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Sonam Field Development
Subsurface Basis of Design
CPDEP Phase 3
July 2011
CI:
Major 100ft
Minor 40ft1KM
CI:
Major 100ft
Minor 40ft1KM
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Sonam Development Subsurface Basis of Design
2
Table of Contents
1. Executive Summary ........................................................................................................... 3 2. Geological Overview .......................................................................................................... 4
2.1 Regional Setting ............................................................................................................. 4 2.3 Field Stratigraphy ........................................................................................................... 5 2.4 Summary of Field In-place Volumes ............................................................................. 6
3 Fluid Properties ................................................................................................................... 7 3.1 Condensate Yields.......................................................................................................... 7 3.2 Fluid Sampling and Analysis ......................................................................................... 7 3.3 Dew Point Pressures....................................................................................................... 7 3.4 Fluid Compositions ........................................................................................................ 8 3.5 Sonam Field Rich Gas Compositions over Time ........................................................... 9
4 Field Development Plan .................................................................................................. 10 4.1 Location Coordinates ................................................................................................... 10 4.2 Number of Wells .......................................................................................................... 10 4.3 Initial Well Production Rates ....................................................................................... 11
5 Production Forecasts ...................................................................................................... 12 5.1 Production Forecasts Plots ........................................................................................... 12 5.2 P10, P50 and P90 Gas, Pool Condensate, and Water Forecasts ................................... 13 5.3 Shut-in and Flowing Tubing Pressures ........................................................................ 14 5.4 Downtime Assumptions in Production Forecasts ........................................................ 14
6 Gas Contaminants ............................................................................................................ 15 7 Water Analysis ................................................................................................................... 16 List of Figures Figure 1: Structure map of Sonam Field .................................................................................... 4 Figure 2: F-02, Depositional Model, Fluvial- Dominated Delta ............................................... 5 Figure 3: J-01, Depositional Model, Wave-Dominated Delta ......................................................... 5 Figure 4: Type log of F-02 Sand ................................................................................................. 6 Figure 5: Type log of J-01 Sand ................................................................................................... 6 Figure 6: Sonam Field Rich Gas Profile .................................................................................. 12 Figure 7: Sonam Field Pool Condensate Profile .................................................................... 12 Figure 8: Sonam Field Water Production Profile .......................................................................... 12
List of Tables Table 1: Sonam Rich Gas Hydrocarbon in-place .................................................................... 6 Table 2: Range of Condensate Yield (bbl/MMscf) ................................................................... 7 Table 3: Composition Sonam F-02 and J-02 Subsurface Samples ...................................... 7 Table 4: Component EOS Model Dew Point Pressures (psi) ................................................ 7 Table 5: Initial Reservoir Fluid Compositions ........................................................................... 8 Table 6: Sonam Fluid Compositions over Time ....................................................................... 9 Table 7: Properties of Pseudo Components ..................................................................................... 9 Table 8: Well Count .................................................................................................................... 10 Table 9: Estimated Initial Production Rates ............................................................................ 11 Table 10: Production Forecasts................................................................................................ 13 Table 11: Estimated Pressures and Temperatures ............................................................... 14 Table 12: Downtime Assumptions in Forecasts ............................................................................ 14
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Sonam Development Subsurface Basis of Design
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1. Executive Summary
This Basis of Design document provides information on Sonam field required for the design
and operation of the wells, the Sonam NAG Well Platform and pipeline, and the modification
of the Train 2 slug catcher to handle Sonam liquids while maintaining the Trains rich gas
capacity. Sonam field will be developed to keep the Escravos Gas Plant (EGP) full as the
current supply sources decline.
Sonam Field is located offshore in the Western Niger Delta in OML-91 at a water depth of
about 185 feet. It is about 35 kilometers southwest of the Okan Field. This gas condensate
field consisting of seven gas reservoirs was discovered in 1976 with the drilling of Sonam-01.
Four additional wells have been drilled as part of the field appraisal program.
Produced fluids will be flowed in bulk approximately 53 kilometers through a 20 pipeline from
the Sonam NAG platform to the Escravos Gas Plant (EGP). The Sonam Field wells and
facilities are designed to provide a maximum daily rich gas production rate of 300 MMSCFD.
The production forecasts in this document are based on the P10, P50 & P90 simulation
models built in 2011. The forecasts assume offshore compression will not be installed in
future since there are no current plans to do so.
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Sonam Development Subsurface Basis of Design
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2. Geological Overview
2.1 Regional Setting
Sonam Field is located within the outer trend of a general northwest-southeast oriented Middle to
Late Miocene depo-center in the Western Niger Delta and lies near a large wave-dominated delta
system that has been in place since Eocene time.
Basal Akata marine shales provide the hydrocarbon source for overlaying Agbada shallow marine
sandstone reservoir rocks. Continental to shallow marine sandstones of the Benin Formation
overlay this system.
This rapidly prograding depositional system and accompanying sediment instability resulted in the
creation of syndepositional structure building listric growth faults which were sometimes
accompanied by shale diapirism. Formation of the growth faults created large rollover anticlines
within the Agbada Formation. These rollover anticlines serve as hydrocarbon traps and the listric
growth faults serve as migration pathways.
2.2 Field Structure
Sonam Field consists of two major faults which define the structure and several minor internal
synthetic and antithetic faults. The Sonam field is a relatively simple 3-way dip closure against the
NNW-SSE trending Sonajapa-Orih main fault. In some reservoirs, minor closure to the northeast
is provided by the NW-SE trending Sonam main fault. The minor internal synthetic and antithetic
faults have minimal impact on reserves.
Figure 1: Structure map of Sonam Field
CI:
Major 100ft
Minor 40ft1KM
CI:
Major 100ft
Minor 40ft1KM
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Sonam Development Subsurface Basis of Design
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2.3 Field Stratigraphy
Sonam field displays typical Niger Delta stratigraphy with massive fresh water sands of the Benin
Formation overlaying interbedded paralic sands and shales of the Agbada Formation.
Hydrocarbon-bearing sands in Sonam Field are found within the Agbada Formation between
6900 feet TVDSS and 11350 feet TVDSS.
Stratigraphic variability and diverse depositional environments in Sonam Field reservoirs are
evidenced by well log signatures, core data and seismic event terminations. Whole cores were
taken in the Sonam-04 well from two of the seven Sonam field reservoirs. Depositional analysis
of this whole core indicates the J-01 sand consists of lower shoreface and marine shelf deposits
within a wave-dominated deltaic system and F-02 sands on the other hand are believed to have
been deposited in a fluvial-dominated deltaic environment and consist of marine shelf, lower
shoreface, lower delta front, lower and upper mouth bar and tidal channel.
Figure 2: F-02, Depositional Model, Fluvial- Dominated Delta
Figure 3: J-01, Depositional Model, Wave-Dominated Delta
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Sonam Development Subsurface Basis of Design
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Figure 4: Type log of F-02 Sand
Figure 5: Type log of J-01 Sand
2.4 Summary of Field In-place Volumes
Probabilistic evaluation of original in-place hydrocarbon volumes was conducted for each
of the seven gas-condensate reservoirs in the Sonam Field. Table 1 below shows the
range of original gas in-place volumes determined for the reservoirs
Reservoir P10
(BCF) P50
(BCF) P90
(BCF)
E-01/SO-01 300 400 531
E-05/SO-01 203 296 450
F-02/SO-01 918 1125 1386
G-01/SO-01 4 31 97
G-05/SO-01 478 671 852
J-01/SO-01 189 279 375
J-02/SO-01 265 329 392
Total 2,357 3,131 4,083
Table 1: Sonam Rich Gas Hydrocarbon in-place
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Sonam Development Subsurface Basis of Design
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3 Fluid Properties
3.1 Condensate Yields
Table 2: Range of Condensate Yield (bbl/MMscf)
3.2 Fluid Sampling and Analysis
The table below shows the fluid composition data obtained from the F-02 and J-02 reservoirs. The compositions of the various reservoirs were synthesized from these two compositions using their various yield data (obtained from drill stem tests).
Table 3: Composition Sonam F-02 and J-02 Subsurface Samples
3.3 Dew Point Pressures
Table 4: Component EOS Model Dew Point Pressures (psi)
Sand Low Mid High
E-01 30 42 55E-05 40 45 50F-02 65 73 80G-01 62 76 89G-05 70 77 85J-01 113 125 138J-02 113 125 138
F-02 J-02
Nitrogen 0.26 0.27
Carbon Dioxide 1.32 3.73
Hydrogen Sulfide 0 0
Methane 79.85 71.12
Ethane 5.36 7.02
Propane 4.03 4.84
i-Butane 1.1 1.26
n-Butane 1.51 1.81
i-Pentane 0.73 0.93
n-Pentane 0.57 0.77
Hexanes 0.8 1.21
Heptanes Plus 4.47 7.04
Mole %Component
Sand Dew Point (psi)
E01 3551
E05 3851
F02 4110
G01 4719
G05 5059
J01 5351
J02 5351
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Sonam Development Subsurface Basis of Design
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3.4 Fluid Compositions
The table below shows the initial compositions of the different reservoirs.
Table 5: Initial Reservoir Fluid Compositions
Component E-01(%) E-05 (%) F-02(%) G-01(%) G-05(%) J-01(%) J-02(%)
N2 0.27 0.27 0.26 0.29 0.29 0.27 0.27
CO2 1.34 1.34 1.32 3.84 3.84 3.78 3.78
C1 82.52 82.52 79.85 74.44 74.44 71.29 71.29
C2 5.41 5.41 5.36 7.17 7.17 7.09 7.09
C3 3.88 3.88 4.03 4.68 4.68 4.84 4.84
iC4 0.98 0.98 1.10 1.28 1.28 1.25 1.25
nC4 1.30 1.30 1.51 1.67 1.67 1.71 1.71
iC5 0.58 0.58 0.73 0.89 0.89 0.87 0.87
nC5 0.44 0.44 0.57 0.76 0.76 0.72 0.72
C6 0.56 0.56 0.80 0.60 0.60 1.01 1.01
C7 0.75 0.40 1.34 0.80 0.70 1.21 1.21
PS-1 0.95 1.09 1.63 1.14 1.16 2.63 2.63
PS-2 0.51 0.59 0.81 0.79 0.81 1.49 1.49
PS-3 0.27 0.32 0.40 0.55 0.56 0.85 0.85
PS-4 0.26 0.34 0.29 1.11 1.15 1.00 1.00
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Sonam Development Subsurface Basis of Design
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3.5 Sonam Field Rich Gas Compositions over Time
Year N2 CO2 C1 C2 C3 IC4 NC4 IC5 NC5 C6 C7 PS-1 PS-2 PS-3 PS-4
2017 0.274 2.808 75.776 6.392 4.387 1.143 1.543 0.778 0.638 0.765 0.877 1.73 1.09 0.771 1.028
2018 0.274 2.82 75.806 6.405 4.397 1.145 1.546 0.774 0.633 0.763 0.875 1.727 1.078 0.755 1.002
2019 0.274 2.835 75.914 6.425 4.411 1.148 1.549 0.765 0.624 0.755 0.863 1.704 1.049 0.726 0.957
2020 0.268 2.606 75.593 6.203 4.36 1.133 1.555 0.749 0.757 1.004 1.509 1.911 1.244 0.526 0.582
2021 0.268 2.545 76.129 6.175 4.355 1.13 1.553 0.721 0.72 0.969 1.465 1.818 1.172 0.475 0.506
2022 0.269 2.497 76.708 6.162 4.357 1.129 1.553 0.691 0.675 0.921 1.397 1.705 1.083 0.42 0.433
2023 0.271 2.508 77.123 6.19 4.372 1.134 1.557 0.674 0.634 0.863 1.302 1.592 0.995 0.382 0.405
2024 0.271 2.451 77.646 6.163 4.362 1.131 1.553 0.659 0.595 0.815 1.227 1.5 0.92 0.345 0.364
2025 0.27 2.092 79.028 5.904 4.214 1.089 1.494 0.645 0.557 0.751 1.106 1.352 0.84 0.323 0.334
2026 0.271 2.046 79.446 5.883 4.202 1.085 1.486 0.637 0.521 0.704 1.01 1.288 0.781 0.311 0.327
2027 0.271 2.006 79.82 5.865 4.187 1.08 1.475 0.631 0.493 0.661 0.932 1.222 0.718 0.311 0.33
2028 0.274 2.443 78.379 6.175 4.33 1.131 1.533 0.696 0.546 0.671 0.927 1.31 0.774 0.348 0.463
2029 0.275 2.492 78.61 6.237 4.369 1.138 1.543 0.665 0.501 0.63 0.828 1.251 0.711 0.325 0.427
2030 0.274 2.385 79.104 6.168 4.33 1.124 1.522 0.65 0.479 0.606 0.788 1.193 0.66 0.317 0.4
2031 0.275 2.345 79.401 6.149 4.319 1.119 1.513 0.634 0.458 0.585 0.75 1.148 0.618 0.307 0.379
2032 0.275 2.355 79.514 6.164 4.33 1.121 1.516 0.625 0.444 0.57 0.723 1.121 0.592 0.291 0.36
2033 0.275 2.348 79.629 6.164 4.331 1.121 1.515 0.621 0.435 0.559 0.706 1.101 0.572 0.278 0.345
2034 0.275 2.346 79.693 6.165 4.332 1.121 1.514 0.619 0.429 0.552 0.693 1.092 0.561 0.271 0.337
2035 0.275 2.252 79.961 6.092 4.289 1.11 1.497 0.627 0.433 0.548 0.697 1.076 0.552 0.263 0.329
2036 0.275 2.229 80.078 6.076 4.281 1.108 1.493 0.626 0.429 0.542 0.688 1.062 0.54 0.254 0.32
2037 0.275 2.213 80.163 6.065 4.275 1.106 1.49 0.625 0.425 0.536 0.682 1.052 0.531 0.248 0.313
2038 0.275 2.194 80.247 6.052 4.267 1.104 1.487 0.625 0.423 0.532 0.677 1.042 0.524 0.243 0.309
2039 0.275 2.156 80.379 6.024 4.252 1.1 1.481 0.626 0.421 0.528 0.674 1.031 0.516 0.237 0.301
2040 0.275 2.159 80.395 6.028 4.254 1.1 1.481 0.625 0.419 0.525 0.669 1.027 0.511 0.234 0.298
2041 0.275 2.165 80.392 6.033 4.256 1.101 1.481 0.624 0.418 0.523 0.665 1.024 0.509 0.234 0.299
2042 0.275 2.174 80.389 6.041 4.26 1.102 1.481 0.623 0.417 0.522 0.66 1.021 0.505 0.232 0.298
2043 0.275 2.219 80.273 6.077 4.278 1.106 1.487 0.619 0.416 0.522 0.653 1.025 0.507 0.236 0.305
2044 0.275 2.172 80.426 6.043 4.261 1.101 1.48 0.616 0.412 0.519 0.652 1.016 0.5 0.231 0.295
2045 0.275 2.116 80.624 6.005 4.246 1.094 1.472 0.604 0.399 0.517 0.647 1.01 0.492 0.224 0.273
2046 0.275 2.058 80.826 5.967 4.232 1.087 1.465 0.591 0.386 0.514 0.643 1.004 0.483 0.217 0.251
2047 0.274 1.848 81.577 5.829 4.18 1.062 1.438 0.541 0.335 0.502 0.629 0.979 0.448 0.192 0.167
2048 0.275 1.976 81.3 5.934 4.218 1.072 1.443 0.523 0.345 0.505 0.59 0.958 0.444 0.214 0.201
Table 6: Sonam Fluid Compositions over Time
PS-1 PS-2 PS-3 PS-4
Mole - % 1.73 1.09 0.77 1.03
Critical Temperature F 538 608 786 975
Critical Pressure psig 517 438 243 210
Accentric Factor 0.273 0.345 0.491 0.671
Molecular Weight - lb/lb.mole 115.3 151.3 192.8 270.5
Specific Gravity 0.75 0.79 0.83 0.88
Critical Volume - l/kg.mole 436.9 557.2 775.8 1,114.4
Boiling Point F 202.3 303.4 456.6 643.7
Parachor Volume - l/kg.mole 353.0 442.6 534.9 687.1
OmegaA 0.457236 0.457236 0.457236 0.457236
OmegaB 0.077796 0.077796 0.077796 0.077796
Costald Volume l/kg.mole 0.56867 0.75804 0.96010 1.40103
Costald Accentric Factor 0.45822 0.58458 0.71550 0.91733
Table 7: Properties of Pseudo Components
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Sonam Development Subsurface Basis of Design
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4 Field Development Plan
4.1 Location Coordinates
Northing (Meters)
Easting (Meters)
Water Depth (Feet)
Proposed Platform Location 165640 265728 180
Northing (Meters)
Easting (Meters)
Reentry Plans? (Yes / No)
SO-01 165675 266430 No
SO-02 164914 268834 No
SO-03 163452 267207 No
SO-04 167219 266336 No
SO-04ST 167218 266336 No
4.2 Number of Wells
Seven completions are planned to be on-stream on the project start-up date in 2016 and a
future well planned for about 2030.
Reservoir Field
Start Up
Future
P10 P50 P90
E-01 1 1
E-05 1
F-02 2
G-01 0 1
G-05 1 1 1
J-01 1
J-02 1
Total 7 0 1 2
Table 8: Well Count
This plan will be reevaluated as the field is produced and production data is interpreted.
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Sonam Development Subsurface Basis of Design
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4.3 Initial Well Production Rates
The ranges of initial gas rates from the seven producers are shown in the table below.
Tubing Size
(inches)
Initial Pool Condensate
Yield
(bbls/MMscf)
P10 Initial Gas Rate
(MMscfd)
P50 Initial Gas Rate
(MMscfd)
P90 Initial Gas Rate
(MMscfd)
Erosional Velocity Limit
Rate
(MMscfd)
E-01A 4 42 38 48 54 105
E-05A 4 45 63 67 69 103
F-02A 5 73 88 89 90 103
F-02C 5 73 88 89 90 103
G-05A 5 77 84 93 97 100
J-01A 4 125 41 55 63 86
J-02C 4 125 49 60 65 65
Table 9: Estimated Initial Production Rates
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5 Production Forecasts
5.1 Production Forecasts Plots
Figure 6: Sonam Field Rich Gas Profile
Figure 7: Sonam Field Pool Condensate Profile
Figure 8: Sonam Field Water Production Profile
0
50
100
150
200
250
300
350
2015 2025 2035 2045 2055
Dai
ly G
as R
ate
(MM
scfd
)
P10
P50
P90
0
5,000
10,000
15,000
20,000
25,000
30,000
2015 2025 2035 2045 2055
Dai
ly C
on
de
nsa
te R
ate
(BP
D)
P10
P50
P90
Excludes Plant Condensates
0
1,000
2,000
3,000
4,000
5,000
2015 2025 2035 2045 2055
Dai
ly W
ate
r R
ate
(BW
PD
)
P10
P50
P90
Constrained to EGP Water Handling Capacity
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Page 13
5.2 P10, P50 and P90 Gas, Pool Condensate, and Water Forecasts
P10 P50 P90
Date Gas Rate
(MMscfd)
Pool Condensate
Rate (BCPD)
Water Rate
(BWPD)
Date Gas Rate
(MMscfd)
Pool Condensate
Rate (BCPD)
Water Rate
(BWPD)
Date Gas Rate
(MMscfd)
Pool Condensate
Rate (BCPD)
Water Rate
(BWPD)
1/1/2017 298 18,581 2
1/1/2017 299 23,659 1
1/1/2017 284 23,708 0
1/1/2018 298 22,321 88
1/1/2018 291 22,723 3
1/1/2018 284 23,366 1
1/1/2019 300 19,668 3,400
1/1/2019 285 21,337 7
1/1/2019 284 22,847 3
1/1/2020 300 18,947 3,400
1/1/2020 300 25,368 7
1/1/2020 284 22,071 5
1/1/2021 300 17,368 3,400
1/1/2021 300 23,319 8
1/1/2021 300 26,318 2
1/1/2022 300 15,978 3,400
1/1/2022 300 21,055 9
1/1/2022 300 24,418 2
1/1/2023 270 12,948 3,400
1/1/2023 300 18,982 10
1/1/2023 300 22,598 1,475
1/1/2024 259 12,892 3,400
1/1/2024 300 17,139 12
1/1/2024 300 20,839 1,398
1/1/2025 212 11,037 3,400
1/1/2025 300 14,358 4
1/1/2025 300 19,129 1,342
1/1/2026 199 9,953 3,400
1/1/2026 300 13,013 996
1/1/2026 300 17,534 1,278
1/1/2027 187 8,926 3,400
1/1/2027 300 11,723 929
1/1/2027 300 16,334 604
1/1/2028 164 7,018 3,400
1/1/2028 300 13,841 28
1/1/2028 300 15,151 782
1/1/2029 155 6,346 3,400
1/1/2029 299 12,346 574
1/1/2029 300 13,917 938
1/1/2030 142 5,497 3,400
1/1/2030 300 11,107 608
1/1/2030 300 13,023 8
1/1/2031 130 4,759 3,400
1/1/2031 300 10,084 779
1/1/2031 300 12,047 9
1/1/2032 119 4,153 3,400
1/1/2032 281 8,893 835
1/1/2032 300 12,223 8
1/1/2033 110 3,632 3,400
1/1/2033 261 7,837 873
1/1/2033 299 11,516 8
1/1/2034 101 3,207 3,400
1/1/2034 241 6,999 2,105
1/1/2034 300 10,894 583
1/1/2035 89 2,744 3,402
1/1/2035 214 5,937 3,700
1/1/2035 300 10,162 1,094
1/1/2036 196 5,245 3,700
1/1/2036 300 9,255 1,859
1/1/2037 180 4,648 3,700
1/1/2037 300 8,417 4,000
1/1/2038 164 4,129 3,698
1/1/2038 299 7,300 1,019
1/1/2039 151 3,684 582
1/1/2039 284 6,698 948
1/1/2040 139 3,326 559
1/1/2040 270 6,171 892
1/1/2041 127 3,018 542
1/1/2041 235 5,928 3,092
1/1/2042 115 2,719 537
1/1/2042 221 5,492 3,108
1/1/2043 104 2,475 3,596
1/1/2043 209 5,106 3,232
1/1/2044 94 2,160 640
1/1/2044 198 4,752 2,457
1/1/2045 82 1,821 835
1/1/2045 187 4,444 3,945
1/1/2046 177 4,158 3,614
1/1/2047 165 3,858 3,105
1/1/2048 154 3,578 2,453
1/1/2049 143 3,279 487
1/1/2050 131 3,016 1,955
1/1/2051 121 2,758 1,017
1/1/2052 112 2,576 3,700
1/1/2053 103 2,373 3,630
1/1/2054 94 2,131 335
1/1/2055 85 1,922 305
1/1/2056 73 1,630 1,094
Table 10: Production Forecasts
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Page 14
5.3 Shut-in and Flowing Tubing Pressures
Shut-in Tubing Pressure
(psig)
Flowing Tubing Pressure
(psig)
Flowing Tubing Temperature
(F)
E-01A 2812 2167 177
E-05A 3092 2,600 190
F-02A 3269 2715 200
F-02C 3269 2715 200
G-05A 3,615 2667 225
J-01A 4673 3477 243
J-02C 4670 3458 226
Table 11: Estimated Pressures and Temperatures
5.4 Downtime Assumptions in Production Forecasts
Pessimistic Most Likely Optimistic
Production Efficiency of Sonam / EGP Combined 90% 91% 92%
Delivery Pressure at EGP (psig) 900 900 900
Lean Gas Sales Pipeline Availability till 2020 70% 80% 95%
Lean Gas Sales Pipeline Availability after 2020 95% 95% 95%
Water Handling Limit (BWPD) 3,300 3,700 4,100
Minimum Pipeline Operating Rate (MMscfd) 85 80 75
Table 12: Downtime Assumptions in Forecasts
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Page 15
6 Gas Contaminants
Parameter Units F-02/SO-01 J-02/SO-01
Well N/A Sonam 4 Sonam 4
Date N/A Dec 2002 Dec 2002
Pressure psig 355 418
Temperature F 107 146
Gas Analysis
H2S ppm volume 0.2 4.9
CO2 % volume 1.2 4
RSH (Mercaptan Sulfur) mg/m3 < 0.1 < 0.1
COS (Carbonyl Sulfide) mg/m3 < 0.1 < 0.1
HG mg/m3 0.85 1.06
Arsenic ng/l < 4 < 4
Condensate Analysis
H2S ppm wt 0.2 3.9
RSH ppm wt < 0.1 < 0.1
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Page 16
7 Water Analysis
Sonam #4D Produced Water Analysis
Sample Description: Water collected during DST.
Sampling Point: Sonam #4D
Sample Date: 12-2002
Reservoir: F-02/SO-01
Chloride, (Cl-) ppm 430
"The water chloride concentration is lower than would be expected from formation water; therefore it is
possible that the water collected was condensed water vapor from the production stream and not
produced formation water." Forrest A. Garb & Associates, DST Report
Sonam #4D Produced Water Analysis
Sample Description: Water collected during DST.
Sampling Point: Sonam #4D
Sample Date: 11-2002
Reservoir: J-02/SO-01
Chloride, (Cl-) ppm 290
"The water chloride concentration is lower than would be expected from formation water; therefore it is
possible that the water collected was condensed water vapor from the production stream and not
produced formation water." Forrest A. Garb & Associates, DST Report