sonam bod july 2011_correct(1)

Sonam Field Development

Subsurface Basis of Design

CPDEP Phase 3

July 2011

CI:

Major 100ft

Minor 40ft1KM

CI:

Major 100ft

Minor 40ft1KM

Sonam Development Subsurface Basis of Design

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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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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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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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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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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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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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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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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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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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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)


(MMscfd)


(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

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

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

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

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

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

sonam bod july 2011_correct(1)

Documents

summary of field

field stratigraphy

field development plan

water forecasts

production forecasts

structure map of sonam

production rates

fluid compositions