
t=
:5
w
0::
1.5
/'"
1.3
V
»<
/
/
/
V
~V
/
1.1
o
5
10
20
15
PRESSURE:
AnalVUcal Expression
25
35
30
40
MPa (gauge)
(below bubblepolntl
1.0763EOO +1. 5706E-02 • pO.3 + 1.5449E-05·
pO.91 + 2.2327E-19.
p4.0
where; P is defined as pressure, kPa(g)
StaUsUcal Symmary
r squared:
Confidence Interval (+1-):
Confidence:
Legend
(I
0.999934
0.00245
99%
Page 19
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMOC Hibernia 916-3 (Subsurface MDT sample #682; Feb-08-98, 3 990.0m MO)
62134-98-2061-1
GAS-OIL RATIOS
450
.,
400
-
.,~400
E
'IIa..
2300
-
i
....I
350
-
~
-
..•E
300
E
i
-
::;
0
~
....•
Uberated }
Gas-Oil Ratio
"' r-,
250
10
-
20
PRESSURE:
~
/
'"
0
0
i=
Saturation pressurfJ36 501 kPa (gauge)
~
~200
In
51100
•••
r
30
40
J'
MPa (gauge)
/
V
q
en
<
C)
200
z
-
0
i=
~
....•
0
en
150
100
50
o
V
V
/
,
V
/
o
8
I
Expression
32
24
16
PRESSURE:
Analytical
/
, , ,
,
,
V
I
40
MPa (gauge)
(Solution GOR - below bubblepolnn
6.7815E-01 • pO.5 + 1.5262E-05·
p1.51 + 7.6472E-19.
p4.4
where; P is defined as pressure, kPa(g)
Statistical
Summary
r squared:
Confidence Interval (+/-):
Confidence:
Legend
(9
0.999845
1.39
99%
----
Page 20
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682; Feb~8-98, 3 990.0m MD)
62134-98-2061-1
GAS DEVIATION (Z) FACTOR
/
{02
J Saturation
pressur~l
36 501 kPa (gauge)
0.99
~
\\
I-
U
<C
&I.
Ei
0.93
>
W
Q
(I)
<C
C»
/
/V
0.96
0
z
0
j:::
~
(i)
0.90
\
-,
"
<,
0.87
/'
~
/
I
0.84
o
5
10
15
20
25
30
35
PRESSURE: MPa (gauge)
Analytical Expression
9.9985E-01 - 8.1952E-02· (Xd)o.7- 1.3303E-01 • (Xd)o.35+ 2.7074E-01 • (Xd)455
where; Xd is defined as ( PI Psat )
Statistical Summary
r squared:
0.999874
Confidence Interval (+/-):
0.0006
Confidence:
99%
Legend
e
Page 21
Laboratory Data
Confidence Limits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682 ; Feb-08-98, 3 990.0m MD)
62134-98-2061-1
GAS FORMATION VOLUME FACTOR & GAS VISCOSITY
0.05
0.20
(saturation pressur~
36 501 kPa (gauge)
0.04
0.16
..,
..,E
~
E
a::
0
~
I
0.12
o
c:
II.
W
~
:IE
~
t-
-'0
>
z
0
i=
~
a::
0.08
0
II.
(I)
C
C)
.
0.04
V
r
V
V
/
V
V
/
V
0.03
•
•
Q.
I-
E
~
en
0
I-
o
(I)
s
(I)
-e
0.02
C)
0.01
\
I-
~
0.00
0.00
o
5
10
20
15
PRESSURE:
25
30
35
MPa (gauge)
Page 22
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface MDT sample #682; Feb-08-98, 3 990.0m MD)
62134-98-2061-1
OIL VISCOSITY
2.2
0.32
0.32
t.•
e 0.31
1.8
[
V
§i= 0.31
~
0.30
..J
•
••
A.
rI
(5
-~
/~
Single-Phase
Oil Viscosity
~
/
0.30
1.4
E
0.29
>•...
e;;
35.0
0
u
(I)
s
....•
(5
,
1.0
0.8
43.(
37.0
39.0
41.0
PRESSURE: MPa (gauge,
-.r-,
r
Saturation pressur~~
36 501 kPa (gauge)
~
~
~
'"
0.2
o
18
8
24
PRESSURE:
Analytical
1.5801EOO + 6.4717E-02·
Expression
32
40
MPa (gauge)
(below bubblepolntl
(Xd)o.45- 1.6347EOO· (Xd)o.7 + 2.8662E-01 • (Xd)4.5
where; Xd is defined as ( P / Psat )
Statistical
Summary
r squared:
Confidence Interval (+/-):
Confidence:
Legend
e
0.999854
0.0061
99%
Page 23
-
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
DATA ADJUSTMENT
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface MDT Sample #682; Feb-08-98,3 990.0m MD)
52134-98-2061
INTRODUCTION TO DATA ADJUSTMENT
Reservoir fluids, while being produced, simultaneously undergo two different thermodynamic
processes. One is the flash separation process which occurs in surface separation facilities and the
second is insitu reservoir fluid expansion ultimately resulting in differential equilibrium separation
of gas and oil in the reservoir during reservoir pressure decline.
Flash separation
(bubblepoint).
data are referenced
to reservoir
fluid volumes
at saturation
pressure
The data are useable only at the specific instant when the reservoir pressure is
equal to the saturation pressure as determined in the PVT study.
It is therefore necessary to adjust flash separation data to account for the insitu changes in
reservoir fluid properties that will occur during primary pressure depletion.
Both the flash
solution gas-oil ratio data (Rs) and the flash formation volume factor data (Bo) require adjustment
for pressures above and below the saturation pressure.
A. Solution Gas-Oil Ratio (Rs)
Pressure above Ps: No correction is required as no gas will escape from solution at pressures
above the saturation pressure. Therefore, Rs is equal to flash Rs at all pressures in excess ofPs.
Pressures below Ps: Due to insitu differential equilibrium separation of gas and oil, flash
separator data must be corrected as follows:
Page 24
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia BI6-3 (Subsurface MDT Sample #682; Feb-08-98, 3 990.0m MD)
52134-98-2061
Introduction to Data Adjustment. ....continued
Rs
=
Rsfb - (Rsdb - Rsd ) * (Bofb
where; Rs
=
=
=
=
Adjusted solution gas-oil ratio
Rsfb
Rsdb
Rsd
/ Bodb)
Total gas-oil ratio from flash at saturation pressure
Gas-oil ratio from differential liberation at saturation pressure
Gas-oil ratio from differential liberation at pressure less than
saturation pressure
Bofb
Bodb
=
=
Formation volume factor from flash at saturation pressure
Relative oil volume from differential liberation at saturation
pressure
This correction must be made for all D.V. gas-oil ratio data points below saturation pressure.
D. Formation Volume Factor (Bol
Pressures
above Ps:
Because flash formation volume factors are referenced to a volume at
saturation pressure, Bo at pressures above saturation pressure must be corrected to account for
oil compressibility. The adjustment is:
Do
=
Bofb * VNsat
where; Bo
=
Adjusted flash formation volume factor for pressures above
saturation pressure
Bofb
VNsat=
=
Formation volume factor from flash at saturation pressure
Relative volume from pressure volume relations at pressure
above saturation pressure
Page 25
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia BI6-3 (Subsurface MDT Sample #682; Feb-OS-9S,3 990.0m MD)
52134-98-2061
Introduction to Data Adjustment. ....continued
Pressure below Ps:
Because insitu oil shrinkage occurs due to differential gas liberation at
pressures below the saturation pressure (Ps), flash formation volume factors which are referenced
to a volume at saturation pressure must be corrected to reflect insitu reservoir fluid shrinkage.
The adjustment is as follows:
Bo
=
Bod * Bofb I Bodb
where; Bo
=
Adjusted flash formation volume factor for pressures below
saturation pressure
Bod
=
Relative oil volume from differential liberation at pressure
below saturation pressure
=
Bodb =
Bofb
Formation volume factor from flash at saturation pressure
Relative oil volume from differential liberation at saturation
pressure
This adjustment must be made for all D. V. relative oil volumes below saturation pressure.
The above adjustments have been made on your behalf and are reported on the following pages.
Page 26
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface MDT sample #682; Feb-08-98, 3990.0m MD)
52134-98-2061-1
DIFFERENTIAL VAPORIZATION
ADJUSTED TO SEPARATOR CONDITIONS·
Pressure
kPa(g)
blt
41369
38611
37921
37232
36542
36501
34129
31544
26890
22063
17237
12445
7584
2758
876
Solution
GaS/Oil
Ratio
Formation
Volume
Factor
Gas
Formation
Volume
Factor
Rs(A)
eo (B)
(C)
286.2
286.2
286.2
286.2
286.2
286.2
251.3
218.4
170.1
131.1
99.2
71.6
45.0
16.1
1.826
1.839
1.843
1.847
1.851
1.851
1.749
1.655
1.523
1.424
1.349
1.286
1.222
1.139
1.082
0.00377
0.00386
0.00425
0.00503
0.00644
0.00904
0.01516
0.04241
0.12749
Oil
Density
kglm"
Oil/Gas
Viscosity
Ratio
611.9
607.3
606.1
604.9
603.6
603.5
615.5
627.6
647.3
664.9
680.0
693.4
707.5
729.8
750.4
7.80
8.89
13.15
21.33
33.86
50.65
72.52
105.00
129.00
·Separator Conditions
First Stage
Second Stage
Third Stage
Stock Tank
4137 kPa(g) at 75.0 ·C
1138 kPa(g) at 73.0·C
109 kPa(g) at 92.0 ·C
o kPa(g) at 45.0 ·C
(A) Cubic metres of gas at 101.325 kPa(a) and 15.0 ·C per cubic metre of stock tank 011 at 15.0 ·C.
(B) Cubic metre of oil at Indicated pressure and temperature per cubic metre of stock tank oil at 15.0 ·C.
(C) Cubic metres of gas at indicated pressure and temperature per cubic metre at 101.325 kPa(a) and 15.0 ·C.
Page 27
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMOC Hibernia 816-3 (Subsurface MOT sample #682; Feb-08-98,3 990.0m MO)
62134-98-2061-1
ADJUSTED
FORMATION VOLUME FACTORS
2.4
(saturation pressure]
36 501 kPa (gauge)
2.2
~
'r-
~
2.0
..,
..,-EE
~
•...
0
o
1.8
<
~
w
~
:)
....•
0
>
z
0
/
1.6
V
j:
<
V
....
/
~
a=:
0
~
..
..
.../~
... ····0
~
..
e'
.fI
,
1.4
1.2
V
/
/
If
••
V
....... 111·····....
..•.... 111········
...e········
••
.
1.0
o
5
10
15
20
PRESSURE:
25
30
35
40
45
MPa (gauge)
Differential Vaporization
Separator Test (4137 kPa (gauge) at 75.0 °C)
Page 29
Core Laboratories Canada Ltd.
J1le #: ----tnitiala :
APR 291998
RECRIVY'D
eanad&.Newfoun4lAnd
~."'f'''C'
~t"'C".I\.'l""":
\Ln_ ....,
Reservoir Fluid Analysis
for
Hibernia Management and
Development Company Ltd.
HMDC Hibernia B16-3
Sample Date:~.~F~eb~-O~8~-9u8WJi..-Sampling Depth~ 4 051
-~··
CQNf
File Number: 52134-98-2060 (Calgary)
File Number: 52143-98-0024 (Newfoundland)
April 22nd, 1998
A product of
Core Laboratories Canada Ltd.
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core Laboratories Canada Ltd. assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other
mineral, proper well or sand in connection with which such report is used or relied upon for any reason whatsoever.
L-
_
Core Laborat
INV-021469
Well 149 Box 28756
CORE LABORATORIES
April 22nd, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
Ale 6K3
Attention:
Mr. John Andrews
Subject:
Reservoir Fluid Analysis
HMDC Hibernia B16-3
Sample Date: Feb-08-98
Sample Depth: 4 051 m MD
File Number: 52134-98-2060 (Calgary)
File Number: 52143-98-0024 (Newfoundland)
Gentlemen:
A subsurface sample (MDT Tool) of reservoir fluid was collected from the subject well by a
representative of Schlumberger on February 8th, 1998. The sample was then submitted to our
Calgary laboratory for analysis.
Initially, the pressure in the MDT tool was raised, using water as a hydraulic fluid on the
piston side, to a working pressure of 48 263 kPa (gauge). The tool was agitated in order to
redissolve any liberated gas into the oil phase. Once the reservoir fluid in the sampler was
confirmed to be in single-phase, an aliquot was transferred, at 48 263 kPa (gauge), to an
evacuated, high-pressure, stainless steel, windowed cell for a reservoir temperature, saturation
pressure measurement. The remainder of the sample from this tool was then transferred to a
high-pressure, stainless steel cylinder.
As stated above, the saturation pressure measurement was carried out using a high-pressure,
windowed cell. After an aliquot of sample was transferred to the cell, the contents of the cell
were stabilized at the working pressure and reservoir temperature. The pressure in the cell
was then lowered by increasing the effective internal volume of the cell, through hydraulic
fluid withdrawal, until free gas was noticed through the window portion of the cell. The
pressure at which the first bubble of gas was noticed was defined as the saturation
(bubblepoint) pressure of the fluid. The fluid in the cell was returned to a single-phase state
and the process repeated to confirm the saturation pressure.
.. .12
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250-5120
-2 -
The saturation pressure was reported and as instructed, a four-stage separator test and a
compositional analysis (C30+) were conducted on the subsurface sample. The conditions for
the separator test were supplied by Mr. John Andrews of Hibernia Management and
Development Company Ltd.
It should be noted that the data contained in the following report, although final for this issue,
maybe be refined once complete reservoir fluid studies have been conducted. The adjustments
or refinements would be as a result of more accurate and comprehensive measurements
required during the reservoir fluid studies. The changes, if any, would probably be within
±2% of the reported values.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LABORATORIES CANADA LTD.
AI Kassam
PVT - Technical Specialist
ak
enclosure
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3; Feb-8-98, 4 051 m MD
52134-98-2060
SUMMARY OF SATURATION PRESSURE DATA
Well
916-3
• Bubblepoint
Sampling
Sampling
Reservoir
Reservoir
Date
Depth
Temperature
Pressure
Pressure *
mMD
·C
kPa (absolute)
kPa (gauge)
4051
98.0
40116
37570
Feb-08-98
pressure
Saturation
(visually measured in a high-pressure, windowed ceil).
Page 1
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3; Feb-8-98, 4051 m MD
52134-98-2060
SEPARATOR TEST OF RESERVOIR FLUID SAMPLE
Separator
Separator
Gas/Oil
Gas/Oil
Stock Tank
Formation
Separator
Specific
Pressure
Temperature
Volume
Volume
Gravity of
°C
Ratio
(m3/STm3)
Oil Gravity
kPa
Ratio
(m3/m3)
@15.6°C
Factor
Factor
Liberated
(A)
(8)
(OAPI)
(C)
(0)
Gas (E)
75.0
186.4
216.3
1.161
0.714
73.0
17.1
18.9
1.107
0.843
92.0
12.7
13.9
1.092
1.278
45.0
0.1
-1U
1.027
N/M
Total
249.2
(Gauge)
37570
98.0
to
4137
to
1138
to
109
to
0
Sample Depth:
36.9
1.838
4051 m MD
Date Sampled:
Feb-08-98
Sampled by:
Schlumberger
NIM - not measured due to insufficient liberated gas.
(A) Cubic metres of gas @ 101.325 kPa (absolute) and 15.0 ·C per cubic metre of oil @ indicated pressure and temperature.
(8) Cubic metres of gas @ 101.325 kPa (absolute) and 15.0 ·C per cubic metre of stock tank oil @ 15.0 ·C.
(C) Cubic metres of saturated oil @ 37 570 kPa (gauge) and 98.0 ·C per cubic metre of stock tank oil @ 15.0 ·C.
(D) Cubic metres of oil @ indicated pressure and temperature per cubic metre of stock tank oil @ 15.0 ·C.
(E) Air = 1.000.
Page 2
Core Laboratories Canada Ltd.
Core Laboratories Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
oXI
52 I 34-9R- 2060
CONTAINER
IDENTITY
LABORATORY
Hibernia Management
and Development
NUMBER
3
OPERATOR
PAGE
HMDC Hibernia B 16-3
LOCATION
WELL OR SAMPLE
Hihernia
LOCATION
KB ELEV. (m)
Hibernia
FIELD OR AREA
POOL OR ZONE
TEST TYPE & NO
Reservoir
SAMPLER
TEST RECOVERY
Fluid (MDT Sample)
@
POINT OF SAMPLE
AMT & TYPE CUSHION
PUMPING
405I.O-
FLOWING
SWAB
~m~3~/d_
(meters)
@
37570
SEPARATOR
"C
@
CONTAINER
WHEN SAMPLED
WHEN RECEIVED
~~~s~
9802
(Y/M/D)
Temperatures. ''C
vs 02 25
13
DATE RECEIVED
(Y/M/D)
DATE ANALYZED
RS/TE
MOLE
MASS
VOLUME
FRACTION
FRACTION
FRACTION
SIGNATURE
ANALYST
(Y/M/D)
OBSERVED
LIQUID
COMPONENT
98.0
LPARATOR
Pressures. kPa (gauge)
C}g 02 08
~m~3~/d~
I ---;:;
°C
CONTAINER
RESERVOIR
PROPERTIES
OFCe.
RESIDUE
(15115"C)
mUm3
R4RA
N2
Trace
Trace
Trace
CO2
0.0073
0.0046
OJlO36
16.5
H2S
0.0000
(>.0000
0.0000
n.o
C)
0.5975
n.1366
0.2911
1351.4
C2
0.0023
0.0267
(W477
221.5
C~
0.0474
O,f)29R
OJ)}75
174.3
35.3
0.8492
kg/ml
RELATIVE
DENSITY
DENSITY
API
@ 15.5° C
API
@ 1S.SoC
Trace
iC4
OJ)OXO
O.OOon
0.0075
34.9
C4
0.0231
0.0191
n.0209
97.2
iC5
O.OOR7
0.OOR9
0.0092
42.5
C5
1).1)135
OJ)) 39
0.0141
05.3
c.;
0.2322
O.753R
056X4
203X.O
Total
1.0000
I.OO()()
I.()()()O
4641.5
228
RELATIVE
CALCULATED
639.0
DENSITY
PROPERTIES
MOLECULAR
MASS
OF TOTAL SAMPLE
(15115°C)
I).M02
kg/m3
RELATIVE
89.7
DENSITY
7n.20
RELATIVE
MOLECULAR
MASS
REMARKS:
Refer to page 4 for the extended analysis of
hexancs plus.
NOTE:
"C
MUD RESISTIVITY
GAS LIFT
~O~IL
WATER
TEST INTERVAL
DATE SAMPLED
GR ELEV (m)
Schlumberger
All Prope<1ies have been calculell!d utilizing GPA 2145·88 physical constant •.
ICWwl
Core Laboratories
ImnWI
Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
Operator:
Well:
Sample Point:
Hibernia
Management
and Development
Page:
File:
Date:
HMDC Hibernia B I 0-3
Reservoir Fluid (MDT Sample)
4
52134-9R-2060
9R 02 25
Analysis of C(,+ Fraction
Boiling Point:
Range to
Carhon
Component
Number
Hexancs
C(,
C7
Cx
C)
CIO
CII
C12
Cn
CI4
CIS
CI6
C17
CIR
CI9
C20
C21
Cn
C23
C24
C25
C26
C27
C2R
C29
36.1- 6X.9
6X.9- 9R.l
91U-125.6
125.6-150.6
150.6-173.9
173.9-196.1
19{-1.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.6-2X7.X
287.8-302.8
302.8-317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
3XOJ)-391.1
391.1-40 I.7
40\.7-412.2
412.2-422.2
422.2-431.7
43 \.7 -441.1
44l.l PLUS
Decancs
Undccanes
Dodccanes
Tridccanes
Tctradccanes
Pentadccancs
Hexadccancs
Hcptadccancs
Octadccancs
Nonadccanes
Eicosanes
Heneicosanes
Docosanes
Tricosanes
Tetracosancs
Pentacosanes
Hexacosancs
Hcptacosancs
Octacosanes
Nonacosanes
Triacontancs Plus
80.0
110.6
136.1-138.9
144.4
16KI}
4X.9
72.2
X1.1
IOl.l
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
(J.(J 163
0.0219
(>.0232
O.02RI
0.0250
0.0299
0.0319
0.0345
0.0279
0.0288
0.0279
0.0277
0.0234
0.0204
(l.O207
OJ)! 97
0.0188
0.0163
(J.O166
0.0152
0.0148
0.0130
0.0129
0.0\ 16
OJ)126
0.1845
OJ1I93
0.019X
0.0233
0.0203
0.0239
0.0251
0.0269
0.0215
OJ)220
0.0212
0.0209
0.0176
0.0152
0.0\54
OJ)146
0.0139
0.0119
0.0121
0.0110
0.0107
0.0094
0.0093
0.0010
0.0090
0.1325
C~O+
(Ul\49
(Ul\5X
(UlI25
0.0135
0.0131
0.0 UO
0.0097
0.0093
O.OOX5
o JlO7R
OJ)063
OJ)052
O.!)()50
(UlO45
(U)()41
OJ)034
0.0033
0.0029
0.0027
0.0023
O.!)()22
OJ)(lI9
O.!)()20
0.01%
Benzene
Toluene
Ethylhcnzenc. p + in-Xylene
o-Xylene
1.2.4 Trimethylbcnzcnc
C(;H(,
C7HR
CRH10
CRHIO
C)HI2
O.!)()26
O.()()45
().!)()41
O.!)()23
().!)()I2
0.0032
0.0065
().0067
OJlO38
(W023
OJlO21
. OJlO44
0.0045
0.0025
0.0015
Cyclopcntane
Mcthylcyclopcntane
Cyclohexane
Methylcyclohexane
TOTAL
C5HIO
C6HI2
C6H12
C7HI4
().!)()2I
O'!)()46
O.f)()47
0.0063
0.2322
0.0023
0.0060
0.0061
0.00%
0.7538
0.0018
0.0047
0.0045
0'(lO73
056R4
Hcptancs
Octanes
Nonancs
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
0.2138
0.7296
05473
240
0.8566
R55.9
IDe #:
_
1DitIaII :
APR 291998
RltCBIVfi
0
Reservoir Fluid Analysis
for
Hibernia Management and
Development Company Ltd.
HMDC Hibernia 616-3
Sample Date: Feb-08-98
Sampling Depth: 4 085 m MD
I
CONFI
T
File Number: 52134-98-0907 (Calgary)
File Number: 52143-98-0023 (Newfoundland)
April 22nd, 1998
A product of
Core Laboratories Canada Ltd.
INV-021471
Well 149 Box 28754
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core Laboratories Canada Ltd. assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other
mineral, proper well or sand in connection with which such report is used or relied upon for any reason whatsoever.
L-
Core Laboratories _----'
CORE LABORATORIES
April 22nd, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
A1C 6K3
Attention:
Mr. John Andrews
SUbject:
Reservoir Fluid Analysis
HMDC Hibernia B16-3
Sample Date: Feb-08-98
Sample Depth: 4 085 m MD
File Number: 52134-98-0907 (Calgary)
File Number: 52143-98-0023 (Newfoundland)
Gentlemen:
A subsurface sample (MDT Tool) of reservoir fluid was collected from the subject well by a
representative ofSchlumberger on February 8th, 1998. The sample was then submitted to our
Calgary laboratory for analysis.
Initially, the pressure in the MDT tool was raised, using water as a hydraulic fluid on the
piston side, to a working pressure of 48 263 kPa (gauge). The tool was agitated in order to
redissolve any liberated gas into the oil phase. Once the reservoir fluid in the sampler was
confirmed to be in single-phase, an aliquot was transferred, at 48 263 kPa (gauge), to an
evacuated, high-pressure, stainless steel, windowed cell for a reservoir temperature, saturation
pressure measurement. The remainder of the sample from this tool was then transferred to a
high-pressure, stainless steel cylinder.
As stated above, the saturation pressure measurement was carried out using a high-pressure,
windowed cell. After an aliquot of sample was transferred to the cell, the contents of the cell
were stabilized at the working pressure and reservoir temperature. The pressure in the cell
was then lowered by increasing the effective internal volume of the cell, through hydraulic
fluid withdrawal, until free gas was noticed through the window portion of the cell. The
pressure at which the first bubble of gas was noticed was defined as the saturation
(bubblepoint) pressure of the fluid. The fluid in the cell was returned to a single-phase state
and the process repeated to confirm the saturation pressure.
...12
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250-5120
-2-
The saturation pressure was reported and as instructed, a four-stage separator test and a
compositional analysis (C30+) were conducted on the subsurface sample. The conditions for
the separator test were supplied by Mr. John Andrews of Hibernia Management and
Development Company Ltd.
It should be noted that the data contained in the following report, although final for this issue,
maybe be refined once complete reservoir fluid studies have been conducted. The adjustments
or refinements would be as a result of more accurate and comprehensive measurements
required during the reservoir fluid studies. The changes, if any, would probably be within
±2% of the reported values.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LADORA TORIES CANADA LTD.
J~y.j.r3-/~
7
AI Kassam
PVT - Technical Specialist
ak
enclosure
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3;
Feb-8-98, 4 085 m MD
52134-98-0907
SUMMARY OF SATURATION PRESSURE DATA
Well
816-3
• Bubblepoint
Sampling
Reservoir
Reservoir
Date
Depth
Temperature
Pressure
Pressure •
mMD
'C
kPa (absolute)
kPa (gauge)
4085
98.8
40309
35887
Feb-08-98
pressure
Saturation
Sampling
(visually measured in a high-pressure, windowed ceil).
Page 1
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3; Feb-8-98, 4 085 m MD
52134-98-0907
SEPARATOR TEST OF RESERVOIR FLUID SAMPLE
Separator
Separator
Gas/Oil
Gas/Oil
Stock Tank
Formation
Separator
Specific
Pressure
Temperature
Volume
Volume
Gravity of
°C
Ratio
(m3/STm3)
Oil Gravity
kPa
Ratio
(m3/m3)
Factor
Liberated
(8)
@ 15.6 °C
(OAPI)
Factor
(A)
(C)
(0)
Gas (E)
75.0
177.8
206.5
1.161
0.691
73.0
16.2
18.0
1.112
0.832
92.0
12.8
14.0
1.095
1.312
45.0
0.6
---.M
1.027
N/M
Total
239.1
(Gauge)
35887
98.8
to
4137
to
1138
to
109
to
0
Sample Depth:
1.701
4085 m MD
Date Sampled:
Feb-08-98
Sampled by:
Schlumberger
N/M
36.1
- not measured due to insufficient liberated gas.
(A) Cubic metres of gas @ 101.325 kPa (absolute) and 15.0 ·C per cubic metre of oil @ indicated pressure and temperature.
(8) Cubic metres of gas @ 101.325 kPa (absolute) and 15.0 ·C per cubic metre of stock tank oil @ 15.0 ·C.
(C) Cubic metres of saturated oil @ 35 887 kPa (gauge) and 98.8 ·C per cubic metre of stock tank oil @ 15.0 ·C.
(D) Cubic metres of oil @ indicated pressure and temperature per cubic metre of stock tank oil @ 15..0 ·C.
(E) Air = 1.000.
Page 2
Core Laboratories Canada Ltd.
Core Laboratories
HYDROCARBON
Canada Ltd.
LIQUID ANALYSIS
(iXO
52134-98-0907
CONTAINER
LABORATORY
IDENTITY
Hibernia Management
and Dcvelopmcni
NUMBER
3
OPERATOR
PAGE
HMDC Hibernia Blo-3
LOCATION
WELL OR SAMPLE
LOCATION
KB ELEV. (m)
Hibernia
Hibernia
FIELD OR AREA
POOL OR ZONE
TEST TYPE & NO.
Reservoir
TEST RECOVERY
Fluid (MDT Sample)
@
AMT
PUMPING
40X5.0 (meters)
~O~IL
@
35HX7
~m~3~/d_
@
"C
CONTAINER
WHEN SAMPLED
WHEN RECEIVED
~G~AS~
DATE RECEIVED
Temperatures, "C
9802 25
98 02 13
(Y/M/D)
(Y/MID)
DATE ANALYZED
RS/TE
(Y/MlD)
MASS
VOLUME
FRACTION
FRACTION
FRACTION
SIGNATURE
ANALYST
OBSERVED
LIQUID
MOLE
98.8
LPARATOR
Pressures, kPa (gauge)
98 02 OS
m~3~/d~
I -=
°C
CONTAINER
PROPERTIES
OFCs.
RESIDUE
(15115"C)
mUmJ
X4<).X kg/m3
0.8506
RELATIVE
DENSITY
N2
Trace
Trace
Trace
CO2
0.0079
0.0046
().Om7
H2S
0.0000
0.0000
O.nooo
OJ)
C,
057R3
0.1225
0.26XI
1307.9
C2
()'o5<)2
(1.0235
0.0431
210.4
C3
0.0422
0.0246
0.031 X
155.1
35.0
API @ 15 5° C
DENSITY
Trace
231
17.9
iC4
0.0079
0.0061
0.0071
345
C4
0.0254
0.0195
0.0219
106.9
iC5
0.00<)9
0.0094
OJ)09<)
4X.4
Cs
0.0154
0.0147
no 153
74.5
Ct\+
0.2538
n.775 I
05<)<)1
2<)22.3
Total
t.oooo
1.0000
I.OO{)()
4X77.9
RELATIVE
CALCULATED
(i5(i.7
PROPERTIES
MOLECULAR
MASS
OF TOTAL SAMPLE
(15/1 saC)
84.0
0.6573
kg/m3
RELATIVE
DENSITY
API @ 15.5° C
DENSITY
75.75
RELATIVE
MOLECULAR
MASS
REMARKS:
Refer to page 4 for the extended analysis of
hcxancs plus.
NOTE:
All Properties
"C
MUD RESISTIVITY
CUSHION
SWAB
.
RESERVOIR
SEPARATOR
& TYPE
GAS LIFT
FLOWING
WATER
TES T INTERVAL
COMPONENT
1m)
SAMPLER
POINT OF SAMPLE
DATE SAMPLED
GR ELEV
Schlumberger
have been calculated
utilizing GPA 2145-88 phy~caI
conetant •.
IrnnwI
Core Laboratories
HYDROCARBON
Operator:
Well:
Sample Point:
Hibernia Management
LIQUID ANALYSIS
and Development
Page:
File:
Date:
HMDC Hibernia B )fi-3
Reservoir
IWWI
Canada Ltd.
Fluid (MDT Sample)
4
52134-9X-0907
9X 0224
Analysis of C(,+ Fraction
Boiling Point:
Range ("C)
30.1- 68.9
08.9- 98.3
98.3-125.0
125.6-150.6
150.6-173.9
173.9-196.1
11J6.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.0-287.8
287.8-302.8
302.8- 317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-309.4
309.4-380.0
380.0- 391.1
391.1-401.7
401.7-412.2
412.2-422.2
422.2-431.7
431.7 -441.1
441.1 PLUS
Carhon
Component
Number
Hexancs
C(,
C7
CR
C<)
CIO
CII
CI2
CI:1
CI4
CI5
CI6
C17
CII!
CI9
C20
C21
C22
Cn
Heptanes
Octanes
Nonanes
Decanes
Undccanes
Dodccancs
Tridccanes
Tctradccancs
Pentadecanes
Hexadecancs
Heptadccanes
Octadecanes
Nonadecanes
Eicosanes
Heneicosanes
Docosanes
Tricosanes
Liq. Vo\.
Fraction
(J.O173
0.0158
(J.O150
o.o 143
(J.(J142
n.o 136
O.(JB6
(J.(J106
(J.(JIOI
(J.(J()91
0.0186
0.0189
0.0208
0.0210
0.0228
0.0236
0.0255
0.0213
0.0216
0.0207
0.0208
om 77
0.0154
0.0159
0.Q153
0.()J41
0.0122
0.0123
0.0114
O.oII4
no 10I
0.0100
0.0087
0.0095
0.1704
C2S
o.no:n
C26
C2R
C29
C:1(H.
0.0027
(J.002O
0.0022
0.0023
0.0278
C6H6
C7HR
CRHtO
CgHIO
C9Ht2
O.n020
(J.OOI9
0.0(142
n.0024
O.OOB
0.0028
0.0024
0.0060
0.0035
0.0021
0.0019
0.0017
0.0042
0.0024
0.0014
CsHIO
C6HI2
C6Ht2
C7Ht4
0.0019
O'()(149
0.11049
0.0009
0.2538
0.0018
0.0057
0.0057
0.0092
n.7751
0.0014
0.0045
0.0044
0.0072
0.5991
C24
Hcptacosancs
Cn
Octacosanes
Nonacosanes
Triacontanes Plus
80.0
110.6
110.1-I3K9
144.4
108.9
Benzene
Toluene
Ethylbcnzene, P + m-Xylcnc
48.9
72.2
81.1
IOI.l
Cyclopcntane
Methylcyclopcntane
Cyclohcxane
Methylcyclohcxanc
TOTAL
1.2.4 Trimethylhenzcnc
Mass
Fraction
0.0205
0.0216
0.0244
(l.O25I
(l.0277
0.0291
0.0317
0.0268
0.0275
(1.0266
(l.O268
0.0229
0.0201
0.0208
0.0200
0.0186
0.0160
0.0164
0.0152
0.0153
on 135
n.0135
(1.0119
0.n128
0.2311
Tetracosanes
Pentacosancs
Hexacosanes
o-Xylene
Mole
Fraction
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
o.omn
(l.(1070
0.0058
0.0057
0.0052
0'(lf146
OJ)038
0.0037
o.om3
0.2340
0.7528
n.5791
243
0.8574
856.6
,0
klJ
-rf!
B
CORE LABORATORIES
Pill #:
DEe
0"'·
O~~R\'( \.
_
2 199&
~~--..,..
~-.,
REcalVED
0Iaada~"'0QP4Ia""
Reservoir Fluid Analysis
for
Hibernia Management and
Development Company Ltd.
HMDC Hibernia B16-3
Subsurface SRS Sample #1300-1A
Sample Date: Feb-27 -98
Sampling Depth: 4 085.0 m MD
File Number: 52134-98-1526 (Calgary)
File Number: 52143-98-0018 (Newfoundland)
November 19th, 1998
A product of
Core Laboratories Canada Ltd.
The analysis, opinions 0( interpretations contained in this report are based upon observations and material supplied by the client for
whose exclusive and confidential use this report has been made. The interpretations 0( opinions expressed represent the best
judgement of Core Laboratories Canada Ltd. Core Laboratories Canada Ltd. assumes no responsibility and makes no warranty or
representations, expressed 0( implied, as to the productivity, proper operations, 0( profitableness however of any oil, gas, coal 0( other
mineral, proper well 0( sand in connection with which such report is used 0( relied upon for any reason whatsoever.
Core Laboratories
Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250-5120
-
CORE LABORATORIES
November 19th, 1998
Hibernia Management and Development Company Ltd.
Suite 1000, 100 New Gower Street
St. John's, Newfoundland
AIC 610
Attention:
Mr. John Andrews
SUbject:
Reservoir Fluid Study (Subsurface Sample)
HMDC Hibernia B16-3
Sample Date: Feb-27-98
File Number: 52134-98-1526(Calgary)
File Number: 52143-98-0018 (Newfoundland)
Gentlemen:
Subsurface samples were collected from the subject well by a representative of Oilphase on
February 27th, 1998. The samples were then submitted to our Calgary laboratory for use in a
reservoir fluid study.
Upon arrival, a visual saturation pressure was measured, a
compositional analysis was conducted, a four-stage separator test conducted, and the results
reported to Mr. John Andrews.
It was then requested that a complete reservoir fluid study be conducted on this sample. The
enclosed report contains a brief description of the tests & the expreimental procedures that
were followed in the laboratory, the laboratory results in tabular and graphical formats, the
compositional data, and concludung remarks.
Thank you for the opportunity to be of service. Please contact us if you have any questions
concerning the enclosed data.
Yours truly,
CORE LABORATORIES CANADA LID.
Dawson Milbury
PVT Co-ordinator
\dm
enclosure
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250-5120
TABLE OF CONTENTS
ITEM
l. Summary ofPVT Data
PAGE
1
2. Project Objective & Scope
2
3. Analytical Summary
3-7
4. Conclusions & Observations
8
5. Tabular Data
A. Pressure-Volume Relations
9,10
B. Differential Vaporization
11,12
C. Reservoir Fluid Viscosity
13
D. Separator Test of Reservoir Fluid
14
6. Compositional Data
A. Reservoir Fluid
15,16
7. Illustrations
A. Relative Volume
17
B. Oil Density
18
C. Relative Oil Volume
19
D. Solution and Liberated Gas-Oil Ratios
20
E. Gas Deviation (Z) Factor
21'
F. Gas Formation Volume Factor & Gas Viscosity
22
G. Oil Viscosity
23
8. Data Adjustment
A. Introduction to Data Adjustment
24-26
B. Adjusted Data
27
C. Adjusted Solution Gas-Oil Ratios (lliustration)
28
29
D. Adjusted Formation Volume Factors (Illustration)
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3
(Subsurface SRS sample #1300-1A; Feb-27-98, 4 085.0 m RT)
52134-98-1526
SUMMARY OF PVT DATA
Reported Reservoir Conditions
Current Reservoir Pressure
.
39470
kPa(a)
Reservoir Temperature
.
95.6
·c
Pressure-Volume
Saturation
Pressure
Avg. Single-Phase
.
Compressibility
Thermal Exp. @ 41 369 kPa(g)
Relations
36611
kPa(g)
.
25.22
E-7 vlvlkPa ( 41 369 to 36 611 kPa(g) )
.
1.10158
Vat 95.6·C I V at 15.0·C
Differential Vaporization
Data
( at 36 611 kPa(g) and 95.6 ·C )
Solution GaS/Oil Ratio
.
277.4
In' I In' of residual oil at 15.0 ·C
Relative Oil Volume
.
1.842
In' I In' of residual oil at 15.0 ·C
633.5
kg/In'
Density of Reservoir Fluid
.
Reservoir Fluid Viscosity
0.384 mPa·s at 36 611 kPa(g) and 95.6 ·C
Separator Test Results
Primary Separator Conditions
Formation
Total Solution
Tank Oil Gravity
Volume Factor
Gas/Oil Ratio
( ·API at 15.6 ·C )
kPa(g)
·C
(A)
(8)
4137
75.0
1.709
241.7
35.6
(A) Cubic metres of saturated oil per cubic metre of stock tank oil at 15.0 ·C.
(8) Total standard cubic metres of gas per cubic metre of stock tank oil at 15.0 ·C.
Page 1
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS Sample #1300-1A; Feb-27-98, 4085.0 m RT)
52134-98-1526
PROJECT OBJECTIVE & SCOPE
The objective of the reservoir fluid study is to determine the PVT properties of the reservoir fluid
from the Hibernia B16-3 well (sampled Feb-27-98, sample depth - 4 08S.0m MD).
The scope of the study entails the following tests; pressure-volume
relations,
differential
vaporization, viscosity measurements, multi-stage separator test and compositional analysis.
Page 2
Core Laboratories Canada Ltd.
Hibernia Management
HMDC Hibernia
B16-3 (Subsurface
and Development Company Ltd.
SRS Sample #1300-1A;
Feb-27-98,
4085.0 m R1)
52134-98-1526
ANALYTICAL
SUMMARY
Sample Transfer & Preparation
Subsurface samples of reservoir fluid were collected from the subject well by Oilphase.
The
samples were transferred, monophasically, to a piston-type cylinder at our Mt. Pearl facility, and
shipped to Calgary. Upon arrival, the samples were heated to a temperature well above reservoir
temperature, and transferred to a high pressure, stainless steel storage cylinder.
The saturation
pressure of the samples, at reservoir temperature, was measured and reported to Mr. John
Andrews. One sample, SRS # 1300-1A, was selected for a full PVT study.
PVT Experiments
A. Pressure-Volume Relations Test
A measured aliquot of the reservoir fluid is transferred, under pressure, to a high-pressure,
windowed cell and stabilized at a working pressure significantly above the reservoir pressure. The
cell is thenheated
to the reported reservoir temperature of 95.6 °C and again stabilized at the
working pressure.
The cell pressure is lowered by withdrawing the inert hydraulic fluid.
Reservoir fluid volumes in the cell are determined at several pressure increments both above and
below the saturation pressure. The saturation pressure (bubblepoint) itself is confirmed by visual
observation through the cell window and is repeated twice.
The results of this test are reported in the form of a ratio of reservoir fluid volume at any pressure
to the reservoir fluid volume at saturation conditions (relative volume or VNsat).
The relative
volume data is then used to calculate single-phase oil compressibilities and densities.
The data from this test is tabulated on pages 9 & 10 and illustrated on page 17 of this report.
Page 3
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface MDT Sample #682; Feb-08-98, 3 990.0 m MD)
52134-98-2061
Analytical Summary ..... continued
B. Differential Vaporization
At the completion of the pressure-volume relations test, the reservoir fluid is put into single phase
and stabilized at the working pressure and reservoir temperature.
The pressure in the cell is then
lowered, through hydraulic fluid withdrawal, to a predetermined pressure below the saturation
pressure.
The gas and oil phase portions of the system are allowed to separate and establish
equilibrium.
Once equilibrium is reached, the liberated gas is removed, at constant pressure,
quantified and its relative density to air measured. The volume of oil remaining in the cell is also
determined.
The pressure is reduced again and the procedure repeated until the final pressure
(atmospheric) is reached.
The stepwise pressure reduction allows for the examination of two-phase properties as a function
of pressure depletion during primary production.
Specifically, the liberated gas relative density,
gas deviation (Z) factor, gas formation volume factor, solution gas-oil ratio, oil formation volume
factor and oil phase density are determined at each pressure stage.
The data generated from the differential vaporization test is tabulated on pages 11 & 12 and
illustrated on pages 18 through 22 of this report.
c. Reservoir Fluid Viscosity
An aliquot of the reservoir fluid from the first cylinder is transferred, in single phase, to a rolling
ball viscometer that is preheated to the reservoir temperature. In this instrument, the roll time of a
steel ball is measured and converted to a viscosity value through calibration factors for a given
stainless steel barrel placed in the viscometer. The measurement is started at a pressure above the
reservoir pressure and is lowered through a relief valve to the next required pressure level. For
Page 4
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface SRS Sample #1300-1A; Feb-27-98, 4085.0 m RT)
52134-98-1526
Analytical Summary ..... continued
pressures below the saturation pressure, the liberated gas is isolated from the oil phase in such a
way as to allow only the oil to fill the measuring chamber (barrel). The same pressure levels used
in the pressure-volume relations and differential vaporization tests are selected such that the oil
density values from these tests can be directly used to convert roll times to viscosity values.
The viscosity of the liberated gas at each pressure level below the saturation pressure is
calculated, based on a correlation by Lee, Eakin & Gonzalez, using the liberated gas properties
determined in the differential vaporization test.
The viscosity data is tabulated on page 13 and illustrated on pages 22 & 23 of this report.
D. Separator Test
A measured aliquot of the reservoir fluid is transferred to a scale separator and flashed at
conditions supplied by Mr. John Andrews of Hibernia Management and Development Company
Ltd. Specifically, flash to high stage separator conditions of 4240 kPa (absolute) & 75.0 °C, then
to medium stage separator conditions of 1 240 kPa (absolute) & 73.0 °C, then to low stage
separator conditions of 210 kPa (absolute) & 92.0 °C and finally to stock tank conditions and
45.0 °C. At each stage, the liberated gas is removed and quantified after equilibrium has been
reached. The volume of liquid remaining is then determined. This data is presented in the form of
solution gas-liquid ratios (total and individual stage), formation volume factor, stock tank liquid
gravity and liberated gas relative densities. The solution gas-oil ratio and the formation volume
factor from this test are adjusted, as documented in the Data Adjustment section of this report,
using data from the pressure-volume relations and differential vaporization tests.
PageS
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS Sample #1300-1A; Feb-27-98, 4 085.0 m R1)
52134-98-1526
Analytical Summary ..... continued
The results from the separator test can be found on page 14 of this report.
E. Reservoir Fluid Composition
The composition of the reservoir fluid is determined by high temperature flash. In this process, an
aliquot of reservoir fluid is flashed to atmospheric pressure at a controlled rate and elevated
temperature.
The evolved gas is collected, quantified and analyzed.
quantified and analyzed.
The residual oil is also
The reservoir fluid composition is arrived at by mathematically
recombining the individual flashed gas and residual oil compositions.
The flashed gas analysis is performed on the HP 6890 gas chromatograph.
employed in this technology.
Three columns are
One column is used to detect oxygen and nitrogen.
The second
column detects carbon dioxide, hydrogen sulphide and light hydrocarbons to propane.
The third
column identifies the remainder of the hydrocarbons in the flashed gas (i.e.; butanes to extinction).
Helium is used as the carrier gas in all three columns. The residual oil is analyzed by capillary
chromatography which adheres to the ASTM simulated distillation method.
In this method, a
multi-component internal standard is used to compensate for column losses.
The resulting reservoir fluid composition is detailed on pages 15 and 16 of this report.
Page 6
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface SRS Sample #1300-1A; Feb-27-98, 4085.0 m RT)
52134-98-1526
Analytical Summary ..... continued
General
A. Illustrations
Where applicable, analytical expressions best representing the PVT data reported
and the
corresponding statistical summaries have been provided. Refer to pages 17 to 23 of this report.
B. Data Adjustment
The total solution gas-oil ratio and the formation volume factor from the multi-stage separator
test have been adjusted such that this data can be used directly in volumetric and material balance
calculations.
Complete documentation is provided on pages 24 to 26.
The adjusted data is
tabulated on page 27 and is illustrated on pages 28 & 29 of this report.
Page 7
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface SRS Sample #1300-1A; Feb-27-98, 4085.0 m RT)
52134-98-1526
CONCLUSIONS
& OBSERVATIONS
Based on the information received from Hibernia Management and Development Company Ltd.,
the data contained in this report and the observations made during the course of this study, the
following can be concluded.
1.
The saturation (bubblepoint) pressure of the bottomhole sample used in this study was
determined to be 36 611 kPa (gauge) at the reported reservoir temperature of 95.6 °C.
The
reported reservoir pressure was 39 470 kPa (absolute).
2. The reservoir fluid exhibited the behaviour of a slightly volatile, medium gravity oil system.
There was no visual evidence of any unusual or uncommon occurrences during the course of this
study.
3. The adjusted data should be used in volumetric and material balance calculations.
4. Core Laboratories can recommend and perform additional tests to further define or characterize
the reservoir.
PageS
Core Laboratories Canada Ltd.
TABULAR DATA
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMOC Hibernia 816-3
(Subsurface SRS sample #1300-1A; Feb-27-98, 4 085.0 m RT)
52134-98-1526
VOLUMETRIC DATA
(at 95.6 ·C)
Saturation Pressure (Psat)
Density at Psat
Thermal Exp.@ 41 369 kPa(g)
.
.
.
36611 kPa(g)
633.5 kglm3
1.10158 Vat 95.6·C I Vat 15.0·C
AVERAGE SINGLE-PHASE COMPRESSIBILITIES
41369
38611
37921
37232
Pressure Range
kPa(g)
Single-Phase
Compressibility
vlvlkPa
to
to
to
to
24.06 E-7
26.35 E-7
27.36 E-7
28.36 E-7
38611
37921
37232
36 611
Page 9
Core Laboratories Canada LId.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3(Subsurface
SRS sample #1300-1A; Feb-27-98,4 085.0mRT)
52134-98-1526
PRESSURE-VOLUME RELATIONS
(at 95.6 °C)
Pressure
Relative
Volume (A)
kPa(g)
41369
38611
37921
37232
b»36611
35611
34887
31957
28262
24428
21 015
17892
15244
12714
11294
0.9880
0.9946
0.9964
0.9982
1.0000
1.0057
1.0102
1.0317
1.0690
1.1261
1.2027
1.3081
1.4421
1.6360
1.7906
V-Function
Density
(8)
kgl~
641.2
637.0
635.8
634.6
633.5
4.897
4.835
4.583
4.266
3.937
3.644
3.376
3.149
2.932
2.810
(A) Relative Volume: VNsat or volume at indicated pressure per volume at saturation pressure.
(6) Where: V-Function
:=
(Psat - P)
(Pabs)· (yNsat -1)
Page 10
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia
816-3
(Subsurface
SRS sample #1300-1A; Feb-27-98, 4 085.0 m RT)
52134-98-1526
DIFFERENTIAL VAPORIZATION
(at 95.6 ·C)
Oil Properties
Oil
Relative
Relative
Solution
Liberated
Pressure
Density
Oil
Total
GaS/Oil
Gas/Oil
kPa(g)
kgIm'
Volume
Volume
Ratio
Ratio
Bod (A)
Btd (B)
Rsd (C)
Rid
1.842
1.775
1.714
1.613
1.531
1.461
1.402
1.842
1.869
1.897
1.968
2.081
2.274
2.606
3.224
4.624
9.540
26.695
277.4
251.7
229.1
191.5
159.8
131.1
105.2
81.6
58.9
35.8
19.4
0.0
0.0
25.7
48.3
85.9
117.6
146.3
172.2
195.8
218.5
241.6
258.0
277.4
b»36 611
34515
32398
28275
24187
20015
15865
11728
7550
3440
1172
0
Gravity
of Residual
Oil
Density
of Residual
Oil
633.5
642.5
651.3
667.5
682.3
696.4
709.6
722.3
735.6
751.7
766.6
803.0
=
=
1.348
1.293
1.230
1.182
1.073
32.8 ·API at 15.6 ·C
861.0 kg/m3 at 15.0·C
(A) Cubic metre of oil at indicated pressure and temperature per cubic metre of residual oil at 15.0 ·C.
(8) Cubic metres of oil plus liberated gas at indicated pressure and temperature per cubic metre of residual oil at 15.0 ·C.
(C) Cubic metres of gas at 101.325 kPa(a) and 15.0 ·C per cubic metre of residual oil at 15.0 ·C.
Page 11
Core Laboratories Canada Ltd.
Hibernia Management and Development
HMDC Hibernia
816-3
(Subsurface
Company Ltd.
SRS sample #1300-1A; Feb-27 -98, 4 085.0 m RT)
52134-98-1526
DIFFERENTIAL VAPORIZATION
(at 95.6 ·C)
Gas Properties
Incremental
Cumulative
Incremental
Gas
Gas
Gas
Deviation
Formation
Gas
Pressure
Relative
Relative
Factor
Volume
Expansion
kPa(g)
Density
Density
Z
Factor
Factor
(A)
(A)
8g (8)
1/8g (C)
0.904
0.880
0.838
0.802
0.772
0.753
0.750
0.776
0.868
1.023
1.843
0.904
0.893
0.869
0.851
0.835
0.823
0.814
0.810
0.816
0.829
0.900
0.00366
0.00378
0.00413
0.00468
0.00556
0.00700
0.00958
0.01525
0.03439
0.09889
273.28
264.27
241.85
213.69
179.95
142.92
104.37
65.58
29.08
10.11
b»36611
34515
32398
28275
24187
20015
15865
11728
7550
3440
1172
0
0.977
0.948
0.905
0.877
0.862
0.862
0.874
0.900
0.939
0.971
(A) Air = 1.000
(8) Cubic metres of gas at indicated pressure and temperature per cubic metre at 101.325 kPa(a) and 15.0 ·C.
(C) Cubic metres of gas at 101.325 kPa(a) and 15.0 'C per cubic metre at indicated pressure and temperature.
Page 12
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3
(Subsurface SRS sample #1300-1A; Feb-27-98, 4 085.0 m RT)
52134-98-1526
RESERVOIR FLUID VISCOSITY
(at 95.6 °C)
Pressure
Oil
Viscosity
Gas
Viscosity *
kPa(g)
mPa·.
mPa·.
41369
38611
37921
37232
b»36 611
34515
32398
28275
24187
20015
15865
11728
7550
3440
1172
0
0.409
0.394
0.391
0.387
0.384
0.385
0.392
0.420
0.0370
0.0342
0.0292
0.0250
0.0214
0.0186
0.0164
0.0147
0.0131
0.0119
0.473
0.555
0.673
0.837
1.074
1.437
1.786
2.148
Oil/Gas
Viscosity
ratio
10.4
11.4
14.4
18.9
25.9
36.1
50.9
73.2
110.0
150.1
• Gas vISCOSity data calculated from correlation of Lee A.L., Gonzalez M.H., and Eakin B.E., "The
VISCOSity of Natural Gases", Journal of Petroleum Technology, August, 1966, pp. 997·1000.
Page 13
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface SRS sample #1300-1A; Feb-27-98, 4085.0 m RT)
52134-98-1526
SEPARATOR TEST OF SEPARATOR FLUID
GaS/Oil
Flash
Conditions
kPa(g)
36611
4137
1 138
109
0
I
Gas/Oil
Stock
Tank
Formation
Separator
Oil Phase
Specific
Ratio
Ratio
Oil Gravity
Volume
Volume
Gravity
of
Density
(m'/m' )
( m'/STm')
at 15.6 ·C
Factor
Factor
Flashed
Gas
(kg/m'
·C
(A)
(8)
(OAPI)
Sofb (C)
(0)
95.6
75.0
73.0
92.0
45.0
177.7
16.1
14.0
0.9
Rsfb
=
207.5
18.0
15.3
0.9
241.7
1.168
35.6
1.709
1.118
1.095
1.027
)
( AIr=1.000 )
0.728
0.830
1.320
628.6 *
761.5
778.7
772.8
824.3
• Calculated by material balance of separator test volumetrics.
(A) Cubic metres of gas at 101.325 kPa(a) and 15.0 ·C per cubic metre of oil at indicated pressure and temperature.
(8) Cubic metres of gas at 101.325 kPa(a) and 15.0 ·C per cubic metre of stock tank oil at 15.0 ·C.
(C) Cubic metres of saturated oil at 36 611 kPa(g) and 95.6 ·C per cubic metre of stock tank oil at 15.0 ·C.
(0) Cubic metres of oil at indicated pressure and temperature per cubic metre of stock tank oil at 15.0 ·C.
Page 14
Core laboratories
Canada Ltd.
CO:MPOSITIONAL DATA
Core Laboratories Canada Ltd.
HYDROCARBON
LIQUID ANALYSIS
P8
52134-98-1526
CONTAINER
IDENTITY
LABORATORY
Hibernia
Management
and Development
NUMBER
15
OPERATOR
HMDC Hihcrnia
LOCATION
PAGE
B16-3
WELL OR SAMPLE
LOCATION
KB ELEV. (m)
Hihernia
FIELD OR AREA
POOL OR ZONE
TEST TYPE & NO.
Reservoir
SAMPLER
TEST RECOVERY
Fluid (SRS Sample)
@
POINT OF SAMPLE
AMT. & TYPE CUSHION
PUMPING
4085
FLOWING
SWAB
~m~3~~_
(meters)
@
3661 I
SEPARATOR
oc
@
CONTAINER
WHEN SAMPLED
WHEN RECEIVED
~GA~S~
~m~3~ld_
I ---::-;
°C
CONTAINER
RESERVOIR
MUD RESISTIVITY
GAS LIFT
~O~IL
WATER
TEST INTERVAL
\}8 03 12
980227
DATE SAMPLED
(YI!AID)
DATE RECEIVED
Temperatures,
\}8 03 27
(YIMID)
DATE ANALYZED
MASS
VOLUME
FRACTION
FRACTION
FRACTION
"C
RS/TE
(YIMID)
SIGNATURE
ANALYST
OBSERVED
LIQUID
MOLE
95.6
LPARATOR
Pressures. kPa (gauge)
COMPONENT
GR ELEV. (m)
Oilphase
PROPERTIES
OFCs.
RESIDUE
(15115OC)
mUm3
855.2
N2
Trace
Trace
Trace
CO2
0.0074
0.0044
OJ)()35
H2S
0.0000
O.OO()()
0.0000
0.0
C,
0.5747
0.1244
0.2713
1299.8
Cz
0.0620
0.0252
0.0460
220.4
C3
O.l14n
OJ)2!}3
0.0378
180.9
34.0
0.8560
kgtm3
RELATIVE
DENSITY
DENSITY
API
@ ts.s= C
API
@ 15.5° C
Trace
229
16.8
iC4
O.OOH5
0.0067
OllO77
37.1
C4
O.O24!}
OJ)I!}5
0.0219
104.8
iC5
nnt ()()
o Jl097
0.0102
48.9
C.~
0.0156
0.0152
0.0157
75.4
C6+
0.2477
0.7656
0.5859
2806.6
TotaJ
1.0000
I.()O()O
1.0000
4790.7
RELATIVE
CALCULATED
654.4
DENSITY
PROPERTIES
MOLECULAR
MASS
OF TOTAL SAMPLE
(151tSOC)
84.7
0.6549
!!!11m3
RELATIVE
DENSITY
74.12
RELATIVE
MOLECULAR
MASS
REMARKS:
Refer to page 16 for the extended
hexanes plus.
NOTE:
All PropertiH
analysis
of
•• va been celcUlet8d utilizing GPA 2145-88 phyalcel conewtt
••
HYDROCARBON LIQUID ANALYSIS
Operator:
Hibernia
Management
Well:
HMDC
Hibernia
Sample
Point:
Reservoir
and Development
Page:
File:
Date:
B 10-3
Fluid (SRS Sample)
16
52134-98-1526
980327
Analysis of C6+ Fraction
Boiling Point:
Range (OC)
36.1- (iR.9
61t\)- \}lU
9R3-125.6
125.(i-150.(i
150.6-173.9
173.9-1l)(i.1
196.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
270.6-2X7.8
287.R-302.8
30V<-317.2
317.2-:nO.O
330.0-344.4
344.4-357.2
357.2-369.4
369.4-380.0
380.0- 391.1
391.1-401.7
401.7-412.2
412.2-422.2
422.2-431.7
43 1.7-441.1
441.1 PLUS
80.0
110.6
136.1-138.9
144.4
168.9
4X.9
72.2
X1.\
101.1
Component
Carbon
Number
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
C6
C7
C8
C9
CIO
CII
CI2
Cl3
CI4
CIS
CI6
Cl7
CI8
CI9
Czo
C2l
C22
0.0187
0.0193
0.0230
0.0203
0.0240
0.0272
0.0295
0.0269
0.0274
0.0259
0.0255
0.0235
0.0208
0.0209
0.0193
0.0183
0.0162
0.0162
0.0149
0.0152
0.0137
0.0137
0.0126
0.0136
0.2404
0.0169
0.0168
0.0195
0.0168
0.0196
0.0219
0.0235
0.0212
0.0214
0.0201
0.0196
0.0180
0.0159
0.0158
0.0146
0.0138
0.0122
0.0121
0.0111
0.0112
0.0101
0.0101
0.0093
0.0100
0.1762
Nonacosanes
Triacontanes Plus
CZ9
C30+
0.0161
0.0143
0.0149
0.0117
0.0125
0.0129
0.0129
0.0108
0.0103
0.0090
0.0083
0.0073
0.0061
0.0058
0.0051
0.0046
0.0039
0.0037
0.0033
0.0032
0.0028
0.0027
0.0024
0.0025
0.0294
Benzene
Toluene
Ethylhcnzene. p + m-Xylene
o-Xylene
1.2.4 Trimethylbcnzene
C6H6
C7HS
CsHIO
CsHIO
C9HI2
0.0025
0.0043
0.0037
0.0021
0.0012
0.0026
0.0053
0.0054
0.0030
0.0019
0.0018
0.0036
0.0037
0.0020
0.0013
CycJopcntane
Methylcyclopentane
Cyclohcxane
Methylcyclohexane
TOTAL
C5HIO
C6HI2
C6Ht2
C7Ht4
0.0022
0.0046
0.0045
0.0061
0.2477
0.0021
0.0052
0.0051
0.0080
0.7656
0.0016
0.0041
0.0039
0.0062
0.5859
Hcxancs
Hcpiancs
Octanes
Nonancs
Decanes
Undccancs
Dodccancs
Tridecancs
Tetradccanes
Pcntadccanes
Hcxadecanes
Hcptadecanes
Octadecancs
Nonadecanes
Eicosancs
Hcneicosanes
Docosancs
Tricosanes
Tctracosanes
Pcntacosanes
Hcxacosanes
Hcptacosanes
Octacosancs
CZ3
C24
C25
C26
C27
C28
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
0.2294
0.7448
0.5674
241
0.8625
861.8
ILLUSTRATIONS
Core Laboratories Canada Ltd.
Hibernia Managament and Development Company Ltd.
HMOC Hibernia 816-3 (Subsurface SRS sample #1300-1A; Feb-27-98. 4 086.0m RT)
62134-98-1626
RELA nVE VOLUME (VNs)
1.015
2.1
,
•• 1.8
E
..-
1.010
,
~1.7
I [saturation pressur~J
36 611 kPa (gauge)
\
~
;1.5
1.006
..,
..,-EE
1.000
&II
::E
;:)
-
.oJ
0
>
w
>
4,
~
.-1.3
<,
r-,
0.995
i=
:5
&II
It:
Relative Volume}
Below BuWepoint
...•..
-
~1.1
r-;
•••••
~
0.8
20
30
PRESSURE: MPa (gauge)
10
<,
""-
0.990
40
<,
0.985
0.980
36.0
38.0
40.0
PRESSURE:
Analytical
Expression
44.0
42.0
MPI (gauge)
(above bubblepolnt)
8.4981EOO - 1.3941E+01 • (Xd)o.1 +6.4428EOO· (Xd)o.2
where; Xd is defined as ( P / Psat )
Statistical
Summary
r squared:
Confidence Interval (+/-):
Confidence:
Legend
•
---
0.999975
O.OOOS
99%
Page 17
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
HMDC Hibernia
Hibernia Management and Development
Company Ltd.
B16-3 (Subsurface
SRS sample #1300-1A;
Feb-27-98,"
62134-98-1626
086.0m RT)
OIL DENSITY
875
"'~~, ~--~--~-----+~~-+-§~~+-~~~---~-
825
~
..,
..
E
a.
~ -+--~--~~---4-----+-775
~
u;
z
36.0
38.0
PRESSURE:
40.0
42.0
MPe (gauge)
w
C
...•
S 725
Saturation Pressure
36 611 kPa (gauge)
875
825
o
9
27
18
38
45
PRESSURE: MPa (gauge)
Analytical Expression
(below bubblepolnn
8.0302E+02 - 1.0554E+02 * (Xd)O.31- 6.3948E+01 • (Xd)2.0
where; Xd is defined 88 ( P 1 Psat )
Statistical Summary
r squared:
Confidence Interval (+1-):
Confidence:
Legend
0.999946
0.349
99%
-
Page 18
e
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS sample '1300-1A; Feb-27-98, 4 086.0m RT)
62134-98-1626
RELATIVE OIL VOLUME (VNr)
2.3
•.• 1.88
..
!
E1.85
2.1
-
/
&.
~
f·84
~1.83
..,
..,-EE 1.9 ~
~
Single-Phase ~
Relative Oil Volume
r-,<,
I(Saturation pressur~
Il36 611 kPa (gauge)
~
51.82
111.81
35.0
~
37.0
PRESSURE:
311.0
41.0
43.0
MPa (gauge)
w
~
~
...•
1.7
0
>
...•
0
w
>
j:
:5
w
1.5
0::
1.3
V
V
V
V
V
Y
V
V
1.1
o
5
10
15
20
25
35
30
40
PRESSURE: MPa (gauge)
Analytical Expression
(below bubblepolntl
1.0729EOO +2.8269E-02 * pO.15 + 1.3717E-04 * pO.75 + 2.8710E-17 * p3.5
where; P is defined as pressure, kPa(g)
Legend
Statistical Summary
r squared:
Confidence Interval (+/-):
Confidence:
19
0.999977
0.0011
99%
Page 19
-
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS sample #1300-1A; Feb-27-98, 4 086.0m RT)
62134-98-1626
GAS-OIL RATIOS
450
..
..-
E400
400
-
E
350
-
..,
oJ
Q200
~
-
~100
..,- 300 -
i
E
E
oJ
0
0
~
...•
""
250
Saturation pressurj
36 611kPa (gauge)
J,
r-,...•.
0
i=
l
Liberated }
\...Gas-Oil Ratio
~300
10
"
30
20
PRESSURE:
-
.&Q
MPII (puge)
q
en
c
e
200
z
0
i=
:)
...•
0
./
150
en
~
100
50
o
V
~
V
V
/
/
/
V
o
18
8
PRESSURE:
Analytical
Expression
24
32
40
MPa (gauge)
(Solution GOR - below bubblepolntl
4.2476E-01 * pO.54 + 1.7101E-07 * p1.95 + 8.4216E-38 * p8.4
where; P is defined as pressure, kPa(g)
Statistical
Summary
r squared:
Confidence Interval (+/-):
Confidence:
Legend
<tl
0.999985
0.32
----
99%
Page 20
Laboratory Data
Confidence Limits
Analytical Expression
Core laboratOries Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface SRS sample #1300-1A; Feb-27-98, 4 086.0m RT)
62134-98-1626
GAS DEVIATION (Z) FACTOR
1.02
r Saturation pressur~l
36 611 kPa (gauge)
0.99
a:
•...
0
-e
•...
0
-
ti
z
0
/
\
0.96
0.93
t=
\
:5
V
\
\
>
III
Q
CI)
C
0
7
0.90
\
~
0.87
<,
V
••••
....•
15
20
PRESSURE:
MPa (gauge)
V
/
/
0.84
o
5
10
Analytical
25
30
35
Expression
1.0001EOO - 3.2228E-01 * (Xd)o.7 + 3.3152E-01 * (Xd)2.5
where; Xd is defined as ( P / ?sat )
Statistical
Summary
r squared:
Confidence Interval (+/-):
Confidence:
~
•
----
0.999883
0.0005
99%
Page 21
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS sample #1300-1A; Feb-27-98, 4 086.0m RT)
62134-98-1626
GAS FORMATION VOLUME FACTOR & GAS VISCOSITY
0.05
0.16
[saturation pressur~
36 611 kPa (gauge)
l-
0.04
0.12
..,
.e
..,
E
t
Iii:
0
~ ~
t-
o
0(
:.•
~
E
u.
w
:IE
~
...I
0
J
0.08
>
z
0
j:
0(
::E
a:
0
u.
U)
0(
0
\
0.04
\
/ k
V
V
/
0.03
V
V
s
U)
0(
e
0.02
I-
-
~
0.00
0.01
I
o
5
~
ino
o
U)
10
15
PRESSURE:
20
25
30
35
MPa (gauge)
Page 22
Core Laboratories Canada Ltd.
HMDC Hibernia
Hibernia Management and Development
Company Ltd.
816-3 (Subsurface
SRS sample #1300-1A;
Feb-27-98,
62134-98-1626
4 086.0m RT)
OIL VISCOSITY
2.2
OAS
0.43 -
\
1.8
.
i
Single·Phase
Oil Viscosity
~
r-
~ 0.41
I •••.
fI)
5
...I
ill
~
~
0.37
0.35
).:
l-
t;;
0
o
(I)
(5
-
1.4
E
s
...•
r'
~
l,.....r' /
§ 0.39
•
)
36.0 37.0 38.0 39.0
PRESSURE:
!'t!...
1.0
-.
41.0
~.O
MPII (gauge)
Saturation pressureJ
36 611 kPa (gauge)
r-,
0.6
42.
+
'-
~
~.
0.2
o
16
8
24
PRESSURE:
AnalyUcal Expression
32
40
MPa (gauge)
(below bubblepolnt)
21478EOO + 1.0876E+01 • (Xd)O.3- 1.3423E01 • (Xd)o.335+7.8299E-01 • (Xd)1.s
where; Xd is defined as ( P / Psat )
Statistical
Summary
r squared:
Confidence Interval (+/-):
Confidence:
Leaend
e
0.999883
o.oon
99%
Page 23
Laboratory Data
Confidence Umits
Analytical Expression
Core Laboratories Canada Ltd.
DATA ADJUSTMENT
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface SRS Sample #1300-1A; Feb-27-98, 4 085.0m MD)
52134-98-1526
INTRODUCTION
TO DATA ADJUSTMENT
Reservoir fluids, while being produced, simultaneously undergo two different thermodynamic
processes. One is the flash separation process which occurs in surface separation facilities and the
second is insitu reservoir fluid expansion ultimately resulting in differential equilibrium separation
of gas and oil in the reservoir during reservoir pressure decline.
Flash separation
(bubblepoint).
data are referenced
to reservoir
fluid volumes
at saturation
pressure
The data are useable only at the specific instant when the reservoir pressure is
equal to the saturation pressure as determined in the PVT study.
It is therefore necessary to adjust flash separation data to account for the insitu changes in
reservoir fluid properties that will occur during primary pressure depletion.
Both the flash
solution gas-oil ratio data (Rs) and the flash formation volume factor data (Bo) require adjustment
for pressures above and below the saturation pressure.
A. Solution Gas-Oil Ratio (Rs)
Pressure above Ps: No correction is required as no gas will escape from solution at pressures
above the saturation pressure. Therefore, Rs is equal to flash Rs at all pressures in excess of Ps.
Pressures
below Ps: Due to insitu differential equilibrium separation of gas and oil, flash
separator data must be corrected as follows:
Page 24
Core Laboratories Canada Ltd.
Hibernia Management
and Development Company Ltd.
HMDC Hibernia Bl6-3 (Subsurface SRS Sample #1300-1A; Feb-27-98,4 085.0m MD)
52134-98-1526
Introduction to Data Adjustment.. ...continued
Rs
=
Rsfb - (Rsdb - Rsd)
where; Rs
=
Adjusted solution gas-oil ratio
Rsfb
=
Total gas-oil ratio from flash at saturation pressure
Rsdb
=
Gas-oil ratio from differential liberation at saturation pressure
Rsd
* (Bofb I Bodb)
Gas-oil ratio from differential liberation at pressure less than
saturation pressure
Bofb
=
Formation volume factor from flash at saturation pressure
Bodb
=
Relative oil volume from differential liberation at saturation
pressure
This correction must be made for all D. V. gas-oil ratio data points below saturation pressure.
B. Formation
Pressures
Volume Factor (Bo)
above Ps:
Because flash formation volume factors are referenced to a volume at
saturation pressure, Bo at pressures above saturation pressure must be corrected to account for
oil compressibility. The adjustment is:
Bo
=
Bofb * VlVsat
where; Bo
=
Adjusted flash formation volume factor for pressures above
saturation pressure
Bofb
=
Formation volume factor from flash at saturation pressure
VlVsat=
Relative volume from pressure volume relations at pressure
above saturation pressure
Page 25
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia Bl6-J (Subsurface SRS Sample #1300-1A; Feb-27-98, 4 085.0m MD)
52134-98-1526
Introduction to Data Adjustment. ....continued
Pressure below Ps: Because insitu oil shrinkage occurs due to differential gas liberation at
pressures below the saturation pressure (Ps), flash formation volume factors which are referenced
to a volume at saturation pressure must be corrected to reflect insitu reservoir fluid shrinkage.
The adjustment is as follows:
Bo
=
Bod * Bofb / Bodb
where; Bo
=
Adjusted flash formation volume factor for pressures below
saturation pressure
Bod
=
Relative oil volume from differential liberation at pressure
below saturation pressure
Bofb =
Bodb =
Formation volume factor from flash at saturation pressure
Relative oil volume from differential liberation at saturation
pressure
This adjustment must be made for all D.Y. relative oil volumes below saturation pressure.
The above adjustments have been made on your behalf and are reported on the following pages.
Page 26
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia 816-3 (Subsurface SRS sample #1300-1A; Feb-27-98, 4 085.0 m RT)
52134-98-1526
DIFFERENTIAL VAPORIZATION
ADJUSTED TO SEPARATOR CONDITIONS·
Gas
b»
Solution
Formation
Formation
Oil
Oil/Gas
Pressure
GaS/Oil
Volume
Volume
Density
Viscosity
kPa(g)
Ratio
Rs(A)
Factor
Bo (8)
Factor
(C)
kgIm"
Ratio
41369
38611
37921
37232
36611
34515
32398
28275
24187
20015
15865
11 728
7550
3440
1172
241.7
241.7
241.7
241.7
241.7
217.9
196.9
162.1
132.7
106.0
82.1
60.1
39.1
17.6
2.4
1.688
1.700
1.703
1.706
1.709
1.647
1.590
1.496
1.420
1.355
1.300
1.250
1.199
1.141
1.096
0.00366
0.00378
0.00413
0.00468
0.00556
0.00700
0.00958
0.01525
0.03439
0.09889
641.2
637.0
635.8
634.6
633.5
642.5
651.3
667.5
682.3
696.4
709.6
722.3
735.6
751.7
766.6
10.4
11.4
14.4
18.9
25.9
36.1
50.9
73.2
110.0
150.0
·Separator Conditions
First Stage
Second
Stage
Third Stage
Stock Tank
4137 kPa(g) at 75.0 °C
1 138 kPa(g) at 73.0 °C
109 kPa(g) at 92.0 °C
o kPa(g) at 45.0 °C
(A) Cubic metres of gas at 101.325 kPa(a) and 15.0·C per cubic metre of stock tank oil at 15.0 ·C.
(8) Cubic metre of oil at Indicated pressure and temperature per cubic metre of stock tank oil at 15.0 ·C.
(C) Cubic metres of gas at indicated pressure and temperature per cubic metre at 101.325 kPa(a) and 15.0 ·C.
Page 27
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS sample #1300-1A; Feb-27-98, 4 086.0m Rn
62134-98-1626
ADJUSTED SOLUTION GAS-OIL RATIOS
350
[saturation pressur~
36611 kPa (gauge)
I
300
~
J
250
"
.!I'J
..,
..,-EE
0
j:
200
~
..J
q
/
V//
(#)
c
e
z
0
150
j:
::»
..J
0
.' '
V
~
..
......•.
......•
(#)
/
100
••
v'
./
.:
..
/
50
.......•.....
~/./.
8'
o
o
9
1.
27
36
45
PRESSURE: MPa (gauge)
Differential Vaporization
Separator Test (4137 kPa (gauge) at 75.0 0c)
Page 28
Core Laboratories Canada Ltd.
Hibernia Management and Development Company Ltd.
HMDC Hibernia B16-3 (Subsurface SRS sample #1300-1A; Feb-27-98,4 086.0m RT)
62134-98-1626
ADJUSTED FORMATION VOLUME FACTORS
2.2
[ Saturation pressur~
36 611 kPa (gauge)
J
2.0
~
..,
..,E
E
/> roe
1.8
a:
e
/'/~S&""
....
$
()
c
II.
/
W
~
::I
1.8
-I
g
V
...
/
Z
0
~
c
~
01::
0
II.
.
1.4
1.2
/
I ••
e'
V
/
-:
V
.•.......
~
••
.'
.:
.'
..•.............
....•...........
........
.'
.'
1.0
o
5
10
15
20
25
30
35
40
45
PRESSURE: MPa (gauge)
Differential Vaporization
Separator Test (4137 kPa (gauge) at 75.0 °C)
Page 29
Core Laboratories Canada Ltd.
)/5
Core Laboratories Reservoir Fluids Report - Calgary
Re-Issue
for
Hibernia Management & Development Company Lt
------
HMDC Hibernia B16-3
Number Of Pages (including cover page):
File Number: 52134-98-1668
Date: April 21, 1998
Report Distribution:
APPROVED BY:
John Andrews, HMDC (St. John's) - 2 copies
Peter Ronayne, HMDC (St. John's) - invoice
(1IJk
ru
Supervisor Reservoir Fluids
Phone # 250-4047
Please contact the above person should there be any questions concerning the
contents of this report. Atmospheric samples will be kept a maximum of 30 days.
The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the
client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed
represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or
representations, expressed or implied, as to the productivity, proper operations, or profitableness however of any oil, gas.
coal or other mineral, proper well or sand in connection with which such report is used or relied upon for any reason
whatsoever.
INV-021576
Well 149 Box 2 8757
Core Laboratories Canada Ltd.
2810 - 12 Street NE, Calgary, Alberta T2E 7P7, (403) 250-4000,
Fax (403) 250-5120
Core Laboratories
Canada Ltd.
GAS ANALYSIS
H'i32
CONTAINER
'i2134-98-1
fifiX
LABORATORY
NUMBER
IDENTITY
Hibernia
Management
and Developmen,
OPERATOR
HMDC
LOCATION
Hibernia
PAGE
B 10-3
WELL OR SAMPLE
Hihernia
LOCATION
Baker
FIELD OR AREA
SAMPLER
Gas Manifold
@
POINT OF SAMPLE
AMT & TYPE CUSHION
PUMPING
FLOWING
TEST INTERVAL
@
RESERVOIR
Pressures.
()l1:41 Hrs
9X 02 27
H2
SWAB
m~3~/d_
~G~AS~
~m3~/d~
(meters)
4137
SEPARATOR
°C
MUD RESISTNITY
GAS LIFT
~O~IL
WATER
COMPONENT
ELEV (m}
TEST RECOVERY
Test Separator
DATE SAMPLED
GR
(m)
Petrolite
POOL OR ZONE
TEST TYPE & NO.
West
KB ELEV
Hibernia
9803
(Y/M/D)
WHEN SAMPLED
WHEN RECEIVED
DATE ANALYZED
MOLE FRACTION
MOLE FRACTION
mUm3
AIR FREE AS
AIR FREE
AIR FREE AS
RECEIVED
ACID GAS FREE
RECEIVED
() .()()()()
().O(){){)
O.{)()OI
N2
0.0020
OJ)026
CALCULATED
SIGNATURE
GROSS HEATING
MOISTURE
CALCULATED
TOTAL SAMPLE
0.0000
HZS
().OOO()
() .()()OO
C,
O.R4XR
O.X571
C2
0.0729
0.0736
2W.I
C~
O.041'i
O.!1419
1'i2.6
O.R3'i
DENSITY
RELATIVE
PROPERTIES
iC4
O.O()'i0
O.!X)'iO
21.X
C4
(Ull l'i
O.!)! 10
4X.4
iC5
O.OO2'i
O.!X)2'i
12.2
C5
0.0032
l'i.'i
C6
0.0016
o.oo:n
o.nn 6
C7+
O.(){)()X
O.{)()OX
'i.'i
Total
1.0000
I.{)()OO
'i23.l1
PENTANES
(AIR.l)
@ 15°C & 101.325 kPa
19.7
RELATIVE
PSEUDOCRITICAL
kPa (abs)
pPe
MOLECULAR
MASS
PROPERTIES
ACID GAS FREE
AS SAMPLED
4602.1
PLUS
FREE AS SAMPLED
DENSITY
CALCULATED
@ 40.O"C
100.2
& ACID GAS FREE
().oX I
kg/m3
VAPOR PRESSURE
kPa (abs.)
44.00
FREE
MOISTURE
OJ)()l}'i
CALCULATED
VALUE
@ 15°C & lOt 325 kPa (abs.)
MJim3
44.19
CO2
''C
JH
ANALYST
(Y/M/D)
MOISTURE
(WOO I
=J
PARATOR
Temperatures.
l1X 03 26
(Y/M/D)
He
L=:5
@22 °C
CONTAINER
kPa (gauge)
16
DATE RECEIVED
21()()
OC
CONTAINER
213.4
K
kPa (abs)
K
pTe
pTe
pPe
REMARKS:
X.X
NOTE:
THE GROSS HEATlNG
VALUE HAS BEEN CALCULATED
AGA REPORT 115AND ALL PROPERTlES
GPA 2145-88 PHYSICAL
CONSTANTS.
IN ACCORDANCE
HAVE BEEN CALCULATED
TO
UTlUZING
Core Laboratories
Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
V7171
52134-9R-1 (i(iX
CONTAINER IDENTITY
LABORATORY NUMBER
Hibernia Management
and Development
2
OPERATOR
PAGE
HMDC Hibernia B 16-3
LOCATION
WELL OR SAMPLE LOCATION
Hibernia
KB ELEV (m)
Hihcrnia
FIELD OR AREA
POOLOR ZONE
TES T TYPE & NO
GR ELEV Iml
Baker Pctrolite
SAMPLER
TEST RECOVERY
West Test Separator
@
POINT OF SAMPLE
AMT & TYPE CUSHION
PUMPING
FLOWING
GAS LIFT
~O~IL
WATER
SWAB
~m~3~/d~ ~G~AS~
TEST INTERVAL (meters)
4137
@
SEPARATOR
@
"C
CONTAINER
WHEN SAMPLED
RESERVOIR
9803
DATE SAMPLED (Y/M/D)
MOLE
MASS
VOLUME
FRACTION
FRACTION
FRACTION
=J
RS
DATE ANALYZED (Y/M/D)
SIGNATURE
ANALYST
OBSERVED
LIQUID
COMPONENT
PARATOR
Temperatures. ''C
1)8 03 31
16
DATE RECEIVED (Y/MIO)
~m3~/d~
L:::'
°C
CONTAINER
WHEN RECEIVED
Pressures. kPa (gauge)
1():32 Hrs
I))ol 02 27
MUD RESISTIVITY
PROPERTIES OFCs.
RESIDUE (15/15"C)
mUm3
R5n.1
34.9
0.8509
kg/mJ
API @ 15.5° C
RELATIVE DENSITY
DENSITY
Trace
N2
Trace
Trace
Trace
CO2
O.n030
OJ)()()R
O.l)()OR
H2S
0.0000
0.0000
().OOO()
0.0
C1
0.1314
OJ) 126
0.0337
2')7.2
C2
O'()424
0.0076
0.0171
150.7
C~
0.(51)4
n.o 157
O.l)24X
21XA
232
6.R
iC4
0.1)124
O'()(J43
0.0061
54.1
C4
O.!1406
0.0141
0.0194
170.9
iC;
(U)176
0.0076
O.OO9R
86.0
C5
0.0272
0.0117
0.0149
131.5
C6+
0.6660
0.9256
0.8734
76')4.7
Total
1.0000
l.OO()()
l.noOO
8X10.3
RELATIVE MOLECULAR MASS
CALCULATED PROPERTIES OF TOTAL SAMPLE (15/150C)
X02.2
o.smn
44.')
RELATIVE DENSITY
API @ 15 sOC
ks/m3
DENSITY
167.12
RELATIVE MOLECULAR MASS
REMARKS:
Refer to page 3 for the extended
of hexancs plus.
NOTE:
All Pr0p8rt1e. have been caleulated
analysis
utilizing GPA 2145·88 phylical
eon.","t
•.
ctlw I
I
Core Laboratories
IB
Canada Ltd.
HYDROCARBON LIQUID ANALYSIS
Operator:
WeIl:
Sample Point:
Page:
File:
Date:
Hibernia Management and Development
HMDC Hibernia B 10-3
West Test Separator
3
52134-9R-looH
9H 03 31
Analysis of Cr,+ Fraction
Boiling Point:
Range (oC)
16.1- 6X.1}
fiR.9- 9R.1
lJX.3-125.6
125.6-150.6
15n.6-173.1}
173.lJ-196.1
1%.1-215.0
215.0-235.0
235.0-252.2
252.2-270.6
ilO.6-2R7.X
2R7.X-302.R
302.X-317.2
317.2-330.0
330.0-344.4
344.4-357.2
357.2-369.4
361}.4-3XO.n
3RO.0-391.1
191.1-401.7
40\.7-412.2
412.2-422.2
422.2-43\.7
411. 7-44 1.1
441.1 PLUS
Carbon
Component
Number
Hcxancs
Cr,
C7
Cx
C<)
CIO
Hcptanes
Octanes
Nonanes
Dccanes
Undccanes
Dodccancs
Tridccancs
Tctradecanes
Pernadccancs
Hcxadccanes
Hcptadccancs
Octadecanes
C"
CI2
CI~
CI4
CIS
c.,
Tctracosanes
Pcntacosancs
Hexacosancs
Heptacosancs
Octacosancs
Nonacosanes
Triacontanes Plus
CI7
CIR
CI9
C20
C21
C22
C23
C24
C2S
C2r,
C27
C2M
C29
C~(~
XO.O
110.6
136.1-138.9
144.4
16X,9
Benzene
Toluene
Ethylbenzcnc, p + m-Xylcnc
o-Xylene
1.2.4 Trimethylhenzene
C(,Hr,
C7HR
CxHlo
CxHln
C9HI2
4X.9
72.2
XI.I
In 1.1
Cyclopentanc
Methylcyclopcntane
Cyclohexanc
Mcthylcyclohcxane
TOTAL
CsHln
C6HI2
Cr,HI2
C7HI4
Nonadecanes
Eicosanes
Hencicosanes
Docosanes
Tricosanes
Mole Fraction of C7+
Mass Fraction of C7+
Liquid Volume Fraction of C7+
Calculated Relative Molecular Mass of C7+
Calculated Relative Density of C7+
Calculated Density of C7+ (kg/m3)
Mole
Fraction
Mass
Fraction
Liq. Vol.
Fraction
o.o:nx
0.mX4
O.043X
O.m50
0.0394
o.m51
O.m47
O.02XO
0.0262
0.0217
(l.O222
o.n IXO
0.0151
0.0146
0.0133
O.OI2()
O.009X
n.OO96
O.OOX6
O.OOX4
0.0071
0.0070
O.005X
O.()()(i3
O.OX60
0.0195
0.0230
0.0300
0.0268
O.()336
n.0329
0.0354
0.0309
0.0312
0.0302
0.0302
0.0259
0.0230
()'()234
n.0225
0.0213
O.01R2
n.0186
0.0174
0.0177
o.o 156
0.0\59
0.0137
o.o 156
O.10R4
0.0217
n.0247
0'<)314
OJ)275
(>.o33R
0.0326
OJl34R
0.0300
0.0300
O.02XX
. O.02R6
0.0245
0.0216
(J.0211)
0.02 \0
n.o II}X
nn 169
0.0172
0.0160
0.0162
n.0141
0.0145
0.0124
OJH40
0.2790
0.0055
0.0105
0.0061
0.0033
0.0026
0.f)061
(W067
0.0040
0.0024
0.0022
.0.0052
O.OOS7
0.<)()33
OJ)()20
(l.OO40
0.0 \09
0.0\21
n.o 164
0.6660
0.0017
0'()O55
0.(>061
0.0096
n.9256
0.0017
n.OO53
OJ)()5R
0.0092
0.X734
nnt II
0.6242
O.I}044
0.X50{)
242
O.X563
X55.5