Pod Lapangan Pqr

OFFSHORE PQR FIELD POD

XYZ FIELD LOCATION MAP

PQR

Presenter

Presentation Notes

ELAN, Net pays, Q, and SW Let compare with the Poleng logs

TOP DEPTH STRUCTURAL MAP

Well-02

Well-01

STRUCTURAL CORRELATION

Well-01 Well-02

SUMMARY OF RESERVOIR PROPERTIES Porosity

Well-01 Well-02 Ave_PORH Por H*SW H Por H*SW

Layer-1 0.00 0.00 0.00 2.89 0.16 0.46 0.16Layer-2 35.50 0.26 9.24 53.61 0.25 13.16 0.25Layer-3 0.00 0.00 0.00 9.53 0.26 2.48 0.26Layer-4 2.65 0.23 0.60 4.50 0.32 1.45 0.29

Water SaturationWell -01 Well-02 Ave_SW

H SW H*SW H SW H*SW


NTG (Net to Gross Ratio)Well-01 Well-02 Ave_NTG

H NTG H*SW H NTG H*SW


OIL PORE VOLUME MAP

Well-02

Well-01

GAS PORE VOLUME MAP

Well-02

Well-01

Lab - Capillary Pressure Oil-Water System

0.0

10.0

20.0

30.0

40.0

50.0

60.0

70.0

80.0

90.0

100.0

110.0

120.0

130.0

140.0

150.0

0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1

Brine Saturation, percent Vp

Cap

illar

y Pr

essu

re,p

s

`

Pc @ Ka 693 mdPhi : 0.275

Pc @ Ka 201 mdPhi : 0.260

Pc @ Ka 14.6 mdPhi : 0.262

Pc @ Ka 14.9 mdPhi : 0.224

Gas-Oil Rel-Permeability

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40

Gas Saturation, Fraction

Rel

-Per

m, K

rog,

Krg

Krg @ Core 107 Krog@ Core 107

Krg#Core 127 Krog # Core 127

Krg#Core 130 Krog#Core 128

Krog#Core 130 Krg#Core128

Oil-Water Rel-Permeability

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80Wat er Sat ur at ion, Fr act ion

Krw @ Core 107Krow@ Core 107Krw @Core 127Krow @ Core 127Krw @ Core 130Krow @ Core 128Krow @ Core 130Krw @ Core128

HYDROCARBON FLUID PVT ANALYSISHYDROCARBON ANALYSIS OF SEPARATOR LIQUID SAMPLE

(UNDECANES PLUS)

Component Mol % Weight %

Hydrogen Sulfide 0.00 0.00Carbon Dioxide 0.17 0.06Nitrogen 0.02 0.00Methane 5.83 0.73Ethane 3.08 0.72Propane 6.95 2.39Iso-Butane 3.00 1.36N-Butane 5.15 2.33Iso-Pentane 4.09 2.30N-Pentane 4.00 2.25Hexanes 7.77 5.08Heptanes 11.66 8.23Octanes 11.58 9.26Nonanes 6.11 5.53Decanes 4.47 4.60Undecanes plus 26.12 55.16

Total ...... 100.00 100.00

Properties of Heptanes Plus

°API Gravity at 60 °F 40.1Density, gm/cc at 60 °F 0.8245Molecular Weight 177.3

Properties of Undecanes Plus

°API Gravity at 60 °F 33.6Density, gm/cc at 60 °F 0.8572Molecular Weight 271.0

Average Total Molecular Weight of Sample = 128.4

HYDROCARBON ANALYSIS OF SEPARATOR GAS SAMPLE

Component Mol % GPM

Hydrogen Sulfide 0.00 Carbon Dioxide 1.07 Nitrogen 0.75 Methane 77.48 Ethane 8.64 2.310 Propane 7.34 2.022 iso-Butane 1.49 0.488 n-Butane 1.81 0.570 iso-Pentane 0.56 0.204 n-Pentane 0.39 0.142 Hexanes 0.26 0.108 Heptanes 0.15 0.054 Octanes 0.05 0.020 Nonanes 0.01 0.004 Decanes 0.00 0.000 Undecanes plus 0.00 0.000

Total ...... 100.00 5.922

Gas Gravity(air = 1.000) 0.759

Gross HeatingValue

BTU / cubic foot 1292.7of dry gas at

14.73 psia and 60 °F

VOLUMETRIC DATA (at 176 °F)

Saturation Pressure (Psat) ......................... 1870 psigDensity at Psat .............................................. 0.6503 gm/ccThermal Exp @ 5000 psig .......................... 1.07295 V at 176 °F / V at 60 °F

AVERAGE SINGLE-PHASE COMPRESSIBILITIES

Single-PhasePressure Range Compressibility

psig v/v/psi

5000 to 4000 11.87 E -64000 to 3000 14.14 E -63000 to 2000 17.16 E -62000 to 1870 18.92 E -6

DIFFERENTIAL VAPORIZATIONADJUSTED TO SEPARATOR CONDITIONS*

GasSolution Formation Formation Oil Oil/Gas

Pressure Gas/Oil Volume Volume Density Viscositypsig Ratio Factor Factor gm/cc Ratio

Rs (A) Bo (B) (C)

5000 836 1.435 0.68054500 836 1.443 0.67674000 836 1.452 0.67253500 836 1.462 0.66803000 836 1.472 0.66312500 836 1.484 0.65782200 836 1.492 0.65432100 836 1.495 0.65322000 836 1.498 0.65191900 836 1.500 0.6507

b» 1870 836 1.501 0.65031600 723 1.446 0.00923 0.6627 18.9 1400 643 1.408 0.01068 0.6715 21.2 1200 567 1.371 0.01263 0.6800 23.8 1000 494 1.336 0.01535 0.6883 26.5 800 423 1.303 0.01945 0.6965 29.6 600 354 1.269 0.02626 0.7050 33.2 400 283 1.234 0.03978 0.7141 38.2 200 201 1.187 0.07894 0.7254 46.7 109 148 1.153 0.13928 0.7326 54.5

0 0.7598

Kodeco Energy Company Ltd. KE-30-1

JFL 2001094 Differential Vaporization

Adjusted to Separator Conditions

Figure D-2 : Differential Vaporization Formation PressureAdjusted to Volume Factor VS

Separator Conditions (Bbl/bbl) (psig)

RIES

1

1.1

1.2

1.3

1.4

1.5

1.6

1.7

1.8

0 250 500 750 1000 1250 1500 1750 2000

Pressure, psig

Differential VaporizationSeparator Test, 350 psig at 90 °FSeparator Test, 250 psig at 90 °FSeparator Test, 150 psig at 90 °FSeparator Test, 50 psig at 90 °F

RESERVOIR FLUID VISCOSITY(at 176 °F)

Oil Gas Oil/GasPressure Viscosity Viscosity Viscosity

psig cp cp ratio

5000 0.346 4500 0.335 4000 0.323 3500 0.312 3000 0.300 2500 0.289 2200 0.282 2100 0.279 2000 0.277 1900 0.275

Pb»1870 0.274 1600 0.304 0.0161 18.9 1400 0.327 0.0154 21.2 1200 0.351 0.0148 23.8 1000 0.375 0.0142 26.5 800 0.402 0.0136 29.6 600 0.431 0.0130 33.2 400 0.467 0.0122 38.2 200 0.520 0.0111 46.7 109 0.564 0.0103 54.5

0 1.00

Kodeco Energy Company Ltd. KE-30-1

JFL 2001094 Reservoir Fluid Viscosity

Figure C-1 : Reservoir Fluid Viscosity Oil Viscosiy (Cp) Pressure(at 176 °F) and VS

Gas Viscosity (Cp) (psig)

RIES

0.20

0.40

0.60

0.80

1.00

1.20

0 1000 2000 3000 4000 5000

Pressure, psig

0.005

0.015

0.025

0.035

0 500 1000 1500 2000 2500

Pressure, psig

DST-SUMMARY

Well-01 Well-02

ESTIMATED HYDROCARBON RESERVES

HYDROCARBON DISTRIBUTION

OIIP : 22.2 MMBOEUR : 2.95 MMBO

GIIP 18.9 BCF (FREE-GAS)19.5 BCF (SOL. GAS)

EUR : 13.0 BCF

Well-01 Well-02

DEVELOPMENT SCENARIOS

SIMULATION PRODUCTION FORECAST

ANNUAL PRODUCTION FORECAST

YEAR OIL GAS(MBO) (MMCF)

2005 749 1195

2006 1040 2970

2007 544 2964

2008 309 2552

2009 169 1741

2010 89 1022

2011 50 601

TOTAL 2,950 13,045

COMPLETION

PQR POD Completion Proposal

• Artificial Lift Completion will be installed immediately.

• Select In-situ/Auto Gas lift Completion.

PQR POD Completion Proposal In-Situ/Auto Gas Lift Selection

• Completion cost considerations (compare with conventional Gas Lift and ESP)

• Utilize Kujung I gas for gas lift supply to optimize production. Minimize the use of the gas as minimum as possible.

• Minimize workover for future completion.

• Minimize wireline works for high angle well.

PQR POD Completion Proposal - Test Data

Chk Size FTP, psi BOPD MMSCF/D BWPD Test Duration, hrs Remark48/64 380 0 3.5 0 6 hrs Before acid48/64" 660 12 7 - 9 100 8 hrs After acid

Total Skin : - 2.5 Permeabilty : 3.3 mD Res. Press : 1838 psi

Chk Size FTP, psi BOPD MMSCF/D BWPD Test Duration, hrs Remark32/64" 500 1740 0.62 2 12 hrs No acid

Total Skin : 42 Permeabilty : 191 mD Res. Press : 1870 psi

Kujung I ( Gas Zone) DST Result :Perforation Intervals : 4268' - 4308' / 40 ft (MD/TVD)

Kujung I ( Oil Zone) DST Result :Perforation Intervals : 4326' - 4348' / 22 ft (MD/TVD)

GOR 400

GOR 600

GOR 800

1868 psi

1700 psi

1600 psi

Inflow/Outflow Curves for PQR POD

Inflow/Outflow Curves for PQR POD

Oil

Gas

Water

PQR Wellbore Angle Strategy

0 degree

64 degree

40 degree64 degree57 degree

40 ft

80 ft

50 ft

Oil

Gas

Water

40 ft

80 ft

50 ft

Gas will perforated between the twopackers

Oil intervals

ITEM ESP SMART COMPLETIONUS $ US $

Tubing $ 8.0/ ft 50,000 50,000Eqpt Surface-Wellhead 64,000 64,000Electric Submersible Pump 60,000Electric Cable 16,000Packer/ SSD/Downhole Safety Eqp. 46,000

Bottom packer 10,000Hydrow II Dual Packer 20,000Remotely Operated SSD 44,000Dual Hydraulic line 22,000Downhole safety valve 14,000Misc. 10,000

Total 236,000 234,000

COMPLETION COST

Dual String Divert from Auto Gas lift Hyd. Flow Control Assign one welloil well to gas well from Surface for gas source only

(OPTION 1) (OPTION 2) (OPTION 3) (OPTION 4) (OPTION 5)

Wellhead Wellhead Wellhead Wellhead Wellhead2-7/8" 3-1/2" 3-1/2" 3-1/2" 3-1/2"

9-5/8" dual packer 7" packer 7" packer 7" packer 7" packer7" packer 7" packer 7" packer 7" packer 7" packer

Standard 75,000.0 75,000.0 75,000.0 75,000.0 75,000.0

Cost per well 105,000.0 75,000.0 91,000.0 130,000.0 75,000.0

Total Cost incl. Rig Cost for 7days 420,000.00 390,000.00 406,000.00 445,000.00 390,000.00(US$ 315,000)

Oil production reduce Require wireline work More expensive but Oil production only fromto 3 wells in the future works easy to operate 3 wells only

COMPLETION COST COMPARISON

PROJECT

Presenter

Presentation Notes

First of all I would like to thank for this opportunity to present about the Kodeco to you this afternoon. When I presented this topic in SPE in May 2000 I only talked about Fast Track in the Poleng Field then when I presented in IAGI in November 2000, in the day when I presented we discovered a new field with 500’ HC column, 300’ oil and 200’ gas. I received a log from Mary and a lot of Pertamina people saw the log in that meeting. We have been fast tracking the development, so I add this topic with explaining the KE-23 POD. As you all know that YPF farmed in this block in 1999. 8 Maxus people were seconded to Kodeco operation. This afternoon I would like to show you how we have been achieving a very good results in about 2 years, increase production >600%, increase reserves >500% and reserves replacement more than 1000%. Before seconding to Kodeco we used to work in South, Central and Northern areas. Like me, I used to work in Exploration, Development, South, Central, and northern areas. Basically, we have been applying our experiences that we have done in Maxus In term of scale do not compare with Maxus, but see the increase in percentage A lot of activities have been done, drilled 8 horizontal wells, discovered 3 new fields, add reserves about 87 MMBOE, increased production capacity from 1200 BOPD to 9000 BOPD and 15 MMSCFGPD to 60 MMSCFGPD. Since this luncheon talk is attended by all discipline, G&G, Res, Prod, Econ, Pet, Managers I would like to talk very general about geology, geophysics, petrophysic, production, reservoir, project economics, and facilities.

PQR DEVELOPMENT

INTRODUCTION :• INSTALL 4 PILE PLATFORM TO ACCOMMODATE

MAX. 7 WELLS AND TIE IN TO AW PLATFORM VIA 10” x 25 KM SUBSEA PIPELINE

EQUIPMENT TO BE INSTALLED :• PRODUCTION AND TEST MANIFOLD• CRANE• WHCP (WELLHEAD CONTROL PANEL)• SCADA SYSTEM• CHEMICAL INJECTION• PRODUCTION SEPARATOR WITH LIQUID AND

GAS METERING FOR ALLOCATION• MULTI PHASE FLOW METER

PROJECT ACTIVITIES:• REVISION OF AMDAL STUDY (RKL / RPL)• FEED STUDY• PROCUREMENT OF LONG LEAD ITEM• PREPARE EPC BID PACKAGE• ISSUE TENDER PROCUREMENT AND FABRICATION • ISSUE TENDER INSTALLATION• FABRICATION OF PLATFORM AND PRODUCTION

FACILITIES• INSTALLATION OF PLATFORM, PRODUCTION

FACILITY AND PIPELINE• TIE IN / HOOK UP AT AW PLATFORM• COMMISSIONING AND START UP

PROJECT COST :PQR FOUR PILE PLATFORM US$8,650• Deck & Substructure Engineering, Procurement

& Fabrication• Installation of Platform• Facilities Hook UpPIPELINES US$3,600• 10 inch x 25 Km : PQR to PolengMISCELLANEOUS US$1,250• Engineering, Certification & QA / QC• Project Management

TOTAL US$13,500

PQR DEVELOPMENT PROJECT SCHEDULE

ECONOMICS

1. The estimated total cost, including three (3) producing wells in 2004 and two (2) wells in 2005, is 27.352 MMUS$.

2. PQR Field is capable of production 2.950 MMSTB of oil production and 10.366 BCF of gas production in Kujung I formation by the end of year 2011 with five (5) producing wells.

3. Oil price was assumed U$$ 22.00 per barrel and gas price of US$ 3.0 per MMBTU.

4. The PQR operating cost is 13.954 MMUS$, which is calculated as the fractional portion of PQR production against the total operating cost of both West Madura and Poleng.

1. Economical Aspects

1. PQR Four File Platform 8,650

• Deck & Substructure eng., Procurement, & Fabrication

• Installation of Platform

• Facilities Hook-up

2. Pipelines 3,600

• 10” OD – 25 Km: PQR – Poleng

3. Miscellaneous 1,250

• Engineering, Certification, and QA/QC

• Project Management

4. Development Drilling and Completion (5 wells) 13,852

TOTAL 27,352

2. Requirements and Proposed Expenditures

Gross Production Mbbls 2,950

Oil Price US$/bbl 22

Gross Revenue MUS$ 96,121

Operation Costs MUS$ 13,954

Capital Expenditure MUS$ 27,352

Total Cost Recovery MUS$ 48,252

Contractor NPV (10% D.C.) MUS$ 3,669

Payout Time Years 4.5

Contractor IRR % 26.6

Pertamina NPV (10% D.C.) MUS$ 6,933

Indonesia NPV (10% D.C.) MUS$ 19,289

3. Economic Summary

4. Sensitivity Analysis KE-30 Field Development

Sensitivity to Contractor NPV

0.01.02.03.04.05.06.07.0

0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4

SENSITIVITY FACTOR

Cont

ract

or N

PV

(@10

%),

MM

$

Oil Price CAPEX OPEX Production

KE-30 Field DevelopmentSensitivity to Pertamina NPV

0.01.02.03.04.05.06.07.08.09.0

10.011.012.013.0

0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4

SENSITIVITY FACTOR

Cont

ract

or N

PV

(@10

%),

MM

$


KE-30 Field DevelopmentSensitivity to Contractor IRR

0.05.0

10.015.020.025.030.035.040.045.0

0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4

SENSITIVITY FACTOR

IRR

( %

)


KE-30 Field DevelopmentSensitivity to Government NPV

0.05.0

10.015.020.025.030.035.040.0

0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4

SENSITIVITY FACTOR

Indo

nesi

a NP

V (@

10%

), M

M$


PQR FIELD DEVELOPMENTSENSITIVITY TO CONTRACTOR NPV

PQR FIELD DEVELOPMENTSENSITIVITY TO CONTRACTOR IRR

PQR FIELD DEVELOPMENTSENSITIVITY TO PARTNER NPV

PQR FIELD DEVELOPMENTSENSITIVITY TO GOVERNMENT NPV

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