Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
205-211
2- Q5- 2,t k Schiumberger Fluid Analysis of MDT Samples ConocoPhillips Field:West Sak Well:1R East Black Oil Full PVT Study Report Prepared for Michael Werner/Dennis Wegener ConocoPhillips same JUN 2 42015 Standard Conditions Used: Pressure: 14.696 psia Temperature:60°F Prepared by: Stefan Smuk Schlumberger WCP Oilphase-DBR 16115 Park Row,Suite 150 Houston,Texas,77084 (281)285-6370 Date:05/23/2006 Report#200600071 2 Client: ConocoPhillips Field: West Sak Well: 16 East Sand: B&A3 Schlumberger Installation: - Job it: 200600071 Table of Contents List of Figures __ _. 2 List of Tables 3 EXECUTIVE SUMMARY 4 Objective 4 Introduction 4 Scope of Work 4 Results 4 PVT Study Data.Quality Check Summary 6 Sequence of Events 6 Chain of Sample Custody 6 RESULTS AND DISCUSSIONS 7 Fluids Preparation and Analysis 7 Reservoir Fluid Analysis 7 PVT Analysis on.Sample 1.07;Cylinder CSB.861.6-DA;Depth 7369.ft.MD 15 Constant Composition Expansion at Tres 15 Reservoir Oil Viscosity at Tres 17 Multi-Stage Separation Test 19 PVT Analysis on.Sample 1.18;Cylinder CSB 7742-OA;Depth 7550 ft.MD 36 Constant Composition Expansion at Tres 36 Reservoir Oil Viscosity at Tres 38 Multi-Stage Separation Test 40 Appendix A:Nomenclature and Definitions 50 Appendix B:Molecular Weights and Densities Used 51 Appendix C:EQUIPMENT 52 Fluid Preparation and Validation 52 Fluid Volumetric(PVT)and Viscosity Equipment 53 Appendix D:PROCEDURE 55 Fluids Preparation and Validation 55 Constant Composition Expansion Procedure 55 Differential Vaporization Procedure 55 Multi-Stage Separation Test 56 Liquid Phase Viscosity and Density Measurements During DV Step 56 Stock-Tank Oil(STO)Viscosity and Density Measurements 56 Asphaltene,Wax and.Sulfur Content Measurements 57 SAR(P)A Analysis 57 High-Temperature High Pressure Filtration Test 57 Oilphase-DBR 1 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 List of Figures Figure 1:Stock Tank Oil Chromatogram(Sample 1.07) 13 Figure 2:k-Plot for Equilibrium.Check(Sample 1.07) 13 Figure 3:Constant.Composition Expansion at 79.0°F-Relative Volume 16 Figure 4:Reservoir Fluid Viscosity 79°F 18 Figure 5:Stock Tank.Oil Chromatogram(Sample 1.09) 25 Figure 6:k-Plot for Equilibrium Check(Sample 1.09) 25 Figure 7:Stock Tank.Oil Chromatogram(Sample 1.10) 28 Figure 8:k-Plot for Equilibrium Check(Sample 1.10) 28 Figure 9:Stock Tank.Oil Chromatogram(Sample 1.11) 31 Figure 10:k-Plotfor Equilibrium Check(Sample 1..11) 31 Figure 11:Stock Tank Oil Chromatogram(Sample 1.18) 34 Figure 12:k-Plot for Equilibrium Check(Sample 1.18) 34 Figure 13:Constant Composition.Expansion at 81.0°F-Relative Volume 37 Figure 14:Reservoir Fluid Viscosity 81°F 39 Figure 15:Stock Tank Oil Chromatogram(Sample 1.20) 46 Figure 16:k-Plot for Equilibrium Check(Sample 1.20) 46 Figure 17:Stock Tank Oil Chromatogram(Sample 1.21) 49 Figure 18:k-Plot for Equilibrium Check(Sample 1.21) 49 Oilphase-DBR 2 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 List of Tables Table 1:Well and Sample.Identification 8 Table 2:Well Position.Data 8 Table 3:Sampling.and Transfer Summary 9 Table 4:Reservoir.Fluid Properties 10 Table 5:Stock-Tank Oil Properties 10 Table 6:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.07) 11 Table 7:Calculated Fluid Properties 12 Table 8:Summary of Results of.Sample 1.07 14 Table 9:Constant.Composition Expansion.at 79.0°F(Sample 1.07). 15 Table 10:Reservoir Fluid.Viscosity 79°F .. 17 Table 11:Multi-Stage Separation Test Vapor&Liquid Properties 20 Table 12:Multi-Stage Separator Test Vapor Composition(mol%o) 21 Table 13:Multi-Stage Separator Test Residual Liquid Composition(mol.%) 22 Table 14:C36+Composition,GOR.°API,by Zero-Flash(Sample 1.09) 23 Table 15:Calculated Fluid Properties 24 Table 16:C36+Composition,GOR°API,by.Zero-Flash(Sample.1.10) 26 Table 17:Calculated Fluid Properties 27 Table 18:C36+Composition,GDR.°AP4.by.Zero1Flash.(Samplei.11) 29 Table 19:Calculated Fluid Properties 30 Table 20:C36+Composition.GOR.°API,by Zero-Flash(Sample 1.18) 32 Table 21:Calculated Fluid Properties 33 Table 22:Summary of Results of Sample 1.18 35 Table 23:Constant Composition Expansion at 81.0°F(Sample 1.18) 36 Table 24:Reservoir Fluid.Viscosity 81°F 38 Table 25:Multi-Stage Separation Test Vapor&Liquid Properties 41 Table 26:Multi-Stage Separator Test Vapor.Composition.(mol%) 42 Table 27:Multi-Stage Separator Test Residual Liquid Composition(mot%) 43 Table 28:C30+Composition,GDR°API,.by Zero-Flash(Sample 1.20) 44 Table 29:Calculated Fluid Properties 45 Table 30:C30+Composition.GOR°API,.by Zero-Flash.(Sample1.21) 47 Table 31:Calculated Fluid Properties 48 Oilphase-DBR 3 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 EXECUTIVE SUMMARY Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected during the modular formation dynamics testing(MDT). Introduction At the request of ConocoPhillips,Oilphase has conducted a fluid analysis study on bottomhole fluid samples collected during the modular formation dynamics testing(MDT)of Well 1R East drilled in the field West Sak. Scope of Work • Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for five • Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas- Oil Ratio(GOR),reservoir fluid composition,stock-tank oil(STO)and monophasic fluid properties. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon samples: • Seven bottomhole samples were used for validation purposes.They were homogenized at the reservoir conditions for five days. • The zero flash GOR was determined to be from 162 - 324 SCF/STB, and the STO density to be from 0.934-0.954 g/cc. • One representative sample from each sampled depth (7369' MD and 7550' MD, 1.07 and 1.18 respectively)was selected for detailed PVT testing. PVT sample 1.18 underwent demulsification prior to analysis;the quality of the demulsification was verified by BS&W analyses. • The results of the two sets of PVT analyses are presented below. Sample 1.07;Cylinder CSB 8616-OA;Depth 7369 lt.MD,B Sand FLASHING CUMULATIVE API Gas Relative FVF FVF OPERATION GOR(scf/stb) GRAVITY Density(air=1) at Pres/Tres at Psat/Tres Zero Flash 233* 17.70 0.580 1.086 1.088 DL Flash CO Tres - - - - - Separator Test 242 17.09 0.581 1.092 1.093 Sample 1.18;Cylinder CSB 774241A;Depth 7550 k.MD,A3 Sand FLASHING CUMULATIVE API Gas Relative FVF FVF OPERATION GOR(scf/stb) GRAVITY Density(air=1) at Pres/Tres at Psat/Tres Zero Flash 230 19.89 0.650 1.098 1.099 DL Flash Cc?Tres - - - - - Separator Test 213 22.29 0.619 1.077 1.078 'The single-stage flash of sample 1.07,B Sand,was confirmed by duplicate tests. Oilphase-DBR 4 Job#:200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Installation: - Job#: 200600071 Quality Assurance Process Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment. A rigorous quality assurance program,continuous employee training and enforcement of strict safety standards maintain our compliance with Quality,Health, Safety and Environment(QHSE)requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures.Details of these programs are available upon request. The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results. a) Establish quality of measurement during data generation. b) Establish quality of processed data as per checklist during data processing by Data Quality Engineer. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency d) The responsible Project Engineer confirms consistency of reported data e) Engineering Project Manager review the results/report for overall consistency Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity.All property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request. The file and laboratory records information are listed below to provide access reference to all records related to this project.For any questions,please do not hesitate to contact the undersigned Project Engineer. File No.:200600071 Laboratory Records:200600071 Data Quality Data Reporting Suyu Ye Meisong Yan Data Quality Engineer Project Engineer Overall Report Quality Clay Young Clay Young Oilphase-DBR Operation Manager,NGC Oilphase-DBR 5 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Sequence of Events 05/04/06 Samples arrived. 05/04/06 Project work scope discussed. 05/04/06 Work agreement approved. 05/04/06 Prelim PVT tests request for all six samples issued. 05/25/06 Sample PVT prelim results sent via e-mail. Chain of Sample Custody The samples collected from the well 1R East were sent to Oilphase-DBR in Houston,Texas.The samples were used to preliminary measurements and subsequent PVT studies.The measurement details are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. Oilphase-DBR 6 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job S: 200600071 RESULTS AND DISCUSSIONS Fluids Preparation and Analysis Seven bottomhole samples collected during MDT operations were transferred to Oilphase-DBR. The well and formation data are summarized in Table 1,along with the respective reservoir conditions for the bottomhole samples. Quality checks of the bottomhole samples were conducted,and the results are summarized in Table 3. After 5 days of homogenization,sample validation tests were conducted to evaluate the validity of the samples. Three of the B-Sand samples were deemed to be unrepresentative, based on preliminary data which suggested irregularities of solution- gas content due to high drawdown during sampling. The A3 samples were judged representative. One representative sample from each sand was selected for complete PVT analysis.The reservoir fluid and stock-tank oil properties for all the samples are presented in Tables 4 and 5. Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined.These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GOR)to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 6, 14, 16, 18, 20, 28 and 30. The molecular weight of the stock-tank oil(STO)was measured.Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Tables 7,15,17,19,21,29 and 31. The A3-Sand samples(7550 ft MD)had consistent GOR's,API's and compositions.However,samples from the B Sand, depth 7369 ft MD, had varied GOR data, despite similiar API's, STO compositions and flash-gas compositions. The GOR measurements for the B-Sand samples were double-checked. It was speculated that the differences in GOR might be due to sampling under diphasic conditions, occurring as a result of high drawdown (410 psi)within the saturated reservoir. A3-Sand sample 1.18(7550 ft MD)contained significant emulsified water. A demulsifier was added to the oil,and the cylinder was allowed to rest vertically for 24 hours. A subsample of flashed stock-tank liquid from the demulsified blend was analyzed by GC to confirm sample integrity. BS&W analyses were also conducted on subsamples taken from both top and bottom portions of the cylinder,to confirm the success of the demulsification procedure. Samples 1.07(7369 ft)and 1.18(7550 ft)underwent a complete PVT study,including the following elements: 1) Constant Composition Expansion(CCE)at reservoir temperature,2)a three-stage separator test,with the final stage conducted at ambient conditions,and 3)viscosity testing at reservoir temperature,over a range of pressures. Oilphase-DBR 7 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Table 1:Well and Sample Identification Client ConocoPhillips Job# 200600071 Field: West Sak Well: 1R East Sample ID Chamber# Chamber Sampling Date Reservoir Conditions Volume Sand Pressure Temperature Depth (cc) (psia) (°F) lit) 1.07 MRSC 292 1 gallon 26/03/2006 B 1,707 79 7369 1.09 SPMC448 250 26/03/2006 B 1,707 79 7369 1.10 SPMC451 250 26/03/2006 B 1,707 79 7369 1.11 SPMC446 250 26/03/2006 B 1,707 79 7369 1.18 MRSC 226 1 gallon 26/03/2006 A3 1,747 81 7550 1.20 MPSR 1295 450 26/03/2006 A3 1,747 81 7550 1.21 SPMC230 250 26/03/2006 A3 1,747 81 7550 Table 2:Well Position Data Well Name Strat Name Latitude Longitude X Loc Y Loc 1R-EAST SURFACE 70.394812836 -149.559377734 1694568.09 5994045.69 1R-EAST WEST SAK D 70.397372178 -149.605220793 1688928.07 5994944.11 1R-EAST WEST SAK B 70.397414402 -149.605789636 1688858.35 5994959.10 1R-EAST WEST SAK A3 70.397459657 -149.606496770 1688770.63 5994975.44 1R-EAST WEST SAK A2 70.397507958 -149.607350332 1688666.42 5994991.98 Oilphase-DBR 8 Job#:200600071 I Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Table 3:Sampling and Transfer Summary Opening Transfer Closing Opening Transferred Sample ID Chamber# conditions Cylinder conditions conditions Water content Sample in the field ID in the field in the Lab Volume (psia/°F) (psia/°F) (psia/°F) (wt%) (cc) 1.07 MRSC 292 2015/65 CSB 8616-QA 1215/70 1265/72 0.3 600 1.09 SPMC 448 5515/65 SSB 13728-0A 4715/65 5015/72 0.8 245 1.10 SPMC 451 5615/65 SSB 12120-QA 5315/70 5515/72 0.7 245 1.11 SPMC 446 4715/65 SSB 13916-QA 4715/70 5515/72 0.8 235 1.18 MRSC 226 3715/67 CSB 7742-QA 915/66 2015/72 3.0 600 1.20 MPSR 1295 4215/65 CSB 8620-QA 715/66 2015/72 2.6 425 1.21 SPMC 230 1915/69 SSB 11875-QA 5015/65 5265/72 2.9 230 Oilphase-DBR 9 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Table 4:Reservoir Fluid Properties Zero Flash Saturation Molar Mass of Monophasic Sample ID Cylinder# Depth GOR* Bo** Pressure monophasic fluid***OBM at Tres fluid contamination (ft) (scf/stb) (psial %(w/w) 1.07 CSB 8616-GA 7,369 233 1.088 1511 226.5 - 1.09 SSB 13728-QA 7,369 162 - - 256.7 - 1.10 SSB 12120-GA 7,369 196 - - 241.0 - 1.11 SSB 13916-0A 7,369 324 - - 197.8 - 1.18 CSB 7742-GA 7,550 230 1.099 1553 199.2 - 1.20 CSB 8620-GA 7,550 233 - - 199.0 - 1.21 SSB 11875-QA 7,550 221 - - 203.4 - *Flashed gas volume(scf)per barrel of stock tank liquid©60°F **Volume of live oil at it's bubble point pressure per flashed stock tank liquid volume Cc3 60°F ***Calculated from oil-based mud contamination in STO Table 5:Stock-Tank Oil Properties STO Properties Sample ID Cylinder# Depth Molar Mass Density API* OBM Contamination (ft) (g/cc) %(w/w) 1.07 CSB 8616-QA 7,369 370.1 0.9484 17.7 - 1.09 SSB 13728-GA 7,369 370.3 0.9515 17.2 - 1.10 SSB 12120-0A 7,369 369.0 0.9505 17.4 - 1.11 SSB 13916-0A 7,369 368.2 0.9539 16.8 - 1.18 CSB 7742-GA 7,550 299.0 0.9347 19.9 - 1.20 CSB 8620-QA 7,550 300.7 0.9344 19.9 - 1.21 SSB 11875-0A 7,550 302.3 0.9350 19.8 - * API=141.5/Density-131.5. Oilphase-DBR 10 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 6:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.07) Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.25 0.10 0.00 0.00 0.01 0.04 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.43 0.26 0.00 0.00 0.01 0.10 Methane 16.04 93.13 97.43 0.00 0.00 2.81 39.60 Ethane 30.07 1.82 1.02 0.00 0.00 0.05 0.41 _ Propane 44.10 0.81 0.31 0.01 0.11 0.04 0.19 I-Butane 58.12 1.54 0.45 0.04 0.24 0.08 0.32 N-Butane 58.12 0.30 0.09 0.01 0.08 0.02 0.08 I-Pentane 72.15 0.87 0.20 0.07 0.38 0.10 0.31 N-Pentane 72.15 0.10 0.02 0.01 0.05 0.01 0.04 C6 84.00 0.35 0.07 0.13 0.57 0.14 0.37 M-C-Pentane 84.16 0.01 0.00 0.01 0.02 0.01 0.01 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.03 0.01 0.02 C7 96.00 0.13 0.02 0.15 0.58 0.15 0.35 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.02 Toluene 92.14 0.01 0.00 0.02 0.07 0.02 0.04 C8 107.00 0.11 0.02 0.30 1.04 0.29 0.62 E-Benzene 106.17 0.00 0.00 0.02 0.09 0.02 0.05 M/P-Xylene 106.17 0.00 0.00 0.00 0.02 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.03 C9 121.00 0.07 0.01 0.46 1.41 0.45 0.84 C10 134.00 0.04 0.01 0.89 2.45 0.86 1.46 C11 147.00 0.01 0.00 1.28 3.21 1.24 1.91 C12 161.00 0.00 0.00 1.76 4.05 1.71 2.40 C13 175.00 0.00 0.00 2.23 4.72 2.17 2.80 C14 190.00 0.00 0.00 2.55 4.97 2.47 2.95 C15 206.00 0.00 0.00 2.90 5.21 2.81 3.09 C16 222.00 3.10 5.17 3.01 3.07 C17 237.00 2.94 4.59 2.85 2.72 C18 251.00 3.12 4.60 3.03 2.73 C19 263.00 3.04 4.28 2.95 2.54 C20 275.00 2.85 3.84 2.77 2.28 C21 291.00 2.72 3.45 2.63 2.05 C22 300.00 2.78 3.43 2.69 2.03 C23 312.00 2.30 2.73 2.23 1.62 C24 324.00 2.32 2.65 2.25 1.57 C25 337.00 2.11 2.31 2.04 1.37 C26 349.00 2.10 2.23 2.04 1.32 C27 360.00 2.13 2.19 2.07 1.30 C28 372.00 2.05 2.04 1.99 1.21 C29 382.00 1.84 1.79 1.79 1.06 C30 394.00 1.90 1.78 1.84 1.06 C31 404.00 1.86 1.70 1.80 1.01 C32 415.00 1.58 1.41 1.54 0.84 C33 426.00 1.50 1.31 1.46 0.78 C34 437.00 1.51 1.28 1.46 0.76 C35 445.00 1.31 1.09 1.27 0.65 C36+ 930.00 42.07 16.74 40.80 9.94 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.78 370.13 226.51 MOLE RATIO 0.4065 0.5935 Oilphase-DBR 11 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 7:Calculated Fluid Properties Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.41 0.06 99.72 v 98.57 96.73 58.53 C12+ 0.00 0.00 96.56 v 89.54 93.65 53.15 C20+ - - 74.92 51.96 72.67 30.84 C30+ - 51.73 25.32 50.18 15.03 C36+ - - 42.07 16.74 40.80 9.94 Molar Mass C7+ 105.48 374.45 374.33 C12+ - 399.14 399.14 C20+ - 533.67 533.67 C30+ - 756.38 756.38 C36+ - 930.00 930.00 Density C7+ - _ 0.9498 - C12+ v 0.9567 0.9567 C20+ - _ 0.9971 0.9971 C30+ 1.0578 1.0578 C36+ 1.0963 1.0963 Fluid at 60°F 0.9484 Gas Gravity(Air=1) J 0.580 Dry Gross Heat Content(BTU/scf) 1,045 Wet Gross Heat Content(BTU/scf) 1,027 OBM Contamination Level(wt°h) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 370.13 370.13 _ 930.00 Density(g/cm31 0.9484 1.096 Single Stage Flash Data Original STO De-Contaminated GOR Iscf/stb) 233 - STO Density(g/cm3) 0.9484 - STO API Gravity 17.7 - OBM Density(g/cm3)©60°F - Oilphase-DBR 12 Job#:200600071 + r Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Figure 1:Stock Tank Oil Chromatogram(Sample 1.07) Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD FI01 A,(F 2lDAT.A1 D8000711CYB616.D1 Nome, 350- JOB 200600071 CONOCO PHIILIPS 1.07 CSB 8616-QA RF FLASH CYLINDER 300- 250- 200 150- 100 41 m 50r� o m C CO mNNCO - to ,OONNNN , , 7 (0 3`Ol � U 0 CCDUCUUCUUnCUmC CCkCJcC �C1 ,. dill C2 F C O C C C C C C C •q+....,,_,,. ..s�.�___ 0 5 10 15 20 25 30 35 mir Figure 2:k-Plot for Equilibrium Check(Sample 1.07) Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD 2 •C3 1.5 •1C4 •nC4 1 •4C5 0.5 a •C6 OI 0 3 •C7 -0.5 - •C8 -1 •C9 -1.5 •C10 -4 -3 -2 -1 0 1 2 3 Oilphase-DBR 13 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 8:Summary of Results of Sample 1.07 Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD Reservoir Conditions: Pressure: 1707 psia Temperature: 79 °F Summary of Fluid Properties: OBM Contamination: - Wt%STO Basis OBM Contamination: - Wt%RF Basis Bubble Point Pressure At Tres 1,511 psia At 130°F - psia At 100°F - psia Gas-Oil Ratio Single-stage Flash: 233 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 242 scf/stb Properties at 60°F STO°API Gas Gravity(Average) Single-stage STO: 17.70 0.580 Differential Liberation STO: - - Separator STO: 17.09 0.581 Properties at Reservoir Conditions Viscosity: 81.4 cP Compressibillity(Co): 6.40 10-6/psi Density: 0.9002 g/cc Properties at Saturation Conditions Viscosity: 78.1 cP Compressibillity(Co): 6.47 10 6/psi Density: 0.8990 g/cc Formation Volume Factor @Pres&Tres @Psat&Tres Single-stage Flash: 1.086 1.088 Total Differential Liberation: - Total Separator Flash: 1.092 1.093 Note:Standard conditions are 14.696 psia and 60°F The single-stage flash of sample 1.07 was confirmed through duplicate tests. Oilphase-DBR 14 Job#:200600071 r Client ConocoPhillips Field: West Sak Well: 1 R East Sand: B&A3 Schlumberger PVT Analysis on Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 79.0°F and at a pressure of 12,031 psia.Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 9.The pressure-volume(P-V)plots of the CCE data are presented in Figure 3. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint.For the subject fluid,the bubblepoint was determined to be 1,511 psia at the reservoir temperature of 79.0 °F. Also, calculated relative volume and oil compressibility is presented in Table 9. As seen in the table,the compressibility of this oil is 6.5 x 10e-61/psia at the saturation pressure. Table 9:Constant Composition Expansion at 79.0°F(Sample 1.07) Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD Pressure Relative Vol 510 Liquid %Liquid Liquid Density Y Function Compressibility (psia) (Vr=V/Vsat) (VI/Vsat) (Vl/Vtotal) (g/cm3) (10-6/psia) 1 12031 0.9523 95.2 100.0 0.9441 3.2 2 11011 0.9555 95.5 100.0 0.9409 3.4 3 10015 0.9589 95.9 100.0 0.9376 3.7 4 9015 0.9625 96.2 100.0 0.9341 3.9 5 8015 0.9664 96.6 100.0 0.9303 42 6 7517 0.9685 96.8 100.0 0.9283 4.3 7 7015 0.9706 97.1 100.0 0.9263 4.5 8 6015 0.9751 97.5 100.0 0.9220 4.8 9 5515 0.9775 97.7 100.0 0.9197 5.0 10 5282 0.9786 97.9 100.0 0.9187 5.0 11 5082 0.9796 98.0 100.0 0.9177 5.1 12 4880 0.9806 98.1 100.0 0.9168 5.2 13 4651 0.9818 98.2 100.0 0.9157 5.3 14 4445 0.9829 98.3 100.0 0.9147 5.3 15 4053 0.9850 98.5 100.0 0.9127 5.5 16 3685 0.9870 98.7 100.0 0.9109 5.6 17 3062 0.9905 99.1 100.0 0.9076 5.8 18 2517 0.9937 99.4 100.0 0.9047 6.1 19 2012 0.9968 99.7 100.0 0.9019 6.3 Pi 1707 0.9987 99.9 100.0 0.9002 6.4 Pb 1511 1.0000 100.0 100.0 0.8990 6.5 22 1445 1.0135 99.5 98.2 3.4 23 1344 1.0374 98.9 95.3 3.3 24 1237 1.0682 98.2 91.9 3.3 25 1034 1.1474 97.1 84.6 3.1 26 830 1.2741 95.9 75.3 3.0 27 631 1.4910 94.9 63.6 2.8 Oilphase-DBR 15 Job 11:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Figure 3:Constant Composition Expansion at 79.0°F-Relative Volume Sample 1.07;Cylinder CSB 8616-0A;Depth 7369 ft.MD 1.6 1.5 0 1.4 a 1.3 0 E 1.2 - o > 0 • W 0 00 1.1 — • • 1 0 ••• • • •• •••••• • • • • • • • • 0.9 0.8 . 0 2000 4000 6000 8000 10000 12000 14000 Pressurelpsia) Oilphase-DBR 16 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 18 East Sand: B&A3 Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 79°F.These values as a function of selected pressure steps are summarized in Table 10.The liquid phase viscosity values are graphically presented in Figure 4.As seen in the figures and as expected,the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 10:Reservoir Fluid Viscosity 79°F Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD Pressure Viscosity @ Tres (psis) (cP) 1 10010 313.90 2 9001 268.07 3 8007 227.88 4 7009 194.01 5 6010 165.27 6 5001 139.82 7 4005 119.09 8 3001 100.87 9 2010 92.05 Pi 1707 86.01 Pb 1511 84.05 12 1320 106.00 13 1037 145.23 15 760 220.54 STO 14.7 665.00 Oilphase-DBR 17 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Figure 4:Reservoir Fluid Viscosity 79°F Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD 100 • 600 - 500 - Et: 400 - u T 41 - f 300 - - - _ • •• 200 - - . . . . 100 . - - - 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Pressurelpsia) Oilphase-DBR 18 Job#:200600071 ! f Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 11 - 13. The fluid properties (i.e., GOR, density and oil formation volume factor)are presented in Table 11.Multi-stage separation test conditions are: STAGE 1 105 psia 125°F STAGE 2 75 psia 185°F STAGE STO 14.7 psia 60°F As seen in Table 11,the GOR value obtained from the multi-stage separation test is 242 SCF/STB and the formation volume factor is 1.093.The compositional analyses of separator gas and tank gas are summarized in Table 12 and the composition of tank liquid is tabulated in Table 13. The total dry gross heat content of the separation gases is calculated to be 1,046 BTU/scf whereas the total wet gross heat content is calculated to be 1,028 BTU/scf. Oilphase-DBR 19 Job N:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 11:Multi-Stage Separation Test Vapor&Liquid Properties Sample 1.07;Cylinder CSB 8616-0A;Depth 7369 ft.MD PROPERTY STAGE Pb STAGE 1 STAGE2 STAGE STO Pressurelpsia) 1511 105 75 14.7 Temperature(CF) 79 125 185 60 Liq.Den(g/cm3) 0.8993 0.9377 0.9307 0.9523 yap.Gravity' 0.579 0.630 0.652 Vap.M,,,,t 16.77 18.25 18.90 Vap Heat Val." 1043 1121 1149 GOR` 233 6 3 GORd 229 6 3 Sep.FVF' 1.093 1.017 1.024 1.000 a)Calculated,at 60°F(air=1) b)Calculated,Dry basis BTU/scf c)scf gas/bbl of oil at STD conditions d)scf gas/bbl of oil at separator conditions e)fluid volume at sep conditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9523 g/cc Sep gas gravity(average) Sg=ERjSgj/ERj 0.581 Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages Sep gas gross heating value(all..=ERi'ki/ER1 1046 BTU/scf(dry basis) Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages ITSEPARATION TEST SUMMARY otal Separation Test GOR 242 Separation Test STO Gravity 17.09 Separation Test FVF 1.093 a)scf gas/bbl of condensate at STD conditions b)Fluid volume at Psat&Tres/Fluid volume at STD Oilphase-DBR 20 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 12:Multi-Stage Separator Test Vapor Composition(mol%) Sample 1.07;Cylinder CSB 8616-QA; Depth 7369 ft.MD Component MW Mole (g/mol) STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.13 0.12 0.49 Hydrogen Sulfide 34.08 0.00 0.00 0.00 Nitrogen 28.01 0.28 0.37 0.27 Methane 16.04 97.60 93.06 90.01 Ethane 30.07 0.79 2.20 4.09 Propane 44.10 0.36 1.35 1.63 I-Butane 58.12 0.29 1.26 2.05 N-Butane 58.12 0.11 0.60 0.39 I-Pentane 72.15 0.14 0.54 0.64 N-Pentane 72.15 0.18 0.06 0.29 C6 84.00 0.06 0.22 0.12 M-C-Pentane 84.16 0.00 0.03 0.00 Benzene 78.11 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.02 0.00 C7 96.00 0.01 0.10 0.00 M-C-Hexane 98.19 0.00 0.02 0.00 Toluene 92.14 0.05 0.01 0.01 C8 107.00 0.00 0.03 0.00 E-Benzene 106.17 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0-Xylene 106.17 0.00 0.00 0.00 C9 121.00 0.00 0.00 0.00 C10 134.00 0.00 0.00 0.00 CII 147.00 0.00 0.00 0.00 C12 161.00 0.00 0.00 0.00 C13 175.00 0.00 0.00 0.00 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0.00 0.00 , C29 382.00 0.00 0.00 0.00 C30+ 762.77 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 16.77 18.25 18.90 Relative Density(air=1) 0.579 0.630 0.652 Dry Gross Heat Content(BTU/scf) 1043 1121 1149 Oilphase-DBR 21 Job#:200600071 Client ConocoPhillips field: West Sak Schlumberger Well: 1R East Sand: B&A3 Table 13:Multi-Stage Separator Test Residual Liquid Composition(mol%) Sample 1.07;Cylinder CSB 8616-QA;Depth 7369 ft.MD COMPONENT MW Residual Liquid (g/mol) (mol%) Carbon Dioxide 44.01 0.00 Hydrogen Sulfide 34.08 0.00 Nitrogen 28.01 0.00 Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.07 I-Butane 58.12 0.42 N-Butane 58.12 0.07 I-Pentane 72.15 0.51 N-Pentane 72.15 0.06 C6 84.00 0.64 M-C-Pentane 84.16 0.02 Benzene 78.11 0.03 Cyclohexane 84.16 0.03 C7 96.00 0.56 M-C-Hexane 98.19 0.04 Toluene 92.14 0.08 C8 107.00 1.06 E-Benzene 106.17 0.10 M/P-Xylene 106.17 0.02 0-Xylene 106.17 0.04 C9 121.00 1.15 C10 134.00 2.17 C11 147.00 2.88 C12 161.00 3.69 C13 175.00 4.43 C14 190.00 4.77 C15 206.00 5.07 C16 222.00 4.83 C17 237.00 4.75 C18 251.00 4.59 C19 263.00 4.36 C20 275.00 3.67 C21 291.00 3.72 C22 300.00 3.40 C23 312.00 2.90 C24 324.00 2.45 C25 337.00 2.54 C26 349.00 2.68 C27 360.00 2.16 C28 372.00 2.10 C29 382.00 2.12 C30+ 762.77 25.82 Total 100.00 MW 376.68 Oilphase-DBR 22 Job#:200000011 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 14:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.09) Sample 1.09;Cylinder SSB 13728-QA;Depth 7369 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.32 0.12 0.00 0.00 0.01 0.04 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.68 0.41 0.00 0.00 0.01 0.13 Methane 16.04 90.87 96.51 0.00 0.00 1.94 31.03 Ethane 30.07 2.30 1.31 0.00 0.00 0.05 0.42 Propane 44.10 1.15 0.45 0.01 0.12 0.04 0.23 I-Butane 58.12 2.16 0.63 0.04 0.27 0.09 0.39 N-Butane 58.12 0.40 0.12 0.01 0.09 0.02 0.10 I-Pentane 72.15 1.13 0.27 0.08 0.40 0.10 0.36 N-Pentane 72.15 0.14 0.03 0.01 0.06 0.01 0.05 C6 84.00 0.41 0.08 0.14 0.62 0.15 0.45 M-C-Pentane 84.16 0.01 0.00 0.01 0.03 0.01 0.02 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.04 0.01 0.03 C7 96.00 0.16 0.03 0.18 0.68 0.18 0.47 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.03 Toluene 92.14 0.01 0.00 0.01 0.06 0.01 0.04 C8 107.00 0.11 0.02 0.31 1.06 0.30 0.73 E-Benzene 106.17 0.00 0.00 0.03 0.09 0.03 0.06 M/P-Xylene 106.17 0.00 0.00 0.01 0.02 0.01 0.01 O-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.03 C9 121.00 0.06 0.01 0.47 1.45 0.47 0.99 C10 134.00 0.02 0.00 0.90 2.50 0.89 1.70 C11 147.00 0.01 0.00 1.32 3.33 1.29 2.26 C12 161.00 0.01 0.00 1.78 4.09 1.74 2.77 C13 175.00 0.00 0.00 2.11 4.47 2.07 3.03 C14 190.00 0.00 0.00 2.60 5.06 2.54 3.43 C15 206.00 0.00 0.00 3.08 5.53 3.01 3.75 C16 222.00 2.99 4.99 2.93 3.39 C17 237.00 2.96 4.62 2.89 3.14 C18 251.00 3.04 4.49 2.98 3.05 C19 263.00 3.08 4.34 3.01 2.94 C20 275.00 2.85 3.84 2.79 2.60 C21 291.00 2.70 3.43 2.64 2.33 C22 300.00 2.59 3.20 2.54 2.17 C23 312.00 2.43 2.89 2.38 1.96 C24 324.00 2.31 2.64 2.26 1.79 C25 337.00 2.19 2.40 2.14 1.63 C26 349.00 1.96 2.08 1.92 1.41 C27 360.00 2.03 2.09 1.99 1.42 C28 372.00 1.99 1.99 1.95 1.35 C29 382.00 1.98 1.92 1.94 1.30 C30 394.00 1.83 1.72 1.79 1.17 C31 404.00 1.83 1.68 1.79 1.14 C32 415.00 1.82 1.62 1.78 1.10 C33 426.00 1.45 1.26 1.42 0.86 C34 437.00 1.37 1.16 1.34 0.79 C35 445.00 1.24 1.03 1.21 0.70 C36+ 945.00 42.22 16.54 41.32 11.22 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.04 370.25 256.70 MOLE RATIO 0.3215 0.6785 Oilphase-DBR 23 Job t.200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Table 15:Calculated Fluid Properties Sample 1.09;Cylinder SSB 13728-QA; Depth 7369 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.43 0.07 99.70 98.44 97.58 66.82 C12+ 0.01 0.00 96.42 89.07 94.37 60.43 C20+ - - 74.78 51.48 73.19 i 34.93 C30+ - - 51.75 25.01 50.64 16.97 C36+ - - 42.22 16.54 41.32 11.22 Molar Mass C7+ 104.19 i 374.98 i 374.89 C12+ i 163.78 400.84 400.83 C20+ - _ 537.88 537.88 C30+ - _ 766.20 766.20 C36+ 945.00 945.00 Density C7+ - _ 0.9530 - C12+ - _ 0.9604 0.9604 C20+ - _ 1.0023 1.0023 C30+ _ 1.0659 1.0659 C36+ 1.1064 1.1064 Fluid at 60°F 0.9515 Gas Gravity(Air=1) 0 588 Dry Gross Heat Content(BTU/scf) 1,056 Wet Gross Heat Content(BTU/scf) 1,037 OBM Contamination Level(wt°7o) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 370.25 370.25 945.00 Density(g/cm3) 0 9515 - 1.106 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 162 - STO Density(g/cm3) i 0.9515 - STO API Gravity 17.2 - OBM Density(g/cm3)@60°F - Oilphase-DBR 24 Job#:200600071 l t Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Figure 5:Stock Tank Oil Chromatogram(Sample 1.09) Sample 1.09;Cylinder SSB 13728-0A; Depth 7369 ft.MD F101 A, FClDAT000800071\CY172 Norm. n 350- JOB 200600071 CONOCO PHILLIPS 1.09 SSB 13728-QA • RF FLASH CYLINDER 300 250- 200- • 1507 100- Y1 ID Od 0 [ c o INN ( yNC - "MN`NN50- 10'1 N UUUUUUU 1 ccccccc �cUcyMJ U° x0UU ccc ccccc 1c2 c oc c "1 � • n 0 5 10 15 20 25 30 35 mir Figure 6:k-Plot for Equilibrium Check(Sample 1.09) Sample 1.09;Cylinder SSB 13728-DA;Depth 7369 ft.MD 2 •C3 1.5 • Ca •nC4 1 •c5 0 0.5 •C6 3 0 •C7 0.5 •C8 - -1 •Ca -1.5 -4 -3 -2 -1 0 1 2 3 F Oilphase-DBR 25 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Table 16:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.10) Sample 1.10;Cylinder SSB 12120-QA;Depth 7369 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/molel WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.30 0.12 0.00 0.00 0.01 0.04 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 !Nitrogen 28.01 0.45 0.27 0.00 0.00 0.01 0.10 Methane 16.04 92.62 97.23 0.00 0.00 2.35 35.34 'Ethane 30.07 2.00 1.12 0.00 0.00 0.05 0.41 Propane 44.10 0.86 0.33 0.02 0.19 0.04 0.24 I-Butane 58.12 1.59 0.46 0.05 0.33 0.09 0.38 N-Butane 58.12 0.30 0.09 0.01 0.09 0.02 0.09 I-Pentane 72.15 0.89 0.21 0.09 0.45 0.11 0.36 N-Pentane 72.15 0.10 0.02 0.01 0.06 0.01 0.05 C6 84.00 0.36 0.07 0.14 0.63 0.15 0.43 M-C-Pentane 84.16 0.01 0.00 0.01 0.03 0.01 0.02 Benzene 78.11 0.01 0.00 0.01 0.04 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.04 0.01 0.03 C7 96.00 0.15 0.03 0.18 0.71 0.180.46 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.03 Toluene 92.14 0.01 0.00 0.02 0.07 0.02 0.04 C8 107.00 0.11 0.02 0.33 1.13 0.32 0.73 E-Benzene 106.17 0.00 0.00 0.03 0.10 0.03 0.06 M/P-Xylene 106.17 0.00 0.00 0.01 0.02 0.01 0.01 O-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.03 C9 121.00 0.09 0.01 0.51 1.55 0.50 0.99 C10 134.00 0.07 0.01 0.90 2.49 0.88 1.59 C11 147.00 0.04 0.00 1.33 3.34 1.30 2.13 C12 161.00 0.02 0.00 1.77 4.07 1.73 2.59 C13 175.00 0.00 0.00 2.25 4.74 2.19 3.02 C14 190.00 0.00 0.00 2.56 4.97 2.49 3.16 C15 206.00 0.00 0.00 2.89 5.17 2.81 3.29 C16 222.00 3.08 5.12 3.00 3.26 C17 237.00 2.92 4.54 2.84 2.89 C18 251.00 3.09 4.54 3.01 2.89 C19 263.00 3.01 4.23 2.94 2.69 C20 275.00 2.81 3.76 2.73 2.40 C21 291.00 2.69 3.41 2.62 2.17 C22 300.00 2.60 3.20 2.54 2.04 C23 312.00 2.35 2.78 2.29 1.77 C24 324.00 2.28 2.60 2.22 1.65 C25 337.00 2.21 2.42 2.15 1.54 C26 349.00 1.95 2.06 1.90 1.31 C27 360.00 2.01 2.06 1.95 1.31 C28 372.00 1.97 1.95 1.92 1.24 C29 382.00 1.96 1.89 1.91 1.20 C30 394.00 1.97 1.85 1.92 1.18 C31 404.00 1.94 1.78 1.89 1.13 C32 415.00 1.54 1.37 1.50 0.87 C33 426.00 1.53 1.33 1.49 0.85 C34 437.00 1.32 1.11 1.29 0.71 C35 445.00 1.33 1.10 1.30 0.70 C36+ 940.00 42.30 16.61 41.23 10.57 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.84 369.05 241.03 MOLE RATIO 0.3635 0.6365 Oilphase-DBR 26 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 17:Calculated Fluid Properties Sample 1.10;Cylinder SSB 12120-QA;Depth 7369 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 0.53 0.08 99.67 _ 98.25 97.15 62.57 C12+ 0.02 0.00 96.31 88.65 93.87 56.43 C20+ - - 74.75 51.27 72.85 32.63 C30+ - - 51.94 25.15 50.62 16.01 - C36+ - - 42.30 16.61 41.23 10.57 Molar Mass C7+ 110.15 374.38 374.25 C12+ 163.11 400.95 400.95 C20+ - 538.05 538.05 _ C30+ - 762.29 762.29 C36+ - 940.00 940.00 Density C7+ - 0.9522 - _ C12+ - 0.9598 0.9598 C20+ - 1.0013 1.0013 C30+ 1.0634 1.0634 C36+ 1.1034 1.1034 Fluid at 60°F 0.9505 Gas Gravity(Air=1) 0.582 I Dry Gross Heat Content(BTU/scf) 1,048 Wet Gross Heat Content(BTU/scf) 1,030 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 369.05 369.05 940.00 Density(g/cm3) 0.9505 - 1.103 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 196 - STO Density(g/cm3) 0.9505 - STO API Gravity 17.4 - OBM Density(g/cm3)0360°F - Oilphase-DBR 27 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Figure 7:Stock Tank Oil Chromatogram(Sample 1.10) Sample 1.10;Cylinder SSB 12120-QA;Depth 7369 ft.MD R61 A,ff12\DAT0006000111CY12120.D1 Noim. 350- 0 JOB 200600071 CONOCO PHILLIPS 1.10 SSB 12120-QA RF FLASH CYLINDER 300- 250- • 200- 150: 1M 50- 100- 0 m mhmmo,NmvotchoD a, 1 NC c m N (n NNNNNNNnt`1 50 v U U U U ODUUUU OODOUCLU) tgalu U° o U U U U 0 c c c c ccccccccccccccc • 0 6 10 15 20 25 30 35 mir Figure 8:k-Plot for Equilibrium Check(Sample 1.10) Sample 1.10;Cylinder SSB 12120-QA;Depth 7369 ft.MD 2 1.5- •C3 •iC4 •nC4 1 •R45 a 0.5 •CU/�6 OI J 0 •C7 0.5 •C8 -1 •C9 •C10 -1 5 - --------- -4 -3 -2 -1 0 1 2 3 F Oilphase-DBR 28 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 18:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.11) Sample 1.11;Cylinder SSB 13916-QA;Depth 7369 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.23 0.09 0.00 0.00 0.01 • 0.04 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.76 0.45 0.00 0.00 0.03 0.22 Methane 16.04 93.75 97.78 0.00 0.00 3.84 47.39 Ethane 30.07 1.46 0.81 0.00 0.00 0.06 0.39 Propane 44.10 0.52 0.20 0.01 0.12 0.04 0.16 I-Butane 58.12 0.90 0.26 0.04 0.27 0.08 0.26 N-Butane 58.12 0.17 0.05 0.01 0.09 0.02 0.07 I-Pentane 72.15 0.49 0.11 0.08 0.40 0.10 0.26 N-Pentane 72.15 0.07 0.02 0.01 0.06 0.01 0.04 C6 84.00 0.24 0.05 0.14 0.62 0.15 0.34 M-C-Pentane 84.16 0.01 0.00 0.01 0.03 0.01 0.01 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.04 0.01 0.02 C7 96.00 0.13 0.02 0.18 0.68 0.18 0.36 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.02 Toluene 92.14 0.01 0.00 0.01 0.06 0.01 0.03 CB 107.00 0.16 0.03 0.31 1.06 0.30 0.56 E-Benzene 106.17 0.00 0.00 0.03 0.09 0.03 0.05 M/P-Xylene 106.17 0.00 0.00 0.01 0.02 0.01 0.01 O-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.02 C9 121.00 0.18 0.02 0.48 1.45 0.47 0.76 C10 134.00 0.42 0.05 0.91 2.50 0.89 1.32 C11 147.00 0.34 0.04 1.33 3.33 1.29 1.74 C12 161.00 0.13 0.01 1.79 4.09 1.72 2.12 C13 175.00 0.00 0.00 2.13 4.48 2.04 2.31 C14 190.00 0.00 0.00 2.62 5.07 2.51 2.61 C15 206.00 0.00 0.00 3.10 5.54 2.97 2.85 C16 222.00 3.01 5.00 2.89 2.58 C17 237.00 2.98 4.63 2.86 2.38 C18 251.00 3.06 4.49 2.94 2.32 C19 263.00 3.10 4.34 2.97 2.24 C20 275.00 2.87 3.84 2.75 1.98 C21 291.00 2.72 3.44 2.61 1.77 C22 300.00 2.61 3.21 2.51 1.65 C23 312.00 2.45 2.89 2.35 1.49 C24 324.00 2.33 2.64 2.23 1.36 C25 337.00 2.20 2.41 2.11 1.24 C26 349.00 1.97 2.08 1.89 1.07 C27 360.00 2.05 2.09 1.96 1.08 C28 372.00 2.01 1.99 1.93 1.02 C29 382.00 2.00 1.92 1.91 0.99 C30 394.00 1.84 1.72 1.77 0.89 C31 404.00 1.84 1.68 1.77 0.87 C32 415.00 1.83 1.62 1.75 0.84 C33 426.00 1.46 1.27 1.40 0.65 C34 437.00 1.38 1.16 1.32 0.60 C35 445.00 1.24 1.03 1.19 0.53 C36+ 937.00 41.81 16.43 40.09 8.47 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.73 368.15 197.84 MOLE RATIO 0.4846 0.5154 Oilphase-DBR 29 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 19:Calculated Fluid Properties Sample 1.11;Cylinder SSB 13916-QA;Depth 1369 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 1.41 0.19 99.70 98.44 95.67 _ 50.82 C12+ 0.13 0.01 96.40 89.05 92.45 45.90 C20+ - - 74.61 51.41 71.55 26.50 C30+ - - 51.41 24.90 49.30 12.83 C36+ - - 41.81 16.43 40.09 8.47 Molar Mass C7+ 126.89 372.85 372.42 C12+ 161.08 398.52 398.49 C20+ - _ 534.24 534.24 C30+ - 759.94 759.94 C36+ - 937.00 937.00 Density C7+ - 0.9554 - C12+ - 0.9630 0.9630 C20+ - 1.0064 1.0064 C30+ 1.0735 1.0735 C36+ 1.1173 1.1173 Fluid at 60°F 0.9539 Gas Gravity(Air=1) 0.578 Dry Gross Heat Content IBTU/scf) 1,040 Wet Gross Heat Content IBTU/scf) 1,022 OBM Contamination Level(wt%) STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW _ 368.15 368.15 937.00 Density(g/cm3) 0.9539 1.117 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) _ 324 - STO Density Ig/cm31 _ 0.9539 - STO API Gravity 16.8 - OBM Density(g/cm3)©60°F - Oilphase-DBR 30 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Figure 9:Stock Tank Oil Chromatogram(Sample 1.11) Sample 1.11;Cylinder SSB 13916-0A;Depth 7369 ft.MD FIM A,(F`%NATA�3010071C,13915 Dl Norm.7 7 • 350- JOB 200600071 CONOCO PHILLIPS 1.11 SSB 13916-QA RF FLASH CYLINDER 300- 250 200 150 100- r<OW ID m a b mPN=ANN\�� m N t7 r � z c� t~� 2 m (3 o o c c c c C - U ccccccccccc c , a U ..,r c� ..`���ra� H A M I lig 11 f Y I 0 5 10 15 20 25 30 35 mir Figure 10:k-Plot for Equilibrium Check(Sample 1.11) Sample 1.11;Cylinder SSB 13916-DA;Depth 7369 ft.MD 1.5 •C3 •iC4 1 •nC4 • 5 0.5 S. 01 0 •C6 •C7 -0.5 •C10 •re •C9 •C11 -1 -4 -3 -2 -1 0 1 2 3 F Oilphase-DBR 31 Job 0:100600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 20:C36+Composition,GOR,°API,by Zero-Flash(Sample 1.18) Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE To Carbon Dioxide 44.01 0.22 0.09 0.00 0.00 0.01 0.03 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.31 0.21 0.00 0.00 0.01 0.07 Methane 16.04 79.00 92.75 0.00 0.00 2.66 33.04 Ethane 30.07 2.23 1.40 0.00 0.00 0.08 0.50 Propane 44.10 3.71 1.59 0.02 0.13 0.14 0.65 I-Butane 58.12 2.39 0.77 0.04 0.22 0.12 0.42 N-Butane 58.12 3.87 1.25 0.11 0.54 0.23 0.80 I-Pentane 72.15 2.25 0.59 0.17 0.72 0.24 0.67 N-Pentane 72.15 1.85 0.48 0.19 0.78 0.24 0.68 C6 84.00 1.79 0.40 0.59 2.09 0.63 1.49 M-C-Pentane 84.16 0.33 0.07 0.19 0.69 0.20 0.47 Benzene 78.11 0.03 0.01 0.02 0.09 0.02 0.06 Cyclohexane 84.16 0.27 0.06 0.23 0.81 0.23 0.55 C7 96.00 0.74 0.15 0.85 2.66 0.85 1.76 M-C-Hexane 98.19 0.27 0.05 0.48 1.47 0.48 0.97 Toluene 92.14 0.07 0.01 0.23 0.75 0.22 0.49 C8 107.00 0.38 0.07 1.39 3.90 1.36 2.53 E-Benzene 106.17 0.01 0.00 0.10 0.28 0.10 0.18 M/P-Xylene 106.17 0.02 0.00 0.31 0.88 0.30 0.57 O-Xylene 106.17 0.01 0.00 0.15 0.43 0.15 0.28 C9 121.00 0.16 0.03 1.47 3.63 1.43 2.35 C10 134.00 0.06 0.01 2.16 4.82 2.09 3.11 C11 147.00 0.02 0.00 2.17 4.42 2.10 2.84 C12 161.00 0.00 0.00 2.48 4.61 2.40 2.97 C13 175.00 0.00 0.00 2.79 4.76 2.69 3.07 C14 190.00 0.00 0.00 2.99 4.70 2.89 3.03 C15 206.00 0.00 0.00 2.84 4.12 2.74 2.65 C16 222.00 2.98 4.01 2.88 2.58 C17 237.00 2.64 3.34 2.56 2.15 C18 251.00 2.73 3.25 2.64 2.09 C19 263.00 2.75 3.13 2.66 2.01 C20 275.00 2.37 2.58 2.29 1.66 C21 291.00 2.35 2.42 2.27 1.56 C22 300.00 2.42 2.41 2.33 1.55 C23 312.00 1.92 1.84 1.86 1.19 C24 324.00 1.99 1.84 1.92 1.18 C25 337.00 1.86 1.65 1.79 1.06 C26 349.00 1.72 1.47 1.66 0.95 C27 360.00 1.76 1.46 1.70 0.94 C28 372.00 1.77 1.43 1.72 0.92 C29 382.00 1.80 1.41 1.74 0.91 C30 394.00 1.81 1.37 1.75 0.88 C31 404.00 1.47 1.09 1.42 0.70 C32 415.00 1.49 1.08 1.44 0.69 C33 426.00 1.39 0.97 1.34 0.63 C34 437.00 1.15 0.78 1.11 0.50 C35 445.00 1.37 0.92 1.32 0.59 C36+ 815.00 38.26 14.04 36.97 9.04 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.84 299.02 199.19 MOLE RATIO 0.3563 0.6437 Oilphase-DBR 32 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Table 21:Calculated Fluid Properties Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 2.38 0.46 98.88 95.52 95.63 61.65 C12+ 0.00 0.00 89.11 70.69 86.11 45.50 C20+ - - 66.91 _ 38.76 64.65 24.95 C30+ - 46.94 20.25 45.36 13.04 C36+ - - 38.26 14.04 36.97 9.04 Molar Mass C7+ 96.43 309.56 308.99 C12+ #DIV/0! 376.95 376.95 C20+ - 516.17 516.17 C30+ - 692.98 692.98 C36+ - 815.00 815.00 Density C7+ - 0.9397 - C12+ _ 0.9624 0.9624 C20+ 1.0130 1.0130 C30+ 1.0800 1.0800 C36+ 1.1251 1.1251 Fluid at 60°F 0.9347 Gas Gravity(Air=1) I 0.650 Dry Gross Heat Content(BTU/scf) 1,156 Wet Gross Heat Content(BTU/scf) 1,136 OBM Contamination Level(wt%) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Condition_s: Measured Calculated C30+Properties MW 299.02 299.02 815.00 Density(g/cm3) 0.9347 - 1.125 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 230 - STO Density(g/cm3) 0.9347 _ STO API Gravity 19.9 - OBM Density(g/cm3)©60°F - Oilphase-DBR 33 Job 0:200600071 • Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Figure 11:Stock Tank Oil Chromatogram(Sample 1.18) Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD FIDI A,(F 1210ATA+DD5000711C'fP42P D1 Notm.' 350- JOB 200600071 CONOCO PHILLIPS 1.18 CSB 7742-QA RF FLASH CYLINDER 300 250 200- 150- U ino u- U<D m 100- U a, mCm c u c n2 3 atm �C C c f N () r N h mmoinnNNNNm� 50 F c m a _ U U U(E)`-'UUUUUUUj oU U U c CC C C CCCCCCCCCCCCCC u C U c c �„, . �L- I II 1111F 1310IIIIIN I I Iglin --� 0 5 10 15 20 25 30 35 mit Figure 12:k-Plot for Equilibrium Check(Sample 1.18) Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD 2.5- -- •C3 2- •iC4 1.5- •--RCA 1 - dep "t 0.5- •-C6 Tai s o- . 1 -0.5- •-68 -1 •C9 -1.5 •C10 -2 -4 -3 -2 -1 0 1 2 3 F Oilphase-DBR 34 Job#:200600071 f Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 22:Summary of Results of Sample 1.18 Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Reservoir Conditions: Pressure: 1747 psia Temperature: 81 °F Summary of Fluid Properties: OBM Contamination: - Wt%STO Basis OBM Contamination: - Wt%RF Basis Bubble Point Pressure At Tres 1,553 psia At 130°F - psia At 100°F - psia Gas-Oil Ratio Single-stage Flash: 230 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 213 scf/stb Properties at 60°F STO°API Gas Gravity(Average) Single-stage STO: 19.89 0.650 Differential Liberation STO: - - Separator STO: 22.29 0.619 Properties at Reservoir Conditions Viscosity: 21.1 _ cP Compressibillity(Co): 5.30 _ 106/psi Density: 0.8812 g/cc Properties at Saturation Conditions Viscosity: 20.8 cP Compressibillity(Co): 5.33 10-6/psi Density: 0.8803 g/cc Formation Volume Factor @Pres&Tres @Psat&Tres Single-stage Flash: 1.098 1.099 Total Differential Liberation: - Total Separator Flash: 1.077 1.078 Note:Standard conditions are 14.696 psia and 60°F ( Oilphase-DBR 35 Job it 200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger PVT Analysis on Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 81.0°F and at a pressure of 6,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 23.The pressure-volume (P-V)plots of the CCE data are presented in Figure 13.The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,553 psia at the reservoir temperature of 81.0°F.Also,calculated relative volume and oil compressibility is presented in Table 23.As seen in the table,the compressibility of this oil is 5.3 x 10e-6 1/psia at the saturation pressure. Table 23:Constant Composition Expansion at 81.0°F(Sample 1.18) Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Pressure Relative Vol %Liquid %Liquid Liquid Density Y Function Compressibility (psia) (Vr=V/Vsat) (VI/Vsat) (VI/Vtotal) (g/cm3) (1176/psia) 1 6015 0.9774 97.7 100.0 0.9007 4.9 2 5515 0.9798 98.0 100.0 0.8984 5.0 3 5015 0.9822 98.2 100.0 0.8962 5.0 4 4015 0.9872 98.7 100.0 0.8917 5.1 5 3015 0.9923 99.2 100.0 0.8871 5.2 6 2015 0.9976 99.8 100.0 0.8825 5.3 7 1813 0.9986 99.9 100.0 0.8815 5.3 Pi 1747 0.9990 99.9 100.0 0.8812 5.3 9 1617 0.9997 100.0 100.0 0.8806 5.3 Pb 1553 1.0000 100.0 100.0 0.8803 5.3 11 1409 1.0231 99.6 97.3 4.4 12 1308 1.0434 99.3 95.2 4.3 13 1222 1.0642 99.1 93.1 4.2 14 1118 1.0948 98.8 90.2 4.1 15 1019 1.1315 98.5 87.1 4.0 16 816 1.2390 98.0 79.1 3.8 17 624 1.4191 97.5 68.7 3.6 18 515 1.5871 97.2 61.2 3.4 19 415 1.8225 96.9 53.2 3.3 Oilphase-DBR 36 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Figure 13:Constant Composition Expansion at 81.0°F-Relative Volume Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD 2.0 0 1.8 1.6 0 a O. E 1.4 • 0 m C To cc • 1.2 • • • • • 1.0 •)•, • C 0.8 0 1000 2000 3000 4000 5000 6000 7000 Pressure(psia) Oilphase-DBR 37 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 81°F.These values as a function of selected pressure steps are summarized in Table 24.The liquid phase viscosity values are graphically presented in Figure 14. As seen in the figures and as expected,the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 24:Reservoir Fluid Viscosity 81°F Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Pressure Viscosity @ Tres (psia) (cP) 1 6020 34.56 2 5026 30.88 3 4032 27.41 4 3033 24.25 5 2525 22.84 6 2016 21.64 Pi 1747 21.13 Pb 1553 20.83 9 1426 22.60 10 1301 24.80 11 1069 26.81 12 864 30.37 13 672 33.63 14 502 37.00 STO 14.696 138.40 Oilphase-DBR 38 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Figure 14:Reservoir Fluid Viscosity 81°F Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD 160 140 120 100 • 80 0 an 60 40 • • • • • • • 20 •• • • • 0 1000 2000 3000 4000 5000 6000 7000 Pressurelpsia) Oilphase-DBR 39 Job#:200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 25-27. The fluid properties(i.e., GOR, density and oil formation volume factor)are presented in Table 25.Multi-stage separation test conditions are: STAGE 1 105 psia 125°F STAGE 2 75 psia 185°F STAGE STO 14.696 psia 60°F As seen in Table 25,the GOR value obtained from the multi-stage separation test is 213 SCF/STB and the formation volume factor is 1.078.The compositional analyses of separator gas and tank gas are summarized in Table 26 and the composition of tank liquid is tabulated in Table 27. The total dry gross heat content of the separation gases is calculated to be 1,107 BTU/scf whereas the total wet gross heat content is calculated to be 1,088 BTU/scf. Oilphase-DBR 40 Job#:200600071 r Client ConocoPhillips Field: West Sak Well: 18 East Sand: B&A3 Schlumberger Table 25:Multi-Stage Separation Test Vapor&Liquid Properties Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD PROPERTY STAGE Pb STAGE 1 STAGE 2 STAGE STO Pressure(psia) 1553 105 75 14.696 Temperature(°F) 81 125 185 60 Liq.Den(g/cm3) 0.8803 0.8967 0.8874 0.9201 Vap.Gravity' 0.591 0.705 0.772 Vap.M,,,r 17.13 20.42 22.35 Vap Heat Vale 1065 1242 1344 GOR` 170 28 15 GOR" 165 27 15 Sep.FVF' 1.078 1.034 1.040 1.000 a)Calculated,at 60°F lair=1 j b)Calculated,Dry basis BTU/scf c)scf gas/bbl of oil at STD conditions dl scf gas/bbl of oil at separator conditions e)fluid volume at sep conditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9201 g/cc Sep gas gravity(average) Sg=ERjSgj/ERj 0.619 Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages Sep gas gross heating value(al Lg=ERI*L°J/ERi 1107 BTU/scf(dry basis) Where: R:GOR(scf gas/bbl of oil at STD conditions), j:separator stages SEPARATION TEST SUMMARY otal Separation Test GOR 213 I. Separation Test STO Gravity 22.29 Separation Test FVF 1.078 a)scf gas/bbl of condensate at STD conditions b)Fluid volume at Psat&Tres/Fluid volume at STD Oilphase-DBR 41 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 26:Multi-Stage Separator Test Vapor Composition(mol%) Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD Component MW Mole (g/mol) STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.07 0.13 0.19 Hydrogen Sulfide 34.08 0.00 0.00 0.00 Nitrogen 28.01 0.23 0.09 0.04 Methane 16.04 96.39 88.24 84.05 Ethane 30.07 1.28 2.39 3.60• Propane 44.10 0.79 2.57 2.90 I-Butane 58.12 0.30 1.59 2.40 N-Butane 58.12 0.41 2.30 3.37 I-Pentane 72.15 0.16 0.88 1.16 N-Pentane 72.15 0.13 1.10 1.08 C6 84.00 0.10 0.37 0.37 M-C-Pentane 84.16 0.02 0.05 0.04 Benzene 78.11 0.00 0.00 0.00 Cyclohexane 84.16 0.01 0.03 0.02 C7 96.00 0.09 0.18 0.05 M-C-Hexane 98.19 0.01 0.01 0.01 Toluene 92.14 0.00 0.02 0.09 C8 107.00 0.00 0.02 0.00 E-Benzene 106.17 0.00 0.00 0.03 M/P-Xylene 106.17 0.00 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.01 C9 121.00 0.00 0.01 0.00 C1O 134.00 0.00 0.01 0.04 C11 147.00 0.00 0.00 0.27 C12 161.00 0.00 0.00 0.27 C13 175.00 0.00 0.00 0.00 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0.00 0.00 C29 382.00 0.00 0.00 0.00 C30+ 692.98 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 17.13 20.42 22.35 Relative Density(air=1) 0.591 0.705 0.772 Dry Gross Heat Content(BTU/scf) 1065 1242 1344 Oilphase-DBR 42 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 27:Multi-Stage Separator Test Residual Liquid Composition(mol%) Sample 1.18;Cylinder CSB 7742-QA;Depth 7550 ft.MD COMPONENT MW Residual Liquid (g/mol) (mol%) Carbon Dioxide 44.01 0.00 Hydrogen Sulfide 34.08 0.00 Nitrogen 28.01 0.00 Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.46 I-Butane 58.12 0.47 N-Butane 58.12 1.01 I-Pentane 72.15 1.06 N-Pentane 72.15 1.14 C6 84.00 2.81 M-C-Pentane 84.16 0.83 Benzene 78.11 0.11 Cyclohexane 84.16 0.96 C7 96.00 3.02 M-C-Hexane 98.19 1.69 Toluene 92.14 0.90 C8 107.00 4.28 E-Benzene 106.17 0.31 M/P-Xylene 106.17 0.96 0-Xylene 106.17 0.45 C9 121.00 3.81 C10 134.00 5.14 C11 147.00 4.07 C12 161.00 4.36 C13 175.00 4.49 C14 190.00 4.46 C15 206.00 3.90 C16 222.00 3.78 C17 237.00 3.12 C18 251.00 3.06 C19 263.00 2.89 C20 275.00 2.39 C21 291.00 2.44 C22 300.00 2.22 C23 312.00 1.88 C24 324.00 1.86 C25 337.00 1.54 C26 349.00 1.12 C27 360.00 1.43 C28 372.00 1.36 C29 382.00 1.39 C30+ 702.94 18.84 Total 100.00 MW 287.60 Oilphase-DBR 43 Job k 200000071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 28:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.20) Sample 1.20;Cylinder CSB 8620-QA;Depth 7550 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid Ig/mole) WE% MOLE% WT% MOLE% WT% MOLE Carbon Dioxide 44.01 0.20 0.08 0.00 0.00 0.01 0.03 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.28 0.19 0.00 0.00 0.01 0.07 Methane 16.04 78.52 92.57 0.00 0.00 2.69 33.41 Ethane 30.07 2.23 1.41 0.00 0.00 0.08 0.51 Propane 44.10 3.78 1.62 0.03 0.20 0.16 0.71 I-Butane 58.12 2.53 0.82 0.05 0.25 0.13 0.46 N-Butane 58.12 4.10 1.33 0.12 0.62 0.26 0.87 I-Pentane 72.15 2.39 0.63 0.19 0.77 0.26 0.72 N-Pentane 72.15 1.90 0.50 0.20 0.83 0.26 0.71 C6 84.00 1.78 0.40 0.61 2.18 0.65 1.54 M-C-Pentane 84.16 0.32 0.07 0.19 0.70 0.20 0.47 Benzene 78.11 0.03 0.01 0.03 0.10 0.03 0.06 Cyclohexane 84.16 0.26 0.06 0.23 0.82 0.23 0.55 C7 96.00 0.73 0.14 0.88 2.76 0.88 1.82 M-C-Hexane 98.19 0.26 0.05 0.48 1.46 0.47 0.95 Toluene 92.14 0.06 0.01 0.22 0.70 0.21 0.45 C8 107.00 0.35 0.06 1.41 3.96 1.37 2.55 E-Benzene 106.17 0.00 0.00 0.10 0.28 0.10 0.18 M/P-Xylene 106.17 0.01 0.00 0.31 0.86 0.30 0.55 O-Xylene 106.17 0.00 0.00 0.15 0.43 0.15 0.27 C9 121.00 0.14 0.02 1.49 3.71 1.45 2.38 C10 134.00 0.08 0.01 2.19 4.92 2.12 3.15 C11 147.00 0.02 0.00 2.21 4.53 2.14 2.90 C12 161.00 0.01 0.00 2.51 4.69 2.42 3.00 C13 175.00 0.00 0.00 2.62 4.50 2.53 2.87 C14 190.00 0.00 0.00 3.15 4.99 3.05 3.19 C15 206.00 0.00 0.00 2.82 4.11 2.72 2.63 C16 222.00 2.80 3.80 2.71 2.43 C17 237.00 2.64 3.35 2.55 2.14 C18 251.00 2.60 3.12 2.51 1.99 C19 263.00 2.64 3.02 2.55 1.93 C20 275.00 2.41 2.64 2.33 1.68 C21 291.00 2.42 2.50 2.33 1.60 C22 300.00 2.33 2.33 2.25 1.49 C23 312.00 1.82 1.76 1.76 1.12 C24 324.00 1.80 1.67 1.73 1.06 C25 337.00 1.82 1.62 1.75 1.04 C26 349.00 1.69 1.46 1.63 0.93 C27 360.00 1.75 1.46 1.69 0.94 C28 372.00 1.77 1.43 1.71 0.91 C29 382.00 1.49 1.18 1.44 0.75 C30 394.00 1.53 1.17 1.47 0.74 C31 404.00 1.49 1.11 1.44 0.71 C32 415.00 1.42 1.03 1.37 0.66 C33 426.00 1.23 0.87 1.19 0.56 C34 437.00 1.06 0.73 1.02 0.47 C35 445.00 1.08 0.73 1.04 0.47 C36+ 819.50 40.04 14.69 38.67 9.39 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.91 300.70 198.99 MOLE RATIO 0.3610 0.6390 Oilphase-DBR 44 Job#:200600071 f Client ConocoPhillips Field: West Sak Well: 11=1 East Sand: B&A3 Schlumberger Table 29:Calculated Fluid Properties Sample 1.20;Cylinder CSB 8620-0A;Depth 7550 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass% Mole% Mass% Mole% C7+ 2.28 0.45 98.81 95.15 95.50 60.97 C12+ 0.01 0.00 88.92 69.92 85.87 44.68 C20+ - - 67.15 38.36 64.84 24.51 C30+ - - 47.84 20.32 46.20 12.98 C36+ - - 40.04 14.69 38.67 9.39 Molar Mass C7+ 96.64 312.26 311.69 C12+ 163.41 382.41 382.41 C20+ 526.34 526.34 C30+ 708.04 708.04 C36+ 819.50 819.50 Density C7+ - 0.9398 C12+ - 0.9628 0.9628 C20+ - 1.0126 _ 1.0126 C30+ 1.0759 1.0759 C36+ 1.1134 1.1134 Fluid at 60°F 0.9344 Gas Gravity(Air=1) I 0.653 Dry Gross Heat Content(BTU/scf) 1,160 Wet Gross Heat Content(BTU/scf) 1,140 OBM Contamination Level(wt%) - .STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 300.70 300.70 819.50 Density(g/cm3) 0.9344 - 1.113 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 233 - STO Density(g/cm3) 0.9344 - STO API Gravity 19.9 - OBM Density(g/cm3)©60°F - Oilphase-DBR 45 Job#:200600071 Client ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Figure 15:Stock Tank Oil Chromatogram(Sample 1.20) Sample 1.20;Cylinder CSB 8620-QA;Depth 7550 ft.MD 1'a iF 121DATAYIr>80007110'r'62':; Horm. 3507 JOB 200600071 CONOCO PHILLIPS 1.20 CSB 8620-QA RF FLASH CYLINDER 300- 250 202- 03 150- U m Ln 6 m U(0 u U i00- 1,';6 u mm ' rum c 0F U X Ncmem NNNUINCEMOMMID U 0NNVWNfW ` - 4 c c OF).) m• cc cc) cU UUcUccUc1c1 (Ec tcjc . I l4.. 11*wl lift IIIV A, — — 0 5 10 15 20 25 30 35 mir Figure 16:k-Plot for Equilibrium Check(Sample 1.20) Sample 1.20;Cylinder CSB 8620-QA;Depth 7550 ft.MD 2.5 2_ •C3 •iC4 1.5 •nC4 1 - nCb5 Y 0.5 •Lb a 3 0 -- --- •Cl -0.5 - •CB — •C9 15- &c10 2 -4 -3 -2 -1 0 1 2 3 Oilphase-DBR 46 Job#:200600071 1 ■ s Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 30:C30+Composition,GOR,°API,by Zero-Flash(Sample 1.21) Sample 1.21;Cylinder SSB 11875-QA;Depth 7550 ft.MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE% WT% MOLE% WT% MOLE% Carbon Dioxide 44.01 0.19 0.08 0.00 0.00 0.01 0.03 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.62 0.43 0.00 0.00 0.02 0.15 Methane 16.04 76.81 91.80 0.00 _ 0.00 2.53 32.07 Ethane 30.07 2.28 1.46 0.00 0.00 0.08 0.51 Propane 44.10 4.04 1.75 0.00 0.03 0.14 0.63 I-Butane 58.12 2.75 0.91 0.02 0.09 0.11 0.38 N-Butane 58.12 4.37 1.44 0.04 0.22 0.18 0.65 I-Pentane 72.15 2.52 0.67 0.11 0.48 0.19 0.55 N-Pentane 72.15 2.01 0.53 0.11 0.46 0.17 0.49 C6 84.00 1.86 0.43 0.51 1.82 0.55 1.33 M-C-Pentane 84.16 0.34 0.08 0.19 0.68 0.19 0.47 Benzene 78.11 0.03 0.01 0.02 0.09 0.02 0.06 Cyclohexane 84.16 0.28 0.06 0.22 0.80 0.22 0.54 C7 96.00 0.78 0.16 0.96 3.03 0.96 2.03 M-C-Hexane 98.19 0.29 0.06 0.44 1.34 0.43 0.89 Toluene 92.14 0.07 0.02 0.17 0.56 0.17 0.37 C8 107.00 0.41 0.07 1.43 4.03 1.39 2.65 E-Benzene 106.17 0.01 0.00 0.16 0.45 0.15 0.29 M/P-Xylene 106.17 0.03 0.00 0.22 0.63 0.21 0.41 O-Xylene 106.17 0.01 0.00 0.13 0.37 0.13 0.24 C9 121.00 0.19 0.03 1.64 4.10 1.59 2.68 C10 134.00 0.09 0.01 2.31 5.21 2.23 3.39 C11 147.00 0.01 0.00 2.27 _ 4.66 2.19 3.03 C12 161.00 0.00 0.00 2.63 4.93 2.54 3.21 C13 175.00 0.00 0.00 2.88 4.98 2.79 3.24 C14 190.00 0.00 0.00 2.99 4.76 2.89 3.10 C15 206.00 0.00 0.00 3.11 4.57 3.01 2.97 C16 222.00 2.94 4.00 2.84 2.61 C17 237.00 2.84 3.62 2.75 2.36 C18 251.00 2.81 3.38 2.71 2.20 C19 263.00 2.54 2.92 2.46 1.90 C20 275.00 2.56 2.81 2.47 1.83 C21 291.00 2.42 2.51 2.34 1.64 C22 300.00 2.18 2.20 2.11 1.43 C23 312.00 2.30 2.23 2.22 1.45 C24 324.00 1.69 1.58 1.64 1.03 C25 337.00 1.86 1.66 1.79 1.08 C26 349.00 1.81 1.57 1.75 1.02 C27 360.00 1.51 1.27 1.46 0.83 C28 372.00 1.60 1.30 1.55 0.85 C29 382.00 1.43 1.13 1.39 0.74 C30 394.00 1.56 1.20 1.51 0.78 C31 404.00 1.17 0.88 1.14 0.57 C32 415.00 1.33 0.97 1.28 0.63 C33 426.00 1.07 0.76 1.03 0.49 C34 437.00 1.00 0.69 0.97 0.45 C35 445.00 0.83 0.56 0.80 0.37 C36+ 836.00 39.97 14.45 38.66 9.40 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 19.17 302.25 203.37 MOLE RATIO 0.3493 0.6507 Oilphase-DBR 47 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Table 31:Calculated Fluid Properties Sample 1.21;Cylinder SSB 11875-QA;Depth 7550 ft.MD Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+Composition Mass% Mole% Mass T. Mole% Mass% Mole% C7+ 2.54 0.50 99.21 96.90 96.02 63.23 C12+ 0.00 0.00 89.05 70.95 86.12 46.17 C20+ - - 66.30 37.78 64.12 24.58 C30+ - - 46.93 19.50 45.38 12.69 C36+ - - 39.97 14.45 38.66 9.40 Molar Mass C7+ 96 96 309.45 308.86 C12+ - 379.36 379.36 C20+ - 530.47 530.47 C30+ - 727.26 727.26 • C36+ 836.00 836.00 Density C7+ 0.9384 - C12+ 0.9621 0.9621 C20+ 1.0146 1.0146 • C30+ 1.0809 1.0809 C36+ 1.1157 1.1157 Fluid at 60°F 0.9350 Gas Gravity(Air=11 0.662 Dry Gross Heat Content(BTU/scf) 1,171 Wet Gross Heat Content(BTU/scfl 1,150 OBM Contamination Level(wt°7o) - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 302.27 302.25 836.00 Density Ig/cm3) 0.9350 0.9350 1.1157 Single Stage Flash Data Original STO De-Contaminated GOR(scf/stb) 221 - STO Density Ig/cm3) 0.9350 - STO API Gravity 19.8 - OBM Density Ig/cm3)©60°F - I Oilphase-DBR 48 Job#:200600071 e t Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Figure 17:Stock Tank Oil Chromatogram(Sample 1.21) Sample 1.21;Cylinder SSB 11875-QA;Depth 7550 ft.MD FID1 A,FF @,D TA005001711C11375 01 Nol, 350, 300- JOB 200600071 CONOCO PHILLIPS 250- 1.21 SSB 11875-QA RF FLASH CYLINDER 200- 150- La U m SAO o m 100- .O u m• �m :1 0 _ c m �- ~ci Fmc at a mnmm0,-rvmalnm M( m NN0ry Ic m ccD ccC0000cWccccccc c U cccccc A1.4 t .I I .. ..01 .( 111111 eellll ixll nil I i 1I i 1.-.11 0 5 10 15 20 25 30 35 min Figure 18:k-Plot for Equilibrium Check(Sample 1.21) Sample 1.21;Cylinder SSB 11875-QA;Depth 7550 ft.MD 3.5 3 •C3 2.5 2 •nN1C4 1.5 • 5 0 1 3 0.5 .c6 0 •C7 -0.5 •C8 -1 •C9 -1.5 •Cl -2 -3 -2 -1 0 1 2 3 F Oilphase-DBR 49 Job t 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Installation: - Job 200600071 Appendix A:Nomenclature and Definitions API Gravity American Petroleum Institute gravity Bg Gas formation volume factor Bo Oil formation volume factor CCE Constant composition Expansion DV Differential Vaporization GLR Gas Liquid Ratio GOR Gas Oil Ratio LO Live Oil n Number of moles OBM Oil Based Mud P Absolute pressure Pb Bubble point pressure PV Pressure-Volume Method Pi Initial Reservoir Pressure R Universal gas constant Rs Solution gas oil ratio T Temperature V Volume Vr Relative volume STL Stock Tank Liquid STO Stock Tank Oil %,w/w Weight Percent Z Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid.Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses,densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems"by M.B.Standing Compressibility in constant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation(Gas deviation factor,Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. • A positive index indicates scaling tendencies. • A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. Oilphase-DBR 50 Job#:200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Appendix B:Molecular Weights and Densities Used Components MW Density Ig/cc) CO2 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 Cl 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-05 72.151 0.625 N-05 72.151 0.631 C6 84 0.660 MCYC-05 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 0-XYLENE 106.17 0.884 C9 121 0.768 C10 134 0.782 C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C15 206 0.836 C16 222 0.843 C17 237 0.851 C18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C29 382 0.902 Oilphase-DBR 51 Job#:200600071 r w Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Installation: - Job M: 200600071 Appendix C:EQUIPMENT fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory.Subsequently,the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies.A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer.This unit in conjunction with GC analysis(see below) provides the full fluid compositional analysis, GOR, density at sampling P&T corrected to standard conditions. The JEFRI gasometer consists of a motor-driven piston in a stationary cylinder.The piston displacement is monitored to determine the swept volume of the cylinder.The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder,which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L.The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr.The operating pressure of the Gasometer is ambient pressure(up to a maximum of 40 psia)and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer,compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography(GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector(FID). In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range,the components eluted are from C1 to C36 along with naphthenes and aromatics components. Based on the physical properties,these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas(helium)through the column.With prior knowledge of the amount of "retention"for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching"retention"times.The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns.The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas.The molecular sieve is used to achieve separation of the light gaseous components (nitrogen,oxygen,and methane)while the packed column serves to separate ethane,propane,butanes,pentanes,and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis.This column is capable of achieving separation of components up to C12+,along with the associated naphthenes and aromatics that are lumped into the C6+fraction during analysis and reporting.Components up to C4 are analyzed using a thermal conductivity detector(TCD)while the Cs+components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence,allowing for the correct separation and analysis of the injected gas. Oilphase-DBR 52 Job#:200600071 4 r Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Fluid Volumetric(PVT)and Viscosity Equipment The preliminary saturation pressure,constant composition expansion(CCE),differential vaporization(DV),multi-stage separation tests (MSST) are measured using a pressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume,visual JEFRI PVT cell.The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm.An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation.The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc.The magnetically coupled impeller mixer,mounted on the bottom end cap of the PVT cell,allow quick equilibration of the hydrocarbon fluid.The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket, which can be rotated 360°.The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven.The cell temperature is measured with a platinum resistance thermal detector(RID)and displayed on a digital indicator with an accuracy of 0.2°F.The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to±0.1%of full scale.The temperature and pressure ratings of this PVT system are 15,000 psi(103 MPa)and 360°F(182°C). The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with a high-resolution video camera that minimizes parallax in readings and uses a high- resolution encoder producing both linear and volumetric readings.The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test.The floating piston is designed in the shape of a truncated cone with gradually tapered sides,which allows measurement of extremely small volumes of liquid(0.005 cc)corresponding to roughly 0.01%of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer,which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston.Viscosity is measured by the motion of the piston,which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe.The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig.The accuracy is±1.5%of full scale for each individual piston range.The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber)with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer.The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. Oilphase-DBR 53 Job#:200600071 • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation(OHSP)due to changes in the temperature,pressure and/or composition.These fiber optic probes are mounted across the windows of the visual cell.The principle behind the measurement is based on the transmittance of a laser light in the near infra red(NIR)wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system,a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation,isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables(i.e.,temperature, pressure, solvent volume,time and transmitted light power level)are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system(LSS). High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions.The filter manifold used is rated for 10,000 psia.The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. Oilphase-DBR 54 Job#:200600071 .. Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Appendix D:PROCEDURE Fluids Preparation and Validation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid.The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids(gas and liquid)are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, a sub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature.Subsequently,a P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps.At each pressure step,the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume(with visual observation of a single or two phase condition in the cell)is measured at each pressure stage,and subsequently,a pressure-volume(P-V)plot is created identifying the phase state at each P-V condition.The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute monophasic-fluid compressibility and relative oil volumes over the entire pressure range. Differential Vaporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (DV) experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps.In these steps,the pressure is reduced below the saturation pressure,and hence,allowing the gas phase to evolve.A typical pressure stage in a DV test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the DV test. • The pressure of the fluid is then reduced to the first pressure stage(below the bubblepoint pressure)of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) • The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Oilphase-DBR 55 Job#:200600071 Client ConocoPhillips Field: West Sak Well: 1R East Sand: B&A3 Schlumberger Installation: - Job#: 200600071 Multi-Stage Separation Test Subsequent to the completion of the DV experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps,the pressure is reduced below the saturation pressure,and hence,allowing the gas phase to evolve.A typical pressure stage in a separation test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. • The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate.The pressure of the fluid is then reduced to the first pressure stage(below the bubblepoint pressure)of the separation test allowing free gas to evolve.The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into a high-pressure high-temperature electromagnetic viscometer.The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell.During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer,flashing of oil takes place, and hence,the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps.At each pressure point,the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration.The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank Oil(STO)Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase.The viscosity and density measurements are repeated for data consistency check. Oilphase-DBR 56 Job#:200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B&A3 Installation: - Job#: 200600071 Asphaltene, Wax and Sulfur Content Measurements Asphaltene content of stock-tank oil samples is conducted using the IP-143(French Institute of Petroleum)procedure. In this procedure,the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil.Wax content of the STO is measured using UOP(Universal Oil Product)46-64 procedure.The sulfur content of the STO is measured using ASTM D 2494 procedure..All other STO analysis were measured according to industrial standards. SAR(P/A Analysis A spinning band distillation was carried out on the original sample to establish two fractions.The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic(ASTM 5186-91)method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes). This method dissolves the fraction in an equal weight of toluene,then 40 volumes of pentane were added to precipitate the insoluble portion of the sample.The precipitate was filtered,dried and weighed.The solvent was removed from the soluble portion of the sample,which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates,aromatics and resins(polars)fraction by elution from a column filled with activated alumina,using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample.Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. Oilphase-DBR 57 Job it:200600071 t 9 ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2052110 Well Name/No. KUPARUK RIV UNIT 1R-EAST Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23295-00-00 MD 8075 TVD 4262 Completion Date 3/29/2006 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes `~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neutron, Dipole Sonic (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 30 8075 Open 6/27/2006 L~ Sample 5 Blu 1 6200 7654 Open 5/8/2006 Sidewall Cores CST/GR 27- Mar-2006 og Formation Tester Col 1 6600 7652 5!8/2006 Modular Dynamic ~D C .P.~s ~~l 13864 Formation Tester !,~ C Pdf 13968 Neutron ED C Pdf " 13968 Neutron ~0 C i ~ Pdf 13968 Gamma Ray C Pdf 13968 Rate of Penetration ~(~B"'~G Ase ~; ~ S 13968~iITiduction/Resistivity t Report: Final Well R 1 1-2 1-2 1-2 1-2 1-3 Formation Tester MDT/GR 25-Mar-2006 6600 7652 Open 5/8/2006 Side Wall Cores & Modular Dynamic Formation Tester MDT/GR 25-Mar-2006 191 4261 6/27/2006 DGR, CTN, ALD 25-Mar- 2006 110 8075 6/27/2006 DGR, CTN, ALD 25-Mar- 2006 191 4261 Open 6/27/2006 DGR, EWR 25-Mar-2006 110 8075 Open 6/27/2006 ROP, DGR, EWR 25-Mar- 2006 80 4480 Open 6/27/2006 ROP, RPS, RPM, GR, CALA, FCNT, RHOB 0 0 Open 7/12/2006 Final Well Report - Mudlogging Equipment & Crew, Well Details, Geological Data, Pressure/Formation Strength Data, Drilling Data, Morning Reports, and Well Logs 27-Mar-2006 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2052110 Well Name/No. KUPARUK RIV UNIT 1R-EAST Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23295-00-00 MD 8075 TVD 4262 Completion Date 3/29/2006 Completion Status P&A Current Status P&A UIC N ED C Wrd Report: Final Well R 0 0 Open 7/12/2006 **In Word Format, PDF and has Excel Graphics as well as Directional** Final ~ Well Report - Mudlogging Equipment & Crew, Well ', Details, Geological Data, Pressure/Formation Strength Data, Drilling Data, Morning Reports, • and Well Logs 27-Mar-2006 !,~ C Las 13978 ,Esumatier~cster pj y, ~ ~~ 0 0 7/12/2006 Depth TVD and LAS Data l~ 13978 Fnrm~+.en~ter X111 y~ ~ 2 Col 110 8075 Open 7/12/2006 Formation Log, MD 12-Mar- 2006 Mud Log ,~ "ED C Pdf 13978 Fo_r~atw~~fer M~"`~.- ~^'r'~ 110 8075 Open 7/12!2006 Formation Log, MD 12-Mar- ~ M' r-~ " ~" 2006 Mud Log g 13978 F s er ` 2 Col 110 4262 Open 7/12/2006 Formation Log TVD 12- Ili( C Pdf 13978 Forma ' er ~~ 110 4262 Open 7/12/2006 Mar-2006 Mud Log Formation Log TVD 12- Mar-2006 Mud Log I' Lo 13978 Mud Log 2 Col 110 8075 Open 7!12/2006 Drilling Dynamics 12-Mar- 2006 ~ '!°ED C Pdf 13978 Mud Log 110 8075 Open 7/12/2006 Drilling Dynamics 12-Mar- 2006 Log 13978 Mud Log 2 Col 110 4262 Open 7/12/2006 Drilling Dynamics ND 12- Mar-2006 ;I ~ C Pdf 13978 Mud Log 110 4262 Open 7/12/2006 Drilling Dynamics TVD 12- I Mar-2006 13978 Mud Log 2 Col 110 8075 Open 7/12/2006 Combo Log 12-Mar-2006 C Pdf 13978 Mud Log 110 8075 Open 7/12/2006 Combo Log 12-Mar-2006 ' ` L og I 13978 Mud Log 2 Col 110 4262 Open 7/12/2006 Combo Log 12-Mar-2006 I~ ND ED C Pdf 13978 Mud Log 110 4262 Open 7/12/2006 Combo Log 12-Mar-2006 / TVD og 13978 Gas Analysis 2 Col 110 4262 Open 7/12/2006 Gas Ratio 12-Mar-2006 TVD ~FD C Pdf 13978 Gas Analysis 110 4262 Open 7/12/2006 Gas Ratio 12-Mar-2006 ND C J DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 • • Permit to Drill 2052110 Well Name/No. KUPARUK RIV UNIT 1R-EAST Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23295-00-00 MD 8075 TVD 4262 Completion Date 3/29/2006 Completion Status P&A Current Status P&A UIC N , D C Pdf 13978 Gas Analysis 110 8075 Open 7/12/2006 Gas Ratio 12-Mar-2006 "'Paper Mud Log for this ', Gas Ratio Mud Log is inncorrect, it is printed out under TVD format" 14344 See Notes 0 0 Case 1/22/2007 Fluid Anal of MDT Samples, Black Oil Full I PVT Study Report Gr~D C Pdf 14344"See Notes 0 0 Case 1/22/2007 Fluid Anal of MDT Samples, Black Oil Full ', PVT Study Report Well Cores/Sam ples Information: Name ADDITIONAL INFORMATION Well Cored? r(~'' ~/ N ~ ~~`~1,4 ~~ Chips Received? Y N Analysis /~( N Received? V Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? `~L' N Formation Tops ~ N Compliance Reviewed By: _ Date: ~ ~ a~11~ - -- • • ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th avenue, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: North East West Sak(NEWS)wells- PVT and API gravity oil analysis summaries DATE: 1/17/2007 Hand delivery Transmitted: West Sak 3J-101 LO/NS 084-130 CD&Hardcopy report a 6 S-- (?5^ 3 4/3 vSchlumberger-Analysis of MDT Fluid Samples-Black Oil PVT Study Report; report 200500215; 8/25/2006; Dlsk(contains all 5 wells)and& Hardcopy report Kuparuk Labs Report of Analysis; DS 3J-1011 Produced oil ; report and spreadsheet West Sak 1Q-101 LO/NS 083-135 CD&Hardcopy report a o 5 - ViSchlumberger-Analysis of MDT Fluid Samples-Black Oil PVT Study Report; report 200500199; 3/29/2006; Disk(contains all 5 wells)and&Hardcopy report V Kuparuk Labs Report of Analysis; DS 1Q-101 Produced oil ; report and spreadsheet West Sak 1 R-East LO/NS 05-026 CD&Hardcopy report a p _alt /L,3 qe _Schlumberger-Analysis of MDT Fluid Samples-Black Oil PVT Study Report; report 200600071; 5/23/2006; Disk(contains all 5 wells)and&Hardcopy report Kuparuk Labs Report of Analysis; DS 1 R-East Produced oil ; report and spreadsheet West Sak 1H-South LO/NS 05-026 CD&Hardcopy report a Schlumberger-Analysis of MDT Fluid Samples-Black Oil PVT Study Report; report 200600089 6/30/2006; Disk(contains all 5 wells)and&Hardcopy report uparuk Labs Report of Analysis; DS 1 H-South Produced oil ; report and spreadsheet West Sak 1 H-North LO/NS 05-026 r SCD& Hardcopy report Dos--009 .-*N36/5— V Schlumberger-Analysis of MDT Fluid Samples-Black Oil PVT Study Report; report 200600050; 6/20//2006; Disk(contains all 5 wells)and&Hardcopy report Kuparuk Labs Report of Analysis; DS 1Q-101 Produced oil ; report and spreadsheet Please check off each item as received, promptly sign and return the transmittal to address below. To all data recipients:All data is confidential until State of r C release date CC: Andy A ndre.u,/PAI Geologist/ JAN ;? 2 2007 Receipt: A -- --'— Date: 2 X311 PAIS Cons.Gommisgio Anchorpve 111111111111111111111111111k GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.L emkeaConocovhillios.com i Kuparuk Laboratory Report of Analysis Report Date: 3/31/06 RECEIVED To: M. Werner JAN 2 2 zoo] pu& CAS Commission Andlaage Lab ID AB 10199 AB 10200 Sample Description 1R East 1R East WellNum 0 0 Date 03/26/06 03/26/06 Time 00:00 00:00 LocDescriptor MRSC 292/7369'MD MRSC 226/7550'MD Analysis Unit Result Result API at 60 degrees F DRY Degrees API 15.8 20.1 If there are any questions regarding this data, please call KLS at 659-7214. Completed By: TN Reviewed By: DAV s)t r tr-)'imf-'A Lui `r-/LlEI`/7I L gds- at ' 1LI3`q R I 1 R-East Sample_ID Well Sand Depth Type API GCMS-Global Curve GC-Global Cruve Comment US137501 1R-EAST UgnuC 6320 SWC 10.1 n.a. US137502 1R-EAST UgnuC 6325 SWC 11.8 n.a. Average 1R-EAST UgnuC SWC n.a. 10.9 n.a. n.a. n.a. US137504 1R-EAST UgnuB 6465 SWC 11.4 n.a. US137505 1R-EAST UgnuB 6475 SWC 11.2 n.a. US137506 1R-EAST UgnuB 6485 SWC 10.5 n.a. US137510 1R-EAST UgnuB 6567 SWC 9.9 n.a. US137512 1R-EAST UgnuB 6577 SWC 8.9 n.a. US137514 1R-EAST UgnuB 6615 SWC 8.7 n.a. US137515 1R-EAST UgnuB 6633 SWC 9.2 n.a. US137516 1R-EAST UgnuB 6637 SWC 8.8 n.a. Average 1R-EAST UgnuB SWC n.a. 9.8 n.a n.a. n.a. US137519 1R-EAST UgnuA 6759 SWC 10.2 n.a. US137521 1R-EAST UgnuA 6828 SWC 9.9 n.a. Average 1R-EAST UgnuA SWC n.a. 10.1 n.a. n.a. n.a. US137522 1R-EAST N 7030 SWC 9.89 n.a. Average 1R-East N SWC n.a. 9.9 n.a. ma. n.a. US137527 1R-EAST D 7313 SWC 14.2 n.a. Average 1R-East D SWC ma. 14.2 n.a. n.a. ma. US137528 1R-EAST B 7368 SWC 16.5 n.a. US137529 1R-EAST B 7375 SWC 15.6 n.a. US137532 1R-EAST B 7400 SWC 15.1 n.a. Average 1R-East B SWC 15.7 15.7 0.0 ma. ma. US137533 1R-EAST A4 7453 SWC 20.4 n.a. Average 1R-East A4 SWC ma. 20.4 n.a. n.a. ma. US137537 1R-EAST A3 7550 SWC 19.9 n.a. US137539 1R-EAST A3 7554 SWC 20.1 n.a. Average 1R-East A3 SWC 19.9 20.0 0.1 n.a. 11.11. US137541 1R-EAST A2 co 7626 SWC 21 n.a. US137542 1R-EAST A2 7646 SWC 20.3 n.a. US137543 1R-EAST A2 7652 SWC 21.6 n.a. Average 1R-East A2 SWC ma. 21.0 ma. n.a. ma. d Nov ConocoPhillips RECEIVED' JUL 1 2 2006 TRANSMITTAL CONFIDENTIAL DATA Alaska Oil &Gas Cons.CorrurtiSSl011 Anchorage FROM: Sandra D. Lemke,AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333. W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 1R-East Permit: 205-211 DATE: 7/11/2006 Hand carry delivery ansmitted: West Sak 1 R-East 500292329500 Report and CDROM Epoch Final Well reports Mudlogging Data- 1R-East; 3/27/2006;well data, geological data; pressure/drilling data; color mudlog prints: Formation log MD, Formation Log ND, Drilling dynamics md, drilling dynamicsTVD, Combo Log MD, Combo Log ND, Gas Ration MD, Gas Ration ND; CDROM containing morning reports,final well report, LAS data, DML data and Lithology remarks data; pdf log image files. Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients:All data is confidential until State of Alaska designated AOGCC release date CC: Andy Andreou, CPAI Geologist Receipt: Date: GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.L emke0Conocoohillips.com -r^ :4 f" - T ." ��`. r J-;„--, 0( �•_1At. WELL LOG TRANSMITTAL To: State of Alaska June 13, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1R-East, AK-MW-4263649 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1R-East: Digital Log Images 50-029-23295-00 1 CD Rom ~~1~lED JUN 2 ~ 2006 AiaSka Gii & Gas Cons. Commission Anchorage • • 18-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 R-East Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and ~`.PDF files. Tie-on Survey: 30.28' MD Window /Kickoff Survey: 8,036.00' MD (if applicable) Projected Survey: 8,075.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date o~.7~~w+~,~l~O Signed ~ _ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) o2~J ~rtlc r~ ConocoPhillips May 5, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 R-East (APD 205-211 / 306-113) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 R-East. ,~,- sty ., If you have any questions regarding this matter, please contact me at 265-6830 or Tom Brassfield at 265-6237. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad . ,; ,r; r f ~ ~..;` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOO' ~- 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ~ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^~ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: March 29, 2006 12. Permit to Drill Number: 205-211 / 306-113 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 12, 2006 13. API Number: 50-029-23295-00 4a. Location of Well (Governmental Section): Surface: 2283' FNL, 965' FEL, Sec. 15, T12N, R10E, UM 7. Date TD Reached: March 24, 2006 14. Well Name and Number: 1R-East At Top Productive Horizon: 1346' FNL, 1317' FEL, Sec. 16, T12N, R10E, UM 8. KB Elevation (ft): 30' RKB 15. FieldlPool(s): Kuparuk River Field Total Depth: 1238' FNL, 1920' FEL, Sec. 16, T12N, R10E, UM 9. Plug Back Depth (MD + ND): surface West Sak Oil Pool -Exploratory 4b. Location of Well (State Base Plane Coordinates): Surface: x- 554537 y- 5994294 ° Zone- 4 10. Total Depth (MD + ND): 8075' MD / 4262' ND~ 16. Property Designation: ADL 25636 TPI: x- 548897 y- 5995192 Zone- 4 Total Depth: x- 548293 - 5995296 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: LE931811 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2270' MD 21. Logs Run: GR/Res/Dens/Neutron, Dipole Sonic 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 63# H-40 30' 108' 30' 108' 24" 265sxAS1 9.625" 40# L-80 30' 4480' 30' 2636' 12.25" 710 sx ASlite, 160 sx LiteCRETE cement plug #1 from 7500' - 8075' cement plug #2 from 6941'-7500' cement plug #3 from 6370' - 6941' Cement retainer @ 4389' cement plug #4 from 5710'-6370' 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET none none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTANDKIND OF MATERIAL USED 6370'-6941' and 5710'-6370' 268 sx Class G each 6941'-7500' 268 sx Class G 7500'-8075' 268 sx Class G 4339'-4580' MD cement retainer has 110 sx Class G Surface to 300' 200 sx AS 1 t0 surface 26. PRODUCTION TEST Date First Production not applicable Method of Operation (Flowing, gas lift, etc.) P&A'd Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none' . ry~' ~~~ ~~~ ~ ~ 1~os I ~ 9 x t``- I ~.~ 23,06 6 y~;l , no rock description available for the side wall core because it is ? .--~~- _. being preserved as oil geochemistry samples. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE \ s- ~~. ~ 6 Q R I G E ~~/~ L t~~` ~,.rJ 2s. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 R-East Top West Sak Sand 7270' 3740' Base West Sak Sand 7948' 4177' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, P&A Summary, P&A photos 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield @ 265-6237 Printed Na R. mas Title: GKA Drillino Team Leader ,_ .1. .. r l 3' ~6 6 ' ~~ ^` Signature ~ \ one - ~-- .^ Date - ~- - INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 CortocoPhillips Alaska Operations Summary Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To '~, Hours Code 'Code Phase ' 3111 /2006 3/12/2006 14:00 - 16:00 16:00 - 17:30 17:30 - 00:00 00:00 - 01:00 01:00 - 12:00 12:00 - 14:00 14:00 - 16:30 ' 16:30 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 21:30 21:30 - 22:30 22:30 - 23:15 !.23:15 - 00:00 Page 1 of 9 Spud Date: 3/12/2006 End: Group: Description of Operations -- 2.00' MOVE - - - -- MOVE MOVE __ __ Lay liner for 1 R, spot mats on 1 R, clean up 1 H North. 1.50' MOVE MOVE j MOVE Move rig over 1 R-East, spot and level rig, berm entire rig and cuttings boxes. RIG ACCEPTED at 18:00 hrs. 6.50' WELCT NUND ~, RIGUP NU diverter stack, gun barrel and tank. 1.00 WELCTL ~ NUND RIGUP , Set mousehole and secure stack. 11.00 DRILL '.OTHR RIGUP Rack and Tally 9 5/8" casing RU handling equipment for 5", function 2.00 2.50 DRILL DRILL 0.50' DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 1.50 ~ DRILL 1.00', DRILL 0.75;. DRILL 0.75', DRILL 3/13/2006 00:00 - 12:00 I 12.001 I DRILL ~ 12:00 - 00:00 ', I 12.00'', DRILL 3/14/2006 ' 00:00 - 08:30 8.50 I DRILL 08:30 - 09:30 ~, 1.00! DRILL i '109:30 - 11:15 i 1.75', DRILL 11:15 - 11:30 0.251 RIGMNT 11:30 - 12:45 1.25 DRILL 12:45 - 00:00 11.25 DRILL 'test diverter, no leaks. PULD RIGUP 'Hold PJSM. PU & MU 12-1/4" bit, Sperry Mud Motor, float sub, stabilizer, & XO. DRLG SURFAC RIH on stand of HWDP, tag bottom at 71'. Fill conductor with water and circulate while crew did walk arounds to verify no leaks in system. Clean out conductor (cement) from 71' to shoe at 108'. Prepare to swap over to spud mud. CIRC ~ SURFAC ~ Displace to 9.2 ppg Spud Mud, clean out shakers and screens. 'DRLG SURFAC 'Drill ahead from 108' to 191' MD. TRIP SURFAC Blow dwn Top Drive and POOH for smart tools. PULD SURFAC PU MWD tools and orient. DEOT I SURFAC Up load MWD. ~ PULD !, SURFAC Cont PU and MU BHA #1. DRLG 'SURFAC Drill ahead from 191' to 26T, up wt 40K, dwn wt 40K, rot wt 40K. SURV i, SURFAC Obtain gyro survey. ;DRLG ',SURFAC , Cont drilling 12 1/4" hole from 26T to 310' MD, AST 1.05hrs, ART ,; .96hrs, ADT 2.01 hrs, jar hrs 122.48, torque on btm 1,500 ft/Ibs, torque off btm 1,000 ft/Ibs, 60 rpm, wob 12K, 150 spm at 880 psi, 450 gpm. DRLG SURFAC 'Directionally drilled 12 1/4" hole per directional plan from 310' MD to 899' MD! 886' TVD (589'), gyro surveys taken at 356', 448' and 538', up wt 63K, dwn wt 63K, rot wt 63K, 60 rpm, wob 25K, 140 spm at 920 psi, 417 gpm, torque on btm 3,000 ft/Ibs, torque off btm 1,500 ft/Ibs. ~~ DRLG I' SURFAC Directionally drilled 12 1/4" hole per directional plan from 899' MD to i 1,714' MD/ 1,468' TVD (815'), up wt 70K, dwn wt 68K, rot wt 68K, 60 rpm, wob 25K, 165 spm at 1,250 psi on btm, 1,150 off btm psi, 492 gpm, torque on btm 5,500 ft/Ibs, torque off btm 4,000 fUlbs, ART 1.74 '~ hrs, AST 7.31 hrs, ADT 9.05 hrs, 140.13 hrs on jars, mud wt 9.2 ppg. ,'DRLG i SURFAC !Directionally drilled 12 1/4" hole per directional plan from 1,714' to ' I~ i ,2,231' MD/ 1,799' TVD (60T), ART 3.76 hrs, AST 2.62 hrs, 20-25K ~ ' ~ I Iwob, 60 rpm's, 165 spm, 500 gpm, off btm pressure 1200 psi, on btm II ~, ~~ 1,400 psi, off btm torque 4,800 ft-Ibs, on btm 5,800 ft/Ibs, rot wt 69K, up ~, wt 80K, do wt 60K, base of permafrost at 2,270' MD/ 1,770 TVD. CIRC 'SURFAC Pumped 30 bbl Hi-Vis Sweep and circ clean, had very little increase in ~I cuttings back from sweep, circ at 496 gpm at 1,200 psi, rot and reciprocated pipe at 60 rpm's. ,WIPR I SURFAC ~ Monitored well-static, blow down top drive and POOH wet on elevators I ', from 2,321' to HWDP at 715' with no problems. RSRV SURFAC I Serviced top drive WIPR ,SURFAC RIH from 715' to 2,231' and washed 90' to btm at 2,321' with no ~ DRLG SURFAC problems Directionally drilled 12 1/4" hole per directional plan from 2,231' to I 3,331' MD/ 2,205' TVD (1,110'), ART 5.38 hrs, AST 2.40 hrs, ADT 7.78 ~i ' hrs, 10-35K wob, 60 rpm's, 170 spm, 506 gpm, off btm pressure 1200 ~ psi, on btm 1,500 psi, off btm torque 4,625 ft-Ibs, on btm 7,200 ft-Ibs, I I rot wt 73K, up wt 90K, do wt 60K, 154.62 hrs on jars, mud wt 9.5+ ppg, ', top of T3 at 2,687 MD/ 1,963' TVD. Pumped 20 bbl wt'd (1# over MW) ', hi vis sweep at 3,080' and had slight increase in cuttings back from Printed: 5/3/2006 1:05:52 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To ' Hours Code _I__ __- - 3/14/2006 12:45 - 00:00 11.25 DRILL 3/15!2006 ~ 00:00 - 12:00 12.00 DRILL 12:00 - 15:00 'I 3.00!.. DRILL I 15:00 - 17:00 2.00 DRILL 3/16/2006 '.17:00 - 18:15 '',18:15-22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01:00 01:00 - 03:30 1.25 DRILL 4.25' DRILL I 0.50 DRILL 1.0011 DRILL 0.50 ~ DRILL 0.501 DRILL 2.50' DRILL ~, 03:30 - 05:30 ', 2.00'1 DRILL 105:30 - 07:45 III ' 2.251 DRILL ! 07:45 - 09:45 Iii 2.00 III DRILL 09:45 - 13:00 13:00 - 14:30 '. 14:30 - 16:30 16:30 - 16:45 3.25'1. DRILL Page 2 of 9 Spud Date: 3/12/2006 End: Group: Sub ~I Phase !, Description of Operations Code_ DRLG SURFAC 'sweep ' " DRLG SURFAC hole per directional plan from 3,331 Directionally drilled 12 1/4 to 4,245' MD/ 2,548' TVD (914'), ART 6.53 hrs, AST 1.52 hrs, ADT 8.05 hrs, 20-25K wob, 60 rpm's, 173 spm, 515 gpm, off btm pressure 1,550 psi, on btm 1,700 psi, off btm torque 5,200 ft-Ibs, on btm 8,200 ft-Ibs, ~ rot wt 76K, up wt 105K, do wt 62K, Pumped 25 bbl wt'd (2# over MW) hi ~ ' i vis sweep at 4,075' and had slight increase in cuttings back from ' 'sweep. , DRLG ',SURFAC 'Directionally drilled 12 1/4" hole per directional plan from 4,245' to 4,490' MD/ 2,640' TVD (245'), ART 1.71 hrs, AST 0.7 hrs, ADT 2.41 ',hrs, 10-20K wob, 60 rpm's, 178 spm, 530 gpm, off btm pressure 1,650 ', ', psi, on btm 1,900 psi, off btm torque 7,500 ft-Ibs, on btm 9,000 ft-Ibs, rot wt 83K, up wt 120K, do wt 55K. CIRC ~ SURFAC ~~ Circ hole for btms up sample then pumped 30 bbl wt'd (2# over MW) hi ' vis sweep at 4,490 and had a 10% increase in cuttings back from ~, ~ sweep, circ an add. btms up and was clean at the shakers, rotated at I 80 rpm's and circ at 182 spm, 550 gpm at 1,720 psi WIPR 'SURFAC II POOH wet on elevators 11 stds from 4,490' to 3,430 when began to swab with 20-30K drag !WIPR '.SURFAC 'Backreamed out of hole from 3,430' to 3,177, BROOH at 60 rpm's, 475 -,gpm at 1,250 psi, attempted to pull on elevators and hole cont. to swab, ', cont to BROOH to 1,947, hole unloaded large amount of sand, loosing 'fluid over shakers, reduce pump rate to 157 spm, 468 gpm, 1,250 psi j ;until cleaned up, cont BROOH from 1,947 to 1,733' with no more ', '~ increase in cuttings, cont POOH wet on elevators from 1,733' to 1,568' ~ ~~ OBSV SURFAC ~I with no problem. 'i Blow down Top Drive and service same while monitoring well on trip tank, well static. WIPR ~, SURFAC ' ~ RIH from 1,568' to 3,775' and string took weight, Kelly Up to wash i through tight spot. WIPR ',SURFAC I Wash down through tight spot at 3,775' with no problem, PU and run I through same area no pump with no problem. ~ WIPR ;SURFAC ' Cont RIH on elevators to 4,404', Kelly up and wash last stnd to btm ~, (4,490'), with no fill. ;CIRC ~ SURFAC ;Pump 35 bbl Hi-Wt Hi-Vis Sweep (2# over) with nut plug, had very little ii ',increase in cuttings at btm up, rot and recip 60 rpm, 160 spm, 1,300 ', I, ~ psi, 476 gpm, cont circ even mud wt in and out at 9.6 ppg, monitor well ' and well was static, blew down Top Drive, st wt up 120K, down wt 55K I ' ' TRIP SURFAC with no problem and hole ', POOH wet on elevators from 4,490 to 1,722 TRIP ~ SURFAC took proper fill, at 1,722' began to see an increase in drag up. ~, Backreamed out of hole from 1,722' to HWDP at 812', BROOH at 60 , rpm's, 160 spm, 475 gpm at 1,250 psi, circ btms up on last 2 stds and '~ hole was clean at shakers TRIP ',SURFAC 'POOH on elevators from 812' standing back HWDP, jars and std of 8" ~ ', NMFDC's, POOH & broke out bit and inspected same, bit was ' ' 4-4-wt-A-E-4-EC-TD PULD '~, SURFAC ', Downloaded MWD and LD motor, MWD and std of 8" NMFDC's and 'cleaned rig floor after wet trip 1.50 RIGMNT! RSRV 'i SURFAC 'I Slip and cut 4T of drilling line 2.00 !, CASE ; RURD I, SURFAC ',Made dummy run with 9 5/8" hanger and landing jt then RU GBR's 9 ', ', ~, ', 5/8" csg equipment with Franks fill up tool and changed out elevator ~ bales. 0.251', CASE ~', SFTY ~, SURFAC Held PJSM with rig crew and GBR hands on running of csg Printed: 5/3/2006 1:05:52 PM ConocoPhillips Alaska Operations Summary Report Page 3 of 9 Legal Well Name: 1 R-East Common Well Name: 1 R-East Spud Date: 3/12/2006 Event Name: ROT -DRILLING Start: 3/11/2006 End: Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To 'Hours !' Code Sub ,Phase 3/16/2006 i 16:45 - 18:30 3/17/2006 18:30 - 19:30 19:30 - 20:45 20:45 - 21:15 21:15 - 23:45 23:45 - 00:00 00:00 - 01:30 ;01:30-02:30 III I I I 102:30 - 05:30 ', I I I i 05:30 - 08:00 it I I I II , 108:00 - 09:15 ' Code 1.75 CASE RUNC !I SURFAC 1.00'( RIGMNT~ RGRP SURFAC 1.25!CASE !RUNC SURFAC 0.501 CASE I CIRC I SURFAC 2.50 0.25 1.50 1.00 3.00 CASE RUNC ~, SURFAC CEMEN (SURFAC CEMEN CIRC (SURFAC CEMENTRURDISURFAC CEMEN CIRC ~ISURFAC 2.50 CEMENT PUMP SURFAC I I II 1.251, CEMEN II DISP SURFAC 1.25' CEMENT RURD ',~ SURFAC i ', 09:15 - 10:30 i 10:30 - 15:15 ~1i15:15-18:30( 18:30 - 22:45 ', 22:45 - 00:00 j 3/18/2006 00:00 - 04:30 'I 04:30 - 09:30 09:30 - 12:00 4.75 WELCTL NUND 'SURFAC 3.251 WELCT NUND '...SURFAC 4.25 WELCT NUND ~I SURFAC 1.251 WELCT BOPE li SURFAC 4.50 ~ WELCTL~ BOPE i SURFAC 5.00'. WELCTL BOPE SURFAC 2.50 12:00 - 15:00 I 3.00 BOPE'SURFAC BOPE ',SURFAC Description of Operations ' MU 9 5/8" shoe track, thread locked same and circ thru same checking !float equip and ck ok, RIH to 575' with a total of 14 jts of 9 5/8", 40#, L-80, BTC csg. Repaired hydraulic leak on pipe skate. Cont RIH with 9 5/8" csg from 575' to 1,974' with no problem, getting up-dwn wt evry 20 studs. Break circ, stage pumps to 4 bpm, 260 psi, for 1,650 stks, up wt 100K, dwn wt 48K. ~ Cont RIH with 9 5/8" csg from 1,974' to 4,446' with no problem, up wt 193K, dwn wt 37K. 'Break circ at 3 bpm, 250 psi, start cond mud for cement job. Cont to circ and cond mud at 4,446' thru Franks fill up tool, circ btms up '~ staging pump rate up to 5 1/2 bpm at 420 psi, reciprocated pipe with st up wt of 195K, do wt 40K MU landing jt and FMC hanger, washed down and landed hanger with 25K do wt (block wt), MU Dowell cement head, est circ and attempted to reciprocate pipe, pulled 275K up with no movement, landed 9 5/8" csg at 4,480' with float collar at 4,404', ran 106 jts of 9 5/8", 40 ppf, L-80 BTC csg (4,442'), total flt equip and csg, 4,449'„ used 14 centralizers ', per well plan Fin circ and conditioning mud for cementing, conditioned mud from 9.6 'l ppg, 230 vis, PV 42 and YP of 44 to a mud wt out of 9.6 ppg, 55 vis, 24 PV and 17 YP, circ at 7 bpm at 450 psi, held PJSM with Dowell, ASRC I vac truck drivers, MI mud eng. and rig crew on cementing operations while circ. Dowell pump 10 bbls of CW 100 then pressure tested lines to 3,000 psi. I Pumped 40 add. bbls of CW100 flush at 8.3 ppg. Pumped 47 bbls of 10.5 ppg Mudpush with red dye at an ave 4 BPM, 150 psi. Dropped bottom plug. Mix & pump 589 bbls (710 sx) of 10.7 ppg Arcticset Lite lead cement, ave 7.4 BPM at 170 psi. followed with 68 bbls (160 sx) of DeepCete cement at 12.0 ppg and 2.47 yield, ave 5.2 bpm at 250 psi. ',shut down and dropped top plug. No reciprocation and had full returns. Dowell chased plug with 20 bbls water, rig displaced cement with 9.6 !I ppg mud, ave 7 bpm at 650 psi, slowed to 4 bpm at 500 psi and bumped plug at talc displacement, bumped plugs to 1,300 psi. ~~ Checked floats and floats held. CIP @ 09:05 hrs, Had 130 bbls of 10.7 ppg lead cement returns to surface. Had full returns throughout the job. it Blow dwn circ lines and RD cement equip, LD landing jut, RD vac equip in cellar. I, ND gun barrel and diverter stack. NU FMC casing head and test metal to metal seal at 1,000 psi for 10 'I min, test OK. NU 11" BOP, kill line, choke line and riser. ', RU and begin testing BOP's to 250 psi low and 3,000 psi high. ;While testing BOPE, found Hinge sea! on blind rams leaking, changed I, out same and fin loading 5" DP into pipe shed and strapping same I Cont to test ROPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high, blind rams would not test. Note Lou Grimaldi W/AOGCC waived witnessing of test Changed out rubber elements on blind rams and attempted to re-test 'with no success Trouble shoot leak on blind rams and determined inner seal was ',leaking, Nordic decided to swap the double shaffer on btm with the Printed: 5/3/2006 1:05:52 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date 3/18/2006 3/19/2006 From - To '~ Hours 12:00 - 15:00 15:00 - 00:00 00:00 - 13:00 ',13:00-21:30 3.00 9.00 13.00 8.50 ', 21:30 - 22:00 22:00 - 22:45 !:22:45 - 00:00 3/20/2006 '~ 00:00 - 04:15 i 04:15 - 09:00 09:00 - 09:30 109:30 - 10:15 ',10:15 - 11:45 11:45 - 13:30 0.50 0.75 1.25 4.25 Code Sub Code WELCT BOPE WELCT NUND I WELCTL NUND I Ii WELCTU BOPE II! I DRILL DRLG RIGMNT RSRV DRILL 'PULD DRILL I PULD 4.751 DRILL PULD 0.501 DRILL II CIRC 0.7511 DRILL !~ CIRC 1.50', CASE DEQT 1.75' CEMENT DSHO 13:30 - 14:00 0.50 14:00 - 16:15 ! 2.25 DRILL DRLG DRILL !CIRC 16:15 - 21:45 21:45 - 00:00 3/21 /2006 ', 00:00 - 01:30 'i 01:30 - 02:30 5.50! DRILL 'OTNR 2.25:. DRILL 'CIRC 1.50 DRILL IOTHR 1.00 DRILL LOT 02:30 - 12;00 9.501 DRILL DRLG Phase Page 4 of 9 Spud Date: 3/12/2006 End: Group: Description of Operations SURFAC Hydil double on top and install re-built single Hydril below mud cross ',SURFAC ND Diverter and set out of cellar, RD riser, disassemble 11" BOP and ~ remove from cellar. 5 Hrs Rig time, 19 Hrs Working on BOP's SURFAC Re-configured BOP stack by removing double gate hydril from below ..,.annular, NU 11" 5M stack with annular, double gate Shafer with 2 7/8" x '~ 5" VBR's on top and blind rams in the btm, mud cross and single gate Hydril with 5" pipe rams, NU riser and flowline, shell tested BOP stack to 250 psi low and 3,000 psi high, flanges check ok and repaired 1 leak on a Graylock fitting. SURFAC RU and tested ROPE, tested rams, Top Drive, valves and manifold to ', 250 psi low and 3,000 psi high, a couple of valves failed on the choke manifold and lower 5" pipe rams in the Hydril failed, had the valve group !grease the choke manifold and changed out the 5" rams in the Hydril, retested manifold and pipe rams and checked ok, tested Koomey and ~, initial pressure was 2,900 psi, pressure after closure was 1,925 psi,took 18 sec. to build 200 psi, 1 min 28 seconds for full recovery, 4- nitrogen bottle ave 1,850 psi. RD test equip, blow dwn Top Drive, kill line, choke line and manifold, set up same for drilling. NOTE: Lou Grimaldi with AOGCC waived witnessing of test. SURFAC Installed wear bushing. ~, SURFAC CO saver sub on top drive, rig up 5" DP handling equip. ~~i SURFAC I, PJSM and start MU 8 1/2" BHA. Had 2.5 hrs Rig Time, 21.5 Hrs Downtime working on 8 re-testing BOP's SURFAC ,Fin MU 8 1/2" BHA #2 RIH to 805'. MU MWD, oriented, uploaded and '~ shallow tested same, MU triple combo logging tools, held PJSM and !loaded radioactive sources, RIH with HWDP and jars to 805' SURFAC RIH with BHA #2 to 4,295', PU 111 Jts of 5" DP from pipe shed RIH with BHA SURFAC Washed down from from 4,295' to 4,390', circ down at 240 gpm at 700 psi (flt collar at 4,404') 'SURFAC Circ hole clean evening MW in and out at 9.4 ppg for csg test, circ hole ', I at 395 gpm at 1,500 psi, 30 rpm's with 9,000 ft-Ibs torque, rot wt 75K, up wt 130K, do wt 49K SURFAC ! RU and tested 9 5/8" csg to 3,000 psi for 30 min SURFAC ',Drilled out cmt plugs, float collar at 4,404', shoe track and float shoe at 4,480', cleaned out to TD at 4,490', drilled out with 5K wob, 30 rpm's, 140 spm, 410 gpm at 1,700 psi, off btm torque 8,800 ft-Ibs, on btm 9,500 ft-Ibs, rot wt 75K, up wt 100K, do wt 65K PROD I Drilled 20' of new formation from 4,490' to 4,510' MD/ 2,648' TVD PROD Circ btms up then pumped 15 bbls waterand 25 bbl hi vis Flo-Pro I sweep and displaced hole over to 9.0 ppg Flo-Pro mud, shut down with !Flo Pro at surface, circ at 146 spm, 435 gpm at 750 psi PROD !Cleaned out, flowline, pits and shakers for Flo-Pro mud. PROD RU and cont circ 290 bbls 9.0 ppg Flo-Pro off vac truck, RD truck and cont circ to shear mud at 145 spm, 660 psi, rot & recip at 25 rpm, up wt 135K, even mud wt in/out 9.0 ppg, 70 vis. Obtained SPR, blew dwn Top Drive. PROD Cleaned out suction line on #2 mud pump PROD RU and performed a LOT to 11.2 ppg EMW, 300 psi at 2,636' TVD and 9.0 PP9 MW li PROD Directionally drilled 8 1/2" hole from 4,510' to 5,167 MD/2,892' (65T) !,ART 4.22 hrs, AST 2.36 hrs, 5-10K WOB, 65 rpm's, 160 spm, 475 gpm, Printed: 5/3/2006 1:05:52 PM ConocOPhillips Alaska Operations Summary-Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours ' Code ', Sub Phase 3/21 /2006 02:30 - 12:00 Code 9.50 DRILL DRLG I PROD 12:00 - 00:00 !, 12.00' DRILL DRLG PROD 3/22/2006 00:00 - 01:00 ' 1.00 ! DRILL i DRLG PROD 01:00 - 01:30 i 0.50' RIGMNT RSRV , PROD 01:30 - 03:30 II 2.00 DRILL ~, DRLG I PROD 1 I 1 03:30 - 05:00 1.50 DRILL 'CIRC I PROD 05:00 - 06:00 '.06:00 - 07:15 07:15 - 08:45 3/23/2006 1.00 1.25 1.50 08:45 - 12:00 ' 3.25 DRILL WIPR 'PROD DRILL WIPR PROD DRILL CIRC PROD I DRILL DRLG I PROD 12:00 - 00:00 I 12.00 i DRILL !DRLG I PROD 00:00 - 02:30 02:30 - 04:00 2.50, DRILL 'DRLG I PROD I I ~I 1.50 i DRILL I CIRC ~ PROD Page 5 of 9 Spud Date: 3/12/2006 End: Group: Description of Operations off btm pressure 1,650 psi, on btm 1,700 psi, off btm torque 8,800 ft-Ibs, on btm 10,300 ft-Ibs, rot wt 80K, up wt 135K, do wt 53K, est clean hole ECD at 500 gpm, 65 rpm's with 8.9 ppg MW, 9.0 ppg Flo-Pro mud ~, ave ECD was 10.6 ppg, ave BGG 10-20 units Directionally drilled 8 1/2" hole 5,167 to 5,968' MD/3191' TVD (801') TART 6.43 hrs, AST 1.27 hrs, 5-10K WOB, 65 rpm's, 165 spm, 487 gpm, ',off btm pressure 1,650 psi, on btm 1,850 psi, off btm torque 11,300 ', ft-Ibs, on btm 10,900 ft-Ibs, While backreaming up to make corm at 5,901' torque was 15K ft-Ibs, rot wt 83K, up wt 145K, do wt 53K, 9.0 ppg Flo-Pro mud ave ECD was 10.7 ppg, ave BGG 10-30 units, 86 units max, pumped hi vis sweep at 5,380' and had a 10% increase in cuttings back from sweep. Pumped hi vis sweeps at 5,750' 8~ 5,820' with good increase in cuttings from each, followed sweeps at 5,380' and 5,820' with 290 bbls fresh 9.0 ppg Flo Pro from mud plant. Est top of UGNU C at 5,931' MD/3,176' TVD (56' Deep to Prog) Drilled 8 1/2" hole from 5,968' to 5,996' (28') ART .3 hrs, AST -0-, Galled saver sub on connection ',Changed out saver sub and LD 1 jt of 5" DP due to galled threads, PU 1 new jt of 5" DP Drilled 8 1/2" hole from 5,996' to 6,091' MD/3,237' TVD (95') when Epochs gas trap motor failed, ART .7 hrs, AST .19 hrs Pumped 25 bbl hi vis sweep while Epoch worked on gas trap motor, circ sweep out of hole, circ at 475 gpm, 1700 psi with slight increase in cuttings back from sweep i Wiped hole 10 stds from 6,091' to 5,120' while working on gas trap RIH from 5,120' to 5,380' and set down, cont RIH washing down from '~ 5,380' to btm at 6,091', saw a increase in cuttings while washing down, uncertain if setting down was from fill or drag in hole Pumped 25 bbl hi vis sweep and circ out of hole, had litte increase in 'cuttings back from sweep, circ out at 65 rpm's, 173 spm, 515 gpm at 1,950 psi, at 65 rpm's torque was 12,100 ft-Ibs 'Directionally drilled 8 1/2" hole from 6,091 to 6,315' MD/3,324' TVD (224') ART 1.47 hrs, AST .97 hrs, 5-10K WOB, 65 rpm's, 175 spm, 520 gpm, off btm pressure 1,750 psi, on btm 1,850 psi, off btm torque ,10,800 ft-Ibs, on btm 12,400 ft-Ibs, rot wt 85K, up wt 150K, do wt 50K, ~i 9.0 ppg Flo-Pro mud ave ECD was 11.0 ppg, ave BGG 80 units. Est top it of UGNU C at 5,931' MD/3,176' TVD (56' Deep to Prog) Directionally drilled 8 1/2" hole from 6,315' to 7,060' MD/3,614' TVD (745') ART 5.91 hrs, AST 1.78 hrs, 5-10K WOB, 65 rpm's, 180 spm, 536 gpm, off btm pressure 2180 psi, on btm 2260 psi, off btm torque '~ 13,900 ft-Ibs, on btm 13,500 ft-Ibs, rot wt 90K, up wt 170K, do wt 55K, 9.0 ppg Flo-Pro mud ave ECD was 10.7 ppg, ave BGG 160 units, max gas 627 units from 6,519'. Est top of UGNU B at 6,440' MD/3,368' TVD (1T High to Prog) Made 2 additions of 290 bbls new Flo-Pro last 24 hrs, at 6100' and 6480'. Started dropping angle at 6840' MD, 3514' TVD. Directionally drilled 8 1/2" hole from 7,060' to 7,226' MD/3,712' TVD (166') ART .81 hrs, AST .65 hrs, 5-10K WOB, 65 rpm's, 180 spm, 536 gpm, off btm pressure 2,200 psi, on btm 2,300 psi, off btm torque 13,900 ft-Ibs, on btm 13,500 ft-Ibs, rot wt 90K, up wt 180K, do wt 55K, 9.0 ppg Flo-Pro mud ave ECD was 10.8 ppg, ave BGG 160 units, Est top of K-13 at 7,139' MD/3,659' TVD (13' Deep to Prog), Drlg at an ave. ~, of 120'/hr ROP for logging data I~ Pumped 35 bbl hi vis sweep and circ out of hole, had a slight increase -,. Printed: 5/3/2006 1:05:52 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Contractor Name: n1433@conocophillips.com Rig Name: Nordic 3 Date f=rom - To "Hours ' Code i, Sub Phase 3/23/2006 02:30 - 04:00 i 04:00 - 05:30 105:30 - 06:15 106:15 - 10:30 ;Code!. __ 150'iDRILL '~iCIRC (PROD 1.50 DRILL 0.75 DRILL 4.25 DRILL 10:30 - 12:00 i 1.50 DRILL I I 12:00 - 00:00 ' 12.001 DRILL WIPR I PROD WIPR PROD CIRC i PROD DRLG 'PROD I DRLG PROD 3/24/2006 00:00 - 00:30 ', 0.50 DRILL I' CIRC 'PROD I ~I I 00.30 - 03.15 2.75 !DRILL i DRLG PROD 03:15 - 07:30 4.25 I DRILL CIRC I PROD Page 6 of 9 Spud Date: 3/12/2006 Start: 3/11/2006 End: Rig Release: 3/29/2006 Group: Rig Number: 3 Description of Operations ', in cuttings back from sweep, circ an add. btms up and was clean at the 'shakers, circ at 180 spm, 535 gpm at 2,300 psi, 65 rpm's with 13,800 ft-Ibs off btm torque, rot wt 90K, up wt 180K, do wt 55K Monitored well-static, POOH wet on elevators 15 stds from 7,226' to 5,800' with no problems RIH from 5,800 to btm at 7,226' with no problems Pumped 35 bbl hi vis sweep and circ out of hole, had 10% increase in ;cuttings back at btms up with slight increase in cuttings from sweep, ', circ and add. btms up while lining up vac trucks and holding PJSM on swapping out Flo-Pro mud, circ hole at 178 spm, 530 gpm at 2,200 psi, 55 rpm's at 14,000 ft-Ibs torque. Displaced hole out with 870 bbls of new 9.0 ppg Flo-Pro mud, Initial ECD was 11.0 ppg, after circ hole with new mud ECD was 10.6 ppg. MBT's in old mud was 3 and after circ new mud around MBTs were 1.25. Wiper trip gas max was 45 units ~ Directionally drilled 8 1/2" hole from 7,226' to 7,311' MD/3,765' TVD ' (85') ART .45 hrs, AST .31 hrs, 5-10K WOB, 65 rpm's, 160 spm, 480 ;.gpm, off btm pressure 1,700 psi, on btm 1,800 psi, off btm torque 'i 15,800 ft-Ibs, on btm 15,500 ft-Ibs, rot wt 90K, up wt 192K, do wt 52K, ~ 9.0 ppg Flo-Pro mud ave ECD was 10.6 ppg, ave BGG 35 units, Est top of West Sak D at 7,270' MD/3,740' TVD (2' High to Prog), Drlg at an ave. of 120'/hr ROP for logging data Directionally drilled 8 1/2" hole from 7,311' to 7,979' MD/4,197' TVD (668') ART 5.47 hrs, AST 0.60 hrs, 5-13K WOB, 65 rpm's, 186 spm, ~ 555 gpm, off btm pressure 2,480 psi, on btm 2,650 psi, off btm torque 16,300 ft-Ibs, on btm 15,375 ft-Ibs, rot wt 102K, up wt 195K, do wt 63K, ', 9.0 ppg Flo-Pro mud ave ECD was 10.9 ppg, ave BGG 30 units, max !i gas 529 from 7548'. Est tops of West Sak B at 7,365' MD/3,802' TVD (9' High to Prog), Drlg at an ave. of 120'/hr ROP for logging data, began adding 3/4 - 1 % EMI-941 lubricant for torque reduction at 7,430' , 14:45 hrs, pumped hi vis sweep at 7420', cleaned out a small amount of gravel from #2 mud pump suction valve. 23:45 hrs pumped hi-vis sweep at 7975'. Est Base West Sak 7,960' MD/4,185' TVD, projected TD at 8,075'. 'Fin circ hi vis sweep out of hole, circ out at 180 spm, 537 gpm at 2,280 'psi. Encountered high torque near base of West Sak (Projected at 7960' MD), slowing and stalling out top drive. Reciprocate & rotate pipe ',while circulating sweep out, 215K PU, 65K SO, 102K Rot Wt, 60 RPM ~ to 15 RPM, 15,500 ft-Ib to 16,000 ft-Ib Torque. No significant change in cuttings when sweep came around. Drilled 8 1!2" hole 7,979' to 8,075' MD / 4,260' TVD (T.D.) (96') ART ~ 1.04 hrs, AST 0 hrs, 5-10K WOB, 20-30 RPM, 180 spm, 537 gpm, off btm pressure 2170 psi, on btm 2280 psi, off btm torque 14,768 ft-Ibs, on btm 14,768 ft-Ibs, rot wt 100K, up wt 215K, do wt 65K, 9.25 ppg Flo-Pro mud ave ECD was 11.4 ppg, ave BGG 45 units, max gas 53 '.units, Drlg at an ave. of 120'/hr ROP for logging data and adding 1 ;EMI-941 lubricant, At base of West Sak to TD torque increased to top drive limit slowing rpm's to 20-30, circ working pipe to fin drlg to TD, MBT's and MW climbed after sweep and drlg out of sand and drlg to TD. MBT went from 2.8 to 3.2 to 3.5, MW from 9.1+ppg to 9.2+ ppg. Pumped hi vis sweep and circ hole clean, had slight increase in cuttings back from sweep, added an add. 290 bbls of new 9.0 Flo-Pro mud lower MBT's to 3.25, circ hole at 180 spm, 535 gpm at 2,200 psi, ', rotated at 20-30 rpm's at 12-14,000 ft-Ibs torque, 9.1 ppg MW in and Printed: 5/3/2006 1:05:52 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date 3/24/2006 Page 7 of 9 Spud Date: 3/12/2006 End: Group: From - To Hours Code Code '' Phase Description of Operations 03:15 - 07:30 07:30 - 07:45 07:45 - 11:00 11:00 - 12:45 12:45 - 14:45 14:45 - 17:00 17:00 - 19:45 19:45 - 22:15 4.25 DRILL CIRC PROD II out with a 10.6 ppg ECD, mixed 1 % EMI-941 lubricant into new mud in pits. 0.25 DRILL OBSV PROD Monitored well-static, blew down top drive 3.25 DRILL I, WIPR PROD ' , POOH wet on elevators from 8,075' to 4,390' with no problems and hole took talc fill (9 5/8" csg shoe at 4,480') 1.75! RIGMNTi RSRV ',PROD Changed out saver sub on top drive and serviced same, monitored well ~ on trip tank and well was static 2.00; RIGMNT RSRV PROD Slip and cut 42' of drlg line. Function test top drive, OK. 2.25 11 DRILL WIPR PROD , RIH from 4,390' to 7,980' then washed 95' to btm with no problems. 2.75 DRILL CIRC PROD ' Pumped 35 bbl hi vis sweep and circ out of hole, had a large amount of ! ,cuttings back prior to btms up and no increase in cuttings from the I sweep, circ hole at 180 spm, 540 gpm at 2,200 psi, rotated pipe on down stroke only at 50 rpm's and 15,800 ft-Ibs torque, circ 3 complete j hole volumes waiting on new Flo-Pro mud. 9.2 ppg MW in & out with I 10.7 PP9 ECD 2.50 ! DRILL I CIRC I PROD Continue circulating, adding 580 Bbls of new 9.0 ppg Flo-Pro with 1 22:15 - 22:30 0.25':, DRILL 122:30 - 00:00 I I 1.50' DRILL 3/25/2006 II 00:00 - 04:30 , 4.50 DRILL 04:30 - 08:00 3.50 DRILL II 08:00 - 08:15 I 0.25 I LOG II 08:15 - 11:15 ! LOG 3.00 11:15 - 17:30 6.25', LOG I ~~ 17:30 - 18:15 ~I'I 0.75 I LOG 'I 18:15 - 19:00 0.75 II LOG 19:00 - 23:00. 4.00 III LOG 3/26/2006 23:00 - 23:45 .23:45 - 00:00 00:00 - 00:30 00:30 - 08:45 08:45 - 09:15 0.75'' LOG 0.25''1 LOG 0.50 I LOG 8.25 LOG 0.50. LOG i EMI-941. Reduced rate to 140 SPM, 417 GPM, 1300 psi while loading !.new mud into pits. Increased rate to 175 SPM, 522 GPM, 1900 psi after new mud returned to surface. Continued circulating two hole I volumes to blend new mud into system, 9.0 ppg in & out, MBT 1.5 ppb. Torque ~ drag decreased with new mud returns, allowing rotation at 50-60 RPM up and down. Increased as mud blended into system. 195K# PU, 65K# Rot Dn at 60 RPM, circulating 175 SPM, 522 GPM, ', 1900 psi at end of circulation. OBSV PROD Monitor well-static, Break out top drive. Drop 2-5/16" hollow drift with '~ 100' slickline tail. Blow down top drive. TRIP PROD ', POOH wet on elevators from 8,075' to 5,770', SLM. Little to no extra drag, hole in good condition ~ taking proper fill. TRIP PROD ~ Cont to POOH wet from 5,770' to 172', stood back HWDP and jars, no 'problems POOH and hole took talc fill, SLM out with no corr. and retreived 2 5/16" rabbit PULD I PROD LD 2-NMFDC's, held PJSM and removed radioactive sources, downloaded MWD and LD remaining BHA, cleared rig floor SFTY ' CMPLTN Held PJSM with Schlumberger (SWS) supervisors and rig crew on DP conveyed logging operations RURD CMPLTN I RU SWS DP conveyed MDT logging tool RIH to 13T, surface tested '..tool and ck ok, RU wireline scheave DLOG CMPLTN 'RIH with SWS MDT tools on 5" DP to 6181'. Broke circulation and i , circulated briefly at 3 BPM on RIH with tools at 3061', 4479', 4949', 5422'. 127K# PU Wt, 60K# SO Wt. RURD CMPLTN MU head pin & circulating hose. Break out top single of DP stand #64 I and install SWS side entry sub. MU single on side entry sub. OTHR ;CMPLTN RIH with SWS docking head on E-line through side entry sub. E-line I I I j stopped and put backlash on SWS hoist drum. OTHR CMPLTN I Clamp E-line at side entry sub. SWS unspool approximately 1500' of I E-line to clear backlash. Respool E-line on drum. Remove E-line I I~ clamp. Worked DP about 10' every 15 to 20 minutes while SWS OTHR CMPLTN L cleared the backlash. Continue RIH with docking head on E-line. DEOT I CMPLTN DE T I Latch up docking head and test SWS MDT tools. i h li l ft O CMPLTN Fin testing MDT logging too s a er latching up w t a- ne DLOG !CMPLTN II RIH from 6,153' taking formation pressures RIH to 7,658' DLOG II CMPLTN I• POOH 3 stds from 7,658' to 7,369' Printed: 5/3/2006 1:05:52 PM ConocoPhiiiips Alaska Operations Summary Report Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date 3/26/2006 From - To 'Hours ' Code 09:15 - 13:30 ' 4.25 13:30 - 14:15 0.75 14:15 - 17:00 j 2.75 17:00 - 17:30 'i 0.50 17:30 - 20:00 2.50 20:00 - 22:00 ' 22:00 - 23:30 23:30 - 00:00 3/27/2006 00:00 - 03:00 03:00 - 05:30 ~' 05:30 - 06:00 06:00 - 10:00 ! 10:00 - 10:30 10:30 - 11:00 11:00 - 14:15 14:15 - 16:15 ' 16:15 - 17:45 ,17:45-20:15 LOG LOG LOG LOG LOG Sub 'I phase Code OTHR CMPLTN DLOG CMPLTN OTHR CMPLTN DLOG ~, CMPLTN OTHR '~, CMPLTN 2.00 LOG I DLOG 1.50' LOG + ELOG 0.50 LOG !I DLOG 3.00 LOG DLOG 2.50', LOG PULD 0.50' WELCT OTHR 4.00 WELCTL -HOPE ~~ 0.50 i WELCTL OTHR 0.50 LOG RURD 3.25 LOG ' DLOG 2.00 i LOG ELOG 1.50'x . LOG ~ DLOG 2.50 ! LOG ! OTHR CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN PROD CMPLTN CMPLTN 20:15 - 21:30 1.25 LOG 21:30 - 00:00 'i 2.50 LOG 3/28/2006 100:00 - 00:45 00:45 - 01:30 01:30 - 02:00 j 02:00 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 08:00 i 08:00 - 10:30 10:30 - 11:30 ELOG ',CMPLTN DLOG ',CMPLTN 0.75 I LOG I~ DLOG 0.75! LOG .PULD 0.50' LOG '.RURD 1.50'1 CEMEN PULD 0.501 1 CEMEN ~ RURD 1.50 , CEMENl TRIP 0.50 ~ CEMEN CIRC 2.00 ~ CEMEN .TRIP 2.50!1 CEMENTCIRC 1.001 CEMENl~PUMP CMPLTN CMPLTN CMPLTN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN Page 8 of 9 Spud Date: 3/12/2006 End: Group: Description of Operations --- __ Took MDT fluid sample in West Sak B at 7,369' RIH from 7,369' to 7,550' Took 2nd MDT sample West Sak in A-3 at 7,550' POOH from 7,550' to 7,456' ~~ Took 3rd MDT sample in West Sak A4 at 7,456' when MDT sample tool 'failed. No sample caught from A4. ' POOH to 6153', to side entry sub. Undock E-line from MDT tools. POOH with E-line. LD side entry sub. POOH from 6153' to 5600' with MDT tools on DP. Hole taking correct fill. .Continue POOH from 5600' to 136' with MDT tools on DP. Hole took I, proper fill. LD SWS MDT tools. Pulled wear bushing and installed test plug RU and tested BOPE to 250 psi low and 3,000 psi high, tested choke manifold on 3/26/06 while logging, ok'd by AOGCC, Koomey test, starting pressure 2,950 psi, after functioning rams, 1,950 psi, took 15 ';seconds to build 200 psi, 1 min 17 seconds for full recovery, 4-nitrogen 'bottles ave 1,900 psi. Received extension to testing of BOP's after logging run from Tom Maunder with AOGCC, notified Jeff Jones with ~ AOGCC of test. Pulled test plug and installed wear bushing Held PJSM and MU SWS sidewall coring logging tool RIH to 28' I RIH with SWC logging tools from 28' to 6,043', broke circ at the csg shoe and every 500' while RIH to 6,043' MU side door entry sub and RIH with SWS docking head on E-line, docked up onto logging tools and tested same RIH with SWC's and a-line from 6,043' to 7,680' ~ POOH from 7680' to to 6050' taking sidewall Cores from West Sak and ~ Ugnu. Shot 45 SWC's. (Note: Recovered 45 SWC's.) Undock E-line from SWC tools and POOH with E-line. LD side door 'entry sub & RD SWS wireline. POOH from 6050' to 1165' with SWC tools on DP. Hole taking correct 'fill. ~I POOH from 1165' t0 29' with SWS sidewall Core tools on DP. LD SWS SWC tools. (Note: Shot 45 SWC & recovered 45.) Clear SWS equipment off rig floor. RU tongs. '~, PU muleshoed joint, 3-1/2" tubing. RIH PU 37 joints of 3-1/2" tubing tail for spotting plugs. RD tubing tongs. RU to run DP. RIH with 3-1/2" tail on 5" DP. Circulate bottoms up at casing shoe at 4480', 105 SPM, 440 psi. RIH with 3-1/2" tail on DP. Break circulation every 2000'. Precautionary wash last stand to bottom. Biowdown top drive. RU 'head pin & cementing lines. 'Circulate to condition mud and hole for cementing, 100 SPM, 7.1 BPM, '...770 psi, 9.0 ppg mud in and out. PJSM with Dowell and rig crew. Prime up and test lines to 3500 psi. Pump 10 Bbls water ahead. Mix & pump 55.4 Bbls, 268 sx, 15.8 ppg Class G Cement with 0.3% D065, 0.3% D167, 0.25% S002. Follow i with 2 Bbls water. Switch to rig pump and displace with 117 Bbls of ~ mud to spot balanced plug. Break out head pin & hose, plug balanced I OK. Printed: 5/3/2006 1:05:52 PM ConocoPhillips Alaska Operations Summary Report Page 9 of 9 Legal Well Name: 1 R-East Common Well Name: 1 R-East Event Name: ROT -DRILLING Start: 3/11/2006 Contractor Name: n1433@conocophillips.com Rig Release: 3/29/2006 Rig Name: Nordic 3 Rig Number: 3 Date :From - To ' Hours 3/28/2006 111:30 - 12:30 ' 1.00 12:30 - 14:00 1.50 14:00 - 15:00 1.00 15:00 - 15:30 0.50 . 15:30 - 16:00 0.50 Spud Date: 3/12/2006 End: Group: Code 'Code ! Phase Description of Operations CEMEN ~ TRIP ABANDN POOH slow, 6 stands from 8075' to 7500'. CEMEN~CIRC ABANDN Circulate bottoms up, 102 SPM, 7.2 BPM, 750 psi. CEMEN PUMP ABANDN Spot Plug #2. 10 Bbls water ahead, 55.4 Bbls of 15.8 ppg cement (as 16:00 - 16:30 0.50 ~ C 16:30 - 17:30 ' 1.00 ~ C 17:30 - 18:00 ' 18:00 - 20:00 0.50' C 2.00 C 20:00 - 00:00 4.00 CEME 3129!2006 ' 00:00 - 00:30 !; 0.50; CEME 00:30 - 02:00 ! 1.50' ABAN i 02:00 - 03:30 ', 1.50'• CEME 03:30 - 07:00 ~ 3.50 ~~i CEME 07:00 - 07:30 i 0.50 ~~ CEME ~,I 07:30 - 08:00 0.501(( CEME 08:00 - 09:00 1.001 CEME 09:00 - 09:30 ! 0.50! CEMEN 09:30 - 10;30 ', 1.00' CEME 10:30 - 11:00 '' i 0.50! CEMEf\ 11:00 - 13:00 l 2.0011 CEMEN 13:00 - 14:00 1.00 ~ ABAND 1 i 14:00 - 15:30 1.50 CEMEN ',15:30 - 16:30 1.00 CEMEN 16:30 - 17:00 0.501 CEMEN '117:00 - 18:00 j 1.0011 CEMEN I 18:00 - 23:00 ' 5.00' ABAND 23:00 - 00:00 1.00 ,ABAND !,above), 2 Bbls water. Displace with mud using rig pump to spot 'balanced plug, OK. TRIP !ABANDN !POOH slow, 6 stands from 7500' to 6941'. PUMP !,ABANDN ',Spot Plug #3. 10 Bbls water ahead, 55.4 Bbls of 15.8 ppg cement (as '~ above), 2 Bbls water. Displace with mud using rig pump to spot balanced plug, OK. TRIP ABANDN POOH slow, 6 stands from 6941' to 6370'. PUMP ABANDN Spot Plug #4. 10 Bbls water ahead, 55.4 Bbls of 15.8 ppg cement (as above), 2 Bbls water. Displace with mud using rig pump to spot balanced plug, OK. TRIP ABANDN 'i POOH slow from 6370' to 5710'. CIRC ~ ABANDN j Drop DP wiper dart. Circulate dart through DP & tail, circulate bottoms up. (NOTE: Calculated cement plugs extend from 8075' to 5775', ', j based on 9-1 /2" average estimated hole size from MWD acoustic caliper. Added 10% excess aver 9-1/2" hole.) TRIP ABANDN POOH from 5710' to 1272'. Kept 47 stands DP in derrick. Continue POOH laying down DP. TRIP ABANDN Continue POOH LDDP from 1272' to 1180'. TRIP ABANDN RIH 6 stands HWDP. POOH LD same. TRIP ABANDN '~ RU & POOH LD 22 joints of 3-1/2" tubing tail. Stand back 5 stands for 'surface plug. TRIP ',ABANDN ' MU Baker K-1 9-5/8" cement retainer. RIH on DP to 4389'. CIRC ABANDN Break circulation and circulate at 3 BPM, 220 psi. OTHR ',,ABANDN ,Set retainer at 4389'. Set 15K# weight down on retainer to verify set, test witnessed by Jeff Jones, AOGCC Field Inspector. PUMP ABANDN ' Perform injection test, 600 psi, 3 BPM. Dowell pump 10 Bbls water, i then mix & pump 22 Bbls, 110 sx, 15.8 ppg Class G with 0.4% D065, 0.3% D167, 0.4% S002. Chase cement with 2 Bbls water. Switch to rig pump and displace with mud, 4 BPM, 990 psi, injecting. Unsting from Il retainer and drop 5 Bbls of cement on top of retainer. TRIP ABANDN I POOH 1 stand & RU to circulate. CIRC ABANDN 'Circulate bottoms up, 5 BPM, 320 psi. OTHR ABANDN !Test casing & cement retainer to 1000 psi for 10 minutes, OK. Test 'witnessed by Jeff Jones, AOGCC. TRIP ABANDN 'POOH. LD Baker running tool. TRIP 1,ABANDN I RIH 6 stands DP. POOH LD same. Pull wear bushing. TRIP ABANDN 1!i RU &RIH with 3-1/2" tubing to 500'. Spot 15 Bbls Hi-Vis pill. PUMP ABANDN '~ POOH to 300'. Dowell mix & pump 32 Bbls, 200 sx, 15.7 ppg Arctic Set ~~ I cement for surface plug, cement to surface. TRIP ABANDN POOH LD 3-1/2" tubing. OTHR ABANDN MU 8~ PU pipe to wash cement out of stack. Wash & clean out BOP !~ ~ stack and riser. NUND (ABANDN ND BOPE. RURD 'ABANDN 'Finish rigging down & prepare rig for move. Rig Released at 2400 hrs, ', ' 3/29/06. Printed: 5/3/2006 1:05:52 PM Halliburton Company • Global Report Company: ConocoPhillipsAlaska Inc. Date: 4/13/2006 Time: 10:36:05 Page: L Field: Kuparuk River Unit Co-ordinate(NE) Refc rcuce: Well: 1 R-East, True North ' Site: NEWS ICEPAD Vertical (TVD) Reference: 1 R-East: 64.9 Well: 1R-East Section (VS) Referenc e: Well (O.OON,O.OOE,279.42Azi) Wellpath: 1R-East Survey Calculation M ethod: Minimum Curvature llb: Oracle - - Survey: -- Start Date: _ , Company: Tool: - - Engineer: Tied-to: i ~, Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre '. Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 !i Site: NEWS ICEPAD ~ Site Position: Northing: 5994294.00 ft - Latitude: 70 23 42.363 N From: Map Easting: 554537.00 ft Longitude: 149 33 22.510 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.42 deg Well: 1 R-East Slot Name: Well Position: +N/-S -0.28. ft Northing: 5994293.72 ft Latitude: 70 23 42.361 N +E/-W -0.56 ft Easting : 554536.44 ft Longitude: 149 33 22.527 W Position Uncertainty: 0.00 ft ~I Wellpath: 1 R-East Drilled From: Well Ref. Point 500292329500 Tie-on Depth: 30.28 ft I Current Datum: 1 R-East: Magnetic Data: 3/9/2006 Height 64.88 ft Above System Da Declination: tum: Mean Sea Level 24.20 deg I, Field Strength: 57572 nT Mag Dip Angle: 80.86 deg i Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg - ~ I 30.28 - - L 0.00 0.00 - - 279.42 --- __ _ Survey Program for Definitive Wellpath _ ___ ___ Date: 1/17/2006 Validated: N o Version: 2 Actual From To Survey Toolcode Tool Name ft ft 90.00 264.00 1 R-East gyro (90.00-264.00) CB-GYRO-SS Camera based gyro single shot 1 291.45 8036.05 1 R-East (291 .45-8036.05) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC i Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE 'fool ft deg deg ft ft ft ft ft ft 30.28 0.00 0.00 30.28 -34.60 0.00 0.00 5994293.72 554536.44 TIE LINE 90.00 0.09 100.14 90.00 25.12 -0.01 0.05 5994293.71 554536.49 CB-GYRO-SS 171.00 0.17 289.99 171.00 106.12 0.02 0.00 5994293.74 554536.44 CB-GYRO-SS 264.00 1.83 296.07 263.98 199.10 0.72 -1.47 5994294.43 554534.97 CB-GYRO-SS 'i 291.45 2.27 291.07 291.41 226.53 1.11 -2.37 5994294.81 554534.06 MWD+IFR-AK-CAZ-SC 'I 380.86 3.41 291.73 380.71 315.83 2.73 -6.49 5994296.40 554529.93 MWD+IFR-AK-CAZ-SC 471.96 5.77 290.55 471.52 406.64 5.34 -13.30 5994298.96 554523.11 MWD+IFR-AK-CAZ-SC 563.02 7.29 289.54 561.98 497.10 8.88 -23.03 5994302.43 554513.35 MWD+IFR-AK-CAZ-SC 652.38 9.15 286.55 650.42 585.54 12.80 -35.18 5994306.26 554501.17 MWD+IFR-AK-CAZ-SC i, 740.99 14.32 284.27 737.15 672.27 17.51 -52.57 5994310.85 554483.75 MWD+IFR-AK-CAZ-SC 836.63 21.68 278.03 828.05 763.17 22.90 -81.57 5994316.03 554454.72 MWD+IFR-AK-CAZ-SC 931.54 27.53 277.71 914.31 849.43 28.30 -120.70 5994321.14 554415.55 MWD+IFR-AK-CAZ-SC 1026.40 29.43 278.64 997.69 932.81 34.74 -165.47 5994327.25 554370.74 MWD+IFR-AK-CAZ-SC ', 1121.43 34.04 277.49 1078.49 1013.61 41.72 -214.94 5994333.87 554321.22 MWD+IFR-AK-CAZ-SC 'i 1217.30 41.38 274.72 1154.28 1089.40 47.83 -273.21 5994339.56 554262.91 MWD+IFR-AK-CAZ-SC ,I 1307.71 46.74 276.39 1219.23 1154.35 53.96 -335.76 5994345.23 554200.33 MWD+IFR-AK-CAZ-SC '' 1404.41 48.32 278.22 1284.53 1219.65 63.05 -406.50 5994353.79 554129.53 MWD+IFR-AK-CAZ-SC 1499.98 52.32 280.43 1345.54 1280.66 75.00 -479.05 5994365.22 554056.90 MWD+IFR-AK-CAZ-SC i S Halliburton Company, Global Report Company: ConocoPhillipsAlaska Inc, _ Date: _ 4/13/2006 Time: 10:36:05 Page: 2 Field: Ku paruk River Unit Co-ord inate(NE) $eferencr. Well: 1 R-East, -True North Site: NEWS ICEPAD Vertica l (TVD) Reference: 1 R -East: 64.9 Well: 1 R -East Section (VS) Refere nce: Well (O.OON,O. OOE,279.42Az) W'ellpath: 1 R -East Su rvey Calculation Method: Minimum Curvature Db: Oracle Sw-ve~ JID Inct Azim TVU Sys'ND N/S E/N ___ N(ap~ ~IapE - __ Tool ft deg deg ft ft ft ft ft ft 1595.42 54.65 278 .94 1402 .33 1337 .45 87. 89 -554.65 5994377. 55 553981. 21 MWD+IFR-AK-CAZ-SC 1690.78 57.16 278 .99 1455 .78 1390 .90 100. 19 -632.65 5994389. 29 553903. 13 MWD+IFR-AK-CAZ-SC 1784.71 58.85 279. 84 1505 .55 1440 .67 113. 23 -711.24 5994401. 75 553824. 47 MWD+IFR-AK-CAZ-SC 1875.27 55.52 280. 57 1554 .62 1489 .74 126. 70 -786.13 5994414. 67 553749. 48 MWD+IFR-AK-CAZ-SC 1969.00 55.69 280. 18 1607 .56 1542 .68 140. 63 -862.21 5994428. 04 553673. 31 MWD+IFR-AK-CAZ-SC 2065.98 57.69 279. 98 1660 .82 1595 .94 154. 81 -942.00 5994441. 64 553593. 43 MWD+IFR-AK-CAZ-SC I 2161.35 58.04 280. 50 1711 .55 1646 .67 169. 17 -1021.47 5994455. 42 553513. 86 MWD+IFR-AK-CAZ-SC 2254.32 56.57 279. 69 1761 .77 1696 .89 182. 89 -1098.50 5994468. 57 553436. 74 MWD+IFR-AK-CAZ-SC ! 2348.96 61.49 278. 50 1810 .45 1745 .57 195. 69 -1178.60 5994480. 79 553356. 56 MWD+IFR-AK-CAZ-SC ', 2441.27 62.62 279. 34 1853 .71 1788 .83 208. 34 -1259.16 5994492. 85 553275. 92 MWD+IFR-AK-CAZ-SC 2538.66 64.22 278. 08 1897 .29 1832 .41 221. 52 -1345.25 5994505. 40 553189. 74 MWD+IFR-AK-CAZ-SC 2635.05 63.18 278. 97 1940 .00 1875 .12 234. 33 -1430.70 5994517. 58 553104. 20 MWD+IFR-AK-CAZ-SC ', 2731.76 65.67 277. 63 1981 .75 1916 .87 246. 91 -1517.02 5994529. 53 553017. 81 MWD+IFR-AK-CAZ-SC 2823.30 68.06 278 .48 2017 .71 1952 .83 258. 71 -1600.36 5994540. 72 552934. 39 MWD+IFR-AK-CAZ-SC 2918.65 66.77 279. 30 2054 .33 1989 .45 272. 31 -1687.33 5994553. 69 552847. 33 MWD+IFR-AK-CAZ-SC 3013.86 68.69 278. 42 2090 .41 2025 .53 285. 87 -1774.39 5994566. 61 552760. 19 MWD+IFR-AK-CAZ-SC 3107.19 69,86 280. 04 2123 .44 2058 .56 299. 88 -1860.54 5994579. 99 552673. 94 MWD+IFR-AK-CAZ-SC '~, 3202.30 68.80 280. 17 2157 .01 2092 .13 315. 49 -1948.15 5994594. 96 552586. 23 MWD+IFR-AK-CAZ-SC 3297.99 67.16 280. 30 2192 .89 2128 .01 331. 25 -2035.44 5994610. 08 552498. 83 MWD+IFR-AK-CAZ-SC 3393.07 68.83 279. 43 2228 .51 2163 .63 346. 35 -2122.29 5994624. 55 552411. 89 MWD+IFR-AK-CAZ-SC 'i 3484.86 67.78 279. 67 2262 .44 2197 .56 360. 50 -2206.39 5994638. 08 552327. 69 MWD+IFR-AK-CAZ-SC it 3579.69 68.57 279. 73 2297 .70 2232 .82 375. 33 -2293.17 5994652. 28 552240. 82 MWD+IFR-AK-CAZ-SC ~, 3675.26 67.73 279. 97 2333 .27 2268 .39 390. 51 -2380.56 5994666. 81 552153. 32 MWD+IFR-AK-CAZ-SC 3768.43 66.59 280. 29 2369 .43 2304 .55 405. 61 -2465.09 5994681. 29 552068. 70 MWD+IFR-AK-CAZ-SC 3860.74 68.64 279. 61 2404 .58 2339 .70 420. 35 -2549.15 5994695. 42 551984. 53 MWD+IFR-AK-CAZ-SC 3956.55 67.35 281. 22 2440 .48 2375 .60 436. 40 -2636.52 5994710. 84 551897. 07 MWD+IFR-AK-CAZ-SC 4050.46 69.25 280. 86 2475 .20 2410 .32 453. 11 -2722.15 5994726. 91 551811. 32 MWD+IFR-AK-CAZ-SC 4144.13 67.86 281. 59 2509 .45 2444 .57 470. 08 -2807.67 5994743. 26 551725. 69 MWD+IFR-AK-CAZ-SC 4239.66 68.40 280. 98 2545 .04 2480 .16 487. 43 -2894.61 5994759. 97 551638. 63 MWD+IFR-AK-CAZ-SC 4335.05 67.20 281. 89 2581 .08 2516 .20 504. 93 -2981.17 5994776. 84 551551. 95 MWD+IFR-AK-CAZ-SC 4422.11 68.22 280. 24 2614 .10 2549 .22 520. 39 -3060.22 5994791. 72 551472. 80 MWD+IFR-AK-CAZ-SC ~I 4492.52 67.65 279. 84 2640 .55 2575 .67 531. 76 -3124.48 5994802. 62 551408. 47 MWD+IFR-AK-CAZ-SC '. 4540.61 66.73 280. 41 2659 .19 2594 .31 539. 56 -3168.12 5994810. 10 551364. 78 MWD+IFR-AK-CAZ-SC 4635.01 64.10 280. 98 2698 .47 2633 .59 555. 48 -3252.46 5994825. 40 551280. 33 MWD+IFR-AK-CAZ-SC 4730.93 65.65 280. 49 2739 .19 2674 .31 571. 65 -3337.78 5994840. 95 551194. 90 MWD+IFR-AK-CAZ-SC II 4824.30 70.71 279. 08 2773 .89 2709 .01 586. 36 -3423.17 5994855. 04 551109. 41 MWD+IFR-AK-CAZ-SC ~, 4919.85 70.92 278. 79 2805 .29 2740 .41 600. 38 -3512.32 5994868. 40 551020. 17 MWD+IFR-AK-CAZ-SC ~i 5015.25 68.39 278. 65 2838 .45 2773 .57 613. 94 -3600.73 5994881. 31 550931. 68 MWD+IFR-AK-CAZ-SC 5110.04 69.50 278. 76 2872 .51 2807 .63 627. 33 -3688:17 5994894. 06 550844. 15 MWD+IFR-AK-CAZ-SC 5204.63 69.52 278. 48 2905 .62 2840 .74 640. 61 -3775.78 5994906. 70 550756. 46 MWD+IFR-AK-CAZ-SC ~ 5298.24 69.37 278. 62 2938 .48 2873 .60 653. 64 -3862.45 5994919. 10 550669. 70 MWD+IFR-AK-CAZ-SC 5392.71 67.49 278. 57 2973 .21 2908 .33 666. 77 -3949.32 5994931. 59 550582. 75 MWD+IFR-AK-CAZ-SC 5483.55 68.91 277. 27 3006 .95 2942 .07 678. 38 -4032.85 5994942. 60 550499. 14 MWD+IFR-AK-CAZ-SC 5579.09 68.35 277. 85 3041 .76 2976 .88 690. 09 -4121.05 5994953. 66 550410. 87 MWD+IFR-AK-CAZ-SC 5673.11 68.33 278. 30 3076 .46 3011 .58 702. 36 -4207.56 5994965. 30 550324. 27 MWD+IFR-AK-CAZ-SC ', 5768.60 68.24 277. 73 3111 .80 3046 .92 714. 73 -4295.41 5994977. 03 550236. 35 MWD+IFR-AK-CAZ-SC 5862.82 66.66 278. 46 3147 .93 3083 .05 726. 98 -4381.56 5994988. 65 550150. 12 MWD+IFR-AK-CAZ-SC 5957.01 67.24 278. 58 3184 .81 3119 .93 739. 82 -4467.27 5995000. 86 550064. 32 MWD+IFR-AK-CAZ-SC 6052.69 66.66 279. 12 3222 .27 3157 .39 753. 37 -4554.26 5995013. 77 549977. 24 MWD+IFR-AK-CAZ-SC 6147.22 68.21 278. 33 3258 .54 3193 .66 766. 60 -4640.54 5995026. 38 549890. 88 MWD+IFR-AK-CAZ-SC 'I 6242.68 67.00 277. 88 3294 .91 3230 .03 779. 05 -4727.92 5995038. 18 549803. 42 MWD+IFR-AK-CAZ-SC i, 6321.06 68.08 278. 74 3324 .85 3259 .97 789. 52 -4799.59 5995048. 13 549731. 68 MWD+IFR-AK-CAZ-SC Halliburton Company! Global Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: NEWS ICEPAD Well: 1 R-East Wcllpath: _ 1 R-East Survcv SID __ _ 1ncl Azim _ 'I'VD _ ft deg deg ft 6431. 20 69.72 278. 55 3364. 50 6525. 86 65.91 279. 23 3400. 24 6620. 73 69.82 280. 08 3435. 98 6715. 01 69.26 280. 60 3468. 94 6810. 42 67.53 281. 28 3504. 06 6895.11 65 .04 280. 36 3538.12 6997.05 62 .02 280. 01 3583.56 7092.12 56 .55 281. 06 3632.10 7185.54 52 .15 280. 82 3686.53 7281.96 49 .45 282. 88 3747.47 7372.58 49 .12 282. 10 3806.58 7468.17 49 .10 279. 93 3869.16 7562.47 51 .59 279. 16 3929.34 7655.92 51 .04 279. 90 3987.75 7751.15 50 .14 279. 35 4048.20 7846.48 49 .35 280. 83 4109.81 7929.46 48 .61 279. 01 4164.27 8036.05 47 .70 279. 74 4235.38 8075.00 47 .70 279. 74 4261.59 Date: 4/13!2006 Time: 10:36:05 Page: 3 Co-ordinate(NE} Reference: Well: 1 R-East, True North Vertical {TVD) Reference: 1 R-East: 64.9 .Section (VS) Reference: Well (O.OON,O.OOE,279.42Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Sys ~,D __ \/S E/W ft ft ft 3299.62 804.96 -4901. 17 3335.36 818.50 -4987. 76 3371.10 833.24 -5074. 37 3404.06 849.10 -5161. 27 3439.18 865.93 -5248. 36 3473.24 880.49 -5324. 51 3518.68 896.63 -5414. 32 3567.22 911.54 -5494. 64 3621.65 925.95 -5569. 16 3682.59 941.27 -5642. 28 3741.70 956.12 -5709. 34 3804,28 969.93 -5780. 26 3864.46 981.96 -5851. 85 3922.87 994.03 -5923. 79 3983.32 1006.34 -5996. 33 4044.93 1019.08 -6067. 96 4099.39 1029.87 -6129. 62 4170.50 1042.80 -6207. 96 4196.71 1047.67 -6236. 36 ---- Jtap\ MapE Tool ft ft 5995062.83 549630.00 MWD+IFR-AK-CAZ-SC 5995075.73 549543.33 MWD+IFR-AK-CAZ-SC 5995089.84 549456.61 MWD+IFR-AK-CAZ-SC 5995105.06 549369.61 MWD+IFR-AK-CAZ-SC 5995121.25 549282.41 MWD+IFR-AK-CAZ-SC 5995135.26 549206.16 MWD+IFR-AK-CAZ-SC 5995150.74 549116.25 MWD+IFR-AK-CAZ-SC 5995165.07 549035.82 MWD+IFR-AK-CAZ-SC 5995178.93 548961.21 MWD+IFR-AK-CAZ-SC 5995193.71 548887.99 MWD+IFR-AK-CAZ-SC 5995208.07 548820.83 MWD+IFR-AK-CAZ-SC 5995221.36 548749.82 MWD+IFR-AK-CAZ-SC 5995232.87 548678.15 MWD+IFR-AK-CAZ-SC 5995244.41 548606.13 MWD+IFR-AK-CAZ-SC 5995256.19 548533.51 MWD+IFR-AK-CAZ-SC 5995268.40 548461.80 MWD+IFR-AK-CAZ-SC 5995278.74 548400.06 MWD+IFR-AK-CAZ-SC 5995291.10 548321.64 MWD+IFR-AK-CAZ-SC 5995295.77. 548293.21 -PROJECTED to TD • • P&A Summary for 1 R-East 1R-East: Excavated conductor and 9 5/8 inch casing on 4/19/06. Cut off conductor and 9 5/8 inch casing 3 feet below ground level on 4/20/06 Melted ice out of 9 5/8 inch casing from 3 feet to 23 feet below ground level on 4/21/06 Cemented 9 5/8 inch casing to top of casing stub with SWS AS1. Cement top witnessed by Chuck Sheve (AOGCC) on 4/21/06 Welded identification plates on casings 4/21/06 Buried conductor and 9 5/8 inch casing with soils removed from the excavation and conductor setting process on 4/22/06. • • ~. ~, ~ w`. :' 1R ~.. +~ f:.. ~ ,~_.wa '~' d a t V ia~:M t` x w r e 'fir .. ~~ ~ ',.~' , '` ~~, -~ ;.-~a4 $' ~ ~ { `~ ~ i 4 ~ ~~ : ~ .~ ~..c #-' gam. ,'~ -- ;} '1~. ~. <o-.; ~~ • • r • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ';~t~~,s~.>~L,~, DATE: April 21, 2006 P. I. Supervisor 7 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Surface Abandonment 1 R East PTD # 205-211 Friday, April 21,2006: I traveled to the Conoco Phillips 1 R East exploratory location to inspect the casing cut off and abandonment of this well. All casing strings were cut off at approximately 4' below original ground level and all were found to be full of cement. A 3/4" thick marker plate was welded to the conductor casing with the required information bead welded to it. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the 1 R East Well and found all to be in order. Attachments: 1 R East plate.JPG 1 R East cut off. J PG • • KRU 1 R-East (ConocoPhillips) Surface Abandonment Inspection Photos from Chuck Scheve, AOGCC April 21, 2006 Casing Cut-off Marker Plate NEWS Wells Status Report 4/3/06 ,~~ ~--~~ 1R-East Well Status Report Moved rig from 1H-North to 1R-East. Accepted rig at 1800 hrs 3/11/06 and function tested the diverter. Spud 1R-East at 1700 hrs 3/12/06. Directionally drilled 12-1/4" hole to 4490' MD. Ran the 9-5/8" 40.0 ppf L-80 BTC casing to 4480' MD. Cemented with 589 bbls (710 sx) of ARCTICSET Lite lead slurry plus 68 bbls (160 sx) of DeepCRETE tail slurry. Full returns during the job, unable to reciprocate the casing, and estimated 130 bbls of 10.7 ppg slurry back to surface. ND diverter NU 11" 5000 psi BOPE stack. Unable to get the blind rams on the top set of doubles to test. Reconfigured the BOPE stack with double on top and a single on the bottom. Tested to 250 psi low and 3000 psi high-OK. PU 8-1/2" BHA, RIH to 4390' MD, tested casing to 3000 psi-OK. Drilled out shoe track, drilled 20' of new hole to 4510' MD, circulated and conditioned mud. Changed over to 9.0 ppg Flo-Pro mud system performed LOT to 11.2 ppg EMW and directionally drilled to 8075' MD and TD. Made wiper trip and RU SWS for drill pipe conveyed logging operations. RIH with drill pipe conveyed MDT tools. Obtained fluid samples in the "B" & "A" sands., Unable to obtain fluid sample from the West Sak "A4" sands- pump failed. POOH. Test BOPE's to 250 psi low & 3000 psi high-OK. PU TLC sidewall core gun and RIH. Retrieved 45 of 45 shots and RD SWS. PU 3-1/2" cement stinger and RIH for P&A plugs. Spot four bottom plugs in 575' lifts- estimated top of cement at 5775' MD. POOH. PU cement retainer, and set at 4389' MD. Weight test-OK. Pump 170' of cement below retainer and spot 50' on top (22 bbls/110 sx). Tested casing and retainer to 1000 psi for 10 minutes- witnessed by AOGCC Field Inspector. POOH and lay down setting tool. RIH with 3-/12" tubing and spot 15 bbls viscosified pill from 500' to 300' MD. Spot cement plug back to surface and flushed wellhead & BOP stack. ND BOPE stack and wellhead. Rig released to 1H-South at 2400 hrs 3/29/06. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ---~ P.I. Supervisor ~ (~ib ~~ ~i ~~~ y~~, ~,~, , FROM: Jeff Jones Petroleum Inspector DATE: March 29, 2006 SUBJECT: Plug & Abandonement 1 R East CPAI KRF /West Sak Poal 205-21~ NON- CONFIDENTIAL Section: 15 Township: 12N Range: 10E Meridian: UM Lease No.: 931811 Drilling Rig: Nordic #3 Rig Elevation: 31.1' Total Depth: 8075 MD Operator Rep.: Dink Heim Casing/Tubing Data: Conductor: 16" O.D. Shoe@ 110' MD Surface: 9 5/8" O.D. Shoe@ 4480' MD Pluaping Data: Type Plua Founded on Bottom Top of Cement Mud Weight Pressure (bottom upl of Cement De th Verified? above plug Test Applied Annulus Balanced 4559' MD 4347' MD Drillpipe tag 9.0 PPG 1000 PSI Type Plua Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface March 29, 2006: I traveled to Conoco-Phillips Alaska Inc.'s (CPAI's) KRF West Sak Pool exploration well 1 R East location to witness the placement, tag and pressure test of a cement retainer well bore segregation plug. Dink Heim was the CPAI representative for the tests today, which were performed in a safe and proficient manner. The cement retainer was run in the hole and set at 4389' MD and the drill stem was then released. The drill stem was then set back down on the retainer with 28K down weight and no movement of the retainer was observed. The drill stem was then stung back into the retainer and a circulation rate of 3 BBLS /min. @ 600 PSI was established. 16.8 BBLS of class G cement was then pumped below the retainer, the drill stem was pulled out and a 5 BBL cap of cement was laid on top of the retainer. Two stands of drill pipe were removed from the drill stem and two bottoms up were circulated. The cement plug was then pressure tested to 1000 PSI for 15 ~,~-' minutes with no pressure loss and recorded on a chart. Summary: I witnessed the placement, tag and pressure test of a cement retainer well bore segregation plug in CPAI's exploration well 1 R East. Operations were in compliance with AOGCC regulation 20 AAC 25.120. Attachments: Well bore schematic & Test Chart (2) Distribution: orig -Well File c -Operator c - DNR/DOG c -Database c - Rpt File c -Inspector Rev.:5/28/00 by L.R.G. P-A CPAI Exp 1 R East 3-29-06 JJ.xls 4!6/2006 ~ J / `d ' ~ ~ 3p ~~ ~ ~ ~ ~s ~~~®~' ~° s0 j ~; ~ ~ \~~~ ~\~\\ \ ~ O , ~ / ~~ i ~ / _ ~ ~ ~~ p '~ / ~ ~ _ __ ~~ ~, 7~ j ~ _ _, i i ~ ~ - ~ti ~~ ~\ i ~~ ~ \ ~ ' ~ // ' / ~~' ~ '~ ~' ~ /: / ~ ~ ' ~ !/ ~ ~-~--r~~~ ~ ~~, i I a~ , ~ ~ ~ $) t! O , ~ ' ~~. \ 1 ' i ~ l~ ~ 7~' 6~'/~'~ ~ ~~`~~ i' V ` ~ ~ \ 1 ~r, I i I ~ I ~ ~ ' I ~ ~ I I ~~ + i L ~~~ ~~ ~ `~ /~ \~~~/ ~+ Ii it I`~ I jl 'I , ~~\ ~~ i ~ ~ it lil ~'~ ~~ ~ ~~ ~ ~1f ~ ~ r- %Cb i 1 o -a ~ ~ i T I ~~ , ~ ~ 1 c , .~, ~ i ( I ~ ~ ~ t ~ ~ ~ ~ ~ I ~ ~ i ~ ~ ~ ~~ 1 A ~ ~ ~ ~ ~ ~ ~~ ~ jQ~s ~ ~, i i 0 / ~ i i I .-~ I ~ ~ ,~ .n ~ ~~ ® Ica ~ ~ ~~~<,%~ ~~ /~ ~ ~ ~ ~ ~~ ~ ~ ~~ r ~ ~ (yl9 ~,; ~, t ~ ~ ,--r ~% ~~/ /~®~ / ~ - ~`-- ~ ~®® _~ ~~ ~~C ~ k ~ / ~ ~ a~ ~®~~ _ f __~ /,, X ~~ sF ~~ ~ ~~ o£ sz 5 oz 5~ of ace _~=. plug der ~ , eau: =P,iC C er. 1I iuct~or: ^° set at '14Q' n~a 'I~ mast ~=~1'1~ N~rdle (~Ci~ ~ F'c~r Rl~~m30' Ffud: 9.~ t~ 9.1 pig l4i11 ~dYeight ".u~ r: Casing n~' Ces~rent fug ors toy of reta:~er per ~CGCC tugs TD t~-','<" ~urfdoe Hoie. Shoe o€ `~-;;~~" 4r; ppf L-84 8TG casing ~a ~t4G'Pr1! .~_ 263' T~ ____ Cement retainer set Est a~pro Yi~G' PY'IL -" ~-- with enough Cement pumped ~ viii a 458th' MD and 54' d~urr~~ed orr tcp. Plaid: O~riliing mud `~ mil- ~.4 to 9.7 Mpg __.~ TD 8-9 d2" hQle drilled t4 $244'>tt11~r~"s1 c' i v`D as indicated in Qirecticral iala~t Cement Flug~,a,'t across hydrocarbon bear€ng aa€tes _ frt~rn T[~ at X244' ~Ai.3 t~ 15l'a' above Ugna at B~a4' P~l?~. • TCJC est ~ 6~~i34' ~9t7- tour 554' lirts. ;: :'. ~, ~'. `~ . y ~,, ---}"~-' c~~~~oP~~1~~ ~~-East ~v€ws vu~~~ PEA Seh~ma~ic ~:as~~ - - i ~ ~ STATE OF ALASKA ~ ~vosio4 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jir:~3 i-e~~ ~adn:in.state.a>c.u~ aogc:^ pr~4d~~oe cav~ad¢~€n.state.ak.us 13:1; f~$ckenste€n :~~acn:in.state.a~.us~ Contractor: Nordic Rig No.: 3 DATE: 3/27/2006 Rig Rep.: Ron Rice Rig Phone: 659-7438 Rig Fax: 659-7566 Operator: Conoco/Phillips Alaska Op. Phone: 659-7446 Op. Fax: 659-7566 Rep.: Peter Wilson Field/Unit & Well No.: KRU/1 R-EAST PTD # 205-211 Operation: Drlg: X Workover: Explor.: X Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: 250/3000 si Annular: 250/3000 s Valves: 250/3000 si TEST DATA MISC . INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 11" P Quantity Test Resul Pipe Rams 1 2 7/8"x5" P No. Valves 12 P Lower Pipe Rams 1 5" P Manual Chokes 1 P Blind Rams 1 P Hydraulic Chokes 1 P Choke Ln. Valves 1 3 1/8" P HCR Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Kill Line Valves 1 3 1/8" P Time/Pressure Test Result Check Valve 1 NA System Pressure 2950 Pressure After Closure 1950 MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 15sec. Trip Tank P P Full Pressure Attained 1 min.17sec. Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 1900 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4.5 Hours Components tested Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at:~ re~~~~~adrr:in.state.a>i.us Remarks: Change out low torque valve that isolates test pump from BOP components being tested. Low torque valve is not part of BOP system. 24 HOUR NOTICE GIVEN YES x NO Waived By Jeff Jones Date 03/26/06 Time 15:00 Witness Rice/VVilson Test start 6:00 Finish 10:30 BOP Test (for rigs) BFL 11/09/04 BOP Test Nordic 3-03-27-06.x1s BOP Extension on CPAI 1 R-East ~' Subject: BOP Extension on CPAI 1R-East From: "Nordic 3 Company Man" <n1433@conocophillipscoin=~ Date: Sun, 26 Mar 2006 19:04:10-09(1 To: ` Hello Tom, Sorry to bother you on the weekend!, We rigged up Schlumberger wireline on Sat AM to run MDT pressures and samples, at that time I figured to be out of the hole by this evening at which time we are scheduled for a BOP test today. Schlumberger ran into a little trouble with their wireline unit last evening and also the MDT samples are taking longer than first anticipated, so what I would like to ask of you is an extension on our BOP test till we get out of the hole. We anticipate to be out of the hole with the logging tools around 8 AM at which time we would test BOP's. Peter Peter Wilson/Don Breeden Nordic 3 Company Man (O) 659-7446 (C) 659-0505 (F) 659-7566 E-Mail: N1433@conocophillips.com BOP Extension on CPAI 1R-East.eml __ __ _ Re: BOP Extension on CPAI I R-East subject: Re: BOP Extension on CPAI 1R-East From: Date: Sun, 26 Mar 2006 23:35:10 -0500 (EST) To: n1433(ri',cont~cophillips.coin CC jeff'~joi~cs(u~adniiilatate.ak.us, jirt~ rcgg~.admin.state.ak.us, torn _maunci~:r(?adniin.state.ak.us Peter and Don, When Tom Brassfield and I spoke yesterday, he too had indicated that you expected to be out of the hole in time to test and satisfy the 7-day requirement. Your new estimate of completing this log run is 0800 tomorrow. It is acceptable to delay the test until you are out of the hole after the MDT run. If operations are further delayed, please contact the Inspector to keep him aware of any changes. Tom Maunder, PE AOGCC ~ • ' ~ ° 3 ~ ~~ "a FRANK H. MURKOWSK/ G V :..~ ~ ,~ ~ a~ ~~ ~ O ERNOR ** ~~ O~ ~ ~ ~ 333 W. 7TM AVENUE, SUITE 100 COI~TSERQATIOi1T COMnIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas GKA Drilling Tam Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 R-East Sundry Number: 306-113 Dear Mr. Thomas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). oa As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of March, 2006 Encl. .,~ ~ ~ ~+ ConocaP"~illips Post Office Boz 100360 Anchorage, Alaska 99510-0360 March 23, 2006 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry approval to P&A Conoco Phillips 1 R-East Surface Location: 2283' FNL, 964' FEL, Sec. 15, T12N, R10E, UM or ASP4, NAD 27 coordinates of X=554,537 & Y=5,994,294 Target Location: 1352' FNL, 1307' FEL, Sec. 16, T12N, R10E, UM BHL: 1241' FNL, 1979' FEL, Sec. 16, T12N, R10E, UM CONFIDENTIAL Dear Commissioner: ConocoPhillips Alaska, Inc. would like to P&A the 1 R-East West Sak wellbore, located in the Kuparuk River Field/West Sak Oil Pool. Nordic 3 spud this well on 3/12/06 and will TD the well on 3/24/06. The attached Sundry and back-up information describes the P&A procedure for the existing wellbore. If you have any questions or require any further information, please contact me at 265-6377 or Randy Thomas at 265-6830 Sincerely, ~~ Tom Brassfield Staff Drilling Engineer ~~ ~ ~ 2"'`f' STATE OF ALASKA ~ 3/z~ ~~ A OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend Operational shutdown Perforate ;Waiver Anchora~her Alter casing ^ Repair well ^ Plug Perforations ^ . Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory^ 205-211 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-029-23295-00 7. KB Elevation (ft): 9. Well Name and Number: 30' RKB + 34.6' to top of pad 1 R-East 8. Property Designation: 10. Field/Pools(s): ADL 025636 Kuparuk River Field/West Sak Oil Pool- Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8200' 4316' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 110' MD 110' TVD 3280 630 Surface 4450' 9-5/8" 4480' MD 2636' TVD 5750 3090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None na na na Packers and SSSV Type: None Packers and SSSV MD (ft): None 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^~ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/26/2006 Oil ^ Gas ^ Plugged ^ Abandoned Q 16. Verbal Approval: Date: 3/23/2006 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brasfield @ 265-6377 Printed Name Randy Thomas Title GKA Drilling Team Leader Signature Phone 265-6830 Date 3/23/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L~ll/ ~ l~ Plug Integrity "ham BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: C~ fcQ ~G`.~VC~ sc~ ~On 0.S ~ pub `O\~'~"~5 EnCOV lR~ Q \`' 'r`" . Q S S ~n~c~-- ~-~Q ~c~-o ~ ~,~-- ~~ ~sS` off- c~~e,.~ c~~ ~ cv~- ~~__ Subsequent Form Required: A d b _ APPROVED BY /' OMMISSIONER THE COMMISSION Date: ~'~ ~'D pprove y: 4./ 7 ~~. ~E~EIVED ~~`~ MAR 2 3 2006 Alaska Oil & Gas Cans. C fission V ``' ,~~ Form 10-403 Revised 07/2005 a ~ ~ - N A ~ ~~(~ ~ ~ L~UU ~ Submit in Duplicate • 1 R-East P&A • Revised 3/23/06 by TJB Summary: The 1 R-East well spud 1700 hrs on 3/12/06 and will be TD'd on 3/24/06. After running drill pipe conveyed MDT's and possibly drill pipe conveyed percussion sidewall cores the well will be P&A'd. Please see the attached wellbore schematic for details. 1. Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. 3. Spot balanced cement plugs from TD @ 8200' MD to 6000'MD (approx. 150' above top of the Ugnu @ 6150' MD). These plugs will be laid in four 550' intervals. Total cemented interval is approx. 2200' in length. Cement volumes will be based on 8-1/2" hole diameter plus 25%. Total volume is approximately 1085 cu ft or 935 sx of slurry. This will cover the West Sak interval from TD to the top of the hydrocarbon bearing Ugnu. Note: not required to tag plugs (setting from TD) as long as the cementing operations go "as planned". fd7-~~'(-~w 4. By the down squeeze method through a retainer set 70' above the shoe (or approx. 4410' MD) pump cement plug #2 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 170' below (70' of casing volume plus 100' of open hole) and lay a 50' cement cap on top of the retainer. Cement volume in open hole will be based on 8-1/2" hole diameter plus 25%. Total volume is approximately 101 cu ft or 86 sx of slurry. Weight test retainer before pumping cement. Not required to tag the plug. Leave 9.0 ppg mud below the plug.(Weight of mud needed to TD the hole). NOTE: Contact AOGCC inspector for option to witness setting the retainer. ''~ 5. POOH standing back 500' of the 3-1/2" stringer (to be used for surface plug) and laying down 5" DP. 6. Spot a 15 bbl viscosified mud gel pill from 500' to 300'. Spot a balanced Arctic Set 1 cement plug #3 from 300' to surface. 7. PU 3-1/2" tubing and RU to circulate water down to top of the 9-5/8" casing hanger. Flush ID of wellhead to clean-up any residual cement. Clear lines and shut down pumps. Rig down cementing unit and clean up. 8. ND BOPE's and remove Gen V wellhead. Send wellhead to shop for cleaning and any repairs- to be used on the next NEWS well. 9. Release rig to 1 H-South 10. After Rig completes the third well on the ice pad (1 H-South) the Kuparuk Toolhouse Techs will cut off wellhead and all casing strings at 3 feet below ground level. The casing head with stub will be sent to Materials for repair / re-dressing. NOTE: Contact AOGCC inspector for option to witness P&A work prior to welding-on the cover plate. TJB 3/23/06 • 1 R-East P&A • Revised 3/23/06 by TJB 11. A cover plate will be welded (at least 18" in diameter and %4' thick) over all casing strings with the following information bead welded into the top: Conoco Phillips Alaska, Inc. 1 R-East PTD# 205-211 API# 50-029-23295-00 12. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 3/23/06 File: 1 R-East Tom Brassfie Staff Drilling Engine TJB 3/23/06 300' Cement surface P&A plug per Fluid: Drilling mud @ +/- 9.0 to 9.1 ppg TD 8-112" hole drilled t 8200'MD/4316' TVQ as indicated in Directional Plan FMC Gen V or: 16" set at 110' MD 1 R East NEWS Well P&A Schematic Nordic Rig 3 Floor RKB=30' luid: 9.0 to 9.1 ppg Kill Weight ud in Casing 50' Cement plug on top of retainer per AOGCC regs TD 12'/4' Surface Hole. Shoe of 9-5/8" 40 ~- ppf L-80 BTC casing @4480'MD/2636' TVD Cement retainer set at approx 4410' MD ~- with enough cement pumped to fill to 4580' MD and 50' dumped on top. o ~ Cement Plug(s) across ~~ hydrocarbon bearing zones ~ from TD at 8200' MD to 150' `. above Ugnu at 6150' MD. ~\ TOC est @ 6000' MD- four ` 550' lifts. ~ ~ ~ ~ ` ~ ~ ~ ,\ ~ i ~~-- ~~ 1 R-East NEWS Well sbeet ~ of ~ CollocoPh i l l s 5 modified by TJB p P&A Schematic ~2~2oos Alaska NEWS Wells Status Report 3/17/06 r: ~C~~~~il 1R-East Well Status Report Moved rig from 1H-North to 1R-East. Accepted rig at 1800 hrs 3/11/06 and function tested the diverter. Spud 1R-East at 1700 hrs 3/12/06. Directionally drilled 12-1/4" hole to 4490' MD. Ran the 9-5/8" 40.0 ppf L-80 BTC casing to 4480' MD. As of 0600 hrs 3/17/06, the rig was pumping their surface cement job. Verbal communication with rig indicates that we had good cement returns to surface. ~ ~ ~ ~ ~ ~~ ~~ t ~ ~~ ~~ ~ ., x~,g ~s : _ ~`~ ~ ~ ~, -~ ~ :~ ~E ~~; '~ ~"? f'~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~, ~~ ~~I ~' 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 j PHONE (907) 279-1433 Randy Thomas FAx t9o7) 27sasa2 GKA Drilling Team Leader Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak Exploration 1 R-East Conoco Phillips Alaska, Inc. Permit No: 205-211 Surface Location: 2283' FNL, 964' FEL, Sec. 15, T12N, RlOE Bottomhole Location: 1241' FNL, 1979' FEL, Sec. 16, T12N, RlOE Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petrole field inspector at (907) 659- 3607 (pager). ~ on~'i~ly o Chairman DATED this day of January, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas~conocophillips.com December 28, 2005 Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Exploration Well 1R-East Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands. This well will be designated 1R-East. As shown in the attached documents, three West Sak wells will be drilled from the same ice pad located NE of Kuparuk's 1H Pad. The three wells will be P&A'd " after drilling and logging. Please find attached for the review of the Commission forms 10-401, and the information required by 20 ACC 25.005 for this well. The expected spud date of 1R-East is February 15, 2006. If you have any questions or require any further information, please contact me at 265-6377 or Randy Thomas at 265-6830. Sincerely, . ~.---r Tom Brassfield Senior Drilling Engineer ~ 1 ~~ arc ~~ ~ ~ ~~~~ dlaak,~ pii ~ has ~~~'~' ~®~-mirrioq ~CfChCJt"8~8 STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~ION PERMIT TO DRILL 20 AAC 25.005 - ~~3 1a. Type of Work: Drill Q Redrill ~ Re-entry ~ 1b. Current Well Class: Exploratory Q Stratigraphic Test ~ Service ~ Development Oil ~ Multiple Zone Development Gas ~ Single Zone Q 2. Operator Name: Conoco Phillips Alaska, Inc. 5. Bond: Blanket Q Single Well ~ Bond No. 59-52-180 ~ 11. Well Name and Number: 1 R-East 3. Address: PO Box 100360, Anchorage, AK, 99510-0360 6. Proposed Depth: MD: $,178' TvD: 4,332' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2283' FNL,964' FEL,Sec 15,T12N,R10E ' 7. Property Designation: ADL 025636 ' West Sak Oil Pool- Exploration ' Top of Productive Horizon: 1352' FNL,1307' FEL, Sec 16,T12N,R10E ' 8. Land Use Permit: LE 931811 13. Approximate Spud Date: 15-Feb-06 Total Depth: 1241' FNL, 1979' FEL,Sec 16, T12N, R10E 9. Acres in Property: 2560 14. Distance to Nearest Property: 3301 4b. Location of Well (State Base Plane Coordinates): Surface:x- 554537 ~ y- 5,994,294 ~ Zone- 4 10. KB Elevation (Height above GL): 30 feet 15. Distance to Nearest Well Within Pool: None 16. Deviated wells: Kickoff depth: 250 feet ~ Maximum Hole Angle: 68 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1796 Surface: 1357 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 63 B Welded 80' 30' 30' 110' - 110' ~ 200 sx AS1 12-1/4" 9-5/8" 40 L-80 BTC 4337' 30' 30' 4367' - 2602' ~ 660 sx ASLite+ 160 sx DeepCRETE 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production . X13 ., Liner - - C1CE' -.~_.ft' Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 12/22/2005 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brasfield@265-6377 Printed Name Randy Thomas Title GKA Drilling Team Leader Signature o ~ Phone 265-6830 Date 12/28/2005 Commission Use Only Permit to Drill _ Number: ads"a-~~ API Number: 50-Oac1 -a3a~s`OC~ Permit Approval Date: - ~-!~" ~ ~' _/ See cover letter for other requirements. Conditions of approval Sa es required dr en sulfide measures Other: Cy~. j!-5 Q~Car~ , Approve b Yes ~ No [~ Mud log required Yes ~ No [~ Yes ~ No ~ Directional survey required Yes [~ No APPROVED BY /~ ~ - „~j THE COMMISSION Date: (~V ~ vV Form 10-40 vised 06/20 ' ~ ~ ~ ~ ~ ~ ~ ~ ~~ BFI ,IQN ~ `~ ~~LYbmit inDuplicate A~ion for Permit to Drill, Well 1 R-East Revision No.0 Saved: 28-Dec-05 Permit It -West Sak Well #1 R-East •~~~~ ~., ;, Application for Permit to Dril/ Document • Il~l~~c'III MlpxirriixE WTI I 1f41u e Table of Contents 1. Well Name ................................................................................................................. 2 Re uirements of 20 AAC 25.005 ........................................................................ q i'fI ............................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ....................................•--......................................-•-•----.............. 2 Requirements of 20 AAC 25.050(b) ........................................•--........................................-•---............... 3 3: Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ..................................................................................•--.............. 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ..................................................•---•--•--........................--•-•-•--..... 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) .............................................•---.................................................. 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Production Hole Mud Program (FLOPRO NT Drill-in Fluid) ................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ....................................................•-•---.................................-•---•- 5 10 . Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 1R-East PERMIT IT 12 28 05.doc Page 1 of 7 o ^ ~ ~ ~ ~ ~ ~ Printed: 28-Dec-05 f~~ A~ion for Permit to Drill, Well 1 R-East Revision No.O Saved: 28-Dec-05 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13J ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ..............•--•--.........................................................................:.. 6 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plan ......................•--•-•--•--•-•-•-•-•-••-----•--.......................................................... 7 Attachment 2 Drilling Hazards Summary .............................................................................................. 7 Attachment 3 Cement Data .............................•-•---•-•-•-•---•-•-•----•-•--.................................................-•--•-- ~ Attachment 4 Well Schematic Attachment 5 Proposed Ice Pad Configuration Attachment 6 Proposed Ice Road Route ................................................................................................ 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each we// must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(b). Far a we/1 with mu/tip/e well branches, each branch must Simi/ar/y be identified by a unique name andAPl number by adding a suffix to the name designated for the wet! by the operator and to the number assigned to the well by the commission, The well for which this Application is submitted will be designated as iR-East. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fo/%wr`ng items, except for an item already on frle with the commission and identified in the application: (2) a plat identifyr"ng the property and the property's owners and showing (A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmenta/section lines (B) the coordinates of the proposed location of the we// at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic .Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at tote/ depth; Location at Surface 2283' FNL, 964' FEL, Section 15 T12N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 80' AMSL Northings: 5,994,294 "Eastings: SS4,S37 " Pad Elevation 50' AMSL Location at Top of Productive Interval West Sak 1352' FNL, 1307' FEL, Section 16, T12N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB,' 7, 289' Northings; 5,995,186 Eastings: 548,906.5 Total l/ertica/De th, RKB,' 3 760' Tote/ ~ertica/ De th, SS.• 3 680' Location at Total De th 1241' FNL, 1979' FEL, Section 16, T12N, R10E - ASP zone 4 NAD 27 Coordinates Measured De th RKB,' 8,178' Northings 5,995,292 Eastings.' 548,234 Total ~ertica/De th, RKB,' 4,332' Tote/ vertical De th, SS.' 4,252' and 1R-East PERMIT IT 12 28 05.doc Page 2 of 7 ®~ ~ ~ ~ ~ ~ ~ Printed: 28-Dec-05 C, (©) other information required by 20 AAC25.050(b); A~ion for Permit to Drill, Well 1 R-East Revision No.0 Saved: 28-Dec-05 Requirements of 20 AAC 25.050(b) If a well is to 6e intentional/y deviated, the app/ication fora Permit to lJril/ (Form 10-401) must (1) include a plat, drawn to a suitab/e scale, showing the path of the proposed we/lbare, inc/uding all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed we/Ibore (A) list the names of the operators of those wells, to the extent that those names are known or discoverab/e in pub/ic records, and show that each named operator has been furnished a copy of the app/ication by certified mail; or (B) state that the applicant is the on/y affected awne~ The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application; (3) a diagram and desorption of the blowout prevention equipment (HOPE) as required by 20 AAC25.035, 20 AAC25.036, or 20 AAC25.037, as applicab/e; An API 11" x 5,000 psi BOP stack (RSRRA) will be utilized to drill well 1R-East. For all operations the stack will be equipped with 2-7/8" to 5" variable bore rams in the uppermost ram cavity,. blind rams in the middle cavity, and 5" DP rams in the lowermost cavity. BOPE diagrams on file for Nordic 3. Due to the formation pressures being far less than the rating of the BOPE, CPAI requests that the stack be operated under the 3000 psi BOP guidelines. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dri/! must be accompanied by each of the fo/lowing items, except for an item already on fi/e with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1R-East area vary from 0.43 to 0.45 psi/ft, or 8.3 to 8.6 ppg EMW (equivalent mud weight). ~ The maximum potential surface pressure (MPSP) based on the above maximum pressure .gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 3,990' TVD feet giving a MPSP of 1,357 psi, calculated thusly: MPSP = (3,990 ft)*(0.45 - 0.11 psi/ft) = 1,357 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. See attached pore pressure/shallow hazards analysis report. and (C) data concerning potentia/causes of hole prob/sins such as abnormal/y geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iR-East Drilling Hazards Summary. 1R-East PERMIT /T 12 28 05.doc Page 3 of 7 Printed: 28-Dec-05 ORIGINA! A~on for Permit to Drill, Well 1 R-East Revision No.O Saved: 28-Dec-05 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dri/l must be accompanied by each of the following items, except for an item already an fr/e with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); iR-East will be not be completed ,and will be P&A'd after wellbore evaluation. The 9-5/8"shoe track will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/icatron for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in in /b/ft Grade Connection ft ft ft Cement Pro ram 16" 24" 63 B Welded 80 30 / 30 ' 110 / 110 ~ Cemented to surface with 200sx ASl g_5/g~~ 12-1/4" 40 L-80 BTC 4,337 30 / 30 - 4367/2602 ' Cemented to Surface w/ 660 sxs ASLite Lead + 160 sxs Dee CRETE Tail 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission. and identified in the app/ication: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); On file with AOGCC. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Dri/I must 6e accompanied 6y each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (LSND) Surface to 9-5/8"Casin Point Mud Properfies Density (ppg) 9.2 - 9.5 Funnel Viscosity (seconds) 150-250 Yield Point (cP) 30 - 45 API Filtrate (cc / 30 min)) 4 - 6 Chlorides (mg/I) <600 1R-East PERMIT IT 12 28 05.doc Page 4 of 7 ®~ ~ ~ ~ ~ ~ Printed: 28-Dec-05 • A~ion for Permit to Drill, Well 1 R-East Revision No.0 Saved: 28-Dec-05 pH 9.0 - 9.5 Production Hole Mud Program (FLOPRO NT Drill-in Fluid) 9-5/BnCasin Point to TD Mud Properties Density (ppg) 9.0 - 9.2 Plastic Viscosity 10 Yield Point (cP) 28-30 - 45 API Filtrate (cc / 30 min)) 4 - 6 Chlorides (mg/1) 15,000-17000 pH 9.0 - 9.5 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic #3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(g) An application for a Permit to Drif! must be accompanied by each of the fo/focving r"terns, except for an item a/ready on fi/e with the commission and identified in the application: (9) for an exploratory or stratigraphic test weI/, a tabu/ation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 25.0330; Please see attached geopressure and hazards analysis report- previously submitted to the AOGCC. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fl/e with the commission and identified in the application: (10) for an exploratory or stratigraphic test weI/, a seismic refraction or reflection analysis as required by 20 AAC25.061(aJ; Please see attached geopressure and hazards analysis report- previously submitted to the AOGCC. - 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to lJri/l must be accompanied by each of the fo//awing items, except for an item already on file with the commission and identified in the app/ication: (11) for a we// dri/fed from an offshore p/atform, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an analysis ofseabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication far a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1R-East PERMIT IT 12 28 05.doc Page 5 of 7 Printed: 28-Dec-05 C7 A~ion for Permit to Drill, Well 1 R-East Revision No.O Saved: 28-Dec-05 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An app/ication for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on fr/e with the commission and identified in the application: The proposed drilling program for iR-East is listed below. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/-110' RKB (2 joints). Install landing ring on conductor. 2. Move in /rig up Nordic #3. Install 21-1/4" Annular with 16" diverter line and function test. Notify AOGCC 24 hours prior to test. , 3. Spud and directionally drill 12-1/4" hole to casing point at +/- 4367' MD /2602' TVD as per directional plan. Run MWD/LWD (GR/RES)tools as required for directional monitoring. Mud log from base of the surface conductor to TD 4. Run and cement 9-5/8", 40 ppf, L-80, BTC casing to surface. Displace cement with water base mud and, pressure test casing to 3000 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install 11" x 5,000 psi BOP's and test to 3000 psi (annular preventer to 1500 psi). Notify AOGCC 24 his before test. 6. PU 8-1/2" bit and drilling assembly, with MWD 8~ LWD (GR/Res/Neutron/Density). RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak- off (or FIT if gradient reaches 16 ppg equivglent) recording results. Change over to the FLOPRO drill-in fluid. 8. Directionally drill to TD at 8178' MD / 4332' TVD. Make short trip and condition hole/mud for E- line logs. 9. RU & run E-line logs per program. Currently planned are 1) a drill pipe conveyed MDT, and 2) drill pipe conveyed percussion sidewall cores. 10. PU P8~A BHA, TIO and lay open hole cement plugs across hydrocarbon bearing zones as discussed with AOGCC. N03 upplt cu~or~ f~¢~,.~\t"t~ ~ ~~N(„ +~ /~ r 11. Set cement retainer at 9-5/8" casing shoe and pump cement below and above the retainer per AOGCC regulations. 12. Set 300' cement surface plug per AOGCC regulations. 13. Nipple down the BOPE's and check top of cement. 14. Release rig to next well. 15. After drilling the three NEWS wells and the rig is released from the ice pad, the Toolhouse Techs will complete the surface PI3u4's per AOGCC regulations, clean-up, and secure the ice pad. 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Fermit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (14) a genera! description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAG 25, t18tJ for an annular dispose/operation in the weI/,; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 1R-East PERMIT IT 12 28 05.doc Page 6 of 7 Printed: 28-Dec-05 ORIGINAL 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Data Attachment 4 Well Schematic Attachment 5 Proposed Ice Pad Configuration Attachment 6 Proposed Ice Road Route A~ion for Permit to Drill, Well 1 R-East Revision No.O Saved: 28-Dec-05 1R-East PERMIT IT 12 28 05.doc Page 7 of 7 Printed: 28-Dec-05 ORIGINAL • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit NEWS ICEPAD Plan 1 R-E Plan: 1R-E (wp01) Proposal Report 12 December, 2005 • HALLI~R7taIV :p+~~ ~r~1ir~ rwic+ ORIGINAL 1300 c -- 0 ~ 1950 s a d ~ 2275 v ~ 2600 N SHL @ 2283ft FNL & 964ft FEL -Sec 15 - T12N - R10E KOP @ 250ft MD, 250ft TVD -Build @ 3.5°l100ft 20° Sail @ 46° Inc : 1564ft MD, 1428ft TVD Continue Build @ 4°/100ft , 1664ft MD, 1497ft TVD pO ""_ - " " " Sail @ 68° Inc : 2214ft MD, 1795ft TVD Base of Permafrost ~o ' " ~" ~f Project: Kuparuk River Unit ~~C'~~~l~~~}J~-` Site: NEWS ICEPAD hU<~ska Well: Plan 1 R-E Wellbore: plan 1R-E Plan: 1R-E (wpO1) CASING DETAILS No TVD MD Name Size 1 2602.00 4366.62 9 5!8" 9-5l8 FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1746.00 1666 2096.07 Base of Permafrost 2 2602.00 2522 4366.62 T3 + 675 3 3135.00 3055 5787.74 Ugnu C 4 340d.00 3320 6494.31 Ugnu B 5 3651.00 3571 7104.58 K13 6 3757.00 3677 7284.07 WSAK D 7 3826.00 3746 7391.43 WSAK B 8 3914.00 3834 7528.33 WSAK A3 9 3990.00 3910 7646.57 WSAK AZ 10 4210.00 4130 7988.82 WSAK Base iFiALLIB W RTOh! 9 518" CSG PT @ 4367ft MD, 2602ft TVD - 1788ft FNL & 1332ft FWL -Sec 15 - T12N - R10E Sperry G'rfil~trg ~rieas T3 + 675 ~' , . ~ , ~ ~ ,~ Drop @ 4°I100ft to 68°Inc : 6839ft MD, 3529ft TVD i i Ugnu C ~ i =------------------------------------------------------------------ ---- Ugnu B ; ~ i Sail @ 50° Inc K13 WSAK D WSAK Target Ccr~ 7289ft MD, 3760ft TVD - 1352ft FNL 8 1307ft FEL _Sec 16 - T12N - R10E ~ WSAK B _ -=----A----------------------------------------------------------------------------------- yO WSAK A2 WSAK A3 TD @ 8178ft MD, 4332ft TVD 1241 ft FNL & 1979 ftFEL -Sec 16 - T12N - R10E WSAK Base 0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175 w C W >aw~o W r' ~~?~ ~ 3 L fn f0 d W lG °-wam~ YZ_~~ ~~ ~ U w ~ 41 ~ m to ?~ a a` ~' C~' W N 1f) in or j ~ W ~~ W 2 m O pN ? ~~ y ~ V p °o zo W O N z~ z N_ F- U J W LL V J Z M N W Z H ~~, N U C p~ V .~ N N ~ ~ ~ ~ M N ~ ~ m ~ ~ ~ ~ h ~ ~ C / ~\\ V aD ~ o S ~ \ ~ a ~ V W ~ ~ ~ c0 ~ Q \\ ~ \ ~ ~~~`` \~ ~ \~ V \ 2 N N W LL n M J Z u. N M. F- - M \ ~ ~ f0 D ~ • ~ ~ ~ U U1 .J \ ~ ~ (n W N \ ~ J ~ ~ ~ \ LL ~ \\ \ ~' y ~ ~ p> ~ ~ ~ ~ ~ F- ~ ~ ~ ~ ot$ Q ~ ~ J (n ~ LL ~ ~~ ~ ~ ~ N ~ \\. ~ (\~ r ~6LZ ~ N ~ U <~ m c ~ ` ~ ~ O 0 LL7 ~ o6LZ _ lA V H r v o N ~- ~- ~ H m °o iq m O ~ N ~ \~ ~ ~ ~ ~ ~ p , ~ N 1 ~ ~ N ^, v ~ ~ ~ a O ~ ~ ~ ~ ~ Y F ~ 1 ~ ~ ~_ 1 ~ 1 ~ ~ ~ U G (O ~ ~ V V ~ O O f0 R a .~ m a~ C U O A O ~ t+~ ryry J Om. W pCY W Y~Y YQ~[ LyyO F.. WCWVm QQ6QQ + ~ ~ p ObM ~O1eM-W Mfq tl1M ao u.mt-»x33$33 ~"~ LhN~~ W hMMhN Z ~omr,e+~~nav~n~gao O Q,iO~ChCI'V'<rWmao W WOfO W O1N W O a pi pN ~ppSN~ hn pr hW.h~ ~ O O O C O O O S O O a a~fi~iv;o~~~o~aio ~~taO~yyO tWGn OND W ANN NMMMMMMMeF O z ~ N M '7 N W h W 01 r i ~ ~! F 1 r ~!~ ~: r~ ~-OC~oo O ~"? dl~.m00 Z ~ IL~ONN m N U~p ~O~ CIS mm~ ~ o w~c fL $Z mtQ m. av ~rnapv 3~ ~~ ~ Q£ ~ ~ F ~ F O O M O h O O h O N 0 v .-. N ~_ O ~ a C c0 N + N (6 O W (h N O m 117 C7 O V O N 7 O~7 V' O N 0 rn O O M ~•` Halliburton Energy Services wAt,a.~t~uAYON ~~~~~~~~~~~ Planning Report -Geographic ----~---- - - - -- Alaska S~ertY 1>trilltng Servl+ees Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 R-E Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) Project: Kuparuk River Unit MD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) Site: NEWS ICEPAD North Reference: True ' Well: Plan 1 R-E Survey Calculation Method: Minimum Curvature Wellbore: Plan 1 R-E Design: 1R-E (wp01) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS} Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Welf Plan 1 R-E Well Position +W-S 0.00 ft Northing: 5,994,294.00 ft Latitude: 70° 23' 42.363" N +E/-W 0.00 ft Easting: 554,537.OOft Longitude: 149° 33' 22.510" W Position Uncertainty O.OOft Wellhead Elevation: ft Ground Level: 50.OOft Wellbore Plan 1 R-E Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 9/10/2005 24.387 80.849 57,569 Design 1R-E(wp01) Audit Notes: Version: Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From (TVD) +N!-S +E/-W Direction (ft) (ft) (ft) (°) 30.00 0.00 0.00 279.42 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft} (ft} (ft) (°/100ft) (°/100ft) (°/100ft) (°) 30.00 0.000 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.000 250.00 0.000 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.000 1,564.29 46.000 279.42 1,427.58 81.81 -493.11 3.50 3.50 0.00 279.420 1,664.29 46.000 279.42 1,497.04 93.58 -564.07 0.00 0.00 0.00 0.000 2,213.59 67.972 279.42 1,794.50 168.51 -1,015.70 4.00 4.00 0.00 -0.002 6,839.44 67.972 279.42 3,529.44 870.29 -5,246.06 0.00 0.00 0.00 0.000 7,288.75 50.000 279.42 3,760.00 933.06 -5,624.39 4.00 -4.00 0.00 179.998 7,977.93 50.000 279.42 4,203.00 1,019.47 -6,145.21 0.00 0.00 0.00 0.000 8,177.93 ~ 50.000 279.42 4,331.56 ' 1,044.54 -6,296.36 0.00 0.00 0.00 0.000 12/12/2QD5 1:54:29PM Page 2 of 6 COMPASS 2003.11 Build 48 • ~-' ~C~l"~~~C~I~~I 5 Halliburton Energy Services hlALLIC~IJATOIV hi Pl i R t G eograp ann ng epor - c A1~sk~ Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1R-E Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) Project: Kuparuk River Unit MD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) Site: NEWS ICEPAD North Reference: True Well: Plan 1R-E Survey Calculation Method: Minimum Curvature Wellbore: Plan 1R-E Design: 1 R-E (wp01) Planned Survey 1R-E (wp01) Map Map MD Inclination Azimuth TVD SSTVD +N/~ +E/-W Northing Easting pLSEV Vert Section lft) (°) (°) (ft) Ift) (ft) (ft) (ft) eft) (°/100ft) (ft) 30.00 0.000 0.00 30.00 -50.00 0.00 0.00 5,994,294.00 554,537.00 0.00 0.00 SHL @ 2283ft FNL >f< 964ft FEL -Sec 15 - T12N - R10E 100.00 0.000 0.00 100.00 20.00 0.00 0.00 5,994,294.00 554,537.00 0.00 0.00 200.00 0.000 0.00 200.00 120.00 0.00 0.00 5,994,294.00 554,537.00 0.00 0.00 250.00 0.000 0.00 250.00 170.00 0.00 0.00 5,994,294.00 554,537.00 0.00 0.00 KOP @ 250ft MD, 250ft TVD -Build @ 3.5°/100ft 300.00 1.750 279.42 299.99 219.99 0.12 -0.75 5,994,294.12 554,536.25 3.50 0.76 400.00 5.250 279.42 399.79 319.79 1.12 -6.77 5,994,295.07 554,530.22 3.50 6.87 500.00 8.750 279.42 499.03 419.03 3.12 -18.80 5,994,296.98 554,518.18 3.50 19.05 600.00 12.250 279.42 597.34 517.34 6.10 -36.77 5,994,299.83 554,500.19 3.50 37.27 700.00 15.750 279.42 694.35 614.35 10.06 -60.63 5,994,303.62 554,476.30 3.50 61.46 800.00 19.250 279.42 789.71 709.71 14.98 -90.29 5,994,308.32 554,446.61 3.50 91.53 900.00 22.750 279.42 883.05 803.05 20.84 -125.64 5,994,313.93 554,411.22 3.50 .127.36 1,000.00 26.250 279.42 974.04 894.04 27.63 -166.55 5,994,320.41 554,370.27 3.50 168.82 1,100.00 29.750 279.42 1,062.32 982.32 35.31 -212.85 5,994,327.76 554,323.92 3.50 215.76 1,200.00 33.250 279.42 1,147.57 1,067.57 43.86 -264.39 5,994,335.93 554,272.32 3.50 268.00 1,300.00 36.750 279.42 1,229.47 1,149.47 53.25 -320.96 5,994,344.90 554,215.69 3.50 325.35 1,400.00 40.250 279.42 1,307.72 1,227.72 63.44 -382.37 5,994,354.64 554,154.22 3.50 387.59 1,500.00 43.750 279.42 1,382.02 1,302.02 74.39 -448.37 5,994,365.11 554,088.15 3.50 454.50 1,564.29 46.000 279.42 1,427.58 1,347.58 81.81 -493.11 5,994,372.20 554,043.35 3.50 499.85 Sail @ 46° Inc : 1564ft MD, 1428ft TVD 1,600.00 46.000 279.42 1,452.38 1,372.38 86.02 -518.45 5,994,376.22 554,017.98 0.00 525.54 1,664.29 46.000 279.42 1,497.04 1,417.04 93.58 -564.07 5,994,383.46 553,972.31 0.00 571.79 Continue Build @ 4°/100ft , 1664ft MD, 1497ft TVD 1,700.00 47.428 279.42 1,521.53 1,441.53 97.84 -589.72 5,994,387.52 553,946.64 4.00 597.78 1,800.00 51.428 279.42 1,586.55 1,506.55 110.27 -664.64 5,994,399.41 553,871.64 4.00 673.73 1,900.00 55.428 279.42 1,646.12 1,566.12 123.41 -743.85 5,994,411.97 553,792.34 4.00 754.02 2,000.00 59.428 279.42 1,699.95 1,619.95 137.20 -826.97 5,994,425.15 553,709.13 4.00 838.28 2,096.07 63271 279.42 1,746.00 1,666.00 150.99 -910.13 5,994,438.34 553,625.88 4.00 922.57 Base of Permafrost 2,100.00 63.428 279.42 1,747.76 1,667.76 151.57 -913.59 5,994,438.89 553,622.41 3.99 926.08 2,200.00 67.428 279.42 1,789.34 1,709.34 166.45 -1,003.29 5,994,453.11 553,532.62 4.00 1,017.01 2,213.59 67.972 279.42 1,794.50 1,714.50 168.51 -1,015.70 5,994,455.08 553,520.20 4.00 1,029.58 Sail @ 68° Inc : 2214ft MD,1795ft TVD 2,300.00 67.972 279.42 1,826.90 1,746.90 181.62 -1,094.72 5,994,467.61 553,441.09 0.00 1,109.68 2,400.00 67.972 279.42 1,864.41 1,784.41 196.79 -1,186.17 5,994,482.11 553,349.54 0.00 1,202.38 2,500.00 67.972 279.42 1,901.91 1,821.91 211.96 -1,277.62 5,994,496.61 553,257.99 0.00 1,295.08 2,600.00 67.972 279.42 1,939.42 1,859.42 227.13 -1,369.07 5,994,511.11 553,166.44 0.00 1,387.78 2,700.00 67.972 279.42 1,976.93 1,896.93 242.30 -1,460.52 5,994,525.62 553,074.89 0.00 1,480.48 2,800.00 67.972 279.42 2,014.43 1,934.43 257.47 -1,551.97 5,994,540.12 552,983.34 0.00 1,573.18 2,900.00 67.972 279.42 2,051.94 1,971.94 272.64 -1,643.42 5,994,554.62 552,891.79 0.00 1,665.88 3,000.00 67.972 279.42 2,089.44 2,009.44 287.81 -1,734.87 5,994,569.12 552,800.24 0.00 1,758.58 3,100.00 67.972 279.42 2,126.95 2,046.95 302.98 -1,826.32 5,994,583.62 552,708.69 0.00 1,851.28 3,200.00 67.972 279.42 2,164.45 2,084.45 318.16 -1,917.77 5,994,598.13 552,617.14 0.00 1,943.98 3,300.00 67.972 279.42 2,201.96 2,121.96 333.33 -2,00922 5,994,612.63 552,525.59 0.00 2,036.69 3,400.00 67.972 279.42 2,239.46 2,159.46 348.50 -2,100.67 5,994,627.13 552,434.04 0.00 2,129.39 3,500.00 67.972 279.42 2,276.97 2,196.97 363.67 -2,192.12 5,994,641.63 552,342.49 0.00 2,222.09 12/12/2005 1:54:29PM Page 3 of 6 COMPASS 2003.11 Build 48 ORIGINAL • C~r~c~coPhilt~ps ~las+~_3 Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: NEWS ICEPAD Well: Plan 1 R-E Wellbore: Plan 1 R-E Design: 1 R-E (wp01) LJ Halliburton Energy Services HALLIBLIATON Planning Report -Geographic -Y---- --- - ry Drilling 5~rvtces Local Co-ordinate Reference: Well Plan 1 R-E ND Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) MD Reference: Initial Plan RKB @ 80.QOft (Nordic 3 {30+50)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1 R-E (wp01) Map Map MD Inclination Azimuth TVD SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100ft) (ft) 3,600.00 67.972 279.42 2,314.48 2,234.48 378.84 -2,283.58 5,994,656.13 552,250.94 0.00 2,314.79 3,700.00 67.972 279.42 2,351.98 2,271.98 394.01 -2,375.03 5,994,670.64 552,159.39 0.00 2,407.49 3,800.00 67.972 279.42 2,389.49 2,309.49 409.18 -2,466.48 5,994,685.14 552,067.84 0.00 2,500.19 3,900.00 67.972 279.42 2,426.99 2,346.99 424.35 -2,557.93 5,994,699.64 551,976.29 0.00 2,592.89 4,000.00 67.972 279.42 2,464.50 2,384.50 439.52 -2,649.38 5,994,714.14 551,884.74 0.00 2,685.59 4,100.00 67.972 279.42 2,502.00 2,422.00 454.69 -2,740.83 5,994,728.64 551,793.19 0.00 2,778.29 4,200.00 67.972 279.42 2,539.51 2,459.51 469.86 -2,832.28 5,994,743.14 551,701.64 0.00 2,870.99 4,300.00 67.972 279.42 2,577.01 2,497.01 485.04 -2,923.73 5,994,757.65 551,610.09 0.00 2,963.69 4,366.62 67.972 279.42 2,602.00 2,522.00 495.14 -2,984.65 5,994,767.31 551,549.10 0.00 3,025.44 9 5/8" CSG PT @ 4367ft MD, 2602ft TVD -1788ft FNL & 1332ft FWL -Sec 15 - T12N - R10E - T3 + 675 - 9518" 4,400.00 67.972 279.42 2,614.52 2,534.52 500.21 -3,015.18 5,994,772.15 551,518.54 0.00 3,056.39 4,500.00 67.972 279.42 2,652.02 2,572.02 515.38 -3,106.63 5,994,786.65 551,426.99 0.00 3,149.09 4,600.00 67.972 279.42 2,689.53 2,609.53 530.55 -3,198.08 5,994,801.15 551,335.44 0.00 3,241.79 4,700.00 67.972 279.42 2,727.04 2,647.04 545.72 -3,289.53 5,994,815.65 551,243.89 0.00 3,334.49 4,800.00 67.972 279.42 2,764.54 2,684.54 560.89 -3,380.98 5,994,830.16 551,152.34 0.00 3,427.19 4,900.00 67.972 279.42 2,802.05 2,722.05 576.06 -3,472.43 5,994,844.66 551,060.79 0.00 3,519.89 5,000.00 67.972 279.42 2,839.55 2,759.55 591.23 -3,563.88 5,994,859.16 550,969.24 0.00 3,612.59 5,100.00 67.972 279.42 2,877.06 2,797.06 606.40 -3,655.33 5,994,873.66 550,877.70 0.00 3,705.29 5,200.00 67.972 279.42 2,914.56 2,834.56 621.57 -3,746.78 5,994,888.16 550,786.15 0.00 3,797.99 5,300.00 67.972 279.42 2,952.07 2,872.07 636.74 -3,838.23 5,994,902.67 550,694.60 0.00 3,890.69 5,400.00 67.972 279.42 2,989.57 2,909.57 651.92 -3,929.68 5,994,917.17 550,603.05 0.00 3,983.39 5,500.00 67.972 279.42 3,027.08 2,947.08 667.09 -4,021.13 5,994,931.67 550,511.50 0.00 4,076.09 5,600.00 67.972 279.42 3,064.59 2,984.59 682.26 -4,112.58 5,994,946.17 550,419.95 0.00 4,168.79 5,700.00 67.972 279.42 3,102.09 3,022.09 697.43 -4,204.03 5,994,960.67 550,328.40 0.00 4,261.49 5,787.74 67.972 279.42 3,135.00 3,055.00 710.74 -4,284.28 5,994,973.40 550,248.07 0.00 4,342.83 Ugnu C 5,800.00 67.972 279.42 3,139.60 3,059.60 712.60 -4,295.48 5,994,975.17 550,236.85 0.00 4,354.19 5,900.00 67.972 279.42 3,177.10 3,097.10 727.77 -4,386.93 5,994,989.68 550,145.30 0.00 4,446.89 6,000.00 67.972 279.42 3,214.61 3,134.61 742.94 -4,478.39 5,995,004.18 550,053.75 0.00 4,539.59 6,100.00 67.972 279.42 3,252.11 3,172.11 758.11 -4,569.84 5,995,018.68 549,962.20 0.00 4,632.29 6,200.00 67.972 279.42 3,289.62 3,209.62 773.28 -4,661.29 5,995,033.18 549,870.65 0.00 4,724.99 6,300.00 67.972 279.42 3,327.12 3,247.12 788.45 -4,752.74 5,995,047.68 549,779.10 0.00 4,817.69 6,400.00 67.972 279.42 3,364.63 3,284.63 803.62 -4,844.19 5,995,062.19 549,687.55 0.00 4,910.39 6,494.31 67.972 279.42 3,400.00 3,320.00 817.93 -4,930.43 5,995,075.86 549,601.21 0.00 4,997.82 Ugnu B 6,500.00 67.972 279.42 3,402.14 3,322.14 818.80 -4,935.64 5,995,076.69 549,596.00 0.00 5,003.09 6,600.00 67.972 279.42 3,439.64 3,359.64 833.97 -5,027.09 5,995,091.19 549,504.45 0.00 5,095.79 6,700.00 67.972 279.42 3,477.15 3,397.15 849.14 -5,118.54 5,995,105.69 549,412.90 0.00 5,188.49 6,800.00 67.972 279.42 3,514.65 3,434.65 864.31 -5,209.99 5,995,120.19 549,321.35 0.00 5,281.19 6,839.44 67.972 279.42 3,529.44 3,449.44 87029 -5,246.06 5,995,125.91 549,285.24 0.00 5,317.76 Drop @ 4°/ 100ft to 68°Inc : 6839ft MD, 3529ft TVD 6,900.00 65.551 279.42 3,553.34 3,473.34 879.40 -5,300.95 5,995,134.62 549,23029 4.00 5,373.40 7,000.00 61.551 279.42 3,597.87 3,517.87 894.05 -5,389.26 5,995,148.62 549,141.89 4.00 5,462.91 7,100.00 57.551 279.42 3,648.54 3,568.54 908.15 -5,474.28 5,995,162.11 549,056.77 4.00 5,549.10 7,104.58 57.367 279.42 3,651.00 3,571.00 908.79 -5,478.09 5,995,162.71 549,052.96 4.02 5,552.96 K13 7,200.00 53.551 279.42 3,705.10 3,625.10 921.65 -5,555.62 5,995,175.00 548,975.34 4.00 5,631.55 12/12/2005 1:54:29PM Page 4 of 6 COMPASS 2003.11 Build 48 ORIGINAL • r Cc~rx~+~o~`hll~~s Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: NEWS ICEPAD Well: Plan 1 R-E Wellbore: Plan 1 R-E Design: 1 R-E (wp01) Halliburton Energy Services wgLLiI~URTON Planning Report -Geographic -----~------- -- -~°- rt~f Oritfi!ng 5ervic~s Local Co-ordinate Reference: Well Plan 1R-E TVD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) MD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)} North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1R-E (vdp01) Map Map MD Inclination Azimuth ND SSND +NI-S +E/_W Northing Easting OLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 7,284.07 50.187 279.42 3,757.00 3,677.00 932.47 -5,620.85 5,995,185.35 548,910.04 4.00 5,697.67 WSAK D 7,288.75 50.000 279.42 3,760.00 3,680.00 933.06 -5,624.39 5,995,185.91 548,906.50 4.00 5,701.26 WSAK Target @ 7289ft MD, 3760ft ND -1352ft FNL & 1307ft FEL -Sec 16 - T12N - R 10E -Sail @ 50° Inc -1R-E (Top WS)(wp01) 7,300.00 50.000 279.42 3,767.23 3,687.23 934.47 -5,632.89 5,995,187.26 548,897.99 0.00 5,709.87 7,391.43 50.000 279.42 3,826.00 3,746.00 945.93 -5,701.98 5,995,198.22 548,828.82 0.00 5,779.91 WSAK B 7,400.00 50.000 279.42 3,831.51 3,751.51 947.00 -5,708.46 5,995,199.24 548,822.33 0.00 5,786.48 7,500.00 50.000 279.42 3,895.79 3,815.79 959.54 -5,784.03 5,995,211.23 548,746.68 0.00 5,863.08 7,528.33 50.000 279.42 3,914.00 3,834.00 963.09 -5,805.44 5,995,214.62 548,725.25 0.00 5,884.79 WSAK A3 7,600.00 50.000 279.42 3,960.07 3,880.07 972.08 -5,859.60 5,995,223.21 548,671.03 0.00 5,939.69 7,646.57 50.000 279.42 3,990.00 3,910.00 977.92 -5,894.79 5,995,228.79 548,635.80 0.00 5,975.36 WSAK A2 7,700.00 50.000 279.42 4,024.35 3,944.35 984.62 -5,935.17 5,995,235.20 548,595.37 0.00 6,016.29 7,800.00 50.000 279.42 4,088.63 4,008.63 997.16 -6,010.75 5,995,247.18 548,519.72 0.00 6,092.90 7,900.00 50.000 279.42 4,152.90 4,072.90 1,009.69 -6,086.32 5,995,259.17 548,444.07 0.00 6,169.50 7,977.93 50.000 279.42 4,203.00 4,123.00 1,019.47 -6,145.21 5,995,268.51 548,385.11 0.00 6,229.20 7,988.82 50.000 279.42 4,210.00 4,130.00 1,020.83 -6,153.44 5,995,269.81 548,376.87 0.00 6,237.54 WSAK Base 8,000.00 50.000 279.42 4,217.18 4,137.18 1,022.23 -6,161.89 5,995,271.15 548,368.41 0.00 6,246.11 8,100.00 50.000 279.42 4,281.46 4,201.46 1,034.77 -6,237.46 5,995,283.14 548,292.76 0.00 6,322.71 8,177.93 50.000 279.42 4,331.56 4,251.56 1,044.54 -6,296.36 5,995,292.48 548,233.80 0.00 6,382.41 TD @ 8178ft MD, 4332ft TVD :1241 ft FNL 8 1 979 ftFEL -Sec 16 - T12N - R10E Geologic Targets Plan 1R-E TVD Target Name +N/-S +EI-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,760.00 1R-E (Top WSj(wp01) 933.06 -5,624.39 5,995,185.91 548,906.50 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ("} (~~) 4,366.62 2,602.00 9-5/8 12-114 12/12/2005 1:54:29PM Page 5 of 6 COMPASS 2003.118ui1d 48 ORIGINAL i~ia~ka database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: NEWS ICEPAD Well: Plan 1R-E Wellbore: Plan 1 R-E Design: 1 R-E (wp01) • Halliburton Energy Services rs+--~.~.teuATlunr Planning Report -Geographic ----- --- -- - ~-- Srtt~( 6~rillln~ $er~vicas Local Co-ordinate Reference: Well Plan 1 R-E TVD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) MD Reference: Initial Plan RKB @ 80.OOft (Nordic 3 {30+50)} North Reference: True Survey Calculation Method: Minimum Curvature Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/_E +E/-W (ft) (°) (°l (ft) (ft) (ft) Name 2,096.07 63.27 279.42 1,746.00 150.99 -910.13 Base of Permafrost 4,366.62 67.97 279.42 2,602.00 495.14 -2,984.65 T3 + 675 5,787.74 67.97 279.42 3,135.00 710.74 -4,284.28 Ugnu C 6,494.31 67.97 279.42 3,400.00 817.93 -4,930.43 Ugnu B 7,104.58 57.37 279.42 3,651.00 908.79 -5,478.09 K73 7,284.07 50.19 279.42 3,757.00 932.47 -5,620.85 WSAK D 7,391.43 50.00 279.42 3,826.00. 945.93 -5,701.98 WSAK B 7,528.33 50.00 279.42 3,914.00 963.09 -5,805.44 WSAK A3 7,646.57 50.00 279.42 3,990.00 977.92 -5,894.79 WSAK AZ 7,988.82 50.00 279.42 4,210.00 1,020.83 -6,153.44 WSAK Base 12/1212005 1:54:29PM Page 6 of 6 tl ~r COMPASS 2003.11 Build 48 • Conoco hillips a~as~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit NEWS ICEPAD Plan 1 R-E Anticollision Summary 12 December, 2005 • :p~rc° ri~~irr+~ ~rvc~ nn~~~NAL ~t~t~~COPhilips Alasi~~S ~- Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference5ite: NEWSICEPAD Site Error: O.OOft Reference Well: Plan 1R-E Well Error: O.OOft Reference Wellbore Plan 1R-E Reference Design: 1R-E (wp01) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLIBURTON w_ . ~rperry Drtlltny Services Well Plan 1 R-E Initial Plan RKB @ SO.OOft (Nordic 3 (30+50)) Initial Plan RKB @ 80.OOft {Nordic 3 (30+50)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1 R-E (wp01) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referee Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,014.79ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 12/12J2005 From To (ft} (ft) Survey (Wellbore) Tool Name Description 30.00 8,177.93 1 R-E (wp01) (Plan 1 R-E) MW D MW D-Standard Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) NEWSICEPAD Plan 1 H-N -Plan 1 H-N -1 H-N(wp01) 299.48 300.00 19.97 5.07 14.91 Pass -Major Risk Plan 1 H-S -Plan 1 H-S - 1 H-S (wp01) 298.96 300.00 40.21 5.06 35.16 Pass -Major Risk CC -Min centre to center distance or covergent pant, SF -min separation factor, ES -min ellipse separation 12112/2005 2:13:22PM Page 2 of 2 COMPASS 2003.11 i3uild 48 ~~~~~~~ SCRVE1' PKOGRAV NAD 27 ASP Zone 4 : WELL DETAILS: Plan iR•E -- ANTI-0OLLISION SETTINGS Uatr: 200509-1OT00:00:00 Validated: Yes Vercion: Ground Level: 50.00 Interpolation Method: MD Interval: SOStationa +NI-S +FJ-W Northing Easting Latittude Longhude Uepth From Uepth To Sun ey/Plan Tool Depth Range From: 30.00 To 8177.93 0.00 0.00 5994294.00 554537.00 70°23'42.383N 149°33'22.51 W ]0.00 6177.93 IR-E (wp01) 1f11D Maximum Renge:1014.79348397807 Reference: Plan: 1R-E (wp01) 270 330 300 ConocoPhillipa Alaska (Kuparuk) Drilling 8 Wells Slot Weat Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 30 5 'Plan 1H-N 64 5 Plan 1H-N' 270 5 ~~ ~ 1 i 9P 1 240 120 20 25 Plan 1HS 210 150 30 180 Travelling Cylinder Azimuth (TF(1*AZI) [°] vs Centre to Cenh•e Separation [15 ft/in] From Colour To MD 30 250 250 500 500 750 750 1000 180 1000 1250 1250 1500 1500 1750 1750 -__.._~ __.__. 2000 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [75 ft/in] 2000 2250 2250 2500 2500 2750 2750 3000 3000 3250 3250 3500 REFERENCE INFORMATION 3500 3750 Coordinate (NIE) Reference: Well Plan 1R-E, True North 3750 4000 Vertical (TVD) Reference: Initial Plan RKB @ 80.OOft (Nordic 3 (30+50)) 4000 5000 Section (VS) Reference: Slot - (O.OON, O.OOE) 5000 6000 Measured Depth Reference: Initial Plan RKB @ SO.OOft (Nordic 3 (30~50)) Calculation Method: Minimum Curvature 6000 850D 90 SECTION DETAILS Sec MD Inc Azi TVD +NI-S +EI-W DLeg TFace VSec Target 1 30.00 0.000 0.00 30.00 0.00 0.00 0.00 0.000 0.00 2 250.00 0.000 0.00 250.00 0.00 0.00 0.00 0.000 0.00 3 1564.2946.000 279.42 1427.58 81.81 -493.11 3.50279.420 499.85 4 1664.2946.000 279.42 1497.04 93.58 -564.07 D.00 0.000 571.79 5 2213.5967.972 279.42 1794.50 168.51-1015.70 4.00 -0.002 1029.58 6 6839.4467.972 279.42 3529.44 870.29.5246.06 0.00 0.000 5317.76 7 7288.7550.000 279.42 3760.00 933.06-5624.39 4.00179.998 5701.26 1R•E (Top WS)(wp01) 8 7977.9350.000 279.42 4203.00 1019.47.6145.21 0.00 0.000 6229.20 9 8177.9350.000 279.42 4331.56 1044.54.6296.36 0.00 0.000 6382.41 ~J • iR-East Drilling Hazards Summary 12-1/4"Open Hole / 9-5/8" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor. Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced , drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 8-1/2" Open Hole to TD Hazard Risk Level Miti ation Strate Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Stuck Pipe Low Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo LCM Hole. swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets um in out 1H-North Drilling Hazards Summary prepared by TJB 12/21/05 ORIGINAL CemCADE Preliminary Job Design 9 5/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purp°ses only. Rig: Nordic 3 Location: NEWS Client: ConocoPhillips Alaska, Inc. Revision Date: 12/21/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6 # casing at 80' MD < Base of Permafrost at 2,096' MD (1,746' TVD) Schlum6ergen Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 40% excess below the permafrost. The top of the tail slurry is designed to be at 3,567' MD. Lead Slurry Minimum pump time: 240 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x (80') x 1.00 (no excess) = 61.1 ft3 0.3132 ft3/ft x (2096' - 80') x 3.50 (250% excess) = 2209.9 ft3 0.3132 ft3/ft x (3567' - 2096') x 1.40 (40% excess) = 645 ft3 61.1 ft3 + 2209.9 ft3+ 645 ft3 = 2916 ft3 2916.0 ft3 / 4.45 ft3/sk = 655.3sks Round up to 660 sks Have 250 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 160 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3132 ft3/ft x (4367' - 3567') x 1.40 (40% excess) = 350.8 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 350.8 ft3 + 34.1 ft3 = 384.9 ft3 384.9 ft3/ 2.52 ft3/sk = 152.7 sks Round up to 160 sks BHST = 52°F, Estimated BHCT = 66°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 3,567' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 4,367 MD (z,soz' rvD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 7.0 519.3 74.2 109.2 DeepCRETE 5.0 68.6 13.7 122.9 Drop top plug 0.0 0.0 5.0 127.9 Wate 5.0 20.0 4.0 131.9 Switch to rig 0.0 0.0 5.0 136.9 Mud 7.0 296 42.3 179.2 Slow & bump plug 3.0 9 3 182.2 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL 300' Cement surface P8~A plug per AOGCC Regs ~ Wellhead: FMC Gen V Conductor: 16" set at 110' MD Fluid: Kill Weight Mud in Casing 1R-East NEWS Well Schematic Nordic Rig 3 Floor RKB=30' 50' Cement plug on top of retainer per ~ AOGCC regs TD 12?/<" Surface Hole drilled to 4367'MD/2602' TVD as indicated in Directional Plan E.=:: Fluid: Drilling mud ~ ~ ~ ~ ~ ~ r, Cement Plug(s) across hydrocarbon bearing zones TD 8-1/2" hole drilled to ~~`~ ~ ~. 8178'MD/4332' TVD ~ ~ ~ ~-~- as indicated in Directional Plan ConocoPhilli 5 Generic Off- Ice NEWS Wells Sheet 1 of 1 Schematic modified by TJB Alaska 12/28/2005 Cement retainer and plug across casing shoe REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 3 ,6 - ,] ~ ° j ,6 ,6 Pr os WE SA S ` :~ S -1R `n 4 19 ~ ~ 2^1 l 1 21 2 , 23 24 i y U N t 5 30 ~'~ T~ 29 8 2] 26 25 S-1 _ - 36 31 32 S ~ e 33 34 35 36 T12N { I • ~T11 N 6 DS-1A~ 3 e SGk 1 Pr ucti SCALE: 1 "- 200' (}/~11 MIN c ] 8 ~ ~F- ~• '~ qos is 9 ' 10 11 J 12 { / \\ // ` ' 4... 1 VICINITY MAP Scale: 1" = 2 Mile ° -o ~'o 50 ~ 20 ocn 160 a _ o ~R,F ,y ~ S 1 y -o geX, ,N ~~tit1~DUmPS\ec M \. ~ ~ ooW v Q ~ ~ EP°O~ 8p1 ~ d fJ OCi ~ Ce g1~ O\C o~y wesNpR CP, C ~5, \ o ° °~ 0. ~C O ; ~~ a ~ ~~ o o, K ~o~;F ~O.O~ 00 N NOTES: 1. Y,X COORDINATES ARE ASP, ZONE 4, NAD 27 . 2. GEODETIC COORDINATES ARE NAD 27. POINT Y X LATITUDE LONGITUDE 1R-E 5,994,294' 554,537 ~ 70' 23' 42.36" 149' 33' 22.52" LOUNSBURY 1H-N 5,994,301 554,555 70' 23' 42.43" 149' 33' 21.97" & assocral~s, n1rc. 1H-S 5,994,308 554,574 70' 23' 42.49" 149' 33' 21.42" SURVEYORS 6NGINSBRB PLANNERS ~ ~,/ AREA: MODULE: UNIT: ConocoPhi 11 i s WEST SAK NEWS WELLS p GGRE ICE PAD Alaska, Inc. PROPOSED CONFIGURATION. CADD FILE N0. LK601D623 s s o5 DRAWING N0: NSK 6.01-d623 PART: 1 of 1 REV: 0 O p (f i. ~~ ~ ~ jN ...... oyw ~' ~ ~ o a ~ N 9 0 a ' ~T~ 1 ~` ~~. II ~ ~ a o ~O ~ s CAS e \ F 3 ~ ~ WO 1 r .~ - ....._ , ...- ui _ - ~ o ~ ~ 0 F ¢ ~ F ~.... :~~ N ° •1~ ~ t'} Proposed ~ n ~ ~° __ .$ ~ ~ ~Nwao ' ~ Q ~ ~ ~ WEST SAK SATELLITE ;~ ~~f}'~' ' ~~ a ~ Y~ ~~ ° a A ~ ° ~ s~~ , GGRE PAD ~-- ~~~'o -~ Na ~, i. ~j~ t . .a F •.~ °o Z °S,J 4 U 3 4 - r..,~ a --' '~ Y a -S t ~' ~ b ~ '' F F`~ym I b°` i~F ~ryA ~~ ,~ .. 9 A 8 @@~1 a y~ e yl? `5 ~ 1 ~ ~ Ch ~ 1 '3 , ~ f ~ ~ ~ c Y ~ x ]k ~°• ~"~3 "~ ° I Q 114) U '~ ~.~''f ~:~I ~""`~~ i tl ~ l~ ~ .. ~` } N 1 F `~ fi ft .t ~ ~ f _ 1 1 } 1 yr `J 0 i}~ /O v' v` ~~ W W i0 I~ in j~ ~ ~ O i0 ~ d M O ~ O M d' M ~ ~ ~ iq i7 ~ i~ in in in in d~ M Z M M M M M M M M M M O ~ OI 01 O] O) ~ OI 07 ~ ~ a _ s O s M A N ~ s M s n a t0 M N O O M ~ N ~ N M N 1+ j d • ~ N N N N N N N N N Q o o o o o o o o o a ~ n n n n n n n n n n O n O n 0 CA ~ M ~ 0 n n OI n N ~ 00 a x 'n m ° 1~n 1~n lMn ln l°n 1°n ~ ~ ln l~n a u~ In In In In In ~ In In In v~ Q 0 M N M ~ ~ 0 ~ M M M 0 0 Cn In O O O 0 ~ O 0 0 ~ j lp i O n ~" ~ o n ~ ~ 00 n n ro a o rn rn rn rn rn rn rn rn rn rn rn rn to 0 an N to <n 0 N u7 In Z a Q O N M ~ M 0 n O W ~- m a a a a a a a a a N Z ~ ~ Z ~ • ~ ~ •~ o Q a ) Zo V pOo O m N V o O ~ z ~ ~•, n lii z ~ 0 HO Z ~~ 0 Z U o Y U J }1A ~PI~SA~ ~~ ~~ ~ ~~gl r~ I l i ~ ~r~ a ~ o`~ ~.1 > ~1P~'4A '~ "R p ~~ + -1H ~t ~i ~t~~ {~~ 1k'1} +I C~ ' {' ~ J ,O a. / ~ ~~~C ~ e ~A 1 b • ¢ '6 r,~ ~ ~ 4l' O a~ ~ •Y /U 1 ~ ~ ~ 1 ; "1 ('~ 5 ~ a / ~~`' ~ ~~~ ~ ~ PIT A ~. ~o~~ ~ ~"yy~~ o •-U T72N i t v P+• m ~t~~ ~ ~ ~~ li ~`~ .5 ~ 1 ~ ~ 1 a '{v' 1 ~"•• "~ 1 ~+.~~, r 1 l~r' fit ~ ~ ~ a ~ ~ it 4 ~~ ~ ~`--`~ ~ - i ~• ~. P -, i ~` ~ ~~ 1 u A~ TRIP ; ~ , f~ a~ KUP ~Z '' ''~ ~ PI tiA~k~~ ~~ , • 1• • W M M ~ O M i~ N O1 p~ ~ ao ri ao ~ of ri au lrj o0 ~ N O M O In O ~ H ~ M M M M N N N M M Z M M M M M M M M M O O CA O O O CA W CA T J d' ~ ~ ~ ~ ~ :- In 0 in O M 00 ~ in W ~ N W pi ^ 00 N 00 p M O M p ~ N N d' ~ N N N N N N N N a O 'O 'O 'O 'O O O O O J \ 1 \ ~ I \ r ` ' \ ryN p N In N M N N 0 X 10 N .M- N ~ N r r 1 D p_ ~ In In In In In In ~ In N Q ,~ p~j c00 n 10 n M ao N CA In 00 N IA N N ~ ,co rn n rn n rn n rn ro rn ao rn rn rn rn rn rn rn In In In In u] In In In lri ~ O ~ ~ ~ ~ N M ~ Ln tD n ~~ ~ m a a a a a a a d N U ~ ~ ° a o ~ ~ o ~1: O O ~ 5 N ~ m M ~ O Z n ~ ~ a ~w a \Y ~ ~ ~ N W ~~, O c NNN '~ C NQ ~ Y N Q Z O Q 0) ~ U N .U/ Z ~ ~ ~ m Q p ~ N rN-, Sao 30 °~'v ° `o 0 O .U. D~U 7 O U O` ~ C'+. 0 -O N ~ om °o a°1 ~~, W~UC.O ~ ~ N ~ (V M ~ 1.1 U Z o v ~' ~ 1 5Qy~y1NPT Pad r N ~' .~• V~ ¢~ ar '` •'~- " . ~ ~ a ~ BOP • -~ ~ ~ ,~ 1 I ~ o / a ~. ''~ ' s-i c ~ o ,\ ~ 4 ® ,~ _ , fP~~' SHARON K. ALLSUP-DRAKE 1125 CONOCOPHILLIPS AT01530 ,.~ 700 G ST. ~~ ~z~s ANCHORAGE AK 99501 [J ~/ DATE ss-1551/441 ~i PAY TO THE ~~~~ ~ /~-/ 1'jF-~ ~~~ ~ ~ (it-'. V~ ORDER OF _ ^(~ l DOLLARS 13I °; Dea snn Bacx J PMOrganChase ~ j Valid up To 5000 DDIIars JPMor~an Ghase Bank, N.A. A - Columbus, OH MEMO ~ ~~` ~~ ~ /~G•+f` i ~:044LL55L1~:528747L90?927ii'LL25 • • ~ • Tg~NS.LIITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TR4NSyiITTAL LETTER WELL N A~IE ~LZ~ W ~ `iZ' t~'.5~ PTD# ~ ~~ ~ ~' ~~ ~~ 'E-F Q\ e~o `~ :~CLLTE.. CHECK WHAT ! ADD-ONS ,I APPLIES ~ (OPTIONS) The permit is for a new wellbore segment of 1~TCTLTI ~ LATERAL ~ existing well , Permit No, API No. , '; (If API number ;Production should continue to be reported as last two (Z) digits ~ a function of the original API number stated are between 60-69) ~ above. ~ i i ' all i PILOT HOLE ; In accordance with 20 AAC 25.005(f), (P~ i records, data and logs acquired for the pilot !. hole must be clearly differentiated in both ' name on permit plus PH) ~; ~ !name ( _ I ': and A.PI number (~0 ~, i 170/80) from records, data and togs acquired ~; for well (name on permit). j SPACING I The permit is approved subject to full EXCEPTION ~' compliance with 20 AAC 25.055. Approval to ', ', perforate .and produce/infect is contingent ', upon issuance of a conservation order' !approving a spacing exception. ~, (Comnanv Name assumes ' the liability of any protest to the spacing '; ~ exception that may occur. DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01!05 C\jody\transm ittai_checklist • • ^^ rn o ~ , a~ a y y ~ , m o ~ ~' ° ~ U ~ 3 ~Q U' E' O. a~ O, >, vi, a ° _, d ~ ~ ~ ~ ~ ~, ~~ •~ ~ vi ~ a c W O ~ ~ O. ~ ~ ~ ~ ~ O. ~ U' ~ ~ ~ f6 ~' N N D' O ~ : ~ ~ ~ N ~ ~ f ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ p ~ ~ ~ ~ f6 ~ ~~ ~ ~ ~ ~ ~ ~ ~~ 4 O~ ~ y ~ c rn' 3' ~' y ~' ~ ~, ~ •y g' • 3. o, ~, ~ aY , i vi . y, co - ~ , ~ _ y ~ ~ o ~ oa °, rn S v. °, ~, 4 ° rn . ~ ~ ~ ~, o. d. ~ ~, . ~~ ~ ~ c ~~ °~ 4.. 4 ~ ~ ~3, ~ c. w. v c. W ~ O ~, ~ ~ • ~, a~ ` , ° ° , o, m U ~ U a ~, v ~~ ° ca _ ,aa m. ~ ~ os c~, ~ ~ ~ Z. ~ ~, ~f' m ° Z~ ~ ° ~ ~ ri ~ "o ' ~' a~ z' _' o m' a' ~, ~; x ~ ~ , ~ y ~ ~ ~ ~ y ~ ~ ~ ~ ~ ~ lJ.. ~ N. U. ~ ay..• ~ 'p. N ~ p. ~ 'y~ ~ ~ C. , .p N > y' C. (O. ' ~~ ~ ' ~~ ' ~ ' ~ ~' Q ~ ~ ~ ~ ~ ~ W ~ O ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ -~ ~ f6 ~ ~ ~ ~ d y O. ~ ~ ~~ ~ t! '~ O ~ '~ 'C 4 4.. N~ fn O a p M (D N ~ pp ~ ~ i ~~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N+ ~ ~ ~ c~ y . ~ ~ L_~ ~ ~ ~ 4 ~ . ~ ~ ~ ~ .p~ ~ ~ ~ ~ ~ N, s G ~ . . ~ _~ V~ ~, ~ ~ ~ ~ ~ ~ c. ~ ~ ~ ~ ~ ~ N. ~ ~ ~ ~~ ~ T ~ N. ~ ~ ~ ~ N. _~ ~ N• ~ y. E ° ~ 3. ~ ' ~ ~ ' ' '~ 14~ ° ° ' m' a ' °, 3 0' y ' L m C7 - ~ m w, ~ i o >+ E ~ L' r' v v ' i o _ H ~ w U p. Q. z. a ~, a, g g Z. Z. w. C7 ° ~ a , 0 y, y y. y f/D y. y, y y~ (/A y~ y fp ~ ~ ~ y~ y. VA Uk y. ~ y. fA~ y y~ y' y~ y. y. y. y. ~ y. a A ~, }, }, r, }, }, }, >-, >-, >-, >-, >-, >- Z Z Z Z ~, Z } Z >-, >-, ~, Z >-, >-, >-, >-, >-, >-, ~, Z Z ~, >-, ~, Z >-, ~ T ~ p J f O' , - ~ ~ o ~ , • , ~ Z ~' ~ ~ ~ c O. a ~ - ~ a`~, 3, ~, i 3; c o~ v J Q. N. U_ N C' C• ~ U ~ ~ O• y Q ~ ~ ~ ~ Z' ~ ~ ~ ~ ~ ~ ~ V, N' y' y. ~ ~ Of ~ ~ ~ ~ `~ ~ ~ ~ ~ ~~ ~ . ~ ~ ~ ~ ~ ~ U o~ ~ , o , ~ m, ~ c N o Q ~ ~ ~ ~ ~ ~~ 4 T L' -O~ c O. ~~ ~ ~ ~ ~ y. y ~ O. ~ C Qy ~ C,A ~Y' a ~ ~ N~ N• y. vi ~ ~ ~~ m ~ M 1 a' ~ ~ ~ ~ 7. N. ~ ~ ~ '"' ~ C• Y •~ .N. C. a0' y' vy O. p~ O. y ~ ~ ~ c• V1. ~ _~ N. c. ~ >~ N• N. W { ~ ~ ~ ~ O ~~ ~ ~ ~ ~ O, ~ 0 N. ~ ~ . ,N. U. d ~ C. ~ O, - py ~ ~~ ~~ a~ N. ~ ~ Vl. ~ ~ U _~ ~ ~ ~ rn ~, 2' ~, • ~ ~ g. ~ ~,, ~ ~y ~ rn L ~ ~ C' y ,~, T Cf O' Q' y' y' N~ N ~ Z Y - ~ -6 o c. v' ~ °~ ' a °, ~ y. c. ' a ,n m, .a~, m >~ ~ .p, w y. ~ ' o. c, ° ° c >~ m. ' o. o, v. 4 _ rn ° ~~ , y ~ ' ' s, c y, ' ° c ' c. o' o. o~ rn ° ~ ~ E, E = a. c c E ~ ~ o °, i c , c; m H ' c o a ~tS Q?' ~ c, ~ ~ • o: ° o N L d c c ~ Q ° ° ~, ~ a, ~, ~ ~ N o o T a ~ ~ ~, ~ j ~ ~ a~ ~ o, ~ a, ' ~, , 3, ~ ~, ~ Y ~ N fn a ~ ~ ~~ o y, N' ~ c O 7 ~ o w 'a f6 ~ u~ ~ ~ O' ~O' ~ a~ tO, O ~, io Q~ ~, f0' ~, %, y, v o. T ~ a ° C N a~ , Y g ~ a~; ~~ a c c a~ m. ~ s' ° L ~ ~ ~~ ~ ~ . ~ S °; ~ ~, ° m, ~ ~. 3' '= ~ a o ~~ L m a ~ 3 .~ ~ m a ca s v ~ v m c y i a s ~ o c >> U ~ . c• ° . o, p, in, ~ ~ 3, 3 a a> `~ m , . , y N, y' a . •m 3 '~ . 3; ~ M ~, O a . ~, u~ o, ' ° a fl, , ,.-, o ~ ~ , 3, a~ L; °~ °' o w U . o a ~ O ~' c' v, > ~, v. v N . > . ~' _ . .. c , _. > ~' , o' , v' o a i o' a , , , O o Z' y O J a J a' N Q f6 ~ ~ .O~ N . . ` O d ~, N' ~ Q~ U. O ~~ T ~~ >~ O D. m' ~' C• O' O' U~ U' O' ~' d O' ~' ~' Y. Yj N ' - ~ O. -° O y ~ N' v E N~ O E f6' 01 O' ~ .c O. ln' ._, ~ N n T C' N~ C~ O' O ~ = L• v O. m . ~ E ~ ~ ~ ~, ~~ o o O< y~ 4 !~ y~ ~ Q m ~~ ~~ N. w~ o 'c a ai , Y ~ m co m N• ~ f0' ~ o ~~ ~ ~ c. U. >, ' - 3, N. ~, _ y. O. !~ y' c, L~ o p ' v a m p . ~, . a`r . m c_' ~ . . °' 3' °' a a ~, N x m ui ~ . a ~ 3 t, , . ~° ~ L of c °' °' m m >, °, y' oj c' vi ~' °c ~ p a d m v °' ~' ° . c. ~ ° ~~ v' ~ °> . . y' :. >, ~ m ii U f6' s' -' ~°' 0 ~°' ~°' v' (6 0 a U y N 'O ~ O , y ~ . 3 . , y ~ ~ O y C N O N G p O ~ ~, °, ~~ .r + 3. m. . ~, w, ~~ 0~ ~p, ca. u~, L. C. o G ° E d~ m 3. . ~ ~' ~ o ° m, m' ~' , , a~ a?, , , - -, 4;, , ~ a ~~ ~6 . (6. c c ci . C. m, rn . . f4. m c~, c, O ~ , , 3 J \ Y ~ a°i •~ °~ °~ °~ ~ ~ fl. 4 ~ ~ ~ ~ , ~ U o', ~ ~, g', ~' ~ a °~ a 'a' 'c~ O. O. r; °' °' a°i' a~' ~, •a af6i~ o, p U c a, -,, ~, ~, ~, ~, cq, _, O, O, a, a, U ~, Q, a, Q, U, cn, U, U, U, U, Q, _, Q, V-, o, m, m, U, ~, ~', ~, a, o, cn, cn, U w a ~ O ~ N M '7 to (D I~ M O O N ~ M ~ V' t!') CO 00 O _ O N N N N M~ N N ~ (O N N _ f~ W O O N N N M M N M tt M M M M O M M N O Q7 M M M -- U U __ ~ ~ ° o °°o o O O 1~6 N ~ f6 ~ Y t0 N V O ll.l r ~ M ~ ~ ~ C ~ N~ D M ~ O N ~ d L . r C ~ E o N g ~ d ~ ~ O E O /~ V C C U a ~ Q Q U w a w 9 Q U i- t C] Well History File APPENDIX • Inforrrration of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Schlumberger ~ Schlum6erger Fluid Analysis of MDT Samples ,....~. ConocoPhillips ~~Y r Field: West Sak ~~ We11:1R East - - ' *:. ~o~~ ~~~~~I ~- ~_ Black Oil Full PVT Study Report ~ ' ,. ~.. Prepared for "" Michael Werner / Dennis Wegener ~° ConocoPhillips ~`~~~~~ Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F ~{EGEIVE JAN ~, 2 2ao~ Prepared by: Stefan Smuk Schlumberger a~gk30i1&GasCons'~ WCP Oilphase-DBR ~ 16115 Park Row, Suite 150 Houston, Texas, 77084 (281 ~ 285-6370 Date: 05/23/2006 Report #200600071 So -oaR - a3 ag 5 -ov -oc~ '~ 1~d 3 W ~t Client: ConocoPhillips field: West Sak Well: 1 R East Sand: B & A3 Schlumberger Installation: - Job #: 200600071 • Table of Contents List of Figures ................................................................................................. .................................................. 2 List o/Tables ................................................................................................. .................................................. 3 EXECUTIVE S.UM.MARY ............................................................................... .................................................. a Ob%ective _ ................................................................................ .................................................. 4 Introduction ..... .................................................. 4 Scope of Work ................................._............................................................ .................................................. a Results _ .................._..................._................_.......... .................................................. a PVT Study Data.Quality..Check.S~mmacy ............................................................. .................................................. s Sequence of Events .......................................................................................... .................................................. 6 Chain of Sample.Custody .................................................................................. .................................................. s RESULTS AND..DIS.GU.SSLONS ..........................................._........................ .................................................. ~ Fluids Preparation.and.Analysis ........................................................................ .................................................. 7 Reservoir Fluid.Analysis ................................................................................... .................................................. 7 PVT Analysis on.Sample.l.OZ;.Cylinder.CSB8G16-QA;.Deptb.Z3fi9fL.MD ................. .................................................. t5 Constant Compasitian.Expansion.at.Tres ............................................................ .................................................. t5 Reservoir Oil Viscosity at.Tres ........................................................................... .................................................. t7 Multi-Stage Separation.Test ............................................................................. .................................................. is PVT Analysis on Sample, 1.18; .C.ylindex. CSB.17.42-QA;.Depth2550 ft..MD ................. .................................................. 36 Constant Compositian.Expansion.at.Tres ............................................................ .................................................. 3s Reservoir Oil Viscosity at.Tres ........................................................................... .................................................. 38 Multi-Stage Separation.Test ............................................................................. .................................................. ao Appendix A: Nomenclature.and.D.efinitinns ................................................................................................ 50 • Appendix B: Mnl.ecularWeightsand.Densities.Used ................................................ ................................ 5t Appendix C: EQUIPMENT......_ ..................................................................................... ................................. 52 Fluid Preparation.and.Validation ......................................................................................... ................................. 52 Fluid Vo/umetric.(PV11and.Viscosity.Egnipment ................................................................ ................................. 53 Appendix D: PROCE.DU.RE .......................................................................................... ................................. 55 Fluids Preparation.and.Validation ...................................................................................... ................................. 55 Constant Composition.Expansion.Pracedure ........................................................................ ................................. 55 Differential Vaporization.Pracedure .................................................................................... ................................. 55 Multi-Stage Separation.Iest .............................................................................................. ................................. 56 Liquid Phase Viscosity.aad.Density.MeasureroentsDuring.DY.Step ....................................... ................................. 56 Stock-Tank Oil.(STD).Viscasity.and.Density.Measurements .................................................. ................................. 5s Asphaltene, Wax.and.Sulfur.Content.Measurements ............................................................. ................................. 57 SAR(PlA Analysis .............................................................................................................. ................................. 57 High-Temperature high. Pressure.Filtration.Test ................................................................... ................................. 57 • Dilphase-DBR 1 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Installation: - Job #: 200600071 Sehlumberger . List of Figures Figure 1: Stock lank .O.il .Chromatogram .(Sample 1.07.- ............... _ ................................................................... figure 2: k-Plot.far.Equilibrium.Chec.k(Sample.].07.- ....................................................................................... Figure 3: Constant.Camposition.Expansion.at I9.0°F -.Relative V.olume ............................................................. Figure 4: Reservoir.Fluid.11iscosity.79°F ......................................................................................................... Figure 5: Stock Tank.O.il.Chromatogram.(.S.ample1.09- .................................................................................... Figure 6: k-Plot.fnr.EquilibriumCheck(SampleJ.09- ....................................................................................... Figure 7: Stock Tank.O.il.Chromatogram.(.S.ample 1.10- ................................................................................... Figure 8: k-Plot.fnr.Equilibrium.Check(Sample.1.10) ..................................................................................... Figure 9: Stock 7ank.0.il.Chromatogram.(.S.ample 1.11- ................................................................................... Figure 10: k-Plat fur. Equilibrium.Check.(Sample .1.1.1) .................................................................................... Figure 11: Stock.l<aok.Oil.Chromatogram.(Sample.1.18- .................................................................................. Figure 12: k-PlatfocEquilibrium.Check.(Sample.1.18) .................................................................................... Figure 13: Constant.CompositionExpansianat.81.0°F-.Relative.Yolume .......................................................... Figuro 14: Reservnir.Fluid.Viscosity.81°f........._ .......................................................................................... Figure 15: Stock.Iank.OilChromatogram.(Sample.1.20- ............................................................................... Figurelli:k-Pint far.Equilibrium.Check.(Sample.1.20) .............. _.................................................................. ~' Figure 17: Stock.Iaok.Oil.Chromatogram.(Sample.1.21.) ................................................................................ Figure 18: k-Plntfor.Equilibrium.Check.(Sample.1.21- .................................................................................... J • 13 13 tfi 1a .. 25 .... 25 ... 28 28 31 31 34 34 37 39 46 46 49 49 Oilphase-DBR 2 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Schlumberger Installation: - Job #: 200600071 • List of Tables Table 1: Well and.Sample.Identification ..................................................... ........................................ 9 Table 2: Well Position Data .................................................................... ........................................ 8 Table 3: Sampling and Transfer Summary .................................................... ........................................ 9 Table 4: Reservoir Fluid. Properties ........................................................... .............................. . ......... t0 Table 5: Stock-Tank.O.il.P.coperties ........................................................... ........................................ to Table 6: C36+ Composition,.GOR,.`API,. by Zero-Flash .(.S.ample.1.01.- ......................... ................................................ 1 t Table 7: Calculated.Fluid.Praperties ..................................................................... ................................................ t2 Table 8:Summary.of. Resulis.ot Sample.1.07 ........................................................... ................................................ to Table 9: Constant.Composition.Expansion.atZ9..0'F..(Sample.1.O..I- ............................ ................................................ t5 Table 10: Reservair.Fluid.Viscosity.79°F ................................................................. ................................................ t7 Table 11: Multi-Stage.Separation.Test.Vapor.&Liquid. P. roperties ............................ ................................................ 20 Table 12: Multi,Stage.Separator.TesiVapor..Composition(mol%.) ............................ ................................................ 2t Table 13: Multi-Stage. Separator.IesL Residual .Liquid .Composition .(mol %.- .............. ................................................ 22 Table 14: C36+ Composition,.fOR, °AP.I,.by.Zero-.Flash.(Sample.1.09.- ........................ ................................................ 23 Table 15: Calculated Fluid Properties ................................................................... ................................................ 2a Table 16: C36+ Composition,.GOR,'APi,.by.Zero-.Flash.(Sample.1.10- ........................ ................................................ 26 Table 17: CalculatedF.IuidProperties ................................................................... ................................................ z~ Table 18: C36+ Compasition,.C~OR, °APl,.by.Zero-.Flash.(Sample.l_11.- ........................ ................................................ 29 Table 19: Calculated Fluid Properties ................................................................... ................................................ 30 Table 20: C36+ Compasition,.GOR, °API,.by.Zero-.Flash.(Sample.1.18- ........................ ................................................ 32 Table 21: Calculated Fluid Properties .................................................................. ............................................... 33 Table 22: Summary. of.Results of.Sample.1.18 ......................................................... ................................................ 35 Table 23: Constant .Composition Expansion at.81.0°F. (Sample. ]..18- .......................... ................................................ 35 Table 24: Reservair.Fluid.Viscosity.81'F ................................................................ ................................................ 38 Table 25:Multi-Stage.Separation.Test.Vapor.&Liquid.Properties ............................ ................................................ 4t • Table 26:Multi-Stage.Sepaxator.TeskVapox.Composition(mol%.) ........................... ................................................ a2 Table 27:Multi-Stage.Separator.TestResidua(.Liquid.Cumpositian~mol%.- .............. ................................................ a3 Table 28: C30+ Compasition,.GOR,'AP.I,.by.Zero-.Flasb.(Sample.1.20- ........................ ................................................ 44 Table 29:CalculatedF.IuidProperties ................................................................... ................................................ a5 Table 30: C30+ Compasition,.GOR, °APl,.by.Zero-.Flash.(Sample.1.21.- ........................ ................................................ 47 Table 3l: Calculated Fluid Properties ................................................................... ................................................ as • Oilphase-DBR 3 Job #: 200600071 Client: ConocoPhillips Well: 1R East Field: Sand: West Sak B & A3 Schlumberger Installation: - Job #: 200600071 • EXECUTIVE SUMMARY Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected during the modular formation dynamics testing (MDT). Introduction At the request of ConocoPhillips, Oilphase has conducted a fluid analysis study on bottomhole fluid samples collected during the modular formation dynamics testing IMDT) of Well 1 A East drilled in the field West Sak. Scope of Work • Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for five • Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas-Oil Ratio (GOA), reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon samples: • Seven bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for five days. • The zero flash GOR was determined to be from 162 - 324 SCF/STB, and the STO density to be from 0.934 - 0.954 g/cc. • One representative sample from each sampled depth (7369' MD and 7550' MD, 1.07 and 1.18 respectively) was selected for detailed PVT testing. PVT sample 1.18 underwent demulsification prior to analysis; the quality of the tlemulsificationtyas verified by BS&W analyses. • The results of the two sets of PVT analyses are presented below. Sample 1.07,• Cylinder CSB 86J6-DA; Depth 7369 /t. MD, 8 Sand FLASHING OPERATION CUMULATIVE GOR (scf/stb) API GRAVITY Gas Relative Density (air=1) FVF at Pres/Tres FVF at Psat/Tres Zero Flash 233* 17.70 0.580 1.086 1.088 DL Flash Q Tres - - - - - SeparatorTest 242 17.09 0.581 1.092 1.093 Sample 1.18,• Cylinder CSB 7741-(JA; Depth 7550 h. MD, A3 Sand FLASHING OPERATION CUMULATIVE GOR (scf/stb) API GRAVITY Gas Relative Density (air=1- FVF at Pres/Tres FVF at Psat/Tres Zero Flash 230 19.89 0.650 1.098 1.099 DL Flash Q Tres - - - - - SeparatorTest 213 22.29 0.619 1.077 1.078 "The single-stage flash of sample 1.07, B Sand, was confirmed by duplicate tests. • Oilphase-DBR 4 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Schlumberger Installation: - Job #: 200600071 • Quality Assurance Process Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment. A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Quality, Health, Safety and Environment (QHSE) requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request. The lah-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results a) Establish quality of measurement during data generation. b) Establish quality of processed data as per checklist during data processing by Data Quality Engineer. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency dl The responsible Project Engineer confirms consistency of reported data e) Engineering Project Manager review the results/report for overall consistency Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity. All property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request. The file and laboratory records information are listed below to provide access reference to all records related to this project. for any questions, please do not hesitate to contact the undersigned Project Engineer. File No.: 200600071 Laboratory Records:200600071 • Data Quality Suyu Ye Data Quality Engineer • Data Reporting Meisong Yan Project Engineer Overall Report Quality Clay Young Clay Young Oilphase-DBR Operation Manager, NGC Oilphase-DBR 5 Job #: 200600071 Client: ConocoPhillips Well: 1 R East Field: Sand: West Sak B & A3 Schlumberger Installation: - Job #: 200600071 Sequence of Events 05/04/06 Samples arrived. 05/04/06 Project work scope discussed. 05/04/06 Work agreement approved. 05/04/06 Prelim PVT tests request for all six samples issued. 05/25/06 Sample PVT prelim results sent via e-mail. Chain of Sample Custody The samples collected from the well 1 R East were sent to Oilphase-DBR in Houston, Texas. The samples were used to preliminary measurements and subsequent PVT studies. The measurement details are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. • • Oilphase-DBR 6 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Schiumberger Installation: - Job #: 200600071 . RESULTS AND DISCUSSIONS Fluids Preparation and Analysis Seven bottomhole samples collected during MDT operations were transferred to Oilphase-DBR. The wel! and formation data are summarized in Table 1, along with the respective reservoir conditions for the bottomhole samples. Quality checks of the bottomhole samples were conducted, and the results are summarized in Table 3. After 5 days of homogenization, sample validation tests were conducted to evaluate the validity of the samples. Three of the B-Sand samples were deemed to be unrepresentative, based on preliminary data which suggested irregularities of solution-gas content due to high drawdown during sampling. The A3 samples were judged representative. One representative sample from each sand was selected for complete PVT analysis. The reservoir fluid and stock-tank oil properties for all the samples are presented in Tables 4 and 5. Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GOR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 6, 14, 16, 18, 20, 28 and 30. The molecular weight of the stock-tank oil (STO) was measured. Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Tables 7, 15, 17, 19, 21, 29 and 31. The A3-Sand samples (7550 ft MD) had consistent GOR's, API's and compositions. However, samples from the B Sand, depth 7369 ft MD, had varied GOR data, despite similiar API's, STO compositions and flash-gas compositions. The GOR measurements for the B-Sand samples were double-checked. It was speculated that the differences in GOR might be due to sampling under tliphasic conditions, occurring as a result of high drawdown (410 psi) within the saturated reservoir. A3-Sand sample 1.1817550 ft MO) contained significant emulsified water. A demuisifier was added to the oil, and the cylinder was allowed to rest vertically for 24 hours. A subsample of flashed stock-tank liquid from the demulsifietl blend was analyzed by GC to confirm sample integrity. BS&W analyses were also conducted on subsamples taken from both top and bottom portions of the cylinder, to confirm the success of the demulsification procedure. Samples 1.07 (7369 ft) and 1.18 (7550 ft) underwent a complete PVT study, including the following elements: 1- Constant Composition Expansion (CCE) at reservoir temperature, 2) a three-stage separator test, with the final stage conducted at ambient conditions, and 3) viscosity testing at reservoir temperature, over a range of pressures. • Oilphase-DBR 7 Job #; 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Schlumberger Installation: - Job #: 200600071 • Table 1: Well and Sample Identification Client: ConocoPhillips Job# 200600071 Field: West Sak Well; 1 R East Sample ID Chamber # Chamber Sampling Date Reservoir Conditions Volume Sand Pressure Temperature Depth (cc) IPSIa) (°F) Iftl 1.07 MRSC 292 1 gallon 26/03/2006 B 1,707 79 7369 1.09 SPMC 448 250 26/03/2006 B 1,707 79 7369 1.10 SPMC 451 250 26/03/2006 B 1,707 79 7369 1.11 SPMC 446 250 26/03/2006 B 1,707 79 7369 1.18 MRSC 226 1 gallon 26/03/2006 A3 1,747 81 7550 1.20 MPSR 1295 450 26/03/2006 A3 1,747 81 7550 1.21 SPMC 230 250 26/03/2006 A3 1,747 81 7550 Table 2: Well Position Data Well Name Strat Name Latitude Longitude X Loc Y Loc 1R -EAST SURFACE 70.394812836 -149.559377734 1694568.09 5994045.69 1 R -EAST WEST SAK D 70.397372178 -149.605220793 1688928.07 5994944.11 1 R -EAST WEST SAK B 70.397414402 -149.605789636 1688858.35 5994959.10 1 R -EAST WEST SAK A3 70.397459657 -149.606496770 1688770.63 5994975.44 1 R -EAST WEST SAK A2 70.397507958 -149.607350332 1688666.42 5994991.98 Oilphase-DBR 8 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Schlumberger Installation: - Jab #: 200600071 • • • Table 3: Sampling and Transfer Summary Sample ID Chamber # Opening conditions in the field Transfer Cylinder ID Closing conditions in the field Opening conditions in the Lab Water content Transferred Sample Volume (psis/°F) (psia/°F) (psia/°F) (wt%) (cc) 1.07 MRSC 292 2015/65 CSB 8616-QA 1215/70 1265/72 0.3 600 1.09 SPMC 446 5515/65 SSB 13728-QA 4715/65 5015/72 0.8 245 1.10 SPMC 451 5615/65 SSB 12120-QA 5315/70 5515/72 0.7 245 1.11 SPMC 446 4715/65 SSB 13916-QA 4715/70 5515/72 0.8 235 1.18 MRSC 226 3715/67 CSB 7742-QA 915/66 2015/72 3.0 600 1.20 MPSR 1295 4215/65 CSB 8620-QA 715/66 2015/72 Z.6 425 1.21 SPMC 230 1915/69 SSB 11875-QA 5015/65 5265/72 2.9 230 Oilphase-DBR 9 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Schlumberger Installation: - Job #: 200600071 • • Table 4: Reservoir Fluid Properties Zero Flash Saturation Molar Mass of Monophasic Sample ID Cylinder # Depth GOR* Bo** Pressure monophasic fluid*** OBM at Tres fluid contamination (ft) (scf/stb) Ipsia) % Iw/w) 1.07 CSB 8616-QA 7,369 233 1.088 1511 226.5 - 1.09 SSB 13728-QA 7,369 162 - - 256.7 - 1.T0 SS812120-QA 7,369 196 - - 241.0 - 1.11 SSB 13916-QA 7,369 324 - - 197.8 - 1.18 CSB 7742-QA 7,550 230 1.099 1553 199.2 - 1.20 CSB 8620-QA 7,550 233 - - 199.0 - 1.21 SSB 11875-QA 7,550 221 - - 203.4 - * Flashed oas volume (scf) per barrel of stock tank liquid Q 60°F ** Volume of live oil at it's bubble point pressure per flashed stock tank liquid volume ~ 60°F *** Calculated from oil-based mud contamination in STO Table 5: Stock-Tank u~l Properties STO Properties Sample ID Cylinder # Depth Molar Mass Density API* OBM Contamination 1.07 CSB 8616-QA 7,369 370.1 0.9484 17.7 - 1.09 SSB 13728-QA 7,369 370.3 0.9515 17.2 - 1.10 SSB 12120-QA 7,369 369.0 0.9505 17.4 - 1.11 SSB 13916-QA 7,369 368.2 0.9539 16.8 - 1.18 CSB 7742-QA 7,550 299.0 0.9347 19.9 - 1.20 CSB 8620-QA 7,550 300.7 0.9344 19.9 - 1.21 SSB 11875-QA 7,550 302.3 0.9350 19.8 - " API =141.5/Density -131.5. Oilphase-DBR 10 Job #: 200600071 • • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 6: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.07) Sample 1.07; Cylinder CSB 8616-OA; Depth 7369 ft. MD Schlumberger Component MW Flashed Gas Flashed liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.25 0.10 0.00 0.00 0.01 0.04 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.43 0.26 0.00 0.00 0.01 0.10 Methane 16.04 93.13 97.43 0.00 0.00 2.81 39.60 Ethane 30.07 1.82 1.02 0.00 0.00 0.05 0.41 Propane 44.10 0.81 0.31 0.01 0.11 0.04 0.19 I -Butane 58.12 1.54 0.45 0.04 0.24 0.08 0.32 N -Butane 58.12 0.30 0.09 0.01 0.08 0.02 0.08 I -Pentane 72.15 0.87 0.20 0.07 0.38 0.10 0.31 N -Pentane 72.15 0.10 0.02 0.01 0.05 0.01 0.04 C6 84.00 0.35 0.07 0.13 0.57 0.14 0.37 M-C-Pentane 84.16 0.01 0.00 0.01 0.02 0.01 0.01 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.03 0.01 0.02 C7 96,00 0.13 0.02 0.15 0.58 0.15 0.35 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.02 Toluene 92.14 0.01 0.00 0.02 0.07 0.02 0.04 C8 107.00 0.11 0.02 0.30 1.04 O.Z9 0.62 E-Benzene 106.17 0.00 0.00 0.02 0.09 0.02 0.05 M/P-Xylene 106.17 0.00 0.00 0.00 0.02 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.03 C9 121.00 0.07 0.01 0.46 1.41 0.45 0.84 C10 134.00 0.04 0.01 0.89 2.45 0.86 1.46 C11 147.00 0.01 0.00 1.28 3.21 1.24 1.91 C12 161.00 0.00 0.00 1.76 4.05 1.71 2.40 C13 175.00 0.00 0.00 2.23 4.72 2.17 2.80 C14 190.D0 0.00 0.00 2.55 4.97 2.47 2.95 C15 206.00 0.00 0.00 2.90 5.21 2.81 3.09 C16 222.00 3.10 5.17 3.01 3.07 C17 237.00 2.94 4.59 2.85 2.7Z C18 251.00 3.12 4.60 3.03 2.73 C19 263.00 3.04 4.28 2.95 2.54 C20 275.00 2.85 3.84 2.77 2.28 C21 291.00 2.72 3.45 2.63 2.05 C22 300.00 2.78 3.43 2.69 2.03 C23 312.00 2.30 2.73 2.23 1.62 C24 324.00 2.32 2.65 2.25 1.57 C25 337.00 2.11 2.31 2.04 1.37 C26 349.00 2.10 2.23 2.04 1.32 C27 360.00 2.13 2.19 2.07 1.30 C28 372.00 2.05 2.04 1.99 1.21 C29 382.00 1.84 1.79 1.79 1.06 C30 394.00 1.90 1.78 1.84 1.06 C31 404.00 1.86 L7D 1.80 1.01 C32 415.00 1.58 1.41 1.54 0.84 C33 426.00 1.50 1.31 1.46 0.78 C34 437.00 1.51 1.28 1.46 0.76 C35 445.00 1.31 1.09 1.27 0.65 C36+ 930.00 42.07 16.74 40.80 9.94 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.78 370.13 226.51 MOLE RATIO 0.4065 0.5935 Oilphase-DBR 11 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: 8 & A3 Table 7: Calculated Fluid Properties Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD Schlumberger Properties flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole °10 C7+ 0.41 0.06 99.72 96.57 96.73 58.53 C12+ 0.00 0.00 96.56 89.54 93.65 53.15 C20+ - - 74.92 51.96 72.67 30.84 C30+ - - 51.73 25.32 50.18 15.03 C36+ - - 42.07 16.74 40.80 9.94 Molar Mass C7+ 105.48 374.45 374.33 C 12+ - 399.14 399.14 C20+ - 533.67 533.67 C30+ - 756.38 756.38 C36+ - 930.00 930.00 Density C7+ - 0.9498 - C12+ - 0.9567 0.9567 C20+ - 0.9971 0.9971 C30+ 1.0578 1.0578 C36+ 1.0963 1.0963 Fluid at 60°F 0.9484 Gas Gravity (Air =1 j 0.580 Dry Gross Heat Content (BTU/scf) 1,045 et Gross Heat Content (BTU/scf 1,027 OBM Contamination Level (uvt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 370.13 370.13 930.00 Density (g/cm31 0.9484 - 1.096 Single Stage flash Data Original STO De-Contaminated GOR (scf/stbj 233 - STO Density (g/cm3) 0.9484 - STO API Gravity 17.7 - OBM Density (g/cm3j Q60°F - Oilphase-DBR 12 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Figure 1: Stock Tank Oil Chromatogram Sample 1.07) Sample 1.07; Cylinder CS8 8616-11A; Ueptn i3ey tt. Ivlu FID1 A, (f.121DATA+A0600071'+CY8616.D) Norm. 350 JOB 200600071 CONOCO PHIILIPS 1.07 CSB 8616-QA RF FLASH CYLINDER 300 25D 200 150 100 ~ ~ ~ v ~ ~ ti C~ O~N(~~U1tDtia~~tl p~ o c m N m V ~1 r NNNNNNNNN~~~~,,,,,,,,,,,,~~~ 5O ~ °tl~ ~~ }, ~ r ~ '-' U U U U C C U C C C C C C C C Cv C~U'~ ~ ? ~ U c c cc~ or, ~ o U X U U U U c c , U ' C C C C ey i ~~ .,~., fj; i it .r....«...~.a 0 0 5 10 15 20 25 30 35 Figure 2: k-Plot for Equilibrium Check 15ample 1.071 Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD z • C3 1.5 --- ---- ----- • i • nC4 1 ------- - - -- --- - --- - _.- -- -- - • ACAS 0.5 - _ __ a. • C6 Y Q ~ __.. _._. __._ __.._. ___..._....___ O J ~ C~ - . 1 p _ _.... .. _ __ .._ _..._.__.---___ __,- ~ CU -1 ~ _ __ _ -_ _.cs. _ ___ __---- ---- -1.5 - - -~-G18 -2 -4 -3 -2 -1 0 1 2 3 F Oilphase-DBR 13 Job #: 200600071 • C Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 8: Summary of Results of Sample 9.07 Sample 1.07; Cylinder CSB 8616-OA; Depth 7369 ft. MD Schlumberger Reservoir Conditions: Pressure: 1707 psia Temperature: 79 °F Summary of Fluid Properties: OBM Contamination: - Wt% STO Basis OBM Contamination: - Wt% RF Basis Bubble Point Pressure At Tres 1,511 psia At 130°F - psia At 100°F - psia Gas-Oil Ratio Single-stage Flash: 233 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 242 scf/stb Properties at 60°F STO °API Gas Gravity (Average) Single-stage STO: 17.70 0.580 Differential Liberation STO; - - Separator STO: 17.09 0.581 Properties at Reservoir Conditions Viscosity: 81.4 cP Compressibillity (Co): 6.40 10-6/psi Density: 0.9002 g/cc Properties at Saturation Conditions Viscosity: 78.1 cP Compressibillity (Co): 6.47 10-6/psi Density: 0.8990 g/cc Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash: 1.086 1.088 Total Differential Liberation: - - Total Separator Flash: 1.092 1.093 Note: Standard conditions are 14.696 psia and 60°F The single-stage flash of sample 1.07 was confirmed through duplicate tests. • Oilphase-DBR 14 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 PVT Analysis on Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD Constant Composition Expansion at Tres Schlumberger The CCE study was initiated by charging asub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 79.0°F and at a pressure of 12,031 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 9. The pressure-volume (P-V) plots of the CCE data are presented in Figure 3. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,511 psia at the reservoir temperature of 79.0 °F. Also, calculated relative volume and oii compressibility is presented in Table 9. As seen in the table, the compressibility of this oil is 6.5 x 10e-61/psia at the saturation pressure. Table 9: Constant Composition Expansion at 79.0°F (Sample 1.07) Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD • • Pressure (psia) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density Ig/cm3) Y Function Compressibility 110-6/psia) 1 12031 0,9523 95.2 100.0 0.9441 3.2 2 11011 0.9555 95.5 100.0 0.9409 3.4 3 10015 0.9589 95.9 100.0 0.9376 3.7 4 9015 0.9625 96.2 100.0 0.9341 3.9 5 8015 0.9664 96.6 100.0 0.9303 4.2 6 7517 0.9685 96.8 100.0 0.9283 4.3 7 7015 0.9706 97.1 100.0 0.9263 4.5 8 6015 0.9751 97.5 100.0 0.9220 4.8 9 5515 0.9775 97.7 100.0 0.9197 5.0 10 5282 0.9786 97.9 100.0 0.9187 5.0 11 5082 0.9796 98.0 100.0 0.9177 5.1 12 4880 0.9806 98.1 100.0 0.9168 5.2 13 4651 0.9818 98.2 100.0 0.9157 5.3 14 4445 0.9829 98.3 100.0 0.9147 5.3 15 4053 0.9850 98.5 100.0 0.9127 5.5 16 3685 0.9870 96.7 100.0 0.9109 5.6 17 3062 0.9905 99.1 100.0 0,9076 5.6 18 2517 0.9937 99.4 100.0 0.9047 6.1 19 2012 0.9968 99.7 100.0 0.9019 6.3 Pi 1707 0.9987 99.9 100.0 0.9002 6.4 Pb 1511 1.0000 100.0 100.0 0.8990 6.5 22 1445 1.0135 99.5 98.2 3.4 23 1344 1.0374 98.9 95.3 3.3 24 1237 1.0682 98.2 91.9 3.3 25 1034 1.1474 97.1 84.6 3.1 26 830 1.2741 95.9 75.3 3.0 27 631 1.4910 94.9 63.6 2.8 oilphase-DBR 15 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 1.6 Figure 3: Constant Composition Expansion at 79.0°F -Relative Volume Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD 1.5 1.4 • 1.3 a E 1.2 0 0 m a .~ d ~ 1.1 1.0 0.9 • Oilphase-DBR 0.8 ~ 0 Pressure~psia) 16 Job #: 200600071 Client: ConocoPhillips Field: West Sak Sch~umberger Well: 1 R East Sand: B & A3 • Reservoir OiI Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 79°F. These values as a function of selected pressure steps are summarized in Table 10. The liquid phase viscosity values are graphically presented in Figure 4. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 10: Reservoir Fluid Viscosity 79°F Sample 1.07; Cylinder CS8 8616-QA; Depth 7369 ft. MD 1 • Pressure Viscosity @ Tres (psia) 1cP1 1 10010 313.90 2 9001 268.07 3 8007 227.88 4 7009 194.01 5 6010 165.27 6 5001 139.82 7 4005 119.09 8 3001 100.87 9 2010 92.05 Pi 1707 86.01 Pb 1511 84.05 12 1320 106.00 13 1037 145.23 15 760 220.54 STO 14.7 665.00 Oilphase-DBR 17 Job #: 200600071. Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Figure 4: Reservoir Fluid Viscosity 79°F Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD 700 a' 400 so0 500 y 0 U N > 300 • • 200 100 0~ 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Pressure~psia) Oilphase-DBR 18 Job #:200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 • Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 11 - 13. The fluid properties (i.e., GOR, density and oil formation volume factor) are presented in Table 11. Multi-stage separation test conditions are: STAGE 1 105 psia 125 °F STAGE 2 75 psia 185 °F STAGE STO 14.7 psia 60 °F As seen in Table 11, the GOR value obtained from the multi-stage separation test is 242 SCF/STB and the formation volume factor is 1.093. The compositional analyses of separator gas and tank gas are summarized in Table 12 and the composition of tank liquid is tabulated in Table 13. The total dry gross heat content of the separation gases is calculated to be 1,046 BTU/scf whereas the total wet gross heat content is calculated to be 1,028 BTU/scf. • Oilphase-DBR 19 Job #: 200600071 • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 11: Multi-Stage Separation Test Vapor & Liquid Properties Camnla 1 n7• Cvlindar CSR RR16-QA' Deoth 7369 ft. MD PROPERTY STAGE Ph STAGE 1 STAGE 2 STAGE STO Pressure (psia) 1511 105 75 14.7 Temperature (°F) 79 125 185 60 Liq. Den (g/cm3) 0.8993 0.9377 0.9307 0.9523 Vap. Gravitya 0.579 0.630 0.652 Vap. M,,,,, 16.77 18.25 18.90 Vap Heat Val." 1043 1121 1149 GOR` 233 6 3 GOR° 229 6 3 Sep. FVFe 1.093 1.017 1.024 1.000 Schlumberger a) Calculated, at 60°h (air=1) b) GalcWatea, ury basis ~ i u/sct cl sct gas/ooi or on at ~ ~ u ~unuwuns d) scf gas/bbl of oil at separator conditions e) fluid volume at sep conditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9523 g/cc Sep gas gravity (average) Sy = ERjSgj/ER 0.581 Where: R: GOR (scf gas/bbl of oil at STD conditions), j: separator stages Sep gas gross heating value la 4 =ERi*L~i/ERi 1046 BTU/scf (dry basis) Where: R: GOR (scf gas/bbl of oil at STD conditions), j: separator stages • SEPARATION TEST SUMMARY eTotal Separation Test GOR 242 Separation Test STO Gravity 17.09 Separation Test FVF 1.093 a) scf gas/bbl of condensate at 5I u conditions b) Fluid volume at Psat & Tres/Fluid volume at STD • Oilphase-DBR ZO Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 12: Multi-Stage Separator Test Vapor Composition ~mol %) Sample 1.07; Cylinder CSB 8616-OA; Depth 7369 ft: MD Schlumherger Component MW (g/mol) Mole STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.13 0.12 0.49 Hydrogen SulfidE 34.08 0.00 0.00 0.00 Nitrogen 28.01 0.28 0.37 0.27 Methane 16.04 97.60 93.06 90.01 Ethane 30.07 0.79 2.20 4.09 Propane 44.10 0.36 1.35 1.63 I -Butane 58.12 0.29 1.26 2.05 N -Butane 58.12 0.11 0.60 0.39 I -Pentane 72.15 0.14 0.54 0.64 N -Pentane 72.15 0.18 0.06 0.29 C6 84.00 0.06 0.22 0.12 M-C-Pentane 84.16 0.00 0.03 0.00 Benzene 78.11 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.02 0.00 C7 96.00 0.01 0.10 0.00 M-C-Hexane 98.19 0.00 0.02 0.00 Toluene 92.14 0.05 0.01 0.01 C8 107.00 0.00 0.03 0.00 E-Benzene 106.17 0.00 0.00 0.00 M/P-Xylene 106.17 0.00 0.00 0.00 0-Xylene 106.17 0.00 0.00 0.00 C9 121.00 0.00 0.00 0.00 C10 134.00 0.00 0.00 0.00 C11 147.00 0.00 0.00 0.00 C12 161.00 0.00 0.00 0.00 C13 175.00 0.00 0.00 0.00 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C 16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C 16 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 C20 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 30D.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 0.00 C25 337.00 0.00 D.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0.00 0.00 C29 382.00 0.00 0.00 0.00 C30+ 762.77 0.00 0.00 0.00 Total 100.00 100.00 100.00 MW 16.77 18.25 18.90 Relative Density (air=1) 0.579 0.630 0.652 Dry Gross Heat Content (BTU/scfi 1043 1121 1149 Oilphase-DBR 21 Job #: 2001100071 • • • Client: ConocoPhillips Field: West Sak Well: 1 A East Sand: B & A3 Table 13: Multi-Stage Separator Test Residual Liquid Composition (mol %- Sample 1.07; Cylinder CSB 8616-QA; Depth 7369 ft. MD Schlumberger COMPONENT MW (g/mol) Residual Liquid (mol %) Carbon Dioxide 44.01 0.00 Hydrogen SulfidE 34.08 0.00 Nitrogen 28.01 0.00 Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.07 I -Butane 58.12 0.42 N -Butane 58.12 0.07 I -Pentane 72.15 0.51 N -Pentane 72.15 0.06 C6 84.00 0.64 M-C-Pentane 84.16 0.02 Benzene 78.11 0.03 Cyclohexane 84.16 0.03 C7 96.00 0.56 M-C-Hexane 98.19 0.04 Toluene 92.14 0.08 C8 107.00 1.06 E-Benzene 106.17 0.10 M/P-Xylene 106.17 0.02 0-Xylene 106.17 0.04 C9 121.00 1.15 C10 134.00 2.17 C11 147.00 2.88 C12 161.00 3.69 C13 175.00 4.43 C14 190.00 4.77 C15 206.00 5.07 C16 222.00 4.83 C17 237.00 4.75 C18 251.00 4.59 C19 263.00 4.36 CZO 275.00 3.67 C21 291.00 3.72 C22 300.00 3.40 CZ3 312.00 2.90 C24 324.00 2.45 C25 337.00 2.54 C26 349.00 2.68 C27 360.00 2.16 CZ8 372.00 2.10 C29 382.00 2.12 C30+ 762.77 25.82 Total 100.00 MW 376.68 Oilphase-DBR 22 Job #: 200600071 • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 14: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.09) Sample 1.09; Cylinder SSB 13728-DA; Depth 7369 ft. MO Schlum6erger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.32 0.12 0.00 0.00 0.01 0.04 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.68 0.41 0.00 0.00 0.01 0.13 Methane 16.04 90.87 96.51 0.00 0.00 1.94 31.03 Ethane 30.07 2.30 1.31 0.00 0.00 0.05 0.42 Propane 44.10 1.15 0.45 0.01 0.12 0.04 0.23 I -Butane 58.12 2.16 0.63 0.04 0.27 0.09 0.39 N -Butane 58.1 Z 0.40 0.12 0.01 0.09 0.02 0.10 I -Pentane 72.15 1.13 0.27 0.08 0.40 0.10 0.36 N -Pentane 72.15 0.14 0.03 0.01 D.O6 0.01 0.05 C6 84.00 0.41 0.08 0.14 0.62 0.15 0.45 M-C-Pentane 84.16 0.01 0.00 0.01 0.03 0.01 0.02 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.04 0.01 0.03 C7 96.00 0. i 6 0.03 0. i 8 0.68 0.18 0.47 M-C-Hexane 98.19 O.D1 0.00 0.01 0.04 0.01 0.03 Toluene 92.14 0.01 0.00 0.01 0.06 0.01 0.04 C8 107.00 0.11 0.02 0.31 1.06 0.30 0.73 E-Benzene 106.17 0.00 0.00 0.03 0.09 0.03 0.06 M/P-Xylene 106.17 0.00 0.00 0.01 O.OZ 0.01 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.03 C9 121.00 0.06 0.01 0.47 1.45 0.47 0.99 C10 134.00 0.02 0.00 0.90 2.50 0.89 1.70 C11 147.00 0.01 0.00 1.32 3.33 1.29 2.26 C12 161.00 0.01 0.00 1.78 4.09 1.74 2.77 C13 175.00 0.00 0.00 2.11 4.47 2.07 3.03 C14 190.00 0.00 0.00 2.60 5.06 2.54 3.43 C15 206.00 0.00 0.00 3.08 5.53 3.01 3.75 C16 222.00 2.99 4.99 2.93 3.39 C17 237.00 2.96 4.62 2.89 3.14 C18 251.00 3.04 4.49 2.98 3.05 C19 263.00 3.08 4.34 3.01 2.94 C20 275.00 2.85 3.84 2.79 2.60 C21 291.00 2.70 3.43 2.64 2.33 C22 300.00 2.59 3.20 2.54 2.17 C23 312.00 2.43 2.89 2.38 1.96 C24 324.00 2.31 2.64 2.26 1.79 C25 337.00 2.19 2.40 2.14 1.63 C26 349.00 1.96 Z.O8 1.92 1.41 C27 360.00 2.03 2.09 1.99 1.42 C28 372.00 1.99 1.99 1.95 1.35 CZ9 382.00 1.98 1.92 1.94 1.30 C30 394.00 1.83 1.72 1.79 1.17 C31 404.00 1.83 1.68 1.79 1.14 C32 415.00 1.82 1.62 1.78 1.10 C33 426.00 1.45 1.26 1.42 0.86 C34 437.00 1.37 1.16 1.34 0.79 C35 445.00 1.24 1.03 1.21 0.70 C36+ 945.00 42.22 16.54 41.32 11.22 Total 100.00 100.00 100.00 100.00 100.00 100.00 M~/ 17.04 370.25 256.70 MOLE RATIO 0.3215 0.6785 Oilphase-DBR 23 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 15: Calculated Fluid Properties Sample 1.09; Cylinder SSB 13728-QA; Depth 7369 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.43 0.07 99.70 98.44 97.58 66.82 C12+ 0.01 0.00 96.42 89.07 94.37 60.43 C20+ - - 74.78 51.48 73.19 34.93 C30+ - - 51.75 25.01 50.64 16.97 C36+ - - 42.22 16.54 41.32 11.22 Molar Mass C7+ 104.19 374.98 374.89 C12+ 163.78 400.84 400.83 C20+ - 537.88 537.88 C30+ - 766.20 766.20 C36+ - 945.00 945.00 Density C7+ - 0.9530 - C 12+ - 0.9604 0.9604 C20+ - 1.0023 1.0023 C30+ 1.0659 1.0659 C36+ 1.1064 1.1064 Fluid at 60°F 0.9515 Gas Gravity (Air =1) 0.588 Dry Gross Heat Content IBTU/scf 1,056 Wet Gross Heat Content IBTU/scf 1,037 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 370.25 370.25 945.00 Density Ig/cm3) 0.9515 - 1.106 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stbl 162 - STO Density Ig/cm3) 0.9515 - STOAPI Gravity 17.2 - OBM Density Ig/cm3) Q60°F - Oiilphase-DBR 24 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B &A3 Figure 5: Stock Tank Oil Chromatogram (Sample 1.09) Sample 1.09; l;ylmder J50 13/Lti-Lt/a; ueptn /3by n. lulu rID1 A, (Fa21DA1AV100000711CY13728.G1 Norm. 350 JOB 200600071 CONOCO PHILLIPS 1.09 SSB 13728-QA RF FLASH CYLINDER 300 250 200 150 100 u~ ~ U~ U ~ m ti m ~o~Nmvu~cn~.o~o~ oq o ~ ~ V ~ ~ NNNNNNNNN`~07~j 5O ~ U~ U ~ ~ ~ ~ U U U ~ ~ ~ C CCCCCCCCC CCCC-C~J ~ h~ 3 W C~ ~" C OC C C C C C'! Ii IiI ~ ~ ill i'ili~j j ~ . ~ I'' I ILIA 0 0 5 10 15 20 25 30 • Figure 6: k-Plot for Equilibrium Check (Sample 1.09) Sample 1.09; Cylinder SSB 13728-QA; Depth 7369 ft. MD 2 • C3 1.5 -- --- - - ~ iC4- -- • nC4 1 -- ---- - -- - - -- - - --- --- • r~C~S- -- -_ _-._- _ _- -- Y • C6 C7 _ I .-__ C liU _-__ - -1 ~ -1.5 -4 -3 -2 -1 0 1 2 3 F Oilphase-DBR 25 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 16: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.10- Sample 1.10; Cylinder SSB 12120-QA; Depth 7369 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.30 0.12 0.00 0.00 0.01 0.04 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.45 0.27 0.00 0.00 0.01 0.10 Methane 16.04 92.62 97.23 0.00 0.00 2.35 35.34 Ethane 30.07 2.00 1.12 0.00 0.00 0.05 0.41 Propane 44.10 0.86 0.33 0.02 0.19 0.04 0.24 I -Butane 58.12 1.59 0.46 0.05 0.33 0.09 0.38 N -Butane 58.12 0.30 0.09 0.01 0.09 0.02 0.09 I -Pentane 72.15 0.89 0.21 0.09 0.45 0.11 0.36 N -Pentane 72.15 0.10 0.02 0.01 0.06 0.01 0.05 C6 84.00 0.36 0.07 0.14 0.63 0.15 0.43 M-C-Pentane 84.1& 0.01 0.00 0.01 0.03 0.01 0.02 Benzene 78.11 0.01 0.00 0.01 0.04 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.04 0.01 0.03 C7 96.00 0.15 0.03 0.18 0.71 0.18 0.46 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.03 Toluene 92.14 0.01 0.00 0.02 0.07 0.02 0.04 C8 107.00 0.11 0.02 0.33 1.13 0.32 0.73 E-Benzene 106.17 0.00 0.00 0.03 0.10 0.03 0.06 M/P-Xylene 106.17 0.00 0.00 0.01 0.02 0.01 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.03 C9 121.00 0.09 0.01 0.51 1.55 0.50 0.99 C10 134.00 0.07 0.01 0.90 2.49 0.88 1.59 C11 147.00 0.04 0.00 1.33 3.34 1.30 2.13 C12 161.00 0.02 0.00 1.77 4.07 1.73 2.59 C13 175.00 0.00 0.00 2.25 4.74 2.19 3.02 C14 190.00 0.00 0.00 2.56 4.97 2.49 3.16 C15 206.00 0.00 0.00 2.89 5.17 2.81 3.29 C16 222.00 3.08 5.12 3.00 3.26 C17 237.00 2.92 4.54 2.84 2.89 C18 251.00 3.09 4.54 3.01 2.89 C19 263.00 3.01 4.23 2.94 2.69 C20 275.00 2.81 3.76 2.73 2.40 C21 291.00 2.69 3.41 2.62 2.17 C22 300.00 2.60 3.20 2.54 2.04 C23 312.00 2.35 2.78 2.29 1.77 C24 324.00 2.28 2.60 2.22 1.65 C25 337.00 2.21 2.42 2.15 1.54 C26 349.00 1.95 2.06 1.90 1.31 C27 360.00 2.01 2.06 1.95 1.31 C28 372.00 1.97 1.95 1.92 1.24 C29 382.00 1.96 1.89 1.91 1.20 C30 394.00 1.97 1.85 1.92 1.18 C31 404.00 1.94 1.78 1.89 1.13 C32 415.00 1.54 1.37 1.50 0.87 C33 426.00 1.53 1.33 1.49 0.85 C34 437.00 1.32 1.11 1.29 0.71 C35 445.00 1.33 1.10 1.30 0.70 C36+ 940.00 42.30 16.61 41.23 10.57 Tota I 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.84 369.05 241.03 MOLE RATIO 0.3635 0.6365 Oilphase-DBR 26 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 17: Calculated Fluid Properties Sample 1.10; Cylinder SSB 12120-QA; Depth 7369 ft. MD Schlumberger Properties flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.53 0.08 99.67 98.25 97.15 62.57 C12+ 0.02 0.00 96.31 88.65 93.87 56.43 C20+ - - 74.75 51.27 72.85 32.63 C30+ - - 51.94 25.15 50.62 16.01 C36+ - - 42.30 16.61 41.23 10.57 Molar Mass C7+ 110.15 374.36 374.25 C12+ 163.11 40D.95 400.95 C20+ - 538.05 538.05 C30+ - 762.29 762.29 C36+ - 940.00 940.00 Density C7+ - 0.9522 - C 12+ - 0.9598 0.9598 C20+ - 1.0013 1.0013 C30+ 1.0634 1.0634 C36+ 1.1034 1.1034 Fluid at 60°F 0.9505 Gas Gravity (Air =1) 0.582 Dry Gross Heat Content (BTU/scf) 1,048 Wet Gross Heat Content (BTU/scf 1,030 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+Properties MW 369.05 369.05 940.00 Density (g/cm3~ 0.9505 - 1.103 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb~ 196 - STO Density (g/cm3~ 0.9505 - STO API Gravity 17.4 - OBM Density (g/cm3) Q60°F - Oilphase-DBR 27 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Figure 7; Stock Tank Oil Chromatogram (Sample 1.10) Sample 1.1U; GyllnderJ501LTZU-Wa; ueptn isbarr. Iv1u f@1 A, (F:4 IGATAVI090007110Y12120.G) Noim. ~0 JOB 200600071 CONOCO PHILLIPS 1.10 SSB 12120-QA RF FLASH CYLINDER 300 250 200 150 100 ~ m ~ ~ o ~, C ~ ~ tio~mo~Nm~~nc~m N t>7 ~ ~ ~ ~ ~ ° N N NN NNNNN6~k~~ ~ 50 ~ h~ 3 0 U o ~ ~ U UUUUUUUW U ~ C C C C CCCCCCCCCCCCCCC ~ U U ~ C p C C C ~ C C j ~~'; ;i j I ?' ' 'i ': (li I!~I i CC ~ I 0 0 5 10 15 20 25 30 35 mi • Figure 8: k-Plot for Equilibrium Check Sample 7.1u- Sample 1.10; Cylinder SSB 12120-DA; Depth 7369 ft. MD 2 1.5 1 Q, 0.5 Y J O -0.5 -1 -1.5 • C10 -4 -3 -2 -1 0 1 2 3 F • Oilphase-DBR 26 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 18: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.11) Sample 1.11; Cylinder SSB 13916-QA; Depth 7369 ft. MD Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.23 0.09 0.00 0.00 0.01 0.04 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.76 0.45 0.00 0.00 0.03 0.22 Methane 16.04 93.75 97.78 0.00 0.00 3.84 47.39 Ethane 30.07 1.46 0.81 0.00 0.00 0.06 0.39 Propane 44.10 0.52 0.20 0.01 0.12 0.04 0.16 I -Butane 58.12 0.90 0.26 0.04 0.27 0.08 0.26 N -Butane 58.12 0.17 0.05 0.01 0.09 0.02 0.07 I -Pentane 72.15 0.49 0.11 0.08 0.40 0.10 0.26 N -Pentane 72.15 0.07 0.02 0.01 0.06 0.01 0.04 C6 84.00 0.24 0.05 0.14 0.62 0.15 0.34 M-C-Pentane 84.16 0.01 0.00 0.01 0.03 0.01 0.01 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.01 0.00 0.01 0.04 0.01 0.02 C7 96.00 0.13 0.02 0.18 0.68 0.18 0.36 M-C-Hexane 98.19 0.01 0.00 0.01 0.04 0.01 0.02 Toluene 92.14 0.01 0.00 0.01 0.06 0.01 0.03 C8 107.00 0.16 0.03 0.31 1.06 0.30 0.56 E-Benzene 106.17 0.00 0.00 0.03 0.09 0.03 0.05 M/P-Xylene 106.17 0.00 O.OD 0.01 0.02 0.01 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.05 0.01 0.02 C9 121.00 0.18 0.02 0.48 1.45 0.47 0.76 C10 134.00 0.42 0.05 0.91 2.50 0.89 1.32 C11 147.00 0.34 0.04 1.33 3.33 1.29 1.74 C12 161.00 0.13 0.01 1.79 4.09 1.72 2.12 C13 175.00 0.00 0.00 2.13 4.48 2.04 2.31 C14 190.00 0.00 0.00 .2.62 5.07 2.51 2.61 C15 206.00 0.00 0.00 3.10 5.54 2.97 2.85 C16 222.00 3.01 5.00 2.89 2.58 C17 237.00 2.98 4.63 2.86 2.38 C18 251.00 3.06 4.49 2.94 2.32 C19 263.00 3.10 4.34 2.97 2.24 C20 275.00 2.87 3.84 2.75 1.98 C21 291.00 2.72 3.44 2.61 1.77 C22 300.00 2.61 3.21 2.51 1.65 C23 312.00 2.45 2.89 2.35 1.49 C24 324.00 2.33 2.64 2.23 1.36 CZ5 337.00 2.20 2.41 2.11 1.Z4 C26 349.00 1.97 2.08 1.89 1.07 C27 360.00 2.05 2.09 1.96 1.08 C28 372.00 2.01 1.99 1.93 1.02 C29 382.00 2.00 1.92 1.91 0.99 C30 394.00 1.84 1.72 1.77 0.89 C31 404.00 1.84 1.68 1.77 0.87 C32 415.00 1.83 1.62 1.75 0.84 C33 426.00 1.46 1.27 1.40 0.65 C34 437.00 1.38 1.16 1.32 0.60 C35 445.00 1.24 1.03 1. i 9 0.53 C36+ 937.00 41.81 16.43 40.09 8.47 Tota I 100.00 100.00 100.00 100.00 100.00 100.00 MN/ 16.73 368.15 197.84 MOLE RATIO 0.4846 0.5154 Oilphase-DBR 29 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 19: Calculated Fluid Properties Sample 1.11; Cylinder SSB 13916-QA; Depth 7369 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 1.41 0.19 99.70 98.44 95.67 50.82 C12+ 0.13 0.01 96.40 89.05 92.45 45.90 C20+ - - 74.61 51.41 71.55 26.50 C30+ - - 51.41 24.90 49.30 12.83 C36+ - - 41.81 16.43 40.09 8.47 Molar Mass C7+ 126.89 372.85 372.42 C1 Z+ 161.08 398.52 398.49 C20+ - 534.24 534.24 C30+ - 759.94 759.94 C36+ - 937.00 937.00 Density C7+ - 0.9554 - C1 Z+ - 0.9630 0.9630 C20+ - 1.0064 1.0064 C30+ 1.0735 1.0735 C36+ 1.1173 1.1173 Fluid at 60°f 0.9539 Gas Gravity (Air =1) 0.578 Dry Gross Heat Content (BTU/scf 1,040 Wet Gross Heat Content (BTU/scf 1,022 OBM Contamination Level (Wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 368.15 368.15 937.00 Density (g/cm3) 0.9539 - 1.117 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 324 - STO Density (g/cm3) 0.9539 - STO API Gravity 16.8 - OBM Density (g/cm3 Q60°F - Oilphase-DBR 30 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Schlumberger Figure 9: Stock Tank Oil Chromatogram (Sample 1.11) Sample 1.11; l;yllntler JSIi 1:iy l6-lw; Ueptn i3ba n. Ivlu FID1 A, (F:@I DATAVJ08000711CY13918.D) Noim. 350 JOB 200600071 CONOCO PHILLIPS 1.11 SSB 13916-QA RF FLASH CYLINDER 300 250 200 150 100 U~ U ~ ~ fD h W~ p ~N(~Vtn(9C`OD61~~ 5O ~ ~ ~~ytJ~..~{~~~~ CC CC CU ~~ XU U U ~ C CCCCC CC CCC ~ C C C C C 0 U 0 0 5 10 15 20 25 30 35 mi • • Figure 10: k-Plot for Equilibrium Check Sample 1.71- Sample 1.11; Cylinder SSB 13916-OA; Depth 7369 ft. MD 1.5 1 0.5 a Y O7 O J 0 -0.5 -1 -4 -3 -2 -1 0 F 1 2 3 Oilphase-DBR 31 Job #: 200600071 Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 • • • Schlum4erger Table 20: C36+ Composition, GOR, °API, by Zero-Flash (Sample 1.18) Sample 1.18; Cylinder CSB 7742-QA; Depth 7550 ft. MD Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/male) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.22 0.09 0.00 0.00 0.01 0.03 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.31 0.21 0.00 D.00 0.01 0.07 Methane 16.04 79.00 92.75 0.00 0.00 2.66 33.04 Ethane 30.07 2.23 1.40 0.00 0.00 0.08 0.50 Propane 44.10 3.71 1.59 0.02 0.13 0.14 0.65 I -Butane 58.12 2.39 0.77 0.04 0.22 0.12 0.42 N -Butane 58.12 3.87 1.25 0.11 0.54 0.23 0.80 I -Pentane 72.15 2.25 0.59 0.17 0.72 0.24 0.67 N -Pentane 72.15 1.85 0.48 0.19 0.78 0.24 0.68 C6 84.00 1.79 0.40 0.59 2.09 0.63 1.49 M-C-Pentane 84.16 0.33 0.07 0.19 0.69 0.20 0.47 Benzene 78.11 0.03 0.01 0.02 0.09 0.02 0.06 Cyclohexane 84.16 0.27 0.06 0.23 0.81 0.23 0.55 C7 96.00 0.74 0.15 0.85 2.66 0.85 1.76 M-C-Hexane 98.19 0.27 0.05 0.48 1.47 0.48 0.97 Toluene 92.14 0.07 0.01 0.23 0.75 0.22 0.49 C8 107.00 0.38 0.07 1.39 3.90 1.36 2.53 E-Benzene 106.17 0.01 0.00 0.10 0.26 0.10 0.18 M/P-Xylene 106.17 D.02 0.00 0.31 0.88 0.30 0.57 0-Xylene 106.17 0.01 0.00 0.15 0.43 0.15 0.28 C9 121.00 0.16 0.03 1.47 3.63 1.43 2.35 C10 134.00 0.06 0.01 2.16 4.82 2.09 3.11 C11 147.00 0.02 0.00 2.17 4.42 2.10 2.84 C 12 161.00 0.00 0.00 2.48 4.61 2.40 2.97 C13 175.00 0.00 0.00 2.79 4.76 2.69 3.07 C14 190.00 0.00 0.00 2.99 4.70 2.89 3.03 C15 206.00 0.00 0.00 2.84 4.12 2.74 2.65 C16 222.00 2.98 4.01 2.88 2.58 C17 237.00 2.64 3.34 2.56 2.15 C18 251.00 2.73 3.25 2.64 2.09 C19 263.00 2.75 3.13 2.66 2.01 C20 275.00 2.37 2.58 2.29 1.66 C21 291.00 2.35 2.42 2.27 1.56 C22 300.00 2.42 2.41 2.33 1.55 C23 312.00 1.92 1.84 1.86 1.19 C24 324.00 1,99 1.84 1.92 1.1 S C25 337.00 1.86 1.65 1.79 1.06 C26 349.00 1.72 1.47 1.66 0.95 C27 360.00 1,76 1.46 1.70 0.94 C28 372.00 1.77 1.43 1.72 0.92 C29 382.00 1.80 1.41 1.74 0.91 C30 394.00 1.81 1.37 1.75 0.88 C31 404.00 1.47 1.09 1.42 0.70 C32 415.00 1.49 1.08 1.44 0.69 C33 426.00 1.39 0.97 1.34 0.63 C34 437.00 1.15 0.78 1.11 0.50 C35 445.00 1.37 0.92 1.32 0.59 C36+ 815.00 38.26 14.04 36.97 9.04 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.84 299.02 199.19 MOLE RATIO 0.3563 0.6437 Oilphase-DBR 32 Job #: 200600071 • ~J • Client: ConocoPhillips field: West Sak Well: 1 R East Sand: B & A3 Table 21: Calculated Fluid Properties Sample 1.18: Cylinder CSB 7742-QA; Depth 7550 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 2.38 0.46 98.88 95.52 95.63 61.65 C12+ 0.00 0.00 89.11 70.69 86.11 45.50 C20+ - - 66.91 38.76 64.65 24.95 C30+ - - 46.94 20.25 45.36 13.04 C36+ - - 38.26 14.04 36.97 9.04 Molar Mass C7+ 96.43 309.56 308.99 C12+ #DIV/0! 376.95 376.95 C20+ - 516.17 516.17 C30+ - 692.98 692.98 C36+ - 815.00 815.00 Density C7+ - 0.9397 - C12+ - 0.9624 0.9624 C20+ - 1.0130 1.0130 C30+ 1.0800 1.0800 C36+ 1.1251 1.1251 Fluid at 60°F 0.9347 Gas Gravity (Air = 1 ~ 0.650 Dry Gross Heat Content (BTU/scf) 1,156 Wet Gross Heat Content IBTU/scf 1,136 OBM Contamination Level (wt%1 - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 299.02 299.02 815.00 Density (g/cm3~ 0.9347 - 1.125 Single Stage Flash Data Original STO De-Contaminated GOR Iscf/stb) 230 - STO Density (g/cm3) 0.9347 - STO API Gravity 19.9 - OBM Density (g/cm31 Q60°F - Oilphase-DBR 33 Job #: 200600071 • • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Schlumberger Figure 11: Stock Tank Oi! Chromatogram Sample 1.18) Samnla 1 1R~ Cvlinriar CSR 7742-QA' DPOth 7550 ft. MD FID1 A., (Fa21 DATAV108000711CY7742P.D) Noim, 350 JOB 200600071 CONOCO PHILLIPS 1.18 CSB 7742-QA RF FLASH CYLINDER 300 250 200 150 0 U m ~ 47 _ UtD o m 100 ~ ~o ~ m ~'® C ~ ~ m ~?' v U h 7 ~ ~ ~ (D t` W 0) O ~ Np74t Ull9~ ~ o U ~X ~ N (h U ~ °-NNNNNNNNN6~ 50 F C ~ m o `' U U U U U UUUUUUUWUUC~Y~ C C C C C C C C C C C CC CC CCCCC U ~ O C C U ~:i is ~Il i; ~~~ . n ... .. ~ , .. .. , . D 0 5 10 15 20 25 30 35 mi Figure 12: k-Plot for Equlibnum GhecK (Sample 1.7tf1 Sample 1.18; Cylinder CSB 7742-OA; Depth 7550 ft. MD 2.5 2 1.5 1 c 0.5 ~ 0 -0.5 -1 I -1.5 -2 -4 -3 -2 -1 0 1 2 3 f Oilphase-DBR 34 Job #: 200600071 • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 22: Summary of Results of Sample 1.18 Sample 1.18; Cylinder CSB 7742-DA; Depth 7550 ft. MD Schlumberger Reservoir Conditions: Pressure: 1747 psia Temperature: 81 °F Summary of Fluid Properties: OBM Contamination: - Wt% STO Basis OBM Contamination: - Wt°~ iiF Basis Bubble Point Pressure At Tres 1,553 psia At 130°F - psia At 100°F - psia Gas-Oil Ratio Single-stage Flash: 230 scf/stb Total Differential Liberation: - scf/stb Total Separator Flash: 213 scf/stb Properties at 60°F STO °API Gas Gravity (Average) Single-stage STO: 19.89 0.650 Differential Liberation STO; - - Separator STO: 22.29 0.619 Properties at Reservoir Conditions Viscosity: 21.1 cP Compressibillity (Cod: 5.30 10-6/psi Density: 0.8812 g/cc Properties at Saturation Conditions Viscosity: 20.8 cP Compressibillity Col: 5.33 10-6/psi Density: 0.8803 g/cc Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash: 1.096 1.099 Total Differential Liberation: - - Total Separator Flash: 1.077 1.078 Note: Standard conditions are 14.696 psia and 60°F • Oilphase-DBR 35 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schiumberger Well: 1R East Sand: B & A3 PVT Analysis on Sample 1.18; Cylinder CSB 7742-QA; Depth 7550 ft. MD Constant Composition Expansion at Tres The CCE study was initiated by charging asub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 81.0°F and at a pressure of 6,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 23. The pressure-volume (P-V) plots of the CCE data are presented in Figure 13. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,553 psia at the reservoir temperature of 81.0 °F. Also, calculated relative volume and oil compressibility is presented in Table 23. As seen in the table, the compressibility of this oil is 5.3 x 10e-61/psia at the saturation pressure. Table 23: Constant Composition Expansion at 81.0°F (Sample 1.18) Camnlo 1 1R• (vfinrier C4R 7747-nA• ~Pnth 7550 ft. MD • • Pressure (psia) Relative Vol (Vr=VNsat) % Liquid (VI/Vsat) % Liquid (VlNtotal) Liquid Density I9/cm3) Y Function Compressibility (10-6/psia) 1 6015 0.9774 97.7 100.0 0.9007 4.9 2 5515 0.9798 98.0 100.0 0.8984 5.0 3 5015 0.9822 98.2 100.0 0.8962 5.0 4 4015 0.9872 98.7 100.0 0.8917 5.1 5 3015 0.9923 99.2 100.0 0.8871 5.2 6 2015 0.9976 99.8 100.0 0,8825 5.3 7 1813 0.9986 99.9 100.0 0.8815 5.3 Pi 1747 0.9990 99.9 100.0 0.8812 5.3 9 1617 0.9997 100.0 100.0 0.8806 5.3 Pb 1553 1.0000 100.0 100.0 0.8803 5.3 11 1409 1.0231 99.6 97.3 4.4 12 1308 1.0434 99.3 95.2 4.3 13 1222 1.0642 99.1 93.1 4.2 14 1118 1.0948 98.8 90.2 4.1 15 1019 1.1315 98.5 87.1 4.0 16 816 1.2390 98.0 79.1 3.8 17 624 1.4191 97.5 68.7 3.6 18 515 1.5871 97.2 61.2 3.4 19 415 1.8225 96.9 53.2 3.3 Oilphase-DBR 36 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 7 R East Sand: B & A3 z.o Figure 13: Constant Composition Expansion at 81.0°F -Relative Volume Sample 1.18; Cylinder CSB 7742-QA; Depth 7550 ft. MD ~.a 1.6 ~_ E 1.4 0 0 a .~ • • 1.2 Oilphase-DBR 1.0 0.8 ~ D Pressurelpsia) 37 Job #: 200600071 • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 81°F. These values as a function of selected pressure steps are summarized in Table 24. The liquid phase viscosity values are graphically presented in Figure 14. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Schlumberger Table 24: Reservoir Fluid Viscosity 81°F Sample 1.18; Cylinder CSB 7742-QA; Depth 7550 ft. MD • • Pressure Viscosity @ Tres (psia) IcP- 1 6020 34.56 2 5026 30.88 3 4032 27.41 4 3033 24.25 5 2525 22.84 6 2016 21.64 Pi 1747 21.13 Pb 1553 20.83 9 1426 22.60 10 1301 24.80 11 1069 26.81 12 864 30.37 13 672 33.63 14 502 37.00 STO 14.696 138.40 Oilphase-DBR 38 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 ~ Figure 14: Reservoir Fluid Viscosity 81°F Sam le 1.18' C tinder CSB 7742-OA; De th 7550 ft. MD P -V P • • 1 so 140 120 100 a v •~ ao 0 U N_ 60 40 0~ 0 20 1000 2000 3000 4000 Pressure~psia- 5000 6000 7000 Oilphase-DBR 39 Job #:200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B & A3 • Multi-Stage Separation Test Multi-stage separation test results are presented in Tables 25 - 27. The fluid properties ~i.e., GOR, density and oil formation volume factor) are presented in Table 25. Multi-stage separation test conditions are: STAGE 1 105 psis 125 °F STAGE 2 75 psia 185 °F STAGE STO 14.696 psia 60 °F As seen in Table 25, the GOR value obtained from the multi-stage separation test is 213 SCF/STB and the formation volume factor is 1.078. The compositional analyses of separator gas and tank gas are summarized in Table 26 and the composition of tank liquid is tabulated in Table 27. The total dry gross heat content of the separation gases is calculated to be 1,107 BTU/scf whereas the total wet gross heat content is calculated to be 1,088 BTU/scf. • Oilphasel-OBR 40 Job #: 200600071 I • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 25: Multi-Stage Separation Test Vapor & Liquid Properties Sample 1.18: Cylinder CSB 7742-QA; Depth 7550 ft. MD PROPERTY STAGE Pb STAGE 1 STAGE 2 STAGE STO Pressure (psia) 1553 105 75 14.696 Temperature (°F) 81 125 185 60 liq. Den (g/cm3) 0.8803 0.8967 0.8874 0.9201 Vap. GravityH 0.591 0.705 0.772 Vap. M~,,,, 17.13 20.42 22.35 Vap Heat Val." 1065 1242 1344 GOR` 170 28 15 GOR° 165 27 15 Sep. FVFe 1.078 1.034 1.040 1.000 Schlumberger a) Calculated, at 60°F (air=1) bj Calculated, Dry basis BTU/scf c~ scf gas/bbl of oil at STD conditions d) scf gas/bbl of oil at separator conditions e) fluid volume at sepconditions/fluid volume at STD conditions Residual oil density at standard conditions 0.9201 g/cc Sep gas gravity (average) S9 = ERjSgj/ER 0.619 Where: R: GOR (scf gas/bbl of oil at STD conditions, j: separator stages Sep gas gross heating value (a !c =ERi*L~~/ER~ 1107 BTU/scf (dry basis) Where: R: GOR (scf gas/bbl of oil at STD conditionsj, j: separator stages • SEPARATION TEST SUMMARY aTotal Separation Test GOR 213 Separation Test STO Gravity 22.29 Separation Test FVF 1.078 a) scf gas/bbl of condensate at STD conditions bj Fluid volume at Psat & Tres/Fluid volume at STD • Oilphase-DBR 41 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 26: Multi-Stage Separator Test Vapor Composition (mol %- Sample 1.18; Cylinder CSS 7742-CA; Depth 7550 ft. MD Schlumberger Component MW (g/mol) Mole STAGE 1 STAGE 2 STAGE STO Carbon Dioxide 44.01 0.07 0.13 0.19 Hydrogen SulfidE 34.08 0.00 0.00 0.00 Nitrogen 28.01 0.23 0.09 0.04 Methane 16.04 96.39 88.24 84.05 Ethane 30.07 1.28 2.39 3.60 Propane 44.10 0.79 2.57 2.90 I -Butane 58.12 0.30 1.59 2.40 N -Butane 58.12 0.41 2.30 3.37 I -Pentane 72.15 0.16 0.88 1.16 N -Pentane 72.15 0.13 1.10 1.08 C6 84.00 0.10 0.37 0.37 M-C-Pentane 84.16 0.02 0.05 0.04 Benzene 78.11 O.DO 0.00 0.00 Cyclohexane 84.16 D.D1 0.03 0.02 C7 96.00 0.09 0.18 0.05 M-C-Hexane 98.19 0.01 0.01 0.01 Toluene 92.14 0.00 0.02 0.09 CB 107.00 0.00 0.02 0.00 E-Benzene 106.17 0.00 0.00 0.03 M/P-Xylene 106.17 0.00 0.00 0.01 D-Xylene 106.17 0.00 0.00 0.01 C9 121.00 0.00 0.01 0.00 C10 134.00 0.00 0.01 0.04 C11 147.00 0.00 0.00 0.27 C12 161.00 0.00 0.00 0.27 C13 175.00 0.00 0.00 0.00 C14 190.00 0.00 0.00 0.00 C15 206.00 0.00 0.00 0.00 C16 222.00 0.00 0.00 0.00 C17 237.00 0.00 0.00 0.00 C18 251.00 0.00 0.00 0.00 C19 263.00 0.00 0.00 0.00 CZO 275.00 0.00 0.00 0.00 C21 291.00 0.00 0.00 0.00 C22 300.00 0.00 0.00 0.00 C23 312.00 0.00 0.00 0.00 C24 324.00 0.00 0.00 D.00 C25 337.00 0.00 0.00 0.00 C26 349.00 0.00 0.00 0.00 C27 360.00 0.00 0.00 0.00 C28 372.00 0.00 0,00 0.00 C29 382.00 0.00 0.00 0.00 C30+ 692.98 0.00 0.00 0.00 Tota I 100.00 100.00 100.00 MW 17.13 20.42 22.35 Relative Density lair=1) 0.591 0.705 0.772 Dry Gross Heat Content IBTU/scf; 1065 1242 1344 Oilphase-DBR 42 Job #: 200600071 • • • Client: ConocoPhillips Field: West Sak Wel I: 1 R East Sand: B & A3 Table 27: Multi-Stage Separator Test Residual Liquid Composition (mol %) Sample 1.18; Cylinder CSB 7742-QA; Depth 7550 ft. MD Schlumberger COMPONENT MW (g/mol) Residual Liquid (mol %) Carbon Dioxide 44.01 0.00 Hydrogen SulfidE 34.08 0.00 Nitrogen 26.01 0.00 Methane 16.04 0.00 Ethane 30.07 0.00 Propane 44.10 0.46 I -Butane 58.12 0.47 N -Butane 58.1 Z 1.01 I-Pentane 72.15 1.06 N -Pentane 72.15 1.14 C6 84.00 2.81 M-C-Pentane 84.16 0.83 Benzene 78.11 0.11 Cyclohexane 84.16 0.96 C7 96.00 3.02 M-C-Hexane 98.19 1.69 Toluene 92.14 0.90 C8 107.00 4.28 E-Benzene 106.17 0.31 M/P-Xylene 106.17 0.96 0-Xylene 106.17 0.45 C9 121.00 3.81 C10 134.00 5.14 C11 147.00 4.07 C12 161.00 4.36 C13 175.00 4.49 C14 190.00 4.46 C15 ZD6.00 3.90 C16 222.00 3.78 C17 237.00 3.12 C18 251.00 3.06 C19 263.00 2.89 CZO 275.00 2.39 C21 291.00 2.44 C22 300.00 2.22 C23 312.00 1.88 C24 324.00 1.66 C25 337.00 1.54 C26 349.00 1.12 C27 360.00 1.43 C28 372.00 1.36 C29 382.00 1.39 C30+ 702.94 18.84 Total 100.00 MW 287.60 Oilphase-DBR 43 Job #: 200600071 :7 ~: Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 28: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.20) Sample 1.20: Cylinder CSB 8620-QA; Depth 7550 ft. MD Schlumherger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/moles WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.20 0.08 0.00 0.00 0.01 0.03 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.28 0.19 0.00 0.00 0.01 0.07 Methane 16.04 78.52 92.57 0.00 0.00 2.69 33.41 Ethane 30.07 2.23 1.41 0.00 0.00 0.08 0.51 Propane 44.10 3.78. 1.62 0.03 0.20 0.16 0.71 1-Butane 56.12 Z.53 0.82 0.05 0.25 0.13 0.46 N -Butane 58.12 4.10 1.33 0.12 0.62 0.26 0.87 I -Pentane 72.15 2.39 0.63 0.19 0.77 0.26 0.72 N -Pentane 72.15 1.90 0.50 0.20 0.83 0.26 0.71 C6 84.00 1.78 0.40 0.61 2.18 0.65 1.54 M-C-Pentane 84.16 0.32 0.07 0.19 0.70 0.20 0.47 Benzene 78.11 0.03 0.01 0.03 0.10 0.03 0.06 Cyclohexane 84.16 0.26 0.06 0.23 0.82 0.23 0.55 C7 96.00 0.73 0.14 0.88 2.76 0.88 1.82 M-C-Hexane 98.19 0.26 0.05 0.48 1.46 0.47 0.95 Toluene 92.14 0.06 0.01 0.22 0.70 0.21 0.45 C8 107.00 0.35 0.06 1.41 3.96 1.37 2.55 E-Benzene 106.17 0.00 0.00 0.10 O.ZB 0.10 0.18 M/P-Xyiene 106.17 0.01 0.00 0.31 0.86 0.30 0.55 0-Xylene 106.17 0.00 0.00 0.15 0.43 0.15 0.27 C9 121.00 0.14 0.02 1.49 3.71 1.45 2.38 C10 134.00 0.08 0.01 2.19 4.92 2.12 3.15 C11 147.00 0.02 0.00 2.21 4.53 2.14 2.90 C12 161.00 0.01 0.00 2.51 4.69 2.42 3.00 C13 175.00 0.00 0.00 2.62 4.50 2.53 2.87 C14 190.00 0.00 0.00 3.15 4.99 3.05 3.19 C15 206.00 0.00 0.00 2.82 4.11 2.72 Z.63 C16 222.00 2.80 3.80 2.71 2.43 C17 237.00 2.64 3.35 2.55 2.14 C18 251.00 2.60 3.12 2.51 1.99 C19 263.00 2.64 3.02 2.55 1.93 C20 275.00 2.41 2.64 2.33 1.68 C21 291.00 2.42 2.50 2.33 1.60 C22 300.00 2.33 2.33 2.25 1.49 CZ3 312.00 1.82 1.76 1.76 1.12 C24 324.00 1.80 1.67 1.73 1.06 C25 337.00 1.82 1.62 1.75 1.04 C26 349.00 1.69 1.46 1.63 0.93 C27 360.00 1.75 1.46 1.69 0.94 C28 372.00 1.77 1.43 1.71 0.91 C29 382.00 1.49 1.18 1.44 0.75 C30 394.00 1.53 1.17 1.47 0.74 C31 404.00 1.49 1.11 1.44 0.71 C32 415.00 1.42 1.03 1.37 0.66 C33 426.00 1.23 0.87 1.19 0.56 C34 437.00 1.06 0.73 1.02 0.47 C35 445.00 1.08 0.73 1.04 0.47 C36+ 819.50 40.04 14.69 38.67 9.39 Total 100.00 100.00 100.00 100.00 100.00 100.00 MN/ 18.91 300.70 198.99 MOLE RATIO 0.3610 0.6390 Oilphase-DBR 44 Job #: 200600071 • .7 • Client: ConocoPhillips Field: West Sak Well: 1 R East Sand: B & A3 Table 29: Calculated Fluid Properties Sample 1.20; Cylinder CSB 8620-QA; Depth 7550 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 2.28 0.45 98.81 95.15 95.50 60.97 C12+ 0.01 0.00 88.92 69.92 85.87 44.68 C20+ - - 67.15 38.36 64.84 24.51 C30+ - - 47.84 20.32 46.20 12.98 C36+ - - 40.04 14.69 38.67 9.39 Molar Mass C7+ 96.64 312.26 311.69 C1 Z+ 163.41 382.41 382.41 C20+ - 526.34 526.34 C30+ - 708.04 708.04 C36+ - 819.50 819.50 Density C7+ - 0.9398 - C 12+ - 0.9628 0.9628 CZO+ - 1.0126 1.0126 C30+ 1.0759 1.0759 C36+ 1.1134 1.1134 Fluitl at 60°F 0.9344 Gas Gravity (Air =1) 0.653 Dry Gross Heat Content (BTU/scf) 1,160 Wet Gross Heat Content (BTU/scf 1,140 OBM Contamination level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 300.70 300.70 819.50 Density (g/cm3) 0.9344 - 1.113 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 233 - STO Density (g/cm3) 0.9344 - STO API Gravity 19.9 - OBM Density 19/cm3) Q60°F - Oilphase-DBR 45 Job #: 200600071 • Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Figure 15: Stock Tank Oil Chromatogram (Sample 1.20- Sample 1.20; Cylinder C56 86ZU-11A; ueptn /5UU tt. Ivlu fID1 A, (F:i2t GATA~A08000711C`f8020.D} Norm. 350 JOB 200600071 CONOCO PH ILLIPS 1.20 CSB 8620-QA RF FLASH CYLINDER 300 250 200 150 U ~ ~ o U m ~ v u 0 ~ ap, ~ ~' 100 _ ~ X h ~ ~ o O ~~ 01 ~ N m U ~ Q 61 m o~Nmv~nmr`~o~-~r~r, j ~~ ~ ~ UNNNNNN(VNNVp'(~r~ 5D ~.- x ,m o C ( U U U U C UUUUUUUUWC} ~ oU '- U U C U C C C C C C CCCCCCCCCCCCCCC I I ~I.,I ~ '! I i I is I i_ 0 0 5 10 15 20 25 30 35 mi • Figure 16: k-Plot for Equilibrium GhecK 1Sampie t.cul Sample 1.20; Cylinder CSB 8620-OA; Depth 7550 ft. MD 2.5 2 1.5 1 Y 0.5 a ~ 0 -0.5 -1 -1.5 -2 -4 -3 -2 -1 0 1 2 3 F • Oilphase-DBR 46 • C3 • iC4 --- - -- ----i !C~5 ---- - --- -- ---- 7 C6 - -------- -- _ __ -__- _- --- - --~ C7 --_ - -- - - - ----- __ --_ rea ---- - __ - - -_ ---_ ___ -- -- -- -- --- ----~ C9 - --- --- --- - x-&10 Job #: 200600071 • • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 30: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.21) Sample 1.21; Cylinder SSB 11875-QA; Depth 7550 ft. MD Schlum6erger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.19 0.08 0.00 0.00 0.01 0.03 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.62 0.43 0.00 0.00 0.02 0.15 Methane 16.04 76.81 91.80 0.00 0.00 2.53 32.07 Ethane 30.07 2.28 1.46 0.00 0.00 0.08 0.51 Propane 44.10 4.04 1.75 0.00 0.03 0.14 0.63 I -Butane 58.12 2.75 0.91 0.02 0.09 0.11 0.38 N -Butane 58.12 4.37 1.44 0.04 0.22 0.18 0.65 I -Pentane 72.15 2.52 0.67 0.11 0.48 0.19 0.55 N -Pentane 72.15 2.01 0.53 0.11 0.46 0.17 0.49 C6 84.00 1.86 0.43 0.51 1.82 0.55 1.33 M-C-Pentane 84.16 0.34 0.08 0.19 0.68 0.19 0.47 Benzene 78.11 0.03 0.01 0.02 0.09 0.02 0.06 Cyclohexane 84.16 0.28 0.06 0.22 0.80 0.22 0.54 C7 96.00 0.78 0.16 0.96 3.03 0.96 2.03 M-C-Hexane 98.19 0.29 0.06 0.44 1.34 0.43 0.89 Toluene 92.14 0.07 0.02 0.17 0.56 0.17 0.37 C8 107.00 0.41 0.07 1.43 4.03 1.39 2.65 E-Benzene 106.17 0.01 0.00 0.16 0.45 0.15 0.29 M/P-Xylene 106.17 0.03 0.00 0.22 0.63 0.21 0.41 0-Xylene 106.17 0.01 0.00 0.13 0.37 0.13 0.24 C9 121.00 0.19 0.03 1.64 4.10 1.59 2.68 C10 134.00 0.09 0.01 2.31 5.21 2.23 3.39 C11 147.00 0.01 0.00 2.27 4.66 2.19 3.03 C12 161.00 0.00 0.00 2.63 4.93 2.54 3.21 C13 175.00 0.00 0.00 2.88 4.98 2.79 3.24 C14 190.00 0.00 0.00 2.99 4.76 2.89 3.10 C15 206.00 0.00 0.00 3.11 4.57 3.01 2.97 C16 222.00 2.94 4.00 2.84 2.61 C17 237.00 2.84 3.62 2.75 2.36 C18 251.00 2.81 3.38 2.71 2.20 C19 263.00 2.54 2.92 2.46 1.90 C20 275.00 2.56 2.81 2.47 1.83 C21 291.00 2.42 2.51 2.34 1.64 CZZ 300.00 2.18 2.20 2.11 1.43 C23 312.00 2.30 2.23 2.22 1.45 C24 324.00 1.69 1.58 1.64 1.03 C25 337.00 1.86 1.66 1.79 1.08 C26 349.00 1.81 1.57 1.75 1.02 C27 360.00 1.51 1.27 1.46 0.83 C28 372.00 1.60 1.30 1.55 0.85 C29 382.00 1.43 1.13 1.39 0.74 C30 394.00 1.56 1.20 1.51 0.78 C31 404.00 1.17 0.88 1.14 0.57 C32 415.00 1.33 0.97 1.28 0.63 C33 426.00 1.07 0.76 1.03 0.49 C34 437.00 1.00 0.69 0.97 0.45 C35 445.00 0.83 0.56 0.80 0.37 C36+ 836.00 39.97 14.45 38.66 9.40 Total 100.00 100.00 100.00 100.00 100.00 100.00 M~/V 19.17 302.25 203.37 MOLE RATIO 0.3493 0.6507 Oilphase-DBR 47 Job #: 200600071 r~ • Client: ConocoPhillips Field: West Sak Well: 1R East Sand: B & A3 Table 31; Calculated Fluid Properties Sample 1.21; Cylinder SSB 11875-QA; Depth 7550 ft. MD Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 2.54 0.50 99.21 96.90 96.02 63.23 C1Z+ 0.00 0.00 89.05 70.95 86.12 46.17 CZO+ - - 66.30 37.78 64.12 24.58 C30+ - - 46.93 19.50 45.38 12.69 C36+ - - 39.97 14.45 38.66 9.40 Molar Mass C7+ 96.96 309.45 308.86 C12+ - 379.36 379.36 C20+ - 530.47 530.47 C30+ - 727.26 727.26 C36+ - 836.00 836.00 Density C7+ - 0.9384 - C12+ - 0.9621 0.9621 C20+ - 1.0146 1.0146 C30+ 1.0809 1.0809 C36+ 1.1157 1.1157 Fluid at 60°F 0.9350 Gas Gravity (Air = 1) 0.662 Dry Gross Heat Content (BTU/scf) 1,171 Wet Gross Heat Content (BTU/scf 1,150 OBM Contamination Level (uvt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 302.27 302.25 836.00 Density (g/cm3) 0.9350 0.9350 1.1157 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 221 - STO Density Ig/cm3) 0.9350 - STO API Gravity 19.8 - OBM Density (g/cm3) Q60°F - Oilphase-DBR 48 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1R East Sand: B & A3 • Figure 17: Stock Tank Oil Chromatogram (Sample 1.21) Sample 1.21; Cylinder SSB 11875-CA; Depth 7550 ft. MD Norm. 350 300 250 200 150 100 50 0 0 • U'.IDATAV]Otl000711CY1 4 JOB 200600071 CONOCO PHILLIPS 1.21 SSB 11875-QA RF FLASH CYLINDER m U ~ c o m ~ u aA U 0 ~ C ~. C C ~ ~~ o U ~x N m U N t9 t+ ~ ~ ~NNNNNNW~jIT~ ~ C OU O U U ~ C C C C CUCCCCCCCC CCCCCCC ~ i ~~' i~~i~ ~ ~~, 5 10 15 20 25 30 Figure 18: k-Plot for Equilibrium Check (Sample 1.21) Sample 1.21; Cylinder SSB 11875-QA; Depth 7550 ft. MD 3.5 . 3 --- ___ _ _ - _-_ _-__ _-_ __ _ --~ 3---- __----- 2.5 2 _ - - ---- - __- - - - - --- -- - __ --------------------------~n~4iC4--------- 1.5 --- ------ - ~ ~~5 Y 1 J 0 5 _-_._ .- - _-- --- ~-G6 . r 0 - __ 0 5 8 . - -1 ~~ -1.5 ~ C7D -2 -3 -2 -1 0 1 2 3 F I • Oilphase-DBR 49 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Installation: - Job #: 200600071 • Appendix A: Nomenclature and Definitions API Gravity American Petroleum Institute gravity Bg Gas formation volume factor Bo Oil formation volume factor CCE Constant composition Expansion DV Differential Vaporization GLR Gas Liquid Ratio GOR Gas Oil Ratio LO Live Oil n Number of moles OBM Oil Based Mud P Absolute pressure Pb Bubble point pressure PV Pressure-Volume Method Pi Initial Reservoir Pressure R Universal gas constant Rs Solution gas oil ratio T Temperature V Volume Vr Relative volume STL Stock Tank Liquid STO Stock Tank Oil • %, w/w Weight Percent Z Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing Compressibility inconstant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation (Gas deviation factor, Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. • A positive index indicates scaling tendencies. • A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. • Oilphase-DBR 50 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Installation: - Job #: 200600071 • • B: Molecular Weights and Densities Used (g/cc- C02 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 C 1 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 0-XYLENE 106.17 0.884 C9 121 0.768 C10 134 0.782 C11 147 0.793 C 12 161 0.804 C13 175 0.815 C14 190 0.826 C 15 206 0.836 C 16 222 0.843 C 17 237 0.851 C18 251 0.856 C 19 263 0.861 CZO 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C29 382 0.902 Oilphase-DBR 51 Job #: 200600071 Client: ConocoPhillips field: West Sak Schlumberger Well: 1R East Sand: B & A3 Installation: - Job #: 200600071 • Appendix C: EQUIPMENT Fluid Preparation and l/alidation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below) provides the full fluid compositional analysis, GOR, density at sampling P&T corrected to standard conditions. The JEFRI gasometer consists of amotor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psial and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC). . Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FIDj. In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C, to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium] through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C12+, along with the associated naphthenes and aromatics that are lumped into the C6+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCDI while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the injected gas. • Oilphase-DBR 52 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Installation: - Job #: 200600071 . Fluid Volumetric (pVrJ and Viscosity Equipment The preliminary saturation pressure, constant composition expansion (CCE-, differential vaporization (DV), multi-stage separation tests (MSSTI are measured using apressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell, allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell Is mounted on a special bracket, which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTD) and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°C-. The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with ahigh-resolution video camera that minimizes parallax in readings and uses a high- . resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. • Oilphase-DBR 53 Job #: 200600071 Client: ConocoPhillips Field: West Sak Schlumberger Well: 1 R East Sand: B & A3 Installation: - Job #: 200600071 • The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. !n this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e., temperature, pressure, solvent volume, time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of ONSP is termed as the light scattering system (LSS-. High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. • • Oilphase-DBR 54 Job #: 200600071 Client: ConocoPhillips Well: 1 R East Field: Sand: West Sak B & A3 Sehiumberger Installation: - Job #: 200600071 • Appendix D: PROCEDURE Fluids Preparation and (/a/illation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, asub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CGE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, apressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute monophasic-fluid compressibility and relative oil volumes over the entire pressure range. • Differential I/aporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (DV) experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a DV test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the DV test. • The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) • The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. • Oilphase-DBR 55 Job #: 200600071 Client: ConocoPhillips field: West Sak Schlumberger Well: 1R East Sand: B & A3 Installation: - Job #: 200600071 Multi-Stage Separation Test Subsequent to the completion of the DV experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. Amulti-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. • The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage Ibelow the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into ahigh-pressure high-temperature • electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point, the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very~well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank Oil ISTDJ Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. • Oilphase-DBR 56 Jab #: 200600071 Client: ConocoPhillips Field: West Sak Sehlumberger Well: 1 R East Sand: B & A3 Installation: - Job #: 200600071 • Asphaltene, Wax and Sulfur Content Measurements Asphaltene content of stock-tank oif samples is conducted using the IP-143 IPrench Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure.. All other STO analysis were measured according to industrial standards. SAfi'(PJA Analysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes). This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins Ipolars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature Nigh Pressure filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. • Oilphase-DBR 57 Job #: 200600071 ConocoPhillips Alaska, lnc. _ WELL REPORT LOGGING DATA R-EAST Date: 3/27/2006 ~~ EPOCH ~~c~ 5~0292~~~ Zas-alb ConocoPhillips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA 1 R-EAST Provided by: • [~ EPOCH Approved by: XXX)OCXXX Compiled by: Ralph Winkelman Dick Ebright Steven Pike Date: 3/27/06 • Distribution: ~~5^~ ~r i COI'1000~U~~1p5 1 R-East • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT &CREW .......................................................... ............................................2 q P ry ................................................................................ 1.1 E ui ment Summa ............................................ 2 1.2 Crew .......................................................................................................... ............................................ 3 2 WELL DETAILS ................................................................................................ ............................................4 ry .......................................................................................... 2.1 Well Summa 4 ............................................ 2.2 Hole Data .................................................................................................. ............................................ 4 3 GEOLOGICAL DATA ....................................................................................... ............................................5 3.1 Lithostratigraphy ........................................................................................ ............................................5 3.2 Mudlog Summary .................................................................................... .............................................6 3.3 Gas Samples (ISOTUBES) ..................................................................... ...........................................13 3.4 Connection Gases ................................................................................... ...........................................14 3.5 Sampling Program /Sample Dispatch ................................................... ...........................................15 4 PRESSURE /FORMATION STRENGTH DATA ........................................... ...........................................16 4.1 Formation Integrity/Leak Off Tests .......................................................... ...........................................16 4.2 Wire line Formation Tests ....................................................................... ...........................................16 4.3 Pore Pressure Evaluation Introduction ................................................... ...........................................16 4.4 Pore Pressure Evaluation Conclusians .................................................. ...........................................17 4.5 Pore pressure evaluation ......................................................................... ...........................................17 5 DRILLING DATA ............................................................................................. ...........................................20 5.1 Survey Data ............................................................................................. ............................................20 5.2 Bit Record ................................................................................................ ............................................23 5.3 Mud Record ............................................................................................. ............................................24 6 MORNING REPORTS .................................................................................... ............................................25 Enclosures 2"/100' Formation Log (MD) 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log [~ ~PO~H 1 • • • MUDLOGGING EQUIPMENT & CREW ~ ~ C..l limm~n4 Cllmm^Jrv COI'IOCOPr11~~IpS 1 R-East 1. 1 LMNIMI..~11• Parameter E ui ment T /Position Q P Ype TO~i Downtime Comments QGM Agitator (Mounted in possum belly) Provided WITS feed to QUADCO system. Ditch gas Flame ionization total gas & chromatography. 2 Some problems in surface hole with clay Insulated umbilical with three of flow lines. cuttin s at shakers. Hook Load / Wei ht on bit H draulic ressure transducer 0 No roblems no missin data. Primary draw-works block position indicator 0 No problems, no missing data. Rate of penetration O tical encoder on draw-works Mudlo in unit com uter s stem HP Coma Pentium 4 X2 DML & Ri watch 0 On UPS should ower shut down on ri Mudlo in unit DAC box In-unit data collection/distribution center 0 On UPS should ower shut down on ri Mud Flow In Derived from Strokes/Minute and Pum Out ut 0 see um stroke counters below Pum stroke counters (2 um s) Ma netic roximit sensors 0 No roblems, no missin data. Quadco Well Monitorin Com onents QUADCO Com uter in Mudlo in Unit 0 On UPS should ower shut down on ri Mud Flow Out WITS feed from QUADCO: S ud -TD 0 No roblems, no missin data. Pit Gain/Loss Pit Volumes WITS feed from QUADCO: S ud -TD 0 No roblems, no missin data. , Pum Pressure WITS feed from QUADCO: S ud -TD 0 No roblems, no missin data. RPM WITS feed from QUADCO: S ud -TD 0 No problems, no missin data. Tor ue WITS feed from QUADCO: S ud -TD 0 No roblems, no missin data. An IP phone in the Epoch unit fed data into the Quadco computer. A WITS feed was set up and provided a data stream between the Quadco Computer and the Epoch Rigwatch computer, with Rigwatch providing ditch gas to the Quadco system, and receiving various data (listed above) from Quadco. Depths were typically inaccurate and often not tracking on the Quadco system, however, Epoch was rigged up with an encoder, hookload sensor, and pump stroke counters, and all data from the Quadco WITS feed was recorded at an accurate depth. No data was missed, as the Quadco system was never down during drilling, and all the computers in the Epoch logging unit continued to operate on UPS when power would occasionally shut down briefly switching generators. Some problems with reading ditch gas in the surface hole, typical for the North Slope, were anticipated and dealt with as they occurred. The base plate on the gas trap allows mud into the trap through a 2" diameter hole. A''/d' mesh screen covering the hole to prevent large rocks from entering the trap and breaking agitator prongs, was partially plugged by clay cuttings. The base plate was removed because clay was plugging the trap The base plate was reinstalled after gravels were no longer a breakage threat. Also, two spare polyflow gas lines were utilized should freezing or plugging have occurred. One spare was rigged up to rig air to blowback lines to keep free of moisture and drilling mud. The second spare was kept as a back up gas line. Gas lines were occasionally switched, the unused line treated with gas line antifreeze (Heat), and blown back to remove any ice or moisture which may have accumulated. • • • 1.2 Crew Unit Type Arctic Series 10 Skid COC10C~~11~~~pS 1 R-East Unit Number ~ Mudlo ers g9 M~u~~ Years Dais Sample Catchers Years Days Technician Days Trainees Days Steven Pike 2 23 Edward Revollo 1 14 None Re uired Ral h Winkelman 15 10 James Kvidera 2 14 Dick Ebri ht 6 5 ~' Years experience as Mudlogger ,2 Days at well site between spud and total depth of well Additional Comments A technician is required to work on DAC box. ~~~~~ COt10C0~1~~~1p5 1 R-East • 2 WELL DETAILS C7 2.1 Well Summary Well: 1R-East West Sak Ex loration API Index #: 50-029-23295-00 Field: North East Wes Sak (NEWS} Surface Co-ordinates: N: 5,994,294 E: 554,537 SEC 15 T12N R10E 2283 FNL 965 FEL Borough: North Slope Primary Target Depth: 7268' MD State: Alaska TD Depth: 8075' MD (4201.4 TVDSS Rig Name /Type: Nordic 3 /Arctic Triple Suspension Date: None Primary Target: West Sak Permit #: 205-211 Spud Date: 3/12/06 Ground Elevation: 34.6' AMSL Completion Date: 3/29/06 RT Elevation: 64.6' AMSL Completion Status: Plug & Abandon Secondary Target Depth: 5772' Classification: Exploration TD Date: 3/24/2006 TD Formation: Base West Sak Days Testing: None Days Drilling: 13 2.2 Hole Data Maximum De th TD Mud Shoe De th FIT Hole Section Conductor MD (ft) 110 TVDSS (ft) -45 Formatio n Permafrost Weight (PPg) 92 Deviation a ~ ma) 0 Corin g NA Casing/ Liner 16" MD ft) 110 TVDSS ft) -45 (PPg) NA 12 %4" 4490 2574.9 T3 9.5 67.65 NA 9 5/8" 4480 2571.1 11.2 8112" 8075 4196.7 W SAK 9.1 47.70 NA NA NA NA NA Additional Comments Epoch personnel were already in Kuparuk after finishing the 1H North well and rigged up the Epoch mudlogging unit for the 1 R-East well following the move of the Nordic 3 drilling rig. Surface hole spudded on March 12 at 110' at the base of the conductor. A 121/4" surface hole wasdrilled with a 9.2 to 9.7 spud mud, directionally, with occasional sliding, to 4490'. Every stand was back reamed once, and surveys taken after the connection, the angle increasing gradually to as high as 69.86 degrees at 3107', and maintained to casing point at 4490'. No connection gases were noted and 65 units of wiper gas was noted after running logs. 9 5/8" casing was run to 4480'. The 8 '/" hole section began on March 20, and was drilled to 8075' on March 24, with a wiper trip at 6093' while waiting for repairs to be made on Epoch's gas trap. The spud mud was displaced with FloPro at 4510'. After circulating and conditioning the mud, a successful FIT was performed to 112 ppg EMW. Each stand was back reamed prior to each connection, and surveys taken after the connection. Mud weight was maintained at 9.0 - 9.3 ppg, and no connection gases were observed despite numerous oil sands and drill gas recorded as high as 627 units. Logging was commenced on March 25 after the wiper trip, and two logging runs were conducted. Both runs were made using drill pipe conveyed equipment. The first run was with an MDT drill pipe conveyed pressure and fluid sampling tool. 12 pressure tests and 2 fluid tests were successfully completed when the tool failed. The tool was pulled from the hole and downloaded. Before the second tool run, the BOP's were tested. The . second drill pipe conveyed run was with an SWC, percussion sidewall coring tool. 45 cores were attempted and all 45 were recovered. ff~~~,l-7 4 COt1000~11~~Ip5 1 R-East 3 GEOLOGICAL DATA • • 3.1 Lithostratigraphy Drilling picks & actual wire line tops refer to provisional picks provided by the well site Geologist. PROGNOSED ACTUAL WIRELINE PICK HIGH/LOW FORMATION MDRT ft TVDSS ft MDRT ft TVD ft TVDSS ft (ft) Permafrost 30 30 +34.6 GL Base Permafrost 2080 1666 2268 1769 1704 38' low T3 1847 2683 1961 1896 49'low K15-Marker 3600 2303 2238 Casing Point (T3+675'TVD) 4351 2522 4490 2640 2575 Ugnu C 5772 3055 5930 3174 3109 55'low Ugnu B 6478 3320 6439 3367 3302 18' high Ugnu A 6665 3453 3388 K13 Marker 7089 3571 7131 3654 3589 1$' low West Sak D 7268 3677 7269 3739 3674 3' high West Sak C 7320 3772 3707 West Sak B 7376 3746 7363 3801 3736 10' high West Sak A4 7421 3838 3773 West Sak A3 7631 3834 7482 3878 3813 21' low West Sak A2 7631 3910 7617 3964 3899 11' high West Sak Al 7797 4078 4013 Base West Sak 7973 4130 7946 4174 4109 21' high Total Depth 8162 4252 8075 4262 4201 ~ ~ P(~~,H ~811OC0~'1t~~tl{~5 1 R-East • 3.2 Mudlog Summary Permafrost to Base Permafrost ~~s~ +.. ~~aQ~ nAn i 7~G'_17~dT/r1C~l •, Drill Rate fFJhr Total Gas units ___ _ _ _ Maximum Minimum Avera a Maximum Minimum Avera e 207 12 93 136 0 14 The top of the permafrost down to 720' was dominantly conglomeratic sand and sand, somefimes grading to claystone or with some interbedded claystone. and from 720' to 1330' is dominantly claystone. From 1330' to 2080' is mostly sand and conglomeratic sand, often gradational to interbedded with claystone, with the conglomeratic fraction noticeably decreasing with depth and mostly gone by 1950' The base of the permafrost is marked by a sharp decrease in resistivity at 2080", due the transfion from ice to water. No oil shows were observed, and only methane was recorded through this section. The sands were medium gray to some medium dark gray, with fine to coarse grains, and a variable very coarse to conglomeratic fraction .Grains were angular to subrounded in the finer fraction, and mostly rounded to subrounded in the very coarse and conglomeratic fraction. The sands were mostly moderately sorted with a slight clay matrix, increasing as grades to claystone. Composition was 65-75°lo quartz, with higher percentages in the finer fraction and almost exclusively clear to translucent, and lower percentages in the very coarse to conglomerate fraction and opaque to yellowy to translucent. The remaining 25-35°lo included chert, or hard siliceous lithics and metalithics, and silicates. Other constituents included wood and carbonaceous fragments, pyrite, and locally minor calcite and shell fragments. Traces of wood and possibly other plant matter, partially to completely altered to carbonaceous matter, • occurred as disseminated flakes and fragments in sands and occasionally as low rank coal. Some carbonaceous matter had traces of micro pyrite. Pyrite sometimes occurred as accretions on grains, primarily the very coarse to conglomeratic fraction, with grains lightly to moderately specked with isolated crystals. Traces of grainy loose pyrite clusters occurred throughout the sequence. Clay (claystone) was medium gray to medium Irctht gray, often with faint brownish to brownish hues. The clays were structureless in the samples throughout, and were soluble to very soluble reacting to the water based mud, caking upon shakers as a soupy to pasty mush, or as pasty amorphous clumps, or simply in solution in the mud. Slight to locally moderate silts persisted throughout, consisting of mostly quartz, very slight to minor carbonaceous matter, and minor non quartz grains. Clays are inferred to be gradational to sand,conglomeratic sand, and conglomerate, as these constituents persist throughout. Brownish hues are from the breakdown of carbonaceous matter to organic clay. Some medium I~ht gray clays were ashy and occasionally grading to ash fall tuff, localty with slight to moderate angular silt to very fine shard like grains. Clays were overall non to very slightly calcareous, exhibiting only minor pin point effervescence, and with only traces of calcite and shell fragments noted in samples. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 1216 35 7000 0 0 0 0 AVE 15 2949 0 0 0 0 r1 [~ EPOCH 6 CC>~1000~1f~~1p5 1 R-East • Base Permafrost to T3 68' t 2683' MD 1704' to -1896" TVDSS 22 0 Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 206 10 130 75 32 55 This interval is composed of a long sequence of dominantly sand with considerable claystone and some siltstone. No oil shows were observed in the section and methane was the only gas recorded. The sands are dominantly light to medium gray. Grain size is extremely variable ranging from very fine to very coarse with fine grain sizes predominating. Thick intervals of conglomerate and conglomeratic sand occur from 2500 to 2683' with individual clasts up to an inferred 10 mm being logged. Angularity was mostly in the angularto very angular range with some sub rounded. The sands were quartz dominated with common accessory minerals of chert, lithic fragments, and more rarely glauconite and pyrite. Carbonaceous and woody material was commonly observed. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 1844 11 2200 0 0 0 0 AVE 34 6809 0 0 0 0 T3 to Casing Point ~co~~ +„ peon' enn i~ Qoa' _757' T11nCC1 LVVJ tV YY7V IYIV ~\/~/V - Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 148 50 119 140 53 88 This section included sand and claystone with minor siltstone. The sand is light gray quartz sand, fine grain, angularto subrounded. No cement was observed. No shows were seen in this interval and methane was the only gas recorded. The claystone is described as medium to dark gray with a silty texture due to silt and sand embedded in the clay matrix. Some silt and sand stringers were seen. Coal was present from 3080' to 3140'. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 2636 43 8000 0 0 0 0 AVE 39 7739 0 0 0 0 Surface Casing to Ugnu C e~nn++., cn7n' Ren ~')C7~' ~~n0' T/IICCI ~FY~7V LV J~7JV IYIV GJ! v - Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 412 38 123 86 1 21 This interval includes sand and conglomeratic sand, with claystone and some siltstone. Sandstone predominates, but in some spots claystone is over 50% of sample volume. Sand in this interval is described as very light gray to dark medium gray overall. Grain size ranges from very fine to lower coarse with angularities from very angularto sub rounded with most being angular. Sorting in generalty poor to fair. The sand is quartzose with individual clasts being clear, white translucent or cloudy. Accessory minerals include black and dark gray chert, dark mafic minerals, dark gray to black lithic chips, and mica. Some sand intervals are described ad "salt and pepper" in appearance. Several conspicuous zones of conglomeratic sand were noted in the interval 5580-5780'. The conglomerate is composed of bit shattered pebbles and cobbles of quartz and chert. Some chlorite stained quartz was seen, possibly from metamorphic lithics. The high claystone content is believed to be in part a clay ma#rix for the ~~1~~~ 7 CtN1000~'11~~1{~5 1 R-East sands and likely results in a loss of insitu porosity. Carbonaceous or organic matterwas seen in the interval, but seemed most concentrated in the zone 5625-5750'. It consists of black to very dark brown specks, films, filaments and clots of undifferentiated organic matter as well as some recognizable woody matter. No oil shows were observed in the interval and only methane was recorded by the gas equipment. Maxmum gas reading was 86 units at 5687' in a zone that correlates with a known producing zone at Milne Paint. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 4490-5930 41 8000 0 0 0 0 AVE 25 5067 .2 0 0 0 Ugnu C to Ugnu B ce~n~ +„ an ~a All LZ1 n~' +., _~QRT T/r1SSl JJJV LV VTVV ~~ Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 468 26 114 327 2 67.9 Oil shows started occurring within the sand, at approximately 6160' MD. Mostly, the gas observed in th~ interval was mainly methane. However, traces of ethane and propane were recorded. Two sands especially, from 6110-6250' and 6260-6410', had peak gases of 155 units and 285 units respectively, and numerous thin beds had lesser gas shows. Predominantly, this section included ail sands, interbedded with siltstone and claystone. The sand was predominantly clear to translucent, with some white and moderate yellowish brown. Mostly the sand consisted of predominantly quartz grain sand matrix, with very dark colored lithic fragments. The sand grains were mostly upper to lower very fine grain sand, with some upper very fine grain sand and some lower medium grained sand. The sand grains were very rounded to subrounded to angularto subangular, and mosiiy • loose sand grains with little or no cement supported matrix, rare poorly consolidated with clay and slight calate mats. Grain composition included 75-80% clear to translucent quartz,. and 25-20% black to gray to light gray to rare amber to grayish green, including hard siliceous lithics, silicates, and chert. Porosity is estimated at slightly good to some fair, while permeability is suspect do to immature nature of oil. Samples from 6160' to 6300' were lightly spotted with medium brown free oil, and oil fluorescence ranged from 60-70%. Fluorescent cuttings had a instantaneous blue green cut, and a pale straw colored fluorescent residue streak. While drilling this interval at 5998', Epoch's gas trap locked up and ceased rotating. After trouble shooting the trap, it was removed from the possum belly and taken to the logging unit for examination. Itwasdetermined that it would be much quicker to replace the trap with a new, backup trap rather than attempt repairs. The new trap was wired up and installed. The rig Beaded to make a short trip while waling for resumption of gas measuring ability. Total downtime for gas trap repairs was about 2 hours. No gas was recorded in the interval 5998 to 6093' due to this incident. Upon resumption of drilling, gas recording returned to normal. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6280 155 37003 0 0 0 0 6320 285 57027 14 0 0 0 AVE 220 47015 7 0 0 0 Ugnu B to Ugnu A c~~n~ +,. ~~a~~ nan / ~~zn'~' +., _2~RA~ T/I'1CCl • VTVV LV VVVV ~~ Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 173 97 126 627 105 390 ~l" ~~~1 8 ~~~~~~ 1 R-East The Ugnu B is a massive oil sand, apparently fining downward. Show gas peaked at 627 units, with shows of free oil and again, with only methane, ethane, and minor propane recorded. Predominantly, this section included oil sands, interbedded with siltstone and claystone. The Ugnu B Sand is 226 feet thick, medium gray, moderately to poorly sorted, and fining downward. Grains were fine to medium in the upper section, to fine and very fine upper in the lower section, subangular to subrounded overall, with some very rounded and very angular, with very slight clay and calcite matrix, to very loosely consolidated. Composition was dominantly clear to translucent quartz, with a slight non quartz fraction more prevalent as coarser grains in the upper section. Porosity is estimated at mostly good in the upper section gradually diminishing in the lower section with increasing matroc. Show properties include a strong oil odor, 20-40% lightto dark brown free oil, 80-90% pale yellow fluorescence, a strong instant blue green cut, and pale straw colored fluorescent residue streak. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6490 465 95991 46 0 0 0 6570 4$0 114755 34 0 0 0 AVE 472 105337 50 0 0 0 Ugnu A to West Sak D FFFS' fin 77FiQ' MIS (_~~RR' tn -'~Fi74' TVDSSI • Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 291 13 109 418 4 62 The Ugnu A includes a well developed oil sand from 6664'-6935', then overall grading downward to the West Sak. Gas peaked at 418 units in the main sand, and 269 units in the thin upper beds with shows of free oil and again, with only methane, ethane, and minor propane recorded. This section was mainly comprised of fine sand which was interbedded with very thin stringers of clay and silt, grading down into a very sandy calcareous clay. Sand was light gray to light brown, upper to lower fine to upper very fine to rare medium lower, moderately to poorly sorted and often grading coarse siltstone and silty claystone and overall fining downward. Grains were dominantly clear to translucent quartz, with minor dark colored lithic fragments throughout. Porosity is estimated at fair to good from 6664'-6935', and mostty poor thereafter. Oil properties include a faint oil sheen with some free oil (30%-60°~) in the upper sections to almost none in the lower sections, 80°fo-90% bright dull yellow fluorescence, good instantaneous blue green cut and a pale straw colored fluorescent residue streak. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6819 418 91561 46 0 0 0 AVE 61.9 12247 3.6 0 0 0 ~ EPC~~;H 9 COr1OC0~1t~,IpS 1 R-East LJ • West Sak D to West Sak C 7269' to 7320' MD -3674' to -3707' TVDSS Drill Rate fUhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 157 94 125 29 9 21 This interval includes the top of the West Sak D and the West Sak C Sand, with no oil staining and little show gas of 44 units. This section is predominantly comprised of fine sand which was interbedded with very thin stringers of clay and silt, grading down into very sandy calcareous clay and siltstone. The West Sak D Sand, from 7269'-7320', is light gray to brownish gray, upper to lower very fine to lower fine, with some grading to coarse silt, and lightly scattered very fine upper to fine lower grains, very angular to subangular, with some subrounded to very rounded, poorly to sorted, and loosely to poorly consolidated with little or no cement supported matrix, with a clay and calcite matrix. Grain composition included 75-80% clear to translucent quartz, and 20-30% black to gray to light gray, to grayish green, including hard siliceous lithics, silicates, and chert. Porosity is estimated at mostly poorto locally fair. Oil properties include a faint oil sheen with very little free oil (5%-10°l0). Very little or no visible fluorescence and no fluorescent cut, was observed throughout this section. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 6755 260 51748 18 0 0 0 6821 418 86635 35 0 0 0 AVE 339 69191 27 0 0 0 West Sak C to West Sak B 7~7n' to 7'~F'~' MI"1 /_'~R7d' to _777' TVf1SSl Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 182 98 158 100 10 165 The sand was predominantly clear to translucent, with some white and moderate yellowish brown. Mostly the sand consisted of predominantly quartz grain sand matrix, with very dark colored lithic fragments. The sand grains were mostly upper to lower very fine grain sand, with some upper very fine grain sand and some lower medium grained sand. The sand grains were very rounded to subrounded to angular to subangular, and mostly loose sand grainswith little or no cement supported matrix, rare poorly consolidated with clay and slight calcite matrix. Grain composfion included 75-80% clear to translucent quartz, and 25-20°k black to gray to light gray to rare amber to grayish green, including hard siliceous lithics, silicates, and chert. The West Sak C is a very fine oil sand. Minor dense siliceous sandstone is moderately consolidated with slight siliceous cement. Porosity is estimated at mostly poor to very poor. Show gas was 320 units maximum, with 150 units minimum in the well. For the first time in the well the presence of propane, butane and pentane, along were detected, along with methane and ethane. Oil properties included considerable free oil in all of the samples collected from this section. A 80%-90°lo bright pale yellow fluorescence, with an instant blue green cut, with a pale straw colored residue streak through out the samples collected. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7330 44 8775 19 0 0 0 AVE EPQ~H 10 COIr1OCOf~11~~1p5 1 R-East • West Sak B to West Sak A4 7~F~' to 7d71' Mrt (_~7~R' to -773' TVDSSI Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 132 94 109 300 29 94 Background gas remained high through this interval, gradational to sandstone and claystone. Gas increased locally to a maximum 320 units at 7379', to a low of 32 units at 7418', from apparent thin oil sands. Oil indicators are real prominent through the West Sak B through to the West Sak A4. Sandstone is light gray to brownish gray, with very fine lower grains to coarse silt, subangular, poorly to locally moderately sorted, often grain supported and moderately to poorly consolidated with slightly siliceous cement, to poorly to loosely consolidated and grain and mats supported with clay and calicite matruc and some slight calcareous cement. Grain composition included 70%-80% clear to translucent quartz, and 20%-30% black to gray to light gray to rare amber to grayish green, including hard siliceous lithics, silicates, and chert. Porosities are estimated at mostly very poor to locally poor to fair. The presence of C-1 through C-5 was detected in all of the gas samples during this section. Oil indicators include approximately 20%-30% free oil, and included 90°!°-100% pale yellow fluorescence, with an instantaneous blue green cut, and a weak s#raw colored residue streak. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7379 320 42823 468 219 455 200 AVE 312 45153 1074 380 717 475 • West Sak A4 to West Sak A3 7421' to 7482' MD -33773' to -3813' TVDSS • Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 115 98 100 305 23 133 Background gas remained very high during this interval. The gas levels detected in this interval (305 units at 7451'). Sandstone is lightgrayto brownish gray, with very fine lower grains to coarse silt, subangular, poorlyto locally moderately sorted, often grain supported and moderately to poorly consolidated with slightly siliceous cement, to poorly to loosely consolidated and grain and mats supported with clay and collate matruc and some slight calcareous cement. The sand grain composition is dominantly clear to translucent quartz (70%$0%},with slight blackcarbon lithics, and minor other constituents (20%-30%). Porosities are estimated at mostly fair. Again, the presence of C-1 through C-5 was detected in all of the gas samples during this section. Oil indicators include approximately 20%-30% free oil, 90%-100°~ moderate to bright fluorescence, with an instantaneous blue green cut, and a weak straw colored residue streak. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7451 305 74784 606 542 949 709 7460 108 27013 420 152 345 130 AVE 206 50898 513 347 647 419 ~P~~~ 11 C0~1OC~ll~~t~5 1 R-East r~ L J • West Sak A3 to West Sak A2 Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 180 64 116 510 7 51 Background gas started to decrease during this interval. Sandstone is light gray to brownish gray, with veryfine lower grains to coarse silt, subangular, poorly to locally moderately sorted, often grain supported and moderately to poorly consolidated with slightly siliceous cement, to poorly to loosely consolidated and grain and matrix supported with clay and calicite matrix and some slight calcareous cement. The quartz sand composfion is dominantly clear to translucent quartz (80%-90%), with slight black carbon lithics, some chert and minor other constituents (10%-20%). Porosities are estimated at mostly poor to slightly fair. The presence of C-1 through C-5 was detected in all of the gas samples during this section. Oil indicators include approximately 70%-80% moderate to bright fluorescence, with an instantaneous blue green cut, and a weak straw colored residue streak. Sandstone and siltstone was medium light gray to medium gray, very fine grained to silty, with traces to locally common fine grains, subrounded to subangular, poorly to locally moderately sorted, moderately softto friable, and matroc and grain supported with an abundant clay and slight calcite matrix. Composfion included 80% quartz, and 20% mostly black carbon silts and fines, some green grains possiblyglauconite, minorsilicates,ond trace carbon streaks. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7549 500 67744 989 1427 1935 1558 AVE 500 67744 989 1427 1935 1558 West Sak A2 to West Sak Al Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 141 51 100 160 18 24 Again, background gas decreased during this interval. The sandstone is light gray to brownish gray, with very fine lower grains to coarse silt, subangular, poorly to locally moderately sorted, often grain supported and moderately to poorly consolidated with slightly siliceous cement, to poorly to loosely consolidated and grain and matrix supported with clay and calicite matrix and some slight calcareous cement. The sand composfion is dominantly clear to translucent quartz, with slight black carbon lithics, and minor other constituents. Porosities are estimated at mostly poor to slightly fair. The presence of C-1 through C-5 was detected in all of the gas samples during this section. Oil indicators include approximately 5%-10°!o free oil, 10%-30% moderate to bright fluorescence, with an instantaneous blue green cut, and a weak straw colored residue streak. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7624 160 2200 250 400 323 300 7699 43 4046 51 114 197 197 AVE 100 2631 73 138 260 248 EPOCH 12 COnOCO~11{~IpS 1 R-East 3.3 Gas Samples (ISOTUBESI 7.. n:4 - A AT.°% Mn4F.ann Gn~~iv~lont n I~ .J .Sam le De thi Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05% M.E. (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 1 2100 6 1176 0 0 0 0 0 0 2 2350 65 13141 0 0 0 0 0 0 3 2600 45 9018 0 0 0 0 0 0 4 2850 35 6399 0 0 0 0 0 0 5 3100 45 9488 0 0 0 0 0 0 6 3350 64 12737 0 0 0 0 0 0 7 3691 87 17760 0 0 0 0 0 0 8 3850 119 22535 0 0 0 0 0 0 9 4100 48 9364 0 0 0 0 0 0 10 4350 88 15723 0 0 0 0 0 0 11 4600 15 3450 0 0 0 0 0 0 12 4850 25 4525 0 0 0 0 0 0 13 5100 35 7078 0 0 0 0 0 0 14 5350 22 4525 0 0 0 0 0 0 15 5600 34 6028 0 0 0 0 0 0 16 5850 34 6062 0 0 0 0 0 0 17 5952 49 10449 0 0 0 0 0 0 18 6100 8 1312 0 0 0 0 0 0 19 6200 89 5005 0 0 0 0 0 0 20 6350 285 57027 24 0 0 0 0 0 21 6490 465 95991 46 0 0 0 0 0 22 6570 480 114755 34 0 0 0 0 0 23 6620 420 84166 39 0 0 0 0 0 24 6755 260 51745 18 0 0 0 0 0 25 6821 418 86635 35 0 0 0 0 0 26 6850 75 15000 0 0 0 0 0 0 27 7100 30 5649 0 0 0 0 0 0 28 7200 25 4632 0 0 0 0 0 0 29 7300 12 2746 0 0 0 0 0 0 30 7330 44 8775 19 0 0 0 0 0 31 7365 150 37450 204 140 301 42 121 0 32 7379 320 42823 468 219 363 92 200 0 33 7400 234 30958 370 220 297 57 191 0 34 7451 305 47484 606 542 508 441 506 209 35 7500 108 27013 220 152 300 45 130 0 36 7549 500 67744 989 1427 739 1196 812 746 37 7600 25 0 0 0 0 0 0 0 38 7624 160 22000 200 400 291 36 119 0 39 7699 43 4046 51 114 22 125 105 92 40 7800 22 2006 15 20 0 0 0 0 41 7900 8 1000 0 0 0 0 0 0 42 8000 20 4212 15 0 0 0 0 0 EPOGH 13 ~~~~~~~ 1 R-East • • 3.4 Connection Gases None noted. 1nnit. 0_A5~/ Methana Fnuivalent Depth(TVD) feet Gas units/BG Depth(TVD) feet Gas unitsBG Depth(TVD) feet Gas unitsBG [~ EPC)~;H 14 ~~l~~l{x 1 R-East 3.5 Sampling Program /Sample Dispatch • Set T e / Pur ose Fre uenc Interval Dis atched to Bayview Warehouse Unwashed Biostratigraphy 60' ' 60' - 2080` MD ' ConocoPhillips Alaska, Inc. ABV 100 A 30 - 8075MD 2080 8105 Eleusis Drive Set owner: CPAI 10' SNOWS Anchorage, AK 99502 Attn: D. P ~ski/M. McCracken Bayview Warehouse Unwashed Biostratigraphy 60' ' 60' - 2080` MD ' ConocoPhillips Alaska, Inc. ABV 100 B 30 - 8075MD 2080 8105 Eleusis Drive Set owner: BP 10' SNOWS Anchorage, AK 99502 Attn: D. P ski/M. McCracken Bayview Warehouse Washed, screened & dried 60' 60' - 2080` MD ConocoPhillips Alaska, Inc. ABV 100 C Reference Samples 30' 2080' - 8075MD 8105 Eleusis Drive Set owner: CPAI 10' SNOWS Anchorage, AK 99502 Attn: D. P o ski/M. McCracken Bayview Warehouse Washed, screened & dried 60' 60' - 2080` MD ConocoPhillips Alaska, Inc. ABV 100 D Reference Samples 30' 2080' - 8075MD 8105 Eleusis Drive Set owner: BP 10' SNOWS Anchorage, AK 99502 Attn: D. P o'ski/M. McCracken Bayview Warehouse Washed, screened & dried 60' 60' - 2080` MD ConocoPhillips Alaska, Inc. ABV 100 E Reference Samples 30' 2080' - 8075MD 8105 Eleusis Drive Set owner: Unocal 10' Shows Anchorage, AK 99502 Attn: D. P "ski/M. McCracken Bayview Warehouse Washed, screened & dried 60' 60' - 2080` MD ConocoPhillips Alaska, Inc. ABV 100 F Reference Samples 30' 2080' - 8075MD 8105 Eleusis Drive Set owner: AOGCC 10' SNOWS Anchorage, AK 99502 Attn: D. P 'skilM. McCracken Isotube gas samples ` Routine intervals and 250' MD 2100 - 7000 Isotech Laboratories, inc. G si nificant eaks above g p 100' 7100 - 8075` MD 1308 Parkland Court 821 and spots of interest Champaign, IL 61 bac round uses H USGS Gas Hydrate 60' 120' - 3000' MD 345 Middlefield Rd. MS-999 Sample Menlo Park, CA, 94025 Attn: Tom Lorenson SETA & B: 1 SET contained in 4 BOXES -each 1 cubic foot (Do Not Freeze] SET C, D, E 8~ F: 1 each - 5 pack bundle 10"x10"x16" (total 4) SET G: 2 BOXES - $'/2" X 8'/2" X 10'/2° -Hazardous Gas, 42 Isotubes (warehouse to re-package) SET H: 1 Cooler -FROZEN -1 set frozen samples. Tota131 boxes C~ EPCJC~-I 15 C011pCt>~11~~IpS 1 R-East • • 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation Integrity/Leak Off Tests Equivalent mud weinht (EMWI is calculated from rotary table. MD ft TVDSS ft) FIT /LOT (ppg EMU1~ FORMATION 4510' 2647.5' 11.2 T3 LOT (Leak Off Test} in bold italics. 4.2 Wire line Formation Tests -Drill Pipe Conveyed MDT tool HYDROSTATIC DEPTH TVD TVDSS Before After F Press Mobility CaG Formation 6275 3307.42 UGNU C 6325 3326.32 UGNU C 6320 3324.46 UGNU C 6450.1 3371.2 UGNU B 6570.1 3417.64 UGNU B 6610 3432.23 UGNU B 6618 3435.03 UGNU B 6653 3447.15 UGNU B 67S6.1 3483.74 UGNU A 6828 3510.86 UGNU A 7040 3604.5 UGNU A ? 7280.2 3746.26 W. SAK D 7374.4 3807.81 W. SAK B 7379.1 3810.86 W. SAK B 7369 3804.23 W. SAK B 7400 3824.54 W. SAK B 7456 3861.21 W. SAK A4 7550 3921.56 W. SAK A3 7652.1 3985.31 W. SAK A2 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Background Gas (BG) Trip Gas (TG) Mud Weight (MW) Resistivity (RES) Corrected D exponent (DXC) Hole Conditions (HC) Pressure Test Wire line (PT) Survey Gas (SG) Equivalent Circulafing Density (ECD) ~Pac~ Downtime Gas (DTG) Wiper Gas (WG) Connection Gas (CG) Pore Pressure (PP) 16 r COt1000~ll~~lPS 1 R-East Quantitative Methods ~ The primary indicators used for PP evaluation were gas trends, including BG, CG, TG, WG, and DTG, and HC including flows and gas from swabbing or backreaming. Wire line testing was not conducted on this well. Epoch was not monitoring RPM, necessary for DXC calculations, and therefore DXC plots were not utilized. Factors such as controlled drill rates, alternate sliding and rotating intervals, variations in angle building, PDC bits, and the absence of clean shale baselines to establish compaction trends, tend to make DXC plots unreliable, anyway. RES plots tend to be reliable in determining a permafrost base, and suggesting compaction trends with depth, although the presence of hydrocarbons skews this data. However, generally, low RES and low gas indicate shaliness. 4.4 Pore Pressure Evaluation Conclusions For the well pore pressure varied from a measured value of 8.53 8'/~" production hole (MD:; TVD:) The following chart and plots summarize the conclusions for pore pressure. PP,MW,ECD, and GAS vs ND - 8.5" • 13 12.5 12 11.5 11 10.5 10 9.5 9 8.5 2500 3000 3500 4000 4.500 ' PP(PP9) • MW(ppg) ECD(ppg) E~ EPOCH 17 COf 1000~'ll~~lp5 1 R-East • DXC and GAS vs ND - 8.5" 3 2 -•-DXC Linear (DXC) • i• 1 0 ~- 2500 loon 100 10 1 2500 3000 3500 4000 4500 ~1 EPOCH 3000 3500 4000 PP,MW,ECD,RES, and GAS vs TVD - 8.5" 4500 '.. .: .~ . ''• .•~• . ~~ •:{ ~. • ~•.:~ . ~ ? ::: • • ~ • '.' ~ ~ ~ _ • j ~ ' ~ ~~ • ' PP(PP9) . ~(PP9) ECD(ppg) • RES(deep) -Linear ES dee 18 • 4.5 Pore pressure evaluation C~10Ca~11~~1~S 1 R-East Primary Secondary Interval To s Pore Pressure EMW Trend Source of Formation Interval Lithology ~%~ Lithology (%~ MD ft TVDSS ft Min Max Trend Indicators Quantitative Estimate Permafrost Sd 60% CI st 30% 110 -36 8.6 8.7 Flat BG RES Base Permafrost Sd 70% CI st 30% 226$' -1704' 8.6 8.7 Flat BG RES To U nu "C" Sd 40% CI st 30% 5930' -3109' 8.6 8.8 Flat BG RES, DXC To West Sak Sltst 40% Sd 30% 7269' -3674' 8.6 9.0 Sli ht U BG RES,DXC,PT Fault Sltst 50% Sd 30% 8.7 9.0 Flat BG RES,DXC,PT Base West Sak Sd 40% CI st 30% 7946' -4109' 8.8 9.0 Flat BG RES,- DXC TD NA NA 8074' -4201' 10.1 10.1 NA HC,TG RES NOTE: Clyst = Claystone ~~~~~ 19 COr1000~11~~1p5 1 R-East 5 DRILLING DATA 5.1 Survev Data • Measure Depth (ft) Ino I. (} Atom. () True Vertical Depth ft Latitude (ft) Departure {ft} Vertical Section (ft) Dogleg Rate (°1100ft) 0.00 0.00 0.00 0.00 0.00 S 0.00E 0.00 0.00 90.00 0.09 100.14 90.00 0.01 S 0.05 E -0.05 0.15 171.00 0.17 289.99 171.00 0.02 N 0.00 W 0.01 0.32 264.00 1.83 296.07 263.98 0.72 N 1.47 W 1.57 1.79 291.45 2.27 291.07 291.41 1.11 N 2.37 W 2.52 1.73 380.86 3.41 291.73 380.71 2.73 N 6.49 W 6.85 1.28 471.96 5.77 290.55 471.52 5.34 N 13.30 W 13.99 2.59 563.02 7.29 289.54 561.98 8.88 N 23.03 W 24.17 1.67 652.38 9.15 286.55 650.42 12.80 N 35.18 W 36.80 2.14 740.99 14.32 284.27 737.15 17.51 N 52.57 W 54.73 5.86 836.63 21.68 278.03 828.05 22.90 N 81.57 W 84.21 7.95 931.54 27.53 277.71 914.31 28.30 N 120.70 W 123.70 6.17 1026.40 29.43 278.64 997.69 34.74 N 165.46 W 168.92 2.06 1121.43 34.04 277.49 1078.49 41.72 N 214.94 W 218.87 4.89 1217.30 41.38 274.72 1154.28 47.83 N 273.21 W 277.36 7.86 1307.71 46.74 276.39 1219.23 53.96 N 335.76 W 340.06 6.07 1404.41 48.32 278.22 1284.53 63.05 N 406.50 W 411.33 2.15 1499.98 52.32 280.43 1345.54 75.00 N 479.05 W 484.86 4.55 1595.42 54.65 278.94 1402.33 87.89 N 554.65 W 561.56 2.75 1690.78 57.16 278.99 1455.78 100.19 N 632.65 W 640.52 2.63 1784.71 58.85 279.84 1505.55 113.23 N 711.24 W 720.18 1.96 1875.27 55.52 280.57 1554.62 126.70 N 786.13 W 796.27 3.74 1969.00 55.69 280.18 1607.56 140.63 N 862.21 W 873.60 0.39 2065.98 57.69 279.98 1660.82 154.81 N 942.00 W 954.64 2.07 2161.35 58.04 280.50 1711.55 169.17 N 1021.47 W 1035.39 0.59 2254.32 56.57 279.69 1761.77 182.89 N 1098.50 W 1113.62 1.74 2348.96 61.49 278.50 1810.45 195.69 N 1178.60 W 1194.74 5.31 2441.27 62.62 279.34 1853.71 208.34 N 1259.16 W 1276.28 1.46 2538.66 64.22 278.08 1897.29 221.52 N 1345.25 W 1363.36 2.01 2635.05 63.18 278.97 1940.00 234.33 N 1430.70 W 1449.76 1.36 2731.76 65.67 277.63 1981.75 246.91 N 1517.02 W 1536.97 2.86 2823.30 68.06 278.48 2017.71 258.71 N 1600.36 W 1621.12 2.75 2918.65 66.77 279.30 2054.33 272.31 N 1687.33 W 1709.15 1.57 3013.86 68.69 278.42 2090.41 285.87 N 1774.39 W 1797.25 2.19 3107.19 69.86 280.04 2123.44 299.88 N 1860.54 W 1884.53 2.05 3202.30 68.80 280.17 2157.01 315.49 N 1948.15 W 1973.51 1.12 3297.99 67.16 280.30 2192.89 331.25 N 2035.44 W 2062.21 1.72 [~ EPOCH 20 CC1t1tKOF~'11~~1p5 1 R-East • • Measured Depth Incl. o Azim. ~ True Vertical Depth Latitude (ft) Departure (ft) Vertical Section Dogleg Rate 3484.86 67.78 279.67 2262.44 360.50 N 2206.39 W 2235.64 1.17 3579.69 68.57 279.73 2297.70 375.33 N 2293.17 W 2323.67 0.84 3675.26 67.73 279.97 2333.27 390.51 N 2380.56 W 2412.38 0.91 3768.43 66.59 280.29 2369.43 405.61 N 2465.09 W 2498.23 1.26 3860.74 68.64 279.61 2404.58 420.35 N 2549.15 W 2583.58 2.32 3956.55 67.35 281.22 2440.48 436.40 N 2636.52 W 2672.39 2.06 4050.46 69.25 280.86 2475.20 453.11 N 2722.15 W 2759.60 2.05 4144.13 67.86 281.59 2509.45 470.08 N 2807.67 W 2846.74 1.65 4239.66 68.40 280.98 2545.04 487.43 N 2894.61 W 2935.35 0.82 4335.05 67.20 281.89 2581.08 504.93 N 2981.17 W 3023.61 1.54 4422.11 68.22 280.24 2614.10 520.39 N 3060.22 W 3104.13 2.11 4492.52 67.65 279.84 2640.55 531.76 N 3124.48 W 3169.38 0.97 4540.61 66.73 280.41 2659.19 539.56 N 3168.12 W 3213.70 2.20 4635.01 64.10 280.98 2698.47 555.48 N 3252.46 W 3299.52 2.84 4730.93 65.65 280.49 2739.19 571.65 N 3337.78 W 3386.33 1.68 4824.30 70.71 279.08 2773.89 586.36 N 3423.17 W 3472.98 5.60 4919.85 70.92 278.79 2805.29 600.38 N 3512.32 W 3563.22 0.36 5015.25 68.39 278.65 2838.45 613.94 N 3600.73 W 3652.66 2.66 5110.04 69.50 278.76 2872.51 627.33 N 3688.17 W 3741.11 1.18 5204.63 69.52 278.48 2905.62 640.61 N 3775.78 W 3829.71 0.28 5298.24 69.37 278.62 2938.48 653.64 N 3862.45 W 3917.35 0.21 5392.71 67.49 278.57 2973.21 666.77 N 3949.31 W 4005.19 1.99 5483.55 68.91 277.27 3006.95 678.38 N 4032.85 W 4089.50 2.05 5579.09 68.35 277.85 3041.76 690.09 N 4121.05 W 4178.42 0,81 5673.11 68.33 278.30 3076.46 702.36 N 4207.56 W 4265.78 0.45 5768.60 68.24 277.73 3111.79 714.73 N 4295.41 W 4354.47 0.56 5862.82 66.66 278.46 3147.93 726.98 N 4381.55 W 4441.46 1.82 5957.01 67.24 278.58 3184.81 739.82 N 4467.27 W 4528.11 0.63 6052.69 66.66 279.12 3222.27 753.37 N 4554.26 W 4616.15 0.80 6147.22 68.21 278.33 3258.54 766.60 N 4640.54 W 4703.43 1.81 6242.68 67.00 277.88 3294.91 779.05 N 4727.92 W 4791.67 1.34 6321.06 68.08 278.74 3324.85 789.52 N 4799.59 W 4864.09 1.71 6431.20 69.72 278.55 3364.50 804.96 N 4901.17 W 4966.83 1.50 6525.86 65.91 279.23 3400.24 818.50 N 4987.76 W 5054.46 4.08 6620.73 69.82 280.08 3435.98 833.24 N 5074.37 W 5142.32 4.20 6715.01 69.26 280.60 3468.94 849.10 N 5161.27 W 5230.64 0.79 6810.42 67.53 281.28 3504.06 865.93 N 5248.36 W 5319.31 1.93 6895.11 65.04 280.36 3538.12 880.49 N 5324.51 W 5396.82 3.10 6997.05 62.02 280.01 3583.56 896.63 N 5414.32 W 5488.06 2.98 7092.12 56.55 281.06 3632.10 911.54 N 5494.64 W 5569.74 5.83 7185.54 52.15 280.82 3686.53 925.95 N 5569.16 W 5645.61 4.72 7281.96 49.45 282.88 3747.47 941.27 N 5642.28 W 5720.25 3.25 ~PocH 21 CO#'1000~'1~~Ii~S 1 R-East 1~ • • Measured Depth (ft) Incl. (°) Azim. (°} True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°/100ft} 7372.58 49.12 282.10 3806.58 956.12 N 5709.34 W 5788.84 0.75 7468.17 49.10 279.93 3869.16 969.93 N 5780.26 W 5861.06 1.72 7562.47 51.59 279.16 3929.34 981.96 N 5851.85 W 5933.66 2.71 7655.92 51.04 279.90 3987.75 994.03 N 5923.79 W 6006.60 0.85 7751.15 50.14 279.35 4048.20 1006.34 N 5996.33 W 6080.18 1.05 7846.48 49.35 280.83 4109.81 1019.08 N 6067.95 W 6152.92 1.45 7929.46 48.61 279.01 4164.27 1029.87 N 6129.62 W 6215.52 1.88 8036.05 47.70 279.74 4235.38 1042.80 N 6207.96 W 6294.92 1.00 8075.00 47.70 279.74 4261.59 1047.67 N 6236.36 W 6323.73 0.00 [~ EP©CH 22 • 5.2 Bit Record • • C011000~'1~~~IpS 1 R-East Bit Make Type Jets / TFA Depth In MD / TVDSS Total Bit Avg. Rif' WEB RPM PP Wear BHA Serial # ft Footage Hrs ftlhr (Klbs) (psi) 12114" Hole 1 SMITH PC2636 1X13 110'/45 12 4380' 44.28 98.92 6-39 50-70 1000 4-4-WT-A-E- 1 ER7079CR 4X18 . 2100 ER-TD 8 1/2" Hole 2 SSDS HCM605 714049 5X13 4490/4425.1 3489' 34.72 120 2-50 0-74 6- 2763 5-6-BT-ALL- NA-IN-LT-TD 2 ~l" ~~1~ 23 5.3 Mud Record Contractor :MI SWACO Mud T e :S ud mud to 4490' Flo Pro to TD. • COn000~1~~~fpS 1 R-East Date Depth MW VIS s/ t PV YP Gels FL cc FC Sols % OMI Ratio Sd % MBT pH CI ml/I Ca ml/I 12114" Surface Hole Section 3/12/06 266 9.3 200 24 57 28/43/49 NC 2 5 /95 1.5 25 9.5 1000 160 3/13/06 1599 9.2 193 20 38 18/42/47 N/A 2 5 /95 1.25 25 9.5 1000 80 3/14/06 3174 9.6 210 31 40 18/46/49 5.4 2 7.5 /93 1.6 20 9.5 300 60 3/15106 4490 9.6 185 28 34 15/41 /47 5.2 2 7.5 /93 1.5 25 9.2 300 80 3/16106 4490 9.6 230 42 44 22/46/50 5.4 2 8 /92 1.5 25 8.9 300 80 3!17/06 4480 9.7 58 16 13 7/28/35 6.2 1 8 /92 1.25 20 8.3 300 80 3/18/06 4480 9.7 58 16 13 7/28/35 6.2 1 8 /92 1.25 20 8.3 300 80 3/19/06 4480 9.7 58 16 13 7/28/35 6.2 1 8 /92 1.25 20 8.3 300 80 8 1/2" Production Hole Section 3/20/06 4510 9.0 72 17 28 10/12/13 5 1 4.5 /96 0.1 1 9.4 24000 60 3/21 /O6 5968 9.0 57 10 34 13/14/15 4.4 1 4.5 /96 0.25 2.75 9.4 22000 120 3/22/06 7060 9.1 56 11 31 11/12/13 4.2 1 5 1 /94 0.2 2.5 8.7 22000 300 3/23/06 7979 9.3 61 10 35 13/14/15 4.8 1 6.5 1 /93 0.25 2.8 9.5 22000 120 3/24/06 8075 9.0 61 10 26 9/11/12 4.8 1 4.6 1/95 TRC 1.5 9.5 24000 92 Abbreviations MW =Mud Weight Gels =Gel Strength Sd =Sand content WL =Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids YP =Yield Point ECD =Effective Circulating Density FC =Filter Cake O/W =Oil to Water ratio EPC~~;H 24 ~~~~~~ 1 R-East r~ U • MORNING REPORTS [~ EPOCH 25 ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Hiem/ Pederson Date: 3/13/06 Time: 04:30 Current Depth: 515 Yesterdays Depth: 110 24 hr Footage: 405 flrillinn Paramatarc Operation: DRILL ROP:v Current: 83 Max: 302 Tor ue: Current: 0 Max: 0 WO13: Current 6 Max: 16 RPM: Current: 0 Max: 0 PP: Current: 1002 Max: 1085 La Strokes: 1065 Time: 7.2 Circulation: Strokes: Time: ECD: Current: 9.54 Max: Mi~rl Prnnertiec MW: 9.3 FV: 200 PV: 24 YP: 57 FL: Nc Gels: 28!43!49 Sol: 5 H: 9.5 CI"~ 1000 Ca++~ 160 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: .92.4 Max: 1.7 De the 400 rac Fvantc Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 400 1.7 370 mac SamnlPs No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: SAND, CONGLOMERATE, CLAY Current: SAND, CLAY Last 24 hrs: Load and strap csg, drill out conductor, displace to spud mud, drill to 191', Operational Summary: POOH and pickup mwd, rig in hole and drill ahead by sliding as per directional plan and using wireline gyro at each connection. Calibrations: Calibrated before start of job. Failures: Gas trap down from 407' - 506' lagged returns, 2 hrs 11 min. C~ ConocoPhillips Alaska Inc. Exploration Well 1 R-East U L~ Report for: Hiem/ Pederson Connie Z Date: 3/14/06 Time: 04:00 Current Depth: 1989 Yesterdays Depth: 515 24 hr Footage: 1474 nrillina Parameters Operation: DRILLING ROP: Current: 67 Max: 184 Torque: Current: N/A Max: N/A WOB: Current 23 Max: 29 RPM: Current: N/A Max: N/A PP: Current: 1295 Max: 1300 La Strokes: 3652 Time: 22 min Circulation: Strokes: 10431 Time: 64 min ECD: Current: 9.53 Max: Mud Pr~nerties MW: 9.2 FV: 193 PV: 20 YP: 38 FL: N/A Gels: 18/42!47 Sol: 5 H: 9.5 CI"~ 1000 Ca++~ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 6 Max: 136 De the 1368 Gas Fvents Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 1368 136 26878 gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: SAND, CONGLOMERATIC SAND, CLAY/ SILT Current: SAND/ COARSE SAND Last 24 hrs: Operational Summary: DRILL AND SURVEY AS PER DIRECTIONAL PLAN Calibrations: WILL BE CHECKED AT WIPER TRIP. Failures: TOTCO ERROR AT 00:08 AM., 1735', STOPPED SENDING WITS DATA ACROSS. i• ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson Connie Z • Date: 3/15/06 Time: 04:00 rlrillinn Paramctcrc Current Depth: 3647 Yesterdays Depth: 1989 24 hr Footage: 1658 ROP: Current: Max: 206 Torque: Current: Max: WOB: Current Max: 28 RPM: Current: Max: PP: Current: Max: 1843 La Strokes: 6840 Time: 40 min Circulation: Strokes: 14733 Time: 87 min ECD: Current: 9.93 Max: Mari Prnnertiac MW: 9.6 FV: 210 PV: 31 YP: 40 FL: 5.4 Gels: 18/46!49 Sol: 7.5 H: 9.5 CI"~ 300 Ca~~ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: 80 De the 3333 C~ac FvF+nfc Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 2321 110 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 2487 63 12678 2829 73 14684 3333 80 16073 r=,ac SamnlPc No. De th TG C1 C2 C3 C41 C4N C51 C5N 4 2850 35 6399 5 3100 45 9485 6 3350 64 12737 Lithologies: SAND, CONGLOMERATIC SAND, CLAY Current: Last 24 hrs: Operational Summary: DRILL TO 2321', PUMP HI VIS SWEEP, WIPER TRIP TO 713', RIH, DRILL. Calibrations: Failures: WITS FEED FROM TOTCO REPAIRED DURING WIPER TRIP. GAS TRAP 40 min Operation: DRILLING L~ ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson Connie Z • Date: 3/16/06 Time: 02:00 Drilling Parameters • Current Depth: 4490 Yesterdays Depth: 3647 24 hr Footage: 843 Operation: CBU/ PUMP SWEEP ROP: Current: 0 Max: 201 Tor ue: Current: Max: WOB: Current 0 Max: 39 RPM: Current: Max: PP: Current: 1611 Max: 2131 La Strokes: 8482 Time: 49.9 Circulation: Strokes: Time: ECD: Current: Max: Mud Properties MW: FV: PV: YP: FL: Gels: Sol: H: CI~~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 4490 150 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Back ream eak 1900 172 33190 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3747 127 25570 3863 137 26855 4437 140 27380 Gas Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N 7 3691 84 17760 8 3850 119 22535 9 4100 48 8364 10 4350 88 15723 Lithologies: Sand, clay, siltstone, shale Current: Sand, clay Last 24 hrs: Operational Summary: Calibrations: Failures: Drill to csg point @ 4490, pump Hi vis sweep. POOH, Back ream out at 3430', circ hole clean, max gas 172. RIH from 1568'. Took wt at 3775', ream down, cant RIH to bottom, CBU, pump sweep. ~ • ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson • Date: 3/17/06 Time: 01:00 Current Depth: 4490 Operation: Circ thru csg prior to cementing Yesterdays Depth: 4490 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: 322 Max: La Strokes: 3470 Time: Circulation: Strokes: 12941 Time: ECD: Current: 9.97 Max: Mud Pro erties MW: FV: PV: YP: FL: Gels: Sol: H: CI"~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 19 Max: 65 De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N yaks No. De th TG C1 C2 C3 C41 C4N C51 C5N as Samples Lithologies: Current: NO DRILLING LAST 24 HOURS Last 24 hrs: Operational Summary: POOH, download and L/D MWD and BHA, rig up and run CSG, break Circ %4 of the way in hole, 65u gas, cont RIH to bottom. Calibrations: Failures: I• ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson Connie Z • Date: 3/18/06 Time: 01:00 Current Depth: 4490 Operation: TEST BOPE'S Yesterdays Depth: 4490 24 hr Footage: 0 f)rillinn ParamPtPrs • Peaks ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Circulation: Strokes: Time: ECD: Current: Max: Mud Properties MW: FV: PV: YP: FL: Gels: Sol: H: CI-~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 57 De the 4480' Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: NO DRILLING LAST 24 HOURS Last 24 hrs: Operational Summary: Land csg at 4480', cond mud for cementing, bump plug with 4423 stks, 314 bbls, clean pits, nipple down diverter, attach csg head, nipple up. Calibrations: Failures: ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson Connie Z Date: 3/19/06 Time: 01:00 Current Depth: 4490 Operation: Repair BOP Yesterdays Depth: 4490 24 hr Footage: 0 Ilrillinn ParamatPrc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Circulation: Strokes: Time: ECD: Current: Max: Mud Pro erties MW: FV: PV: YP: FL: Gels: Sol: H: CI"~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De the (?aS Fvantc Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N eaks No. De th TG C1 C2 C3 C41 C4N C51 C5N •as Sam les Lithologies: Current: NO DRILLING LAST 24 HOURS Last 24 hrs: Operational Summary: TEST AND REPAIR BOP. Calibrations: Failures: ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson Connie Z Date: 3/20/06 Time: 02:00 Current Depth: 4490 Yesterdays Depth: 4490 24 hr Footage: 0 Drilling Parameters • Operation: TEST MWD ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Circulation: Strokes: Time: ECD: Current: Max: _. _ _~ Mud Pro erties MW: FV: PV: YP: FL: Gels: Sol: H: CI"~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks No. De th TG C1 C2 C3 C41 C4N C51 C5N gas Sam les Lithologies: NO NEW HOLE PAST 24 HRS Current: Last 24 hrs: Operational Summary: NU STACK; CHANGE OUT RAMS; FUNCTION TEST BOP'S; P/U BHA Calibrations: CHECKED TOTAL GAS CAL; OK Failures: ConocoPhillips Alaska Inc. Explora#ion Well 1 R-East Report for: Wilson/ Pederson Connie Z • Date: 3/21/06 Time: 03:00 Current Depth: 4535 Operation: DRILL AHEAD Yesterdays Depth: 4490 24 hr Footage: Drilling Parameters • ROP: Current: 117 Max: Tor ue: Current: 7826 Max: _ WOB: Current 3 Max: RPM: Current: 33 Max: PP: Current: 1559 Max: La Strokes: 3222 Time: 21.7" Circulation: Strokes: 4193 Time: 28.3" ECD: Current: Max: Mud Properties MW: FV: PV: YP: FL: Gels: Sol: H: CI-~ Ca++: MW Change: Depth: From; To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De the Gas Events Trip Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam ples No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: SAND 80%, CLAYSTONE 20% Last 24 hrs: SAME AS ABOVE M/U BHA; RIH TO 4297'; WASH DN TO 4390`, CIRC; TEST CSG TO 3000# Operational Summary: ;DRILL TO 4510'; CLEAN PITS; CIRCL FLOPRO; WORK ON PUMP; FIT 11.2 PPG. Calibrations: Failures: • ConocoPhillips Alaska Inc. Exploration Well 1 R-East • Report for: Wilson/ Pederson Connie Z Date: 3/22/06 Time: 02:00 r)rillinn ParamatPrs Current Depth: 5998 Yesterdays Depth: 4535 24 hr Footage: .1463' Operation: DRILL AHEAD ROP: Current: 98 Max: 354 Tor ue: Current: 7826 Max: WOB: Current 5 Max: 43 RPM: Current: 33 Max: PP: Current: 1773 Max: 2085 La Strokes: 4100 Time: 28" Circulation: Strokes: 5443 Time: 37.3" ECD: Current: 10.53 Max: Mud Pmnerties MW: 9.0 FV: 57 PV: 10 YP: 34 FL: 4.4 Gels: 13/14/15 Sol: 4.5 H: 9.4 CI-- 22000 Ca++~ 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 27 Max: 86 De the 5687' C~a~ FvPnt~ Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE peaks De th TG C1 C2 C3 C41 C4N C51 C5N 5687 86 No. De th TG C1 C2 C3 C4i C4N C51 C5N 7 TOTAL 250' I NT VAR 3as Sam les Lithologies: Current: SAND 70%, SILTSTONE 10%, CLAYSTONE 20% Last 24 hrs: SAND, SILTSTONE, CLAYSTONE, CONGLOMERATE Operational Summary: DRILL FROM 4535 TO REPORT DEPTH Calibrations: CHECKED ON DAYLIGHT TOUR Failures: .7 ConocoPhillips Alaska Inc. Exploration Well 1 R-East i • • Report for: Wilson/ Pederson Connie Z Date: 3/23/06 Time: 02:00 Current Depth: 7138 Yesterdays Depth: 5998 24 hr Footage: 1140' Drilling Parameters Operation: DRILL AHEAD ROP: Current: 164 Max: 468 Tor ue: Current: 14841 Max: 16090 WOB: Current 2 Max: 50 RPM: Current: 72 Max: 73 PP: Current: 2223 Max: 2763 La Strokes: 4793 Time: 26.5 Circulation: Strokes: 6431 Time: 35.6" ECD: Current: 10.45 Max: Mud Properties MW: 9.1 FV: 56 PV: 11 YP: 31 FL 4.2 Gels: 11/12/13 Sol: 5 H: 8.7 CI-~ 22000 Ca++~ 300 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 17 Max: 627 De the 6519 Gas Events Tri Gas Depth TG C1 C2 C3 C41 C4N C51 C5N 6093 107 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 6325 327 67940 22 6519 627 133838 64 6641 612 156354 69 6819 418 91561 36 Gas Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N 11TOTAL 250/100' INT & PEAKS VAR Lithologies: Current: CLAYSTONE 80%, SILTSTONE 10%, SAND 10% Last 24 hrs: SAND, SILTSTONE, CLAYSTONE, CONGLOMERATE Operational Summary: DRILL 5998-6093'; MUDLOGGERS GAS TRAP LOCKED UP; WIPER TRIP WHILE WAITING FOR TRAP REPAIR; DRILL 6093-REPORT DEPTH. Calibrations: 6925' Failures: GAS TRAP MOTOR LOCKED UP. ConocoPhillips Alaska Inc. Exploration Well 1 R-East n U • Report for: Wilson/ Pederson Connie Z Date: 3/24/06 Time: 02:00 Current Depth: 71388015 Operation: DRILL AHEAD Yesterdays Depth: 7138 24 hr Footage: 877' I~rillinn ParamPtPrs ROP: Current: 100 Max: 375 Tor ue: Current: NA Max: WOB: Current 4 Max: 57 RPM: Current: NA Max: PP: Current: 2160 Max: 2736 La Strokes: 5288 Time: 29.7" Circulation: Strokes: 7136 Time: 40.1" ECD: Current: NA Max: Mud Pro ernes :MUD REPORT NOT AVAILABLE TODAY MW: FV: PV: YP: FL: Gels: Sol: H: CI"~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 29 Max: 529 De the 7548' r~ac Fvantc Tri Gas Depth TG C1 C2 C3 C41 C4N C51 C5N 7222 45 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE PPakc De th TG C1 C2 C3 C41 C4N C51 C5N 7379 319 55706 589 275 438 91 237 7452 300 47484 607 542 508 442 448 7548 529 74621 993 1555 7$0 1264 798 7621 174 22345 316 538 303 510 380 350 [was Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N 15 250/100' INT & PEAKS VARIABLE Lithologies: Current: SAND 50%, SILTSTONE 20%, CLAYSTONE 20%, SHALE 10% Last 24 hrs: SAND, SILTSTONE, CLAYSTONE, CONGLOMERATE Operational Summary: DRILL FROM 7138 TO 7222; WIPER TRIP; DISPLACE MUD; DRILL TO 7980; PUMP SWEEP; DRILL TO REPORT DEPTH Calibrations: Failures: • ConocoPhillips Alaska Inc. Exploration Well 1 R-East Report for: Wilson/ Pederson Connie Z Date: 3/25/06 Time: 02:00 Current Depth: 8075 Yesterdays Depth: 8015 24 hr Footage: 60 rlrillinn Paramatarc L~ Operation: POOH TO LOG ROP: Current: NA Max: 664 Tor ue: Current: NA Max: 15572 WOB: Current NA Max: 34 RPM: Current: NA Max: 19 PP: Current: NA Max: 2461 La Strokes: 5322 Time: 29.9" Circulation: Strokes: 7184 Time: 40.4" ECD: Current: NA Max: 10.82 Mutt PrnnPrtiPC MW: 9.0 FV: 61 PV: 10 YP: 26 FL: 4.8 Gels: 9/11/12 Sol: 4.6 H: 9.5 CI"~ 24000 Ca~`~'- 92 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: NA Max: 51 De the 8069 (;ac FvPntc Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NONE De th TG C1 C2 C3 C41 C4N C51 C5N NONE 'eaks No. De th TG C1 C2 C3 C41 C4N C51 C5N 41 7900 8 533 42 8000 20 3459 12 10 gas Sam les Lithologies: Current: SAND 80%; CLAYSTONE 20% Last 24 hrs: SAND, SILTSTONE, CLAYSTONE, RARE CONGLOMERATE Operational Summary: DRILL TO 8075'; POOH TO 4390'; SLIP/CUT; RIH TO BTM; PUMP SWEEP; DISPLACE HOLE W/NEW FLO PRO MUD; POOH Calibrations: AT TD Failures: U ConocoPhillips Alaska Inc. Exploration Well 1 R-East • L~ Report for: Wilson/ Pederson Connie Z Date: 3/26/06 Time: 02:00 Current Depth: 8075 Yesterdays Depth: 8075 24 hr Footage: 0 Drilling Parameters ROP: Current: NA Max: NA Tor ue: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA La : Strokes: NA Time: NA Circulation: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Pro erties MW: FV: YP: FL: Gels: Sol: H: CI~~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: NA Max: De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: NA Last 24 hrs: Operational Summary: Calibrations: Failures: POOH; L/D MWD-LWD TOOLS; R/U SWSC; M/U MDT TOOLS; RIH; WORK ON WIRE LINE; RUN LOGS Operation: RUN LOGS • ConocoPhillips Alaska Inc. Exploration Well 1 R-East • L~ Report for: Wilson/ Pederson Connie Z Date: 3127/06 Time: 02:00 Current Depth: 8075 Yesterdays Depth: 8075 24 hr Footage: 0 f)rillinn Paramatarc Operation: POOH W/MDT ROP: Current: NA Max: NA Tor ue: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA La Strokes: NA Time: NA Circulation: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties MW: FV: YP: FL: Gels: Sol: H: CI"~ Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: NA Max: De the was Fvents Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam ples No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithoiogies: Current: NA Last 24 hrs: Operational Summary: Calibrations: Failures: CONTINUE TO RUN MDT TOOL; TOOL FAILED AFTER 12 PRESSURE TESTS AND 2 FLUID TESTS; POOH W/MDT TOOL. •
