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PAB4034 FIELD DEVELOPMENT PROJECT (FDP)

GELAMA MERAH, OFFSHORE SABAH

PREPARED BY: GROUP 4

Muhammad Aiman Bin Jamaluddin 10022

Muhamad Ridzuan Bin Shaedin 10210

Izzuddin Bin Jamaludin 9686

Muhammad Hafizzudin Bin Abdul Wahid 11725

Wan Mohd Shafie Bin Wan Ibrahim 11736

Nurul Fathiah Binti Mohammad 11729

Hudzaifah Bin Zol Hamidy 10076

Nurul Syafiqa Binti Abdul Wahab 10062

Zairul Zahha Bin Zabidi 10272

Faridzul Rusyidee Bin Ibrahim 10283

Final Report submitted in partial fulfillment of

the requirements for the

Bachelor of Engineering (Hons)

Petroleum Engineering

JANUARY 2011

Universiti Teknologi PETRONASBandar Seri Iskandar

31750 TronohPerak Darul Ridzuan


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CERTIFICATION OF APPROVAL

GELAMA MERAH, OFFSHORE SABAH

PREPARED BY: GROUP 4

Muhammad Aiman Bin Jamaluddin 10022

Muhamad Ridzuan Bin Shaedin 10210

Izzuddin Bin Jamaludin 9686

Muhammad Hafizzudin Bin Abdul Wahid 11725

Wan Mohd Shafie Bin Wan Ibrahim 11736

Nurul Fathiah Binti Mohammad 11729

Hudzaifah Bin Zol Hamidy 10076

Nurul Syafiqa Binti Abdul Wahab 10062

Zairul Zahha Bin Zabidi 10272

Faridzul Rusyidee Bin Ibrahim 10283

A project dissertation submitted to the

Universiti Teknologi PETRONAS

in partial fulfillment of the requirement for the

Bachelor of Engineering (Hons)

Petroleum Engineering

Approved by,

UNIVERSITI TEKNOLOGI PETRONAS

TRONOH, PERAK

JANUARY 2011

_____________________

(AP DR ISMAIL MSAAID)

FDP Supervisor

_____________________

(ALI FIKRET MANGIALTA‟EE)

FDP Supervisor

_____________________

(AP DR EASWARANPADMANABHAN)

FDP Supervisor


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CERTIFICATION OF ORIGINALITY

This is to certify that we are responsible for the work submitted in this project, that theoriginal work is our own except as specified in the references and acknowledgements, and

that the original work contained herein have not been undertaken or done by unspecified

sources or persons.

_______________________________

MUHAMMAD AIMAN BIN JAMALUDDIN

_________________________________

NURUL FATHIAH BINTI MOHAMMAD

_______________________________MUHAMAD RIDZUAN BIN SHAEDIN

_________________________________HUDZAIFAH BIN ZOL HAMIDY

_______________________________IZZUDDIN BIN JAMALUDIN

_________________________________ NURUL SYAFIQA BINTI ABDUL WAHAB

_______________________________MUHAMMAD HAFIZZUDIN BIN ABDUL

WAHID

_________________________________ZAIRUL ZAHHA BIN ZABIDI

_______________________________WAN MOHD SHAFIE BIN WAN IBRAHIM

_________________________________FARIDZUL RUSYIDEE BIN IBRAHIM


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ACKNOWLEDGEMENT

We would like to express our sincere gratitude and deep appreciation to the following people

for their support, patience and guidance. Without them, this project wouldn‟t have been made

possible. It is to them that we owe our gratitude.

AP Dr Ismail M Saaid, Mr. Ali Fikre t Mangi Alta’ee and AP Dr Eswaran

Padmanabhan for the continuous advice, guidance, constructive criticism and

support to the team. Despite their heavy workload, they spared their precious time to

discuss the project.

Pn Mazli n I dress, FDP Coordinator for her constant assistance, encouragement,

guidance and excellent advice throughout this research project. We also acknowledge

her dedication for inviting lecturers and industry speakers to conduct presentation

which are very helpful in the completion of the project.

Finally, above all, we would also like to thank our family, friends, and Geoscience and

Petroleum Engineering Department lecturers for their unwavering love, support and

assistance throughout the project.


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EXECUTIVE SUMMARY

The objective of this project is to develop the optimum plan for the management of the

natural resources in the Gelama Merah field. Significant reserves of hydrocarbons have been

confirmed in it, by GM-1 and GM-1 ST1 appraisal wells. The estimated Stock Tank Oil

Initially in Place (STOIIP) of Gelama Merah Field is 85.74 MMstb while the estimated Gas

Initially in Place (GIIP) is 111.91 Bscf.

Simulation modeling was carried out using RMS software with different scenarios considered

such as natural depletion, gas and water injection. Reservoir and economic simulations

conclude the best strategy to develop the field is via natural depletion. Six horizontal wells

and one WAG injector well are proposed with maximum recovery factor of 27.8%.

Drilling engineering and well construction of Gelama Merah were performed utilizing data

from GM-1 and GM-1 ST1 appraisal wells and results from reservoir engineering simulation

for drainage plan and reservoir management. A jack-up drilling rig is proposed for the

drilling campaign. All six wells are proposed to be completed as single oil producer with

stand alone wire wrapped screen as a sand control.

Surface development plan is to install jacket platform at Gelama Merah field. It is decided to

tie in the platform into nearby existing infrastructure at Semarang Central Processing Plant

(CPP) which is both technically and economically viable.

The development strategies have been evaluated in terms of Internal Rate Return (IRR) and

Net Present Value (NPV). The CAPEX is about 165.69 Mil USD and the OPEX is estimatedabout 3.909 Mil USD/year. The calculated NPV at 10% is 55.78 MM USD with IRR at 37%;

the breakeven is estimated in 3.7 years from the first year of production.


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Table of Contents

ACKNOWLEDGEMENT ..................................................................................................... iii

EXECUTIVE SUMMARY .................................................................................................... iv

ABBREVIATIONS ................................................................................................................ xv

NOMENCLATURES .......................................................................................................... xvii

Chapter 1 : INTRODUCTION ........................................................................................... 1

1.1 Background of Project ................................................................................................. 1

1.2 Problem Statement ...................................................................................................... 2

1.3 Objectives .................................................................................................................... 3

1.4 Scope of Work ............................................................................................................. 3

1.5 Gantt Chart .................................................................................................................. 4

1.6 Project Team ............................................................................................................... 5

Chapter 2 : DATA INVENTORY AND QUALITY CONTROL .................................... 7

2.1 Introduction ................................................................................................................. 7

2.2 Workflow .................................................................................................................... 7

2.2.1 Data Acquisition and Sorting ............................................................................... 7

2.2.2 Data Checklist and Inventory Setup .................................................................... 8

2.2.3 Data Digitizing ..................................................................................................... 9

2.2.4 Data Quality Check ............................................................................................ 10

Chapter 3 : GEOLOGY & GEOPHYSICS ..................................................................... 12

3.1 2-Dimensional Cross Imaging ................................................................................... 12

3.2 Stratigraphic Correlation ........................................................................................... 18

3.3 Regional Setting ........................................................................................................ 21 3.4 Hydrocarbon Petroleum System ............................................................................... 23

3.5 Depositional Environment and Facies Analysis........................................................ 25

3.6 3-Dimensional (3D) Static Model (Roxar‟s IRAP RMS) ......................................... 29

3.6.1 General Description ........................................................................................... 29

3.6.2 Surface Contour Map Digitizing ........................................................................ 30

3.6.3 Import Well Data ............................................................................................... 31

3.6.4 Horizon Modeling .............................................................................................. 31

3.6.5 Petrophysical Modelling .................................................................................... 31 3.7 Volumetric Calculation ............................................................................................. 32


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3.7.1 Reservoir Evaluation .......................................................................................... 32

3.7.2 Gross Rock Volume ........................................................................................... 32

3.7.3 Volumetric Estimation Approach ...................................................................... 36

3.7.4 Hydrocarbon in Place (HIP) Calculation ........................................................... 36

3.7.5 Hydrocarbon Contribution ................................................................................. 39

3.7.6 Static Model Volumetric Estimation ................................................................. 40

3.7.7 Hydrocarbon in Place by Static Model .............................................................. 41

3.8 Risk Analysis and Uncertainties ............................................................................... 42

3.8.1 2-Dimensional Cross Imaging ........................................................................... 42

3.8.2 Stratigraphic Correlation .................................................................................... 44

3.8.3 Volumetric Estimation Approach ...................................................................... 46

3.9 Summary ................................................................................................................... 46

Chapter 4 : PETROPHYSICS .......................................................................................... 47

4.1 Introduction ............................................................................................................... 47

4.2 Data Availability ....................................................................................................... 47

4.3 Quality Check (QC) For Log Data ............................................................................ 47

4.4 Petrophysical Evaluation ........................................................................................... 49

4.4.1 Lithology Study ................................................................................................. 49

4.4.2 Interpretation of Log Data ................................................................................. 51

4.4.3 Identification of Permeable and Non-Permeable Zones .................................... 53

4.4.4 Determination of the water and hydrocarbon bearing zones ............................. 54

4.5 Fluid Types ................................................................................................................ 56

4.6 Shale Volume () ................................................................................................. 57 4.7 Porosity (φ) ............................................................................................................... 58

4.7.1 Effect of Shale on Porosity Determination from Density Log .......................... 58

4.7.2 Effect of Shale on Porosity Determination from Neutron Log .......................... 59

4.7.3 Effective Porosity Calculation ........................................................................... 60

4.8 Water Saturation ()............................................................................................... 60 4.9 The Cut-off Values .................................................................................................... 62

4.10 Net to Gross Ration (NTG) ................................................................................... 63

Chapter 5 : RESERVOIR ENGINEERING ................................................................... 64

5.1 Introduction ............................................................................................................... 64

5.2 Reservoir Data and Analyses .................................................................................... 65

5.2.1 Reservoir Pressure and Fluid Contacts .............................................................. 65

5.2.2 Reservoir Temperature....................................................................................... 66


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5.2.3 Reservoir Fluid Studies ...................................................................................... 67

5.2.4 Reservoir Fluid Study (PVT) Using PVTi Software ......................................... 74

5.2.5 Rock Compressibility......................................................................................... 77

5.2.6 Routine Core and Special Core Analysis (SCAL) ............................................. 79

5.3 Reservoir Simulation Study ...................................................................................... 93

5.3.1 Preliminary Studies of Reservoir Drive Mechanisms ........................................ 94

5.3.2 3D Geological Static Model Export ................................................................... 98

5.3.3 Simulator Data Input .......................................................................................... 99

5.3.4 Dynamic Initialization ..................................................................................... 100

5.3.5 Sensitivity Analysis ......................................................................................... 102

5.4 Enhanced Oil Recovery (EOR) ............................................................................... 115

5.5 Reservoir Surveillance ............................................................................................ 120

5.6 Uncertainty Analysis ............................................................................................... 121

Chapter 6 : PRODUCTION TECHNOLOGY .............................................................. 123

6.1 Introduction ............................................................................................................. 123

6.2 Nodal Analysis ........................................................................................................ 123

6.3 Inflow Performance Relationship (IPR) and PVT Correlation ............................... 124

6.3.1 Inflow Performance Prediction ........................................................................ 124

6.3.2 Outflow Performance Prediction ..................................................................... 125

6.4 Tubing Size ............................................................................................................. 127

6.5 Artificial Lift ........................................................................................................... 127

6.5.1 Gas Lift Method Justifications ......................................................................... 127

6.5.2 Gas Lift Design ................................................................................................ 129

6.6 Sand Control ............................................................................................................ 132

6.6.1 Sand Control Design ........................................................................................ 133

6.7 Well Completion Design ......................................................................................... 136

6.7.1 Summary .......................................................................................................... 136

6.7.2 Well Completion Matrix .................................................................................. 136

6.7.3 Completion string Design and Accessories ..................................................... 137

6.7.4 Wellhead and Christmas tree ........................................................................... 139

6.7.5 Material Selection ............................................................................................ 140

6.7.6 Packer and Completion Fluid........................................................................... 140

6.8 Potential Production Problem.................................................................................. 141

6.8.1 Wax Deposition ............................................................................................... 141

6.8.2 Corrosion.......................................................................................................... 141

6.8.3 Scale Formation ............................................................................................... 141


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6.8.4 Emulsion formation ......................................................................................... 142

Chapter 7 : DRILLING ENGINEERING ..................................................................... 143

7.1 Introduction ............................................................................................................. 143

7.2 Drilling History ....................................................................................................... 143

7.3 Platform Location .................................................................................................... 143

7.4 Design Framework .................................................................................................. 143

7.5 Rig Selection ........................................................................................................... 144

7.6 Subsurface Environment ......................................................................................... 145

7.7 Potential Drilling Problem ...................................................................................... 145

7.8 Planning Well Profile (Well Trajectory) ................................................................. 146

7.8.1 Parameters of Well Path................................................................................... 147

7.8.2 Well Type......................................................................................................... 147

7.9 Casing Design ......................................................................................................... 148

7.9.1 Casing Configuration ....................................................................................... 148

7.9.2 Casing Setting Depth ....................................................................................... 150

7.10 Drilling Fluids and Cementing Design ................................................................ 151

7.10.1 Drilling Fluids Design...................................................................................... 151

7.10.2 Cementing Design ............................................................................................ 152

7.11 Bit Selection ........................................................................................................ 154

7.12 Well Control ........................................................................................................ 154

7.12.1 Blow Out Preventer (BOP) .............................................................................. 154

7.12.2 Actuator / SSV ................................................................................................. 154

7.12.3 Wellhead .......................................................................................................... 155

7.13 Drilling Time and Cost Estimation ...................................................................... 155

7.14 Drilling Optimization .......................................................................................... 158

7.14.1 Monobore Completion ..................................................................................... 158

7.14.2 Casing While Drilling (CWD) ......................................................................... 158

7.14.3 Multilateral Completion ................................................................................... 158

7.14.4 Rotary Steerable System (RSS) ....................................................................... 159

7.14.5 Pile Driven Conductor ..................................................................................... 159

7.14.6 Cement Assessment Tool (CAT) ..................................................................... 159

Chapter 8 : FACILITIES ENGINEERING .................................................................. 160

8.1 Introduction ............................................................................................................. 160

8.1.1 Overview of Facilities ...................................................................................... 160

8.1.2 Design Philosophy ........................................................................................... 160


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8.1.3 Types of Development Platform Option .......................................................... 161

8.2 Design Features and Basis....................................................................................... 162

8.2.1 Facilities Design Concept ................................................................................ 162

8.2.2 Top Structure ................................................................................................... 163

8.2.3 Substructure ..................................................................................................... 163

8.3 Operation Facilities and Equipments ...................................................................... 164

8.3.1 Production Flowlines, Flow Control and Manifold ......................................... 164

8.3.2 Wellhead .......................................................................................................... 164

8.3.3 Gas Metering and Measurement ...................................................................... 164

8.3.4 3-Phase Separator............................................................................................. 165

8.3.5 Gas Injection .................................................................................................... 165

8.3.6 Gas Lift Surfaces Facilities .............................................................................. 165

8.3.7 Electrical Power and Lighting ......................................................................... 165

8.3.8 Drain System .................................................................................................... 165

8.3.9 Flare Boom / Vent System ............................................................................... 166

8.3.10 Instrument Air System ..................................................................................... 166

8.4 Safety Facilities System .......................................................................................... 166

8.4.1 Safety Shutdown System ................................................................................. 166

8.4.2 Automatic Fire Detection and Alarm System .................................................. 167

8.4.3 Life Saving Appliances .................................................................................... 168

8.4.4 Platform Data and Communication System ..................................................... 168

8.5 Pipelines and Host Tie-Ins to Existing Platform ..................................................... 168

8.5.1 Pipeline Tie-Ins ................................................................................................ 168

8.5.2 Pipeline Optimum Sizing using PIPESim ....................................................... 169

8.5.3 Wax Mitigation ................................................................................................ 175

8.5.4 Slug Suppression System (Sss) ........................................................................ 176

8.6 Pipeline Corrosion Management ............................................................................. 176

8.6.1 Corrosion Inhibitor Injection ........................................................................... 176

8.6.2 Corrosion Allowance ....................................................................................... 176

8.6.3 Pipeline Pigging ............................................................................................... 177

8.6.4 Corrosion Monitoring ...................................................................................... 177

8.7 Operation and Maintenance .................................................................................... 178

8.7.1 Operations ........................................................................................................ 178

8.7.2 Operating Philosophy....................................................................................... 178

8.7.3 Pipeline Operation Philosophy ........................................................................ 179

8.7.4

Process Control ................................................................................................ 179

8.7.5 Pigging ............................................................................................................. 179


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8.7.6 Maintenance Philosophy .................................................................................. 179

8.8 Abandonment .......................................................................................................... 180

8.9 Facilities CAPEX, Decommission and OPEX ........................................................ 180

8.9.1 Capital Expenditure (CAPEX) ......................................................................... 180

8.9.2 Decommissioning Cost .................................................................................... 181

8.9.3 Operating Expenditure (OPEX) ....................................................................... 182

Chapter 9 : ECONOMIC ANALYSES .......................................................................... 184

9.1 Introduction and Objective ...................................................................................... 184

9.2 Development Options and Total Expenditures ....................................................... 185

9.3 Fiscal Terms ............................................................................................................ 187

9.4 Economic Assumptions ........................................................................................... 188

9.5 Economic Analysis and Results .............................................................................. 189

9.5.1 Net Cash Flow Profile ...................................................................................... 190

9.5.2 Sensitivity Analysis ......................................................................................... 191

9.6 Discussion and Recommendation ........................................................................... 193

Chapter 10 : HEALTH, SAFETY & ENVIRONMENT ................................................ 195

10.1 HSE Management Policy..................................................................................... 195

10.2 Risk Acceptance Criteria ..................................................................................... 195

10.3 Project HSE Objectives and Program .................................................................. 195 10.4 HSE Hold Points .................................................................................................. 196

10.5 Safety Awareness ................................................................................................ 197

10.6 Emergency Response Plan (ERP) ........................................................................ 197

10.7 Environment Concerns ........................................................................................ 197

10.7.1 Drilling Waste .................................................................................................. 197

10.7.2 Produced Water ................................................................................................ 198

10.7.3 Associated Waste ............................................................................................. 198

10.7.4 Gas Venting and Flaring .................................................................................. 198

10.8 Safety System ...................................................................................................... 199

10.8.1 Safety Shutdown System ................................................................................. 199

10.8.2 Flare and Emergency Relief System ................................................................ 199

10.8.3 Ventilation........................................................................................................ 200

10.9 Transportation ...................................................................................................... 200

10.10 HSE for Abandonment ........................................................................................ 201

Chapter 11 : FUTURE PLANS ......................................................................................... 203

11.1 Introduction ......................................................................................................... 203


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11.2 Geology ............................................................................................................... 203

11.3 Reserves ............................................................................................................... 204

11.4 Reservoir Engineering ......................................................................................... 204

11.5 Drilling Engineering ............................................................................................ 204

11.6 Production Engineering ....................................................................................... 205

11.7 Facilities Engineering .......................................................................................... 205

11.8 Economic and HSE .............................................................................................. 205

11.9 CO₂ Sequestration................................................................................................ 205

11.9.1 Character of Underground Structure and Rock Layers Desired ...................... 206

11.9.2 Geologic Site Characterization ........................................................................ 207

11.9.3 Costing Methodology....................................................................................... 207

11.9.4 Monitoring ....................................................................................................... 208

11.9.5 Monitoring ....................................................................................................... 209

11.9.6 Raw Cost Estimation........................................................................................ 209

11.10 Conclusion ........................................................................................................... 210

Chapter 12 : REFERENCES ............................................................................................ 211

Appendix A Geology and Geophysics ........................................................................ 212

Appendix B Petrophysics ............................................................................................ 213

Appendix C Reservoir Engineering............................................................................ 216

Appendix D Production Technology .......................................................................... 225

Appendix E Drilling Engineering ............................................................................... 234

E.1 Well Profiles and Trajectories for Six Horizontal Wells ........................................ 234

E.2 Pressure Plot and Casing Setting Depth for the Proposed Wells ............................ 238

E.3 Casing Design Configuration for the Proposed Wells ............................................ 240

E.4 Cementing Calculations .......................................................................................... 251

E.5 Drilling Time and Cost Estimation ......................................................................... 258

Appendix F Facilities Engineering ............................................................................. 260


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List of Figures

Figure 1.1 - Location of the Block 6S-18 .................................................................................. 1

Figure 1.2 - The work schedule of Gelama Merah Field Development Project ........................ 4

Figure 1.3 – Organization chart of Group 4 ............................................................................... 6

Figure 2.1 - Workflow ............................................................................................................... 7

Figure 3.1 - Surface map for Unit U3.2 ................................................................................... 12

Figure 3.2 - Possible geological features ................................................................................. 13

Figure 3.3 - Spreadsheet of horizontal cross section for Gelama Merah 1 and ST-1 .............. 15

Figure 3.4 - OWC and GOC determination using pressure gradient plot ................................ 16

Figure 3.5 - 3-Dimensional (3-D) Static Model....................................................................... 17

Figure 3.6 - The anticline structure with eroded surfaces (unconformity) structure ............... 18

Figure 3.7 - Well top correlations using Gamma ray log for GM-1 and GM-1 ST1 ............... 19

Figure 3.8 - Stratigraphic correlation for GM-1 and GM-1 ST1 ............................................. 20

Figure 3.9 - Regional aerial view of Gelama Merah field ....................................................... 21

Figure 3.10 - Regional location of Northern and Southern Inboard Belt with major anticline

and syncline structure .............................................................................................................. 22

Figure 3.11 - Regional cross-section of Southern Inboard Belt............................................... 23

Figure 3.12 - Gelama Merah depositional environment model ............................................... 25

Figure 3.13 - Sand deposition is from high energy storm generated breaker bar at upper shore

face on top, moderate energy lower shoreface at middle and low energy environment at base

sand shows trending coarsening upward sequence .................................................................. 26

Figure 3.14 - Depositional environment is shallow marine with wave influence of lower

coastal plain – high stand, prograding delta to coastal sediment. ............................................ 28

Figure 3.15 - Procedures in developing Gelama Merah static model ...................................... 30

Figure 3.16 - Digitized contour points and 3D contour map ................................................... 30

Figure 3.17 - Well picks and 3D contour map ......................................................................... 31

Figure 3.18 - Area calculated by planimeter and grid square counting ................................... 33

Figure 3.19 - Summary Results of Simulation......................................................................... 38

Figure 3.20 - OIIP contribution for each sand unit .................................................................. 39

Figure 3.21 - GIIP contribution for each sand unit .................................................................. 39

Figure 3.22 - Anticline structure with eroded surfaces (unconformity) structure and fault .... 42

Figure 3.23 - Anticline structure .............................................................................................. 43 Figure 3.24 - Stratigraphic correlation for heavily faulted formation ..................................... 44

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Figure 3.25 - Stratigraphic correlation for sand pocket existence ........................................... 45

Figure 4.1 - Caliper log ............................................................................................................ 48

Figure 4.2 - Highest average value of gamma ray log ............................................................. 53

Figure 4.3 - Lowest average value of gamma ray log.............................................................. 53

Figure 4.4 - The identified permeable and non-permeable zones ............................................ 54

Figure 4.5 - Water and hydrocarbon bearing zone identification using resistivity log and

porosity log for GM-1 .............................................................................................................. 55

Figure 4.6 - Water and hydrocarbon bearing zone identification using resistivity log and

porosity log for GM-1 ST1 ...................................................................................................... 55

Figure 4.7 - Pressure plot for Gelama Merah-1 ....................................................................... 56

Figure 4.8 - Sand and shale distribution from the log.............................................................. 58

Figure 4.9 - The porosity cut off for Gelama Merah field ....................................................... 62

Figure 5.1 - Gelama Merah field pressure data from Gelama Merah-1 well ........................... 65

Figure 5.2 - Gelama Merah field temperature data from Gelama Merah-1 well ..................... 66

Figure 5.3 - Phase plot for Gelama Merah ST-1 DST#1 generated by EOS ........................... 74

Figure 5.4 - PVT matching ...................................................................................................... 76

Figure 5.5 - Rock compressibility measurements from eight core samples ............................ 78

Figure 5.6 - Porosity-Permeability Model ............................................................................... 81

Figure 5.7 - Capillary pressure curve classification based on J-function vs Swnormalized .... 86

Figure 5.8 - Normalized relative permeability curve for gas-oil and oil-water ....................... 90

Figure 5.9 - Corey fitted curve with de-normalized curve for Oil-Water System ................... 91

Figure 5.10 - End-points correlation with porosity and permeability ...................................... 92

Figure 5.11 - Drive mechanism of Gelama Merah .................................................................. 96

Figure 5.12 - Cumulative production without aquifer support. ............................................... 97

Figure 5.13 - Cumulative oil Production (MM stb) and Oil Recovery Factor ........................ 98

Figure 5.14 - Porosity Distribution of Gelama Merah reservoir model ................................... 99

Figure 5.15 - Simulation results showing different well types (Horizontal and Vertical)

against well counts ................................................................................................................. 104

Figure 5.16 - Simulation results showing optimized performance between vertical and

horizontal wells ...................................................................................................................... 106

Figure 5.17 - Simulation results showing optimized performance for limiting liquid and gas

rate production ....................................................................................................................... 107

Figure 5.18 - Simulation results of production profile, pressure decline and water cut for

water injector to the aquifer, oil zone, and gas cap ................................................................ 109

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Figure 5.19 - Simulation results of production profile for gas injector to the aquifer, oil zone,

and gas cap ............................................................................................................................. 110

Figure 5.20 - Simulation results of pressure decline and water cut for gas injector to the

aquifer, oil zone, and gas cap ................................................................................................. 111

Figure 5.21 - Simulation results of WAG production profile, pressure decline and water cut

................................................................................................................................................ 113

Figure 6.1 - Horizontal data for GM-A .................................................................................. 125

Figure 6.2 - Gas lift valves design by simulation .................................................................. 129

Figure 6.3 - Depth vs. sonic transit time for Gelama Merah-1 .............................................. 133

Figure 7.1 - Casing configuration for GM-A ......................................................................... 149

Figure 7.2 - Gelama Merah drilling and completion cost vs. time ........................................ 157

Figure 8.1 - Types of platform used in field development .................................................... 161

Figure 8.2 - Tie-in from GMJT-A to SMP-B diagram .......................................................... 169

Figure 9.1 - Production profile for Gelama Merah ................................................................ 185

Figure 9.2 Fiscal structure of Gelama Merah field ................................................................ 188

Figure 9.3 Net cash flow for Gelama Merah with decommissioning in year 2031 (graph

changed) ................................................................................................................................. 190

Figure 9.4 Spider plot for NPV @ 10% ................................................................................. 191

Figure 9.5 Spider plot for IRR ............................................................................................... 192

Figure 11.1 - The geological structure of Gelama Merah ...................................................... 203

Figure 11.2 - GIIP contribution for each sand unit ................................................................ 204

Figure A.1 - Cumulative probability of the total STOIIP for sand unit 5.0 to 9.2................. 212

Figure A.2 - Cumulative probability of the total GIIP for sand unit 5.0 to 9.2 ..................... 212

Figure B.1 - Non-corrected Neutron-Density crossplot ......................................................... 213

Figure B.2 - Corrected Neutron-Density crossplot ................................................................ 214

Figure B.3 - M-N crossplot .................................................................................................... 215

Figure C.1 - Sand pocket structure ........................................................................................ 216

Figure C.2 - Fault structure .................................................................................................... 217

Figure C.3 - PVTi output for dynamic model; PVTO – live oil with dissolved gas ............. 217

Figure C.4 - PVTi output for dynamic model; PVDG – dry gas ........................................... 218

Figure C.5 - Un-normalized gas-oil relative Permeability Curve .......................................... 219

Figure C.6 - Normalized gas oil Relative permeability curve .............................................. 220

Figure C.7 - Sand Facies type 1 – Gas Oil Relative Permeability Curve .............................. 221 Figure C.8 - Sand Facies Type 2: Gas Oil Relative Permeability curve................................ 222


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Figure D.1 - IPR matching for vertical well, Gelama Merah Well Test ................................ 225

Figure D.2 - IPR for horizontal GM-A .................................................................................. 225

Figure D.3 - Tubing performance at different wellhead pressure .......................................... 226

Figure D.4 - Tubing performance with increasing water cut @ WHP of 390 psi ................. 226

Figure D.5 - Tubing performance with varying GOR ........................................................... 227

Figure D.6 - Tubing performance with pressure depletion .................................................... 227

Figure D.7 - Gas lift design for GM-A .................................................................................. 228

Figure D.8 - Tubing performance at different wellhead pressure with GLI .......................... 228

Figure D.9 - Tubing performance with increasing water cut @ WHP of 390 psi with GLI . 229

Figure D.10 - Tubing performance with varying GOR with GLI .......................................... 229

Figure D.11 - Tubing performance with pressure depletion with GLI .................................. 230

Figure D.12 - Kawasaki and Sumitomo materials selection process ..................................... 231

Figure D.13 - Typical horizontal completion configuration for oil producers ...................... 232

Figure D.14 - Typical vertical completion configuration for WAG injector ......................... 233

Figure E.1 - Plan view for six horizontal wells ..................................................................... 234

Figure E.2 - Well trajectory for GM-A .................................................................................. 235

Figure E.3 - Well trajectory for GM-B .................................................................................. 235

Figure E.4 - Well trajectory for GM-C .................................................................................. 236

Figure E.5 - Well trajectory for GM-D .................................................................................. 236

Figure E.6 - Well trajectory for GM-E .................................................................................. 237

Figure E.7 - Well trajectory for GM-F................................................................................... 237

Figure E.8 - Casing setting depth ........................................................................................... 239

Figure E.9 - Time-depth curve ............................................................................................... 258

Figure F.1 - Pipeline Sizing using PIPESim .......................................................................... 260

Figure F.2 - Option 1: A production platform tie-in to the nearby Samarang Mother Platform-

B (SMP-B) Central Processing Platform (CPP) .................................................................... 260

Figure F.3 - A production platform tie-in directly to Labuan Crude Oil Terminal (LCOT) . 261

Figure F.4 - Production using floating, production, storage and offloading (FPSO) ............ 261


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List of Tables

Table 2.1 - Data Checklist ......................................................................................................... 8

Table 3.1 - Measured area using planimeter and grid square counting for gas zone ............... 34

Table 3.2 - Measured area using planimeter and grid square counting for oil zone ................ 35

Table 3.3 - Minimum, median and maximum values of N/G, porosity, So and Bo ................ 37

Table 3.4 - Minimum, median and maximum values of N/G, porosity, Sg and Bg ................ 37

Table 3.5 - Total OIIP and GIIP .............................................................................................. 37

Table 3.6 - Sum of OIIP and GIIP ........................................................................................... 41

Table 4.1 - Recorded depth from log and well report .............................................................. 48

Table 4.2 - Recorded hole and casing size ............................................................................... 48

Table 4.3 - Summary of fluid contact ...................................................................................... 56

Table 4.4 - Average volume of shale in each sand unit ........................................................... 57

Table 4.5 - Average porosity for each sand unit ...................................................................... 60

Table 5.1 - Quality check of separator samples ....................................................................... 68

Table 5.2 - Compositional analysis of stock tank oil, stock tank gas and calculated wellstream

composition (adjusted bubble point pressure to 2014 Psig) .................................................... 69

Table 5.3 - Constant composition expansion test results at 155°F .......................................... 70 Table 5.4 - Differential vaporization test at 155°F* ................................................................ 72

Table 5.5 - Oil and gas viscosity @ 155°F .............................................................................. 73

Table 5.6 - Components grouping for regression .................................................................... 75

Table 5.7 - Rock compressibility correlations ......................................................................... 78

Table 5.8 - Porosity and permeability according to core sample ............................................. 81

Table 5.9 - Rock Facies Classification .................................................................................... 81

Table 5.10 - Laboratory-reservoir fluid properties for capillary conversion ........................... 82

Table 5.11 - Core sample 1-01 properties ................................................................................ 84

Table 5.12 - Injected mercury pressure with respect to saturation .......................................... 84

Table 5.13 - Capillary Pressure classification according to sand facies .................................. 86

Table 5.14 - Core samples for relative permeability curve measurements .............................. 87

Table 5.15 - Relative Permeability Measurement.................................................................... 89

Table 5.16 - R-Squared error for end-points correlations ........................................................ 93

Table 5.17 - Base case results simulation .............................................................................. 103

Table 5.18 - Simulation results for Water Injection scheme ................................................. 109


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Table 5.19 - Simulation results for VRR = 1 sensitivity analyses ......................................... 112

Table 5.20 - Recovery factor comparison for different geological model ............................. 115

Table 5.21 - Screening criteria for EOR ................................................................................ 118

Table 5.22 - CO2 technical screening guides ........................................................................ 119

Table 5.23 - CO2-miscible/immiscible flooding ................................................................... 119

Table 6.1 - Tubing performance at different wellhead pressure (0% water cut) ................... 125

Table 6.2 - Tubing performance with increasing water cut @ WHP of 390 psi ................... 126

Table 6.3 - Tubing performance with varying GOR.............................................................. 126

Table 6.4 - Tubing performance with pressure depletion ...................................................... 126

Table 6.5 - ESP and gas lift comparisons .............................................................................. 127

Table 6.6 - Production profile natural flow vs. gas lift injection (WHP) .............................. 130

Table 6.7 - Production profile natural flow vs. gas lift injection (water cut) ........................ 130

Table 6.8 - Production profile natural flow vs. gas lift injection (GOR) ............................... 131

Table 6.9 - Production profile natural flow vs. gas lift injection (reservoir pressure depletion)

................................................................................................................................................ 131

Table 6.10 - Comparison of different options available for sand exclusion .......................... 135

Table 6.11 - Well completion matrix ..................................................................................... 137

Table 6.12 - Basic data for material selection ........................................................................ 140

Table 7.1 - Water depth and average daily rate for several types of MODUs (Source:

www.rigzone.com) ................................................................................................................. 144

Table 7.2 - Well profiles ........................................................................................................ 147

Table 7.3 - Well survey and logging ...................................................................................... 148

Table 7.4 - PCSB casing design safety factors ...................................................................... 148

Table 7.5 - Casing design configuration for the seven proposed wells ................................. 149

Table 7.6 - PCSB standard drilling fluid system ................................................................... 152

Table 7.7 - Drilling fluid properties ....................................................................................... 152

Table 7.8 - Required cement volume ..................................................................................... 153

Table 7.9 - BOP standard (surface stack) .............................................................................. 154

Table 7.10 - Drilling time and cost summary ........................................................................ 156

Table 8.1 - Production forecast for Gelama Merah ............................................................... 162

Table 8.2 - Reservoir fluid properties for Gelama Merah ..................................................... 163

Table 8.3 - CAPEX for jacket facilities for Gelama Merah .................................................. 181

Table 8.4 - Comparison of CAPEX for different options ...................................................... 182

Table 8.5 - Operating cost for Gelama Merah platform ........................................................ 182


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Table 9.1 - Proposed Gelama Merah production scenario ..................................................... 184

Table 9.2 - Summary of development costs........................................................................... 186

Table 9.3 - Fiscal terms for PSC 1985 ................................................................................... 187

Table 9.4 Sensitivity manipulation (+/- 40%) results for four main parameters (USD million)

................................................................................................................................................ 192

Table 9.5 summary of economic analysis of Gelama Merah field ........................................ 193

Table 10.1 - Risk comparison between installation and decommissioning process .............. 201

Table C.1 - Summary of case studies..................................................................................... 223

Table C.2 - Case study for WAG ........................................................................................... 224

Table D.1 - Advantages and disadvantages of cased hole and open hole completion........... 230

Table E.1 - Prognosed formation pressure and plan mud weight .......................................... 238

Table E.2 - Drilling Days ....................................................................................................... 258

Table E.3 - Drilling cost......................................................................................................... 259


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ABBREVIATIONS

API American Petroleum InstituteASP alkaline surfactant polymer

BHP bottom hole pressure

BOP blowout preventer

BUR build up rate

CAPEX capital expenditure

CCE constant composition expension

CPP central processing platform

CWD casing while drilling

DLL Deep lateral logDST Drill stem test

DV differential vaporization test

EMW equivalent mud weight

EOR enhanced oil recovery

EUR expected ultimate recovery

FBU flowing and build up

FPSO floating, production, storage and offloading vessel

FSO floating, storage and offloading vessel

GIIP gas initial in place

GOC gas oil contact

GOR gas oil ratio

GR gamma ray

GRV gross rock volume

HSE health, safety and environment

HTGC high temperature gas chromatography

ID inner diameter

IFT interfacial tension

IPR inflow performance relationship

KCl potassium chlorideKOP kick off point

LCOT Labuan Crude Oil Terminal

LWD logging while drilling

MD measured depth

MDT modular formation dynamic tester

MLL Micro lateral log

MOPU mobile offshore production unit

MWD measurement while drilling

NGA natural gas analyzerOBM oil based mud


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OD outer diameter

OIIP oil initial in place

OPEX operating expenditure

PDC polycrystalline diamond compact

PDO PETRONAS Procedures for Drilling OperationPHPA partially hydrolysed polyacrylamide

PRSS PETRONAS Research & Scientific Services Sdn. Bhd.

PTS PETRONAS Technical Standard

PV pore volume

PVT pressure, volume and temperature

QC quality check

RF recovery factor

RFT repeat formation tester

SBM synthetic based mud

SCAL special core analysis

STOIIP stock tank oil in place

TAPR tender assisted platform

THP tubing head pressure

TOL top of lead

TOT top of tail

TVD true vertical depth

TVDRKB true vertical depth rotary kelly busher

UBD underbalance drilling

VRR voidage replacement rateWAG water alternating gas

WOC water oil contact

WWR wire wrapped screens


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NOMENCLATURES

ρ b bulk density (g/cc)

ϕd density porosityϕeff effective porosity

ϕn neutron porosity (v/v)

VSH shale volume

Swirr irreducible water saturation

R w water saturation

m cementation factor

n saturation factor

R t true resistivity

Vclay clay volumePcr capillary pressure in reservoir condition

Pcl capillary pressure in laboratory condition

σr interfacial tension in reservoir system (dyne/cm)

σl interfacial tension in laboratory system (dyne/cm)

Swn normalized drainage water saturation

Swc connate water saturation


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Chapter 1 : INTRODUCTION

1.1 Background of Project

Gelama Merah is located in Sub-Block 6S-18 of Sabah Basin at the North-West region. This

field is located at Latitude: 050 33‟ 49.98”N and Longitude: 1140 59‟ 06.34”E which is

approximately 10.5 km East to Semarang field. Gelama Merah is operated by PETRONAS

Carigali Sdn Bhd. Two exploration wells had been drilled in Gelama Merah structure which

is GM-1 and GM 1ST-1 to collect geological, petrophysical and reservoir data for the field

development. The water depth is 42.8 meter (from the mean sea level to the sea bed).

The depositional environment was interpreted as Shallow Marine Lower Coastal Plain to

Coastal Plain with average porosity of 20-30%. The target reservoir is below Stage IVC

Middle Miocene Unconformity to the top of 9.3 unit sand. The depositional is from South-

East to North-West and the age is Middle Miocene. The source rock in this region is vicinity

with large N-trending Labuan – Paisley Syncline.

Figure 1.1 - Location of the Block 6S-18


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1.2 Problem Statement

The Gelama Merah field was discovered in 2002. There are two exploration wells that

provide the information about the field. With the time constraint, limited data and largenumber of uncertainties, the determination of the best field development plan has been

considered a challenging task. Further information is required in order to reduce risk.

The FDP report should cover all aspects of field development which are as following:

Phase I : Geology & Geophysics and Petrophysics

Phase II : Reservoir Engineering

Phase III : Drilling Engineering, Production Technology, Facilities Engineering

and Project Economics

Phase IV : Sustainable Development and Health, Safety, & Environment

A dataset for Gelama Merah field are given which includes:

Well log data for GM-1 and GM-1 ST-1

Well deviation survey for GM-1 and GM-1 ST-1

Surface contour map for GM-1 and GM-1 ST-1

Well marker depth for GM-1 and GM-1 ST-1

Core data GP-1 and GM-2 ST-1

PVT fluid data for GM-1

MDT/RFT data for GM-1

Well test data for GM-1

Well drilling data for GM-1 and GM-1 ST-1

Seismic data were not provided as part of the data acquisition. This will be one the cause of

uncertainties especially in geology development phase as seismic control is important in

interpreting important structural features. In addition, the core analysis data is not from GM-1

or GM 1ST-1 well which increase the uncertainties of the project.


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1.3 Objectives

The objective of the Gelama Merah Field Development Project (FDP) is to carry out a

technical and economics study of the proposed development utilizing the latest technology,economics and environmental element. Objectives in formulating the best, possible FDP will

include the following:

Maximizing economic return

Maximizing recoverable hydrocarbons

Maximizing hydrocarbon production

Compliance with health, safety and environment requirements

Providing recommendations in reducing risks and uncertainties Providing sustainable development options

The ultimate objective to come up with technically and economically viable development

plan to maximize return to operator within the stipulated schedule. The development strategy

must satisfy the needs of high-level management in making decision of the proposed

development for Gelama Merah field.

1.4 Scope of Work

The general scope of works for the Gelama Merah Field Development Project is:

To determine the Gross Rock volume, Net to Gross (NTG), porosity and saturation

distribution profile, types of fluids and their contacts, Stock Tank Oil Initially in Place

(STOIIP) and Gas Initially in Place (GIIP).

To develop the static model of Gelama Merah Field.

To prepare a dynamic model and perform simulation to achieve highest recovery

factor (RF) and economic return of the field.

To prepare well completion design and propose a drilling program.

To propose the most feasible and economical facilities.

To perform economic evaluation and sensitivity analysis for all development stages

and options.

To ensure the FDP is in compliance with national regulation and HSE requirements.


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1.5 Gantt Chart

Figure 1.2 - The work schedule of Gelama Merah Field Development Project

1 FDP Kick-off and Data Handover 9/2/2011 9/2/2011

2 GnG & Petrophysics 9/2/2011 3/3/2011

3 Interim Oral Presentation 4/3/2011 4/3/2011

5 Reservoir Engineering 4/3/2011 11/4/2011

6 Production Technology 16/3/2011 11/4/2011

7 Drilling & Completion 16/3/2011 11/4/2011

8 Facilities Engineering 16/3/2011 11/4/2011

9 Economics 1/4/2011 11/4/2011

11 Sustainable Development 12/4/2011 19/4/2011

12 HSE 12/4/2011 19/4/2011

13 Final Report Submission 22/4/2011 22/4/2011

14 Final Oral Presentation 3/5/2011 3/5/2011

8

Feb 2011 March 2011 April 2011 May 11No Task Name Start Finish

27 3 10 17 24 113 20 27 6 13 20


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1.6 Project Team

The Group 4 team has 10 members who are assigned to come out with a final report on the

Field Development Plan for Gelama Merah. The followings are the full name of the teammembers and the organizational structure is presented in Error! Reference source not

found..

Muhammad Aiman Bin Jamaluddin (Team leader)

Muhamad Ridzuan Bin Shaedin

Izzuddin Bin Jamaludin

Muhammad Hafizzudin Bin Abdul Wahid Wan Mohd Shafie Bin Wan Ibrahim

Nurul Fathiah Binti Mohammad

Hudzaifah Bin Zol Hamidy

Nurul Syafiqa Binti Abdul Wahab

Zairul Zahha Bin Zabidi

Faridzul Rusyidee Bin Ibrahim

A total of 11 weeks were allocated for the project. The project was initiated in 9 February

2011 and the team managed to complete the FDP by 21 April, 2011 as shown in the work

schedule in Figure 1.2.


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Figure 1.3 – Organization chart of Group 4

TEAM LEADER

PHASE I PHASE II PHASE III PHASE IV

Geology

EconomicsFacilities Eng

Drilling & Completion ProductionPetrophysics Sustainable DevelopmentReservoir

Leader:

ShafieMembers:

HafizzudinFathiahSyafiqa

Aiman

Leader:

AimanMembers:

RusyideeHudzaifahRidzuan

Leader:

ZahhaMembers:

ShafieHafizzudin

HSE

Leader:

HudzaifahMembers:

RusyideeAiman

Leader:

SyafiqaMembers:

RidzuanFathiah

Leader:

IzzuddinMembers:HafizzudinRidzuan

Leader:

RusyideeMember:

Hafizzudin

Leader:

FathiahMember:

Hafizzudin

Leader:

RidzuanMembers:

IzzuddinZahhaAiman


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Chapter 2 : DATA INVENTORY AND QUALITY CONTROL

2.1 Introduction

Before coming up with a strategic planning to develop Gelama Merah field, a systematic data

inventory was created to ensure all the resources and information are fully utilized and

maximized in each of the development phases in consideration of the uncertainties and risk

that will be undertaken based on the data that is available.

2.2 Workflow

Below described the workflow in setting up the data inventory undertaken by the

development team:

Figure 2.1 - Workflow

2.2.1 Data Acquisition and Sorting

All the data that were given are coming from the exploration and appraisal wells of Gelama

Merah Field; Gelama Merah-1, Gelama Merah-1 ST-1, Gelama Putih-1, and Gelama Merah-2


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ST-1. Data were sorted according to the wells and sand units for checklist and inventory

setup. Raw and processed data are separated for quality checking and development team‟s

interpretation and processing.

2.2.2 Data Checklist and Inventory Setup

Table 2.1 - Data Checklist

Gelama

Merah-1

Gelama

Merah 1ST-1

Gelama

Putih-1

Gelama Merah

2ST-1

Seismic Data

Well Log Data ✓ ✓

Well Deviation Survey✓

✓

Surface Contour Map ✓ ✓

Well Marker Depth ✓ ✓

Core Data ✓ ✓

PVT Fluid Data ✓

MDT/RFT Data ✓

Well Test Data ✓

Well Drilling Data ✓ ✓

Seismic data were not provided as part of the data acquisition. This will be one the cause ofuncertainties especially in Geology development phase as seismic control is important in

interpreting important structural features for instance fault, unconformity, and anticline

features. Nevertheless, these uncertainties will be further discussed later.

Since the team was provided with very limited data, risk and uncertainties are heavily

focused throughout the development phase, by considering the worst case scenario, and at the

same coming up with the proposed geological structure and anticipated production profile

which are solely based on the information that were given at present time.

In detail, data that were obtained from the acquisition phase are as followed:

Well Log Data

Gamma Ray, SP Log, Neutron Log, Neutron Density Log, Resistivity Log,

Caliper Log


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Deviation Survey

Well Trajectories, Well Coordinates

Surface Contour Map

Well Marker, Well Position, Sand Area and Thickness, Contour Lines Core Data (Special Core Analysis SCAL)

Horizontal Porosity and Permeability, Capillary Pressure (Mercury Capillary

Injection Pressure), Formation Resistivity Measurement, Relative Permeability,

Rock Compressibility

PVT Fluid Studies

Constant Compaction Experiment, Differential Liberation Experiment, Multi-

stage Separator Test, Gas Chromatography

Modular Dynamic Tester/Repeat Formation Test Data

Fluid Pressure Gradient, Fluid Contacts

Well Test Data

Zonal Permeability, Boundary/ Drive Mechanism Identification, Hydrocarbon

Fluid Contacts, Skin Factor

Well Drilling Data

Rock Cuttings, Mud Program, Casing Setup, Drill Stem Test, Well Completion

Diagram

The list above only described in general the data that were available for interpretation and

integration for Gelama Merah field development. Each development phases will be

describing further how the data is processed and utilized.

2.2.3 Data Digitizing

Data which is useful in the development phases which are either in written report and

important images are digitized and extracted as part of the data inventory. From the data

acquisition, the written reports contain valuable information regarding Gelama Merah field

thus it is digitized to help the development team in further reducing the uncertainties as well

as constructing the model that best describe Gelama Merah reservoir by taking into

consideration all the data that were available.


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2.2.4 Data Quality Check

Data accuracy and reliability are important to ensure all the interpretation are done correctly,

truthfully, because in field development , data transfer between development phases happens

frequently, thus if the data is initially wrong or inaccurate, thus it will jeopardize the whole

development planning. The goal of quality assurance and quality control (QA/QC) is to

identify and implement sampling and analytical methodologies which limit the introduction

of error into analytical data for instance logging data where later in petro physical modeling;

an intensive interpretation will be carried out. This is one of the important stages in reducing

the uncertainties which will be carried forward in the development phases. These two

methods below are used for Gelama Merah field data quality control.

Data Verification

Data verification ensures that the requirements stated in the planned data

acquisition are implemented as prescribed. This means that deficiencies or

problems that occur during implementation should be documented and reported to

show the degree of errors or uncertainties and doubt related to the data being

obtained. Corrective actions undertaken should be reviewed for adequacy and

appropriateness and documented in response to the data acquisition. These

assessments may include but are not limited to inspections, QC checks,

surveillance, technical reviews, performance evaluations, and audits. To ensure

that conditions requiring corrective actions are identified and addressed promptly,

data verification activities should be initiated as part of data collection.

Data Validation

Validation activities ensure that the results of data collection fulfils the

requirement as per needed. The data once validated, the data usability is checked

where it is process of ensuring or determining whether the quality of the data produced meets the intended use of the data. Corrective actions may improve data

quality and reduce uncertainty, and may eliminate the need to qualify or reject

data.

All in all, the key criteria that our development team focused on the data being obtained:

Accuracy

Precision Completeness


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Portability

Credibility

Specific data quality control will be explained in details according to each development phases that will be discussed in this report. This to ensure that the risk and uncertainties

involved in the data are inter-related and well described and illustrated in any of the

interpretation and findings that has been made.


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Chapter 3 : GEOLOGY & GEOPHYSICS

3.1 2-Dimensional Cross Imaging

Surface map consist of contour line which indicate the depth of the area from top view.

Contour lines connect a series of points of equal elevation and are used to illustrate relief on a

map. For instance, numerous contour lines which are close to one another show hilly or

mountainous terrain while in apart, they indicate a gentler slope. The depth range that plotted

on the top map is within 1300-1800 m. There are a total of 10 layers of surface map which

are U3.2, U4.0, U5.0, U6.0, U7.0, U8.0, U9.0, U9.1, U9.2 and U10.0. The maps were scaled

as 1:233 m which is in A4 sizes. For conventional cross section imaging, an identical scale of

horizontal and vertical are recommended (where the vertical exaggeration is 1) as shown

below.

Vertical Exaggeration (VE) = the value of one unit of measurement on the Horizontal (Map) Scale

the value of the same unit of measurement on the Vertical z

= 1:233 m = 1

1:233 m

Figure 3.1 - Surface map for Unit U3.2


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From the surface map, the depth cross section was drawn to visualize the contour line in two

dimensional views. The horizontal and vertical cross sections were both plotted using

Microsoft Excel spreadsheet. On the x-axis is given for the width (horizontal and vertical)

while the y-axis indicates the thickness of each zone.

There are 3 possible geological features that had been done during structural correlation

workflow before drawing the depth of the cross section. This method was done by drawing

the initial predictions. Theses geological features are based on the contour map and

geological information that had been interpreted in two dimensions (2-D). Figure 3.2 below

shows the possible geological features.

In Figure 3.3, the well trajectory was developed using the Measurement While Drilling(MWD) data, where the angle, direction, true vertical depth (TVD), N/S departure and E/W

departure were already given. The Water Oil Contact (WOC) is found to be at 1502 m TVDss

while the Gas Oil Contact (GOC) is at 1468 m TVDss. The two points of well given in the

surface maps are constant in scale for every maps, indicating that the points given are in TVD

for both the wells.

The distance between both of the wells are calculated to be approximately 600 m, calculated

using simple Pythagoras rule where the hypotenuse of the curve should be lesser than 1774.6

Anticline with eroded surfaces (Unconformity) structure

Anticline structure

Anticline with faultstructure

Figure 3.2 - Possible geological features


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m (as this is a curved, not a straight line) and having the TVD value of 1580 m. Therefore,

the x and y axis scale both indicate the coordinate of the location in term of meters. From the

3 plots, we can see that there is no minor or major fault detected. The zones from U3.2 to

U.9.2 can be seen truncated as the top layers were slightly eroded. Zone U10.0 from the

figures is set to be the base reservoir which confines the boundary of the reservoir.

The horizontal cross section for Gelama Merah-1 and ST-1 in Figure 3.3 had been confirmed

and approved by static model of this field. The static model had been done based on the

contour map from each sand unit (U3.2 to U.9.2). Figure 3.5 shows the static model which is

the same as the horizontal cross section that had been done.


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Figure 3.3 - Spreadsheet of horizontal cross section for Gelama Merah 1 and ST-1

Horizontal Cros s S ection GM-1 S T -1 & GM-1

1250

1300

1350

1400

1450

1500

1550

1600

1650

1700

1750

1800

1850

274500 275000 275500 276000 276500 277000 277500 278000 278500 279000 279500

Length

D e p t h

Unit 4.0

Unit 4.3

Unit 5.0

Unit 6.0

Unit 7.0

Unit 8.0

Unit 9.0

Unit 9.2

Unit 9.1

Unit 3.2


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+

Pressure Gradient

1250.0

1300.0

1350.0

1400.0

1450.0

1500.0

1550.0

1600.0

1650.0

1700.0

1750.0

1800.0

1850.0

2 0 80 . 0 2 1 00 . 0 2 1 20 . 0 2 1 40 . 0 2 1 60 . 0 2 1 80 . 0 2 2 00 . 0 2 2 20 . 0 2 2 40 . 0 2 2 60 . 0

Formation Pressure (psia)

m T V D R K B

( R K B = 2 7 . 3 m )

OWC

GOC

All units

1250

1300

1350

1400

1450

1500

1550

1600

1650

1700

1750

1800

1850

274500 275000 275500 276000 276500 277000 277500 278000 278500 279000 279500

Unit4.0

Unit4.3

Unit5.0

Unit6.0

Unit7.0

Unit8.0

Unit9.0

Unit9.2

Unit9.1

Unit3.2

All units

1250

1300

1350

1400

1450

1500

1550

1600

1650

1700

1750

1800

1850

274500 275000 275500 276000 276500 277000 277500 278000 278500 279000 279500

Unit4.0

Unit4.3

Unit5.0

Unit6.0

Unit7.0

Unit8.0

Unit9.0

Unit9.2

Unit9.1

Unit3.2

P ress ure Gradient

1250.0

1300.0

1350.0

1400.0

1450.0

1500.0

1550.0

1600.0

1650.0

1700.0

1750.0

1800.0

1850.0

2080.0 2100.0 2120.0 2140.0 2160.0 2180.0 2200.0 2220.0 2240.0 2260.0

Formation Pressure (psia)

m T V D R K B ( R

K B = 2 7 . 3 m )

OWC

GOC

Figure 3.4 - OWC and GOC determination using pressure gradient plot


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Figure 3.5 - 3-Dimensional (3-D) Static Model


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From the structural correlation, the structure was affected by syncline anticline regimes that

act as hydrocarbon trap. Therefore, the geological structure was anticline structure in which

the other limb has been eroded. There

fdp aiman j [january 2011]

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