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Home My WebLink About205-109 T R A N S M I T T A LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit Colville CD1-01A 50-103-20299-01 212099_CD1-01A_PERF_23Jul22 212099_CD1-01A_WFL_23May2022 CD1-04 50-103-20346-00 200117_CD1-04_PLUG_27Aug2022 CD1-33 50-103-20357-00 222105_CD1-33_Puncher_21Sep2022 CD1-48A 50-103-20592-01 212004_CD1-48A_LDL_28Jul2022 CD2-02 50-103-20513-00 205109_CD2-02_LDL_11Oct2022 205109_CD2-02_LDL_12Jul2022 205109_CD2-02_Patch_07Nov2022 205109_CD2-02_PLUG_23Aug2022 CD2-15 50-103-20386-00 201159_CD2-15_LDL_06Oct23 CD2-310 50-103-20826-00 220028_CD2-310_DHSIT_10Aug2022 220028_CD2-310_USIT_25Apr2022 CD2-404 50-103-20530-00 206054_CD2-404_Patch_30Dec2021 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38291 T38292 T38293 T38294 T38295 T39296 T38297 T38734 200-212 CD2-02 50-103-20513-00 205109_CD2-02_LDL_11Oct2022 205109_CD2-02_LDL_12Jul2022 205109_CD2-02_Patch_07Nov2022 205109_CD2-02_PLUG_23Aug2022 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:54:09 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-02 PTD (205-109) IA Suspect Date:Thursday, March 2, 2023 3:00:35 PM Attachments:AnnComm Surveillance TIO for CD2-02.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, March 2, 2023 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD2-02 PTD (205-109) IA Suspect Chris, CRU CD2-02 PTD (205-109) was reported by operations IA above DNE. Currently the TIO pressure is 2500/2500/550. DHD will conduct the initial diagnostics. Depending on results, proper notifications will be made as needed. Attached in the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com CD2-02 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD2-02 2022-12-15 1625 575 -1050 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 16,009.0 CD2-02 12/12/2005 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added leaks and patches CD2-02 12/6/2022 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: Slickline acheived passing MIT-T 8' above patch with D&D HF @13,055' 8/31/2022 oberr NOTE: TREE: FMC 4-1/16" 5K - TREE CAP CONNECTION: 7" OTIS 8/2/2005 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By TREE: FMC 4-1/16"" 5K TREE CAP CONNECTION: 7"" OTIS 8/2/2005 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 37.0 114.0 114.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 36.9 3,856.3 2,380.9 36.00 J-55 BTC PRODUCTION 7 6.28 34.7 16,048.6 7,259.8 26.00 L-80 BTCM OPEN HOLE 6 1/8 16,048.0 21,178.0 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.8 Set Depth … 15,488.4 Set Depth … 7,134.5 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.8 32.8 0.20 HANGER 10.800 FMC TUBING HANGER 4.500 2,321.7 1,756.3 65.35 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 15,301.4 7,060.9 66.47 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 15,414.9 7,105.7 66.72 PACKER 5.970 BAKER PREMIER PACKER BAKER PREMIE R 3.875 15,476.1 7,129.8 67.39 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 15,487.1 7,134.0 67.66 WLEG 5.000 WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,321.7 1,756.2 65.35 INJ VALVE 4.5" A-1 Injection Valve on 3.812" DB Lock 11/16/2022 1.250 13,055.0 6,137.4 65.84 PACKER - PATCH - UPR 4.5" Paragon II Packer, ME= 13055' MD 11/15/2022 2.000 13,059.0 6,139.0 65.79 SPACER PIPE Spacer Pipe w/ 2.875" OD beveled Coupling 11/15/2022 1.995 13,073.0 6,144.8 65.68 LEAK - TUBING LDL Located Leak in tubing at 13,073' MD 7/12/2022 3.960 13,090.0 6,151.8 65.63 PACKER - PATCH - LWR 4.5" Paragon II Packer, ME= 13,090' MD 11/15/2022 2.000 13,544.0 6,341.1 66.72 PACKER - PATCH - UPR 4.5" Paragon II Packer, ME= 13544' MD 11/14/2022 2.000 13,548.0 6,342.7 66.74 SPACER PIPE Spacer Pipe w/ 2.875" OD beveled Coupling 11/14/2022 1.995 13,555.6 6,345.7 66.78 LEAK LDL Located Leak in tubing at 13,555.6' MD 10/11/2022 0.000 13,567.0 6,350.2 66.83 PACKER - PATCH - LWR 4.5" Paragon II Packer, ME= 13567' MD 11/12/2022 2.000 13,815.0 6,448.8 64.82 PACKER - PATCH - UPR 4.5" Paragon II Packer, ME= 13815' MD 11/9/2022 2.000 13,819.0 6,450.5 64.73 SPACER PIPE Spacer Pipe w/ 2.875" OD beveled Coupling 11/9/2022 1.995 13,820.7 6,451.2 64.70 LEAK - TUBING LDL Located Leak in tubing at 13,820.7' MD 10/11/2022 3.960 13,845.0 6,461.6 64.62 PACKER - PATCH - LWR 4.5" Paragon II Packer, ME= 13845.0' 11/8/2022 2.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 15,301.4 7,060.9 66.47 1 GAS LIFT DMY BK 1 0.0 6/23/2018 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 16,048.0 7,259.8 89.75 OPEN HOLE 6.125 CD2-02, 12/12/2022 9:16:15 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 FLOAT SHOE; 16,046.5- 16,048.6 FLOAT COLLAR; 15,961.9- 15,963.1 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 PACKER - PATCH - LWR; 13,845.0 SPACER PIPE; 13,819.0 LEAK - TUBING; 13,820.7 PACKER - PATCH - UPR; 13,815.0 PACKER - PATCH - LWR; 13,567.0 SPACER PIPE; 13,548.0 LEAK; 13,555.6 PACKER - PATCH - UPR; 13,544.0 PACKER - PATCH - LWR; 13,090.0 SPACER PIPE; 13,059.0 LEAK - TUBING; 13,073.0 PACKER - PATCH - UPR; 13,055.0 SURFACE; 36.9-3,856.3 FLOAT SHOE; 3,854.1-3,856.3 FLOAT COLLAR; 3,771.8- 3,773.3 INJ VALVE; 2,321.7 NIPPLE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 36.9-39.1 HANGER; 34.7-37.0 HANGER; 32.8 WNS INJ KB-Grd (ft) 43.81 RR Date 8/22/2005 Other Elev… CD2-02 ... TD Act Btm (ftKB) 21,178.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032051300 Wellbore Status INJ Max Angle & MD Incl (°) 95.76 MD (ftKB) 21,129.76 WELLNAME WELLBORECD2-02 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP CD2-02, 12/12/2022 9:16:16 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 FLOAT SHOE; 16,046.5- 16,048.6 FLOAT COLLAR; 15,961.9- 15,963.1 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 PACKER - PATCH - LWR; 13,845.0 SPACER PIPE; 13,819.0 LEAK - TUBING; 13,820.7 PACKER - PATCH - UPR; 13,815.0 PACKER - PATCH - LWR; 13,567.0 SPACER PIPE; 13,548.0 LEAK; 13,555.6 PACKER - PATCH - UPR; 13,544.0 PACKER - PATCH - LWR; 13,090.0 SPACER PIPE; 13,059.0 LEAK - TUBING; 13,073.0 PACKER - PATCH - UPR; 13,055.0 SURFACE; 36.9-3,856.3 FLOAT SHOE; 3,854.1-3,856.3 FLOAT COLLAR; 3,771.8- 3,773.3 INJ VALVE; 2,321.7 NIPPLE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 36.9-39.1 HANGER; 34.7-37.0 HANGER; 32.8 WNS INJ CD2-02 ... WELLNAME WELLBORECD2-02 Comment 3.81" A-1 INJ VLV (S/N: HRS-3… CD2-02, 12/12/2022 9:16:17 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 FLOAT SHOE; 16,046.5- 16,048.6 FLOAT COLLAR; 15,961.9- 15,963.1 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 PACKER - PATCH - LWR; 13,845.0 SPACER PIPE; 13,819.0 LEAK - TUBING; 13,820.7 PACKER - PATCH - UPR; 13,815.0 PACKER - PATCH - LWR; 13,567.0 SPACER PIPE; 13,548.0 LEAK; 13,555.6 PACKER - PATCH - UPR; 13,544.0 PACKER - PATCH - LWR; 13,090.0 SPACER PIPE; 13,059.0 LEAK - TUBING; 13,073.0 PACKER - PATCH - UPR; 13,055.0 SURFACE; 36.9-3,856.3 FLOAT SHOE; 3,854.1-3,856.3 FLOAT COLLAR; 3,771.8- 3,773.3 INJ VALVE; 2,321.7 NIPPLE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 36.9-39.1 HANGER; 34.7-37.0 HANGER; 32.8 WNS INJ CD2-02 ... WELLNAME WELLBORECD2-02 Comment 3.81" A-1 INJ VLV (S/N: HSS-1… MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-02 COLVILLE RIV UNIT CD2-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 CD2-02 50-103-20513-00-00 205-109-0 W SPT 7105 2051090 3000 1644 1648 1644 1642 370 480 480 480 OTHER P Bob Noble 12/18/2022 MIT-IA post patch as per undry 322-452. MIT-IA to max injection pressure as per AIO 18D.003 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: COLVILLE RIV UNIT CD2-02 Inspection Date: Tubing OA Packer Depth 880 3300 3190 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN221221144441 BBL Pumped:4.5 BBL Returned:4.5 Thursday, January 26, 2023 Page 1 of 1 MIT-IA post patch as per undry 322-452. MIT-IA to max injection pressure as per AIO 18D.003 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 21178'feet None feet true vertical 7241' feet None feet Effective Depth measured 21178'feet feet true vertical 7241'feet feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 15488' MD 7134' TVD Packers and SSSV (type, measured and true vertical depth) 13055' MD 13090' MD 13544' MD 13567' MD 13815' MD 13845' MD 15415' MD N/A 6137' TVD 6152' TVD 6341' TVD 6350' TVD 6449' TVD 6462' TVD 7106' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Alpine Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 13055', 13090', 13544', 13567', 13815', 13845', 15415' 6137', 6152', 6341', 6350', 6449', 6462', 7106' 322-452 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker Premier Packer SSSV: None Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist Open Hole: 16048-21178' feet Open Hole: 7260-7241' feet measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 114' ~ ~~ INJECTOR ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-109 50-103-20513-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380075, ADL0387212, ADL0388466, ASRC NPRA-1 Colville River Field/ Alpine Oil Pool CRU CD2-02 Plugs Junk measured Length Production Liner 16014' Casing 7260'16048' 3819' 114'Conductor Surface Intermediate 16" 9-5/8" 77' 3856' 2381' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 8:46 am, Dec 13, 2022 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2022.12.12 10:13:24-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 12, 2022 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patches set across known tubing leaks in injector CRU CD2-02 PTD #205-109) as per sundry 322-452. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN= Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2022.12.12 10:11:44-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 8/10/2022 ACQUIRE DATA PULLED KEYLESS 3.81" XN PLUG w/ FLOW THRU SUB AND DUAL SPARTEK GUAGES @ 15,476' RKB ( BHP 3685 PSI, TEMP 149* ). JOB IN PROGRESS. 8/11/2022 ACQUIRE DATA BRUSH AND FLUSHED PATCH AREA f/ 13,000' RKB TO 13,181' RKB. RAN 3.77" DUMMY PATCH DRIFT ( OAL= 30.3' ) TO 13,181' RKB. JOB IN PROGRESS. 8/23/2022 ACQUIRE DATA SET LOWER PACKER FOR PATCH AT 13090' JOB COMPLETE 8/29/2022 ACQUIRE DATA SET 4.5" PIIP UPPER PACKER PATCH ASSEMBLY IN LOWER PATCH AT @ 13062' RKB. ATTEMPT MIT-IA TO 2500 PSI, 407 PSI IN 15 MINUTES, BUMP UP TO 2500 PSI, SAME LINIER PRESSURE LOSS IN 15 MINUTES. JOB SUSPENDED FOR TAR PRIOPITIES. IN PROGRESS. 8/31/2022 ACQUIRE DATA SET STUBBY 4-1/2" HF ON TOP OF PATCH @ 13062' RKB, UNABLE TO PRESSURE UP TBG HIGHER THEN 1800 PSI @ 1 BPM. RE-ATTEMPT TEST @ TOP OF PATCH W/ SLIPSTOP HF @ 13062' RKB, 2000 PSI ON TBG BUT LOST 400 PSI IN 4 MIN., RESET SS HF 27' FROM TOP OF PATCH @ 13035' RKB & ACHIEVED PASSING MIT-T TO 2000 PSI, SET 4-1/2" SS HF W/ ELEMENT 8' FROM UPPER PKR ME @ 13055' RKB & ACHIEVED PASSING MIT-T TO 2000 PSI. IN PROGRESS. 9/21/2022 ACQUIRE DATA PULLED UPPER PIIP PACKER AND SPACER PIPE @ 13,062' RKB, TEST LOWER PACKER ** FAIL **. PULLED LOWER PIIP PACKER @ 13,087' RKB. JOB IN PROGRESS. 9/24/2022 ACQUIRE DATA SET 3.81'' XN CAT SV IN NIPPLE SD @ 15,514' SLM, LRS ON LOCAION TO PERFORM CMIT. JOB IN PROGRRESS. 10/10/2022 ACQUIRE DATA (AC EVAL) ESTABLISH LLR T X IA OF 0.28 BPM @ 2830 PSI 10/11/2022 ACQUIRE DATA LOG LEAK DETECTION WITH LRS PUMPING DOWN THE TBG TAKING RETURNS TO THE FLOWLINE AT THE MIN PUMP RATE TO HOLD TUBING PRESSURE 3000 PSI AND IA AT 1000 PSI FROM JUST ABOVE XN CAT AT 15,476' TO SURFACE. ANOMALIES NOTED AT 13,080' AND 13,830'. JOB COMPLETE 11/4/2022 ACQUIRE DATA PULLED 4.5" CSV FROM 15,476' RKB. IN PROGRESS. 11/6/2022 ACQUIRE DATA BRUSH N FLUSH AREAS BETWEEN 13,050' ~ 13,100' RKB & 13,800' ~ 13,875' RKB; DRIFT TBG W/ DUMMY PACKER/PATCH TO 13,900' RKB. READY FOR E- LINE. 11/8/2022 ACQUIRE DATA SLB INSTALLED LOWER 4.5" PIIP PATCH PACKER IN 4.5" TUBING @ 13845'. READY FOR SLICKLINE. 11/9/2022 ACQUIRE DATA SET TTS TEST TOOL IN 4.5" PIIP @ 13845' RKB. LRS CMIT-TxIA TO 3000 PSI ***PASSED***. SET UPPER PIIP & SPACER PIPE @ 13815' RKB (ME). LDFN. IN PROGRESS 11/10/2022 ACQUIRE DATA SET 4-1/2" LOWER PATCH PIIP ANCHOR @ 13090' RKB. ATTEMPT TO SET TTS TEST TOOL & CMIT-TxIA. LDFN. IN PROGRESS. 11/11/2022 ACQUIRE DATA ATTEMPT TO TEST PIIP ANCHOR @ 13090' RKB. PULL 4-1/2" PIIP FROM 13090' RKB BUT HANG UP IN SVLN @ 2321' RKB & LEFT PACKER IN NIPPLE. LDFN. IN PROGRESS. 11/12/2022 ACQUIRE DATA PULLED 4-1/2" PIIP PACKER FROM 2321' RKB. SET 4-1/2" PIIP ANCHOR @ 13567' RKB (ME). CMIT-TxIA TO 3000 PSI ***PASSED***. RDMO. IN PROGRESS. 11/14/2022 ACQUIRE DATA SET UPPER PIIP & SPACER PIPE @ 13544' RKB' (ME). PERFORM 2000 PSI PT OF T/IA W/ HOLE FINDER ELEMENT ON PATCH @ 13540' RKB - HOLDING. PERFROM 2000 PSI PT OF T/IA W/ HOLE FINDER @ 13090' RKB - HOLDING. LDFN. IN PROGRESS 11/15/2022 ACQUIRE DATA SET 4-1/2" PIIP ANCHOR @ 13090' RKB. SET UPPER PATCH PIIP W/ SPACER PIPE @ 13056' RKB. LRS PERFORM MIT-IA TO 3000 PSI ****PASSED****. ATTEMPT TO SET 4-1/2" A-1 INJECTION VALVE @ 2321' RKB. LDFN. IN PROGRESS. 11/16/2022 ACQUIRE DATA BRUSH SVLN @ 2312' RKB WHILE LRS PUMP HOT CRUDE. SET 4-1/2" A-1 INJECTION VALVE ON 3.812" DB6 IN SVLN @ 2321' RKB. GOOD DDT. JOB COMPLETE. CRU CD2-02 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:16,009.0 CD2-02 12/12/2005 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added leaks and patches CD2-02 12/6/2022 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: Slickline acheived passing MIT-T 8' above patch with D&D HF @13,055' 8/31/2022 oberr NOTE: TREE: FMC 4-1/16" 5K - TREE CAP CONNECTION: 7" OTIS 8/2/2005 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By TREE: FMC 4-1/16"" 5K TREE CAP CONNECTION: 7"" OTIS 8/2/2005 Admin Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 37.0 114.0 114.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 36.9 3,856.3 2,380.9 36.00 J-55 BTC PRODUCTION 7 6.28 34.7 16,048.6 7,259.8 26.00 L-80 BTCM OPEN HOLE 6 1/8 16,048.0 21,178.0 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.8 Set Depth 15,488.4 Set Depth 7,134.5 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.8 32.8 0.20 HANGER 10.800 FMC TUBING HANGER 4.500 2,321.7 1,756.3 65.35 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 15,301.4 7,060.9 66.47 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 15,414.9 7,105.7 66.72 PACKER 5.970 BAKER PREMIER PACKER BAKER PREMIE R 3.875 15,476.1 7,129.8 67.39 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 15,487.1 7,134.0 67.66 WLEG 5.000 WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,321.7 1,756.2 65.35 INJ VALVE 4.5" A-1 Injection Valve on 3.812" DB Lock 11/16/2022 1.250 13,055.0 6,137.4 65.84 PACKER - PATCH - UPR 4.5" Paragon II Packer, ME= 13055' MD 11/15/2022 2.000 13,059.0 6,139.0 65.79 SPACER PIPE Spacer Pipe w/ 2.875" OD beveled Coupling 11/15/2022 1.995 13,073.0 6,144.8 65.68 LEAK - TUBING LDL Located Leak in tubing at 13,073' MD 7/12/2022 3.960 13,090.0 6,151.8 65.63 PACKER - PATCH - LWR 4.5" Paragon II Packer, ME= 13,090' MD 11/15/2022 2.000 13,544.0 6,341.1 66.72 PACKER - PATCH - UPR 4.5" Paragon II Packer, ME= 13544' MD 11/14/2022 2.000 13,548.0 6,342.7 66.74 SPACER PIPE Spacer Pipe w/ 2.875" OD beveled Coupling 11/14/2022 1.995 13,555.6 6,345.7 66.78 LEAK LDL Located Leak in tubing at 13,555.6' MD 10/11/2022 0.000 13,567.0 6,350.2 66.83 PACKER - PATCH - LWR 4.5" Paragon II Packer, ME= 13567' MD 11/12/2022 2.000 13,815.0 6,448.8 64.82 PACKER - PATCH - UPR 4.5" Paragon II Packer, ME= 13815' MD 11/9/2022 2.000 13,819.0 6,450.5 64.73 SPACER PIPE Spacer Pipe w/ 2.875" OD beveled Coupling 11/9/2022 1.995 13,820.7 6,451.2 64.70 LEAK - TUBING LDL Located Leak in tubing at 13,820.7' MD 10/11/2022 3.960 13,845.0 6,461.6 64.62 PACKER - PATCH - LWR 4.5" Paragon II Packer, ME= 13845.0' 11/8/2022 2.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 15,301.4 7,060.9 66.47 1 GAS LIFT DMY BK 1 0.0 6/23/2018 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 16,048.0 7,259.8 89.75 OPEN HOLE 6.125 CD2-02, 12/12/2022 9:16:15 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 FLOAT SHOE; 16,046.5- 16,048.6 FLOAT COLLAR; 15,961.9- 15,963.1 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 PACKER - PATCH - LWR; 13,845.0 SPACER PIPE; 13,819.0 LEAK - TUBING; 13,820.7 PACKER - PATCH - UPR; 13,815.0 PACKER - PATCH - LWR; 13,567.0 SPACER PIPE; 13,548.0 LEAK; 13,555.6 PACKER - PATCH - UPR; 13,544.0 PACKER - PATCH - LWR; 13,090.0 SPACER PIPE; 13,059.0 LEAK - TUBING; 13,073.0 PACKER - PATCH - UPR; 13,055.0 SURFACE; 36.9-3,856.3 FLOAT SHOE; 3,854.1-3,856.3 FLOAT COLLAR; 3,771.8- 3,773.3 INJ VALVE; 2,321.7 NIPPLE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 36.9-39.1 HANGER; 34.7-37.0 HANGER; 32.8 WNS INJ KB-Grd (ft) 43.81 RR Date 8/22/2005 Other Elev CD2-02 ... TD Act Btm (ftKB) 21,178.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032051300 Wellbore Status INJ Max Angle & MD Incl (°) 95.76 MD (ftKB) 21,129.76 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP CD2-02, 12/12/2022 9:16:17 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 FLOAT SHOE; 16,046.5- 16,048.6 FLOAT COLLAR; 15,961.9- 15,963.1 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 PACKER - PATCH - LWR; 13,845.0 SPACER PIPE; 13,819.0 LEAK - TUBING; 13,820.7 PACKER - PATCH - UPR; 13,815.0 PACKER - PATCH - LWR; 13,567.0 SPACER PIPE; 13,548.0 LEAK; 13,555.6 PACKER - PATCH - UPR; 13,544.0 PACKER - PATCH - LWR; 13,090.0 SPACER PIPE; 13,059.0 LEAK - TUBING; 13,073.0 PACKER - PATCH - UPR; 13,055.0 SURFACE; 36.9-3,856.3 FLOAT SHOE; 3,854.1-3,856.3 FLOAT COLLAR; 3,771.8- 3,773.3 INJ VALVE; 2,321.7 NIPPLE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 36.9-39.1 HANGER; 34.7-37.0 HANGER; 32.8 WNS INJ CD2-02 ... WELLNAME WELLBORE Comment 3.81" A-1 INJ VLV (S/N: HSS-1 Originated: Delivered to:8-Sep-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 CD1-33 50-103-20357-00 908071484 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 26-Aug-22 0 12 CD1-35 50-103-20297-00 908071486 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 28-Aug-22 0 13 CD1-41 50-103-20328-00 908072045 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 29-Aug-22 0 14 CD2-02 50-103-20513-00 907988867 Colville River Multi Finger Caliper Field & Processed 12-Jul-22 0 15PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:CD1-33 PTD:200-212 T36990CD1-35 PTD:199-038 T36991CD1-41 PTD:200-017 T36992CD2-02 PTD:205-109 T369934CD2-0250-103-20513-00907988867Colville RiverMulti Finger CaliperField & Processed12-Jul-2201Kayla JunkeDigitally signed by Kayla Junke Date: 2022.09.09 09:43:03 -08'00' ! 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-02 (PTD# 205-109) Failed IA Date:Tuesday, June 14, 2022 11:10:34 AM Attachments:CD2-02.pdf CD2-02 90-day TIO.pdf From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, June 13, 2022 9:21 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD2-02 (PTD# 205-109) Failed IA Chris— Alpine injection well CRU CD2-02 (PTD# 205-109) failed a diagnostic MITIA over the weekend. This injector operates under AIO 18D.003 restricting it to water-only injection due to TxIA while on gas injection. The well was shut-in for reservoir management at the time of the MITIA failure. It will remain shut-in awaiting diagnostics and a path forward. We will submit appropriate paperwork if a repair plan can be identified. A well schematic and 90-day TIO plot are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 15 Well Name:CCD2-02 Start Date:15-Mar-2022 13 Days:90 End Date:13-Jun-2022 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 15-Mar-2218-Mar-2221-Mar-2224-Mar-2227-Mar-2230-Mar-222-Apr-225-Apr-228-Apr-2211-Apr-2214-Apr-2217-Apr-2220-Apr-2223-Apr-2226-Apr-2229-Apr-222-May-225-May-228-May-2211-May-2214-May-2217-May-2220-May-2223-May-2226-May-2229-May-221-Jun-224-Jun-227-Jun-2210-Jun-2213-Jun-22Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 15-Mar-2218-Mar-2221-Mar-2224-Mar-2227-Mar-2230-Mar-222-Apr-225-Apr-228-Apr-2211-Apr-2214-Apr-2217-Apr-2220-Apr-2223-Apr-2226-Apr-2229-Apr-222-May-225-May-228-May-2211-May-2214-May-2217-May-2220-May-2223-May-2226-May-2229-May-221-Jun-224-Jun-227-Jun-2210-Jun-22Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: 16,009.0 12/12/2005 CD2-02 WV5.3 Conversion Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: SBHP for Surveillance, Set A-1 11/21/2021 CD2-02 praffer Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.9 Set Depth (ftKB) 3,856.3 Set Depth (TVD)… 2,380.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 16,048.6 Set Depth (TVD)… 7,259.8 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 6 1/8 ID (in)Top (ftKB) 16,048.0 Set Depth (ftKB) 21,178.0 Set Depth (TVD)…Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.8 Set Depth (ft… 15,488.4 Set Depth (TVD) (… 7,134.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Nominal ID (in) OD Nominal (in)Make Model Com 32.832.80.20 HANGER 4.500 10.800 FMC TUBING HANGER 2,321.7 1,756.365.35 NIPPLE 3.812 5.620 CAMCO DB NIPPLE 15,301.4 7,060.966.47 GAS LIFT 3.938 5.984 CAMCO KBG-2CAMCO KBG-2 15,414.9 7,105.7 66.72 PACKER 3.875 5.970 BAKER PREMIE R BAKER PREMIER PACKER 15,476.1 7,129.8 67.39 NIPPLE 3.725 5.000 HES XN HES XN NIPPLE 15,487.1 7,134.0 67.66 WLEG 3.875 5.000 WIRELINE GUIDE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,321.7 1,756.265.35INJ VALVE 4.5" A-1 INJ VLV ON 3.812" DB LOCK.11/21/2021 1.000 HWS-209 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Ty pe Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 15,301.4 7,060.9 66.47 1 GAS LIFT DMY BK 0.000 0.06/23/2018 Notes: General & Safety End Date Annotation 8/24/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 8/2/2005 NOTE: TREE: FMC 4-1/16" 5K - TREE CAP CONNECTION: 7" OTIS CD2-02, 11/24/2021 9:53:06 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 SURFACE; 36.9-3,856.3 NIPPLE; 2,321.7 INJ VALVE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 32.8 WNS INJ KB-Grd (ft) 43.81 Rig Release Date 8/22/2005 CD2-02 ... TD Act Btm (ftKB) 21,178.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032051300 Wellbore Status INJ Max Angle & MD Incl (°) 95.76 MD (ftKB) 21,129.76 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP CD2-02, 11/24/2021 9:53:08 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 SURFACE; 36.9-3,856.3 NIPPLE; 2,321.7 INJ VALVE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 32.8 WNS INJ CD2-02 ... WELLNAME WELLBORE Comment 3.81" A-1 INJ VLV (S/N: HRS-3… CD2-02, 11/24/2021 9:53:10 AM Vertical schematic (actual) OPEN HOLE; 16,048.0-21,178.0 PRODUCTION; 34.7-16,048.6 WLEG; 15,487.1 NIPPLE; 15,476.1 PACKER; 15,414.9 GAS LIFT; 15,301.4 SURFACE; 36.9-3,856.3 NIPPLE; 2,321.7 INJ VALVE; 2,321.7 CONDUCTOR; 37.0-114.0 HANGER; 32.8 WNS INJ CD2-02 ... WELLNAME WELLBORE Comment 3.81" A-1 INJ VLV (S/N: HSS-1… III If 177 U\ ` 1] il►� i TO: Jim Regg P.I. Supervisor l FROM: Lou Laubenstein Petroleum Inspector 7+23*2,o NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 10, 2020 SUBJECT: Mechanical Integrity Tests Conowthillips Alaska, Inc. CD2 -02 COLVILLE RIV UNIT CD2 -02 Src: Inspector Reviewed By: P.I. Supry J Comm Well Name COLVILLE RIV UNIT CD2 -02 API Well Number 50-103-20513-00,00 Inspector Name: Lou Laubenstein Permit Number: 205-109-0 Inspection Date: 623/2020 ✓ Irtsp Num: mid,OL200708111231 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well CD2 -02 Type Inj W'TVD nos 'Tubing 2350 2350- 2350 ' 2350 ' PTD zosloso Type Test sPT Test psi 3000 IA 88SO 3310. 3275 ' 3260 BBL Pumped: 3.8 - BBL Re#edj:�� OA 65 680 ' 680 680 ' Interval REQVAR Notes: MIT -IA to maximum anticipated injection pressure per AIO 18D.003 Friday, July 10, 2020 Page 1 of I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 MEMORANDUM • TO: Jim Regg P.I. Supervisor ~~~ ~`~~1~ FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, August 02, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-02 COLVILLE RIV UNIT CD2-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~',i~ Comm Well Name: COLVILLE RIV UNIT CD2-02 Insp Num: mitJJ100802072731 Rel Insp Num: API Well Number: 50-103-20513-00-00 Permit Number: 205-109-0 Inspector Name: Jeff Jones Inspection Date: 6/12/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cD2-o2 ' Type Inj. ~'~' TVD 71os - IA j 97s 3000 , i 2920 z91o - P.T.Di 2oslo9o " TypeTest ; sPT Test psi 1776 ~ QA 400 400 400 400 Interval avRTST p~F P ~ Tubing 2140 2lao zlao zlao Notes: 3.5 BBLS diesel pumped; no exceptions noted. _ Monday, August 02, 2010 Page 1 of 1 • • CD2-02 Details dos-coq s~~~,~~ ~~~4P~~-~~ ~~~~~ MAY Q 2 2008 • • ConoCOF~hillips using Detail 9 5/8" Surface Casing Well: CD2-02 Date: 8/2!2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.90 FMC Gen V Hanger 223 36.90 Jts 3 to 91 89 Jts 9-5/8" 36# J-55 BTC Csg 3732.63 39.13 Weatherford Float Collar 1..50 3771.76 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 80.82 3773.26 Ray Oil Tools "Silver Bullet" Float Shoe 2.26 3854.08 3856.34 TD 12 1/4" Surface Hole 3866.34 TOTAL BOWSPRING CENTRALIZERS - 50 1 per jt on Jt #1 - #12 (stop ring on Jt #1 & 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68,70,72,74,76,78,80,82,84,86,88 95 joints in the pipe shed. Run 91 joints - 4 joints stay out Use Best-o-Life 2000 pipe dope MU torgue -- 8100 ftllbs Remarks: Up Wt - 155 k Dn Wt - 105 k Block Wt - 75k Supervisor. Burley/Mickey _ r~ ; ~ ~`~' ~ Cement Detail Report .. 4 ~ -~- = , , r ~ _'~` ~ ;_ CD2-02 ,. _ ...• Surface Casing -- - - - Cement Details Description Cementing Start Date Gementing End Date - Wellbore Name Surface Casing 8/2/2005 20:40 8/2/2005 21:15 CD2-02P61 Comment PJSM on cementing csg. Test lines to 2700 psi. Pumped 40 bbls bizan/nut plug spacer and drop bottom plug. Pump 50 bbls 10.5 mud push, 519 bbls 10.7 lead cement and 50 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H2O. Rig displaced with 272 bbls 9.6 mud. Bumped plug. Check floats. OK. Lost returns after 90 Bbls displaced. Had partial to no returns throughout job. Worked hanger and flushed stack with black water to regain returns with limited success. Cement was standing at the lower casing valve. When we laid down riser cement was at the hanger. No top job was required. CIP C~ 2115 Hrs. 8/2/05. - -- --- -~ Cement Staqes -- - Sta e # 1 _ - - -- '- - Description Objective Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Cement Casing 36.9 3,856.0 1.0 Yes Yes Q (start) (bbl/min) O (end) (bbUmin) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 5 770.0 1,250.0 0.00 Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Found Between Shoe and Collar (Y/N): N Cement found on liner tool (Y/N): N Annular flow after cement job (Y/N): N Circulating BHT (F): 84 Pressure before cementing (psi): 270 Hours circulated between stages: 3 Bbls cmt to surf: 1 Method used to measure density: Densometer Method used for mixing cement in this stage: Tub Returns (pct): 25 Time cementing mixing started: 20:40 Cement Fluids 8 Additives - -- - -- - - Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) FLUSH Biozan water 0 40.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 8.30 0.00 0.0 Additives Type Concentration Conc Unit label Additive 'Fluid..- - -- - Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) -- --- Class - Volume Pumped (bbl) Spacer MUDPUSH XL 0 50.0 Yield (ft'/sack) Mix H2O Ratio (gaVsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 10.50 0.00 0.0 Additives Type Concentration Conc Unit label Additive Fluid - Fluid Type Fluid Description Estimated Top (tiKB) Est Btm (ftK6) Amount (sacks) -- -- Class Volume Pumped (bbl) LEAD ASLite 36.9 3,356.0 655 G 519.0 Yield (fP/sack) Mix H2O Ratio (gaUsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) ~ ~ ~ 20.77 0.00 10.70 0.00 0.0 Additives Type Concentration Conc Unit label Additive D-44 ACCELERATOR 9.0 %BWOW Additive Type Concentration Conc Unit label g1 ACCELERATOR 1.5 Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.6 Page 1/2 Report Printed: 4/21!2008 • • ~~. ~, ` Cement Detail Report ,- _~_'' CD2-02 Surface Casing Additives Additive Type Concentration Conc Unit label D$5 DISPERSANT 0.5 Additive Type Concentration Conc Unit label D-79 EXTENDER 1.5 Additive Type Concentration Conc Unit label D-124 FILLITE 43.0 Additive Type Concentration Conc Unit label D-53 GYPSUM 30.0 _ _ iCement Fluids & Additives "Fluid - Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftKB) 'Amount (sacks) Class Volume Pumped (bbl) TAIL 3,356.0 3,856.0 240 G 50.0 Yield (ft%sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 0.00 15.80 0.00 0.0 Additives Additive Type Concentration Conc Unit label S1 ACCELERATOR 2.0 % Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.2 % Additive Type Concentration Conc Unit label D-65 DISPERSANT 0.3 % Page 2!2 Report Printed: 4/21/2008 • • Security Level: Development ~~ Daily Drilling Report ,-^ ~~~; CD2-02 Report Number: 4 ... Report Date: 8/2!2005 Rig: DOYON 19 _ - - AFE Type. Network/ID#. __ TotaI.AFE+Sup.. _ _ . 10088238 5,654,886.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK6) Depth End (ftKB) CD2-02P61 Development ALPINE 4.00 4.0 0.00 3,866.0 3,866.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 361,119.00 856,805.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/30/2005 7/30/2005 Last Casing String Next Casi ng OD (in) Neut Casing Set Depth (itK6) Conductor, 114.OffK6 Ops and Depth @ Morning Report 24hr Forecast Testing BOP. Test BOP. PU DP & BHA. RIH. last 24hr Summary PJSM -Ran 91 joints of 9 518"" csg, landed with FS @ 3856' - Cond mud for cementing -Cement casing -test casing to 2500 psi, 30 min. -Rigged down cement and casing tools. General Remarks Weather Head Count ... 47.0 - Supervisor ~_ - --- -`- - -----_ -- - -- Vern Johnson, Engineer i Engineer D. Burley / L. Hill, Supervisor Supervisor _ __ Time Lo - --- ~ Starr End Dur Time Depth Start t Depth End Time Time (hrs) Phase Op Code I OpSub-Code P-N-T Trbl Code 7rb1 Class. (flKB):: ~ (1IKB1 : Operallon 00:00 00:30 0.50 SURFAC CASE SFTY P 0.0 0.0 Pre-Job safety and Opts meeting on running 9 5/8"" casing 00:30 04:00 3.50 SURFAC CASE RUNC P 0.0 1,020.0 Run 9 5/8"" 36# J-55 BTC casing as follows: FS (silver bullet) 2jts.FC - 2 jts.( fill pipe & checked floats -first 4 connections made up w/ BakerLoc) 21 jts -tight spot at 1020' (25 jts. total) Fill pipe every 5 joints 04:00 05:45 1.75 SURFAC CASE RUNC Np DH 1,020.0 1,084.0 RU circ swedge and wash down from 1020' to 1084' 2.6 bpm / 140 psi 05:45 07:30 1.75 SURFAC CASE RUNC P 1,084.0 1,630.0 Run casing from 1084' to 1630' -lost 15K SOW last 2 joints 39 joints total 07:30 08:15 0.75 SURFAC CASE CIRC Np DH 1,630.0 1,630.0 RU circ swedge -stage pumps up to 6 bpm -CBU -FCP 520 psi PUW 123K SOW 90K 08:15 10:00 1.75 SURFAC CASE RUNC P 1,630.0 2,550.0 Run casing from 1630' to 2550' -return dropping off - 61 joints total 10:00 10:45 75 0 SURFAC CASE CIRC Np DH 2,550.0 2,550.0 Fill pipe - MU circ swedge -stage pumps . up to 6 bpm -CBU -FCP 520 psi PUW 125 K SOW 95K 10:45 11:45 1.00 SURFAC CASE RUNC P 2,550.0 3,180.0 Run casing from 2550' to 3180' 76 jts total -return % dropping off 11:45 12:30 0.75 SURFAC CASE CIRC Np DH 3,180.0 3,180.0 Fill pipe - MU circ swedge -stage pumps up to 4 bpm / 420 psi- total pumped 95 bbls, lost 15 bbis of mud. 12:30 14:15 1.75 SURFAC CASE RUNC P 3,180.0 3,856.0 Run 9 5/8"" casing from 3180' to 3801' total of 91 jts.) -MU FMC mandrel hanger and landed casing with FS @ 3856', FC @ 3772'. 14:15 14:45 0.50 SURFAC CEMENT RURD P 3,856.0 3,856.0 Fill pipe - MU Dowell cement head 14:45 17:45 3.00 SURFAC CEMENT CIRC P 3,856.0 3,856.0 Stage pumps up slowly -initial 1.6 bpm / 390 psi -circ and condition mud -final rate 6.5 BPM 270 PSI. Latest BOP lest Data -- Date ---~_ .; ':Comment Page 1/3 Report Printed: 4/21/2008 • • Security Level: Development ~ • `~`~' °~~' •~' Dail Drilling Report £ . =~ t-rror- _ y i ~ ~ "~~= x ~~~ 5 ~ CD2-02 .i . ~. Report Number: 4 . ... Report Date: 8/2/2005 Rig: ( DOYON 19 _ _ ) _ -l Time Lo Start End Our - Time T ~ pN- Depth Start ~ Depth End _ (ftK8) : I {ftK8) OperaLon Glass d ~ bl C Lme~Time (hrs) phase ? Dp Coder OpSub-Code _ . 1. r o e 856.0 PJSM on cementing csg. 0 3 856 3 17:45 21:15 3.50 SURFAC CEMENT PUMP P , . , Test lines to 2700 psi. Pumped 40 bbls bizan/nut plug spacer and drop bottom plug. Pump 50 bbls 10.5 mud push, 519 bbls 10.7 lead cement and 50 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H2O. Rig displaced with 272 bbls 9.6 mud. Bumped plug. Check floats. OK. Lost returns after 90 Bbls displaced. Had partial to no returns throughout job. Worked hanger and flushed stack with black water to regain returns with limited success. Cement was standing at the lower casing valve. When we laid down riser cement was at the hanger. No top job was required. Total mud lost 260 Bbls. CIP 2115 Hrs. 8/2/05. 75 SURFAC 21:15 22:00 0 CASE MIT P 3,856.0 0.0 Rigged up and tested casing to 2500 PSI . for 30 Min. 00 SURFAC 22:00 00:00 2 CASE RURD P 0.0 0.0 Laid down Cement head, Landing joint . and bails. Mud Check Data -- -------T -( _ YP Calc Gel (90s) Gel (lDm) Gel {30m) ~ HTHP Flt Density Temp' Solids Corr. Type ~ Depth (ftK8) ~ Dens {Iblgal} Vis (s/qt) ~, PV Calc(cp) (Ibtll ODft~ (Ibfl'IOOft~ (IbfllODft'~ (Ibfliibft) MBT (Iblbbl) } (mLf30mfi) pH :: ' (~~ (~) Spud Mud 2,384.0 9.60 67 29.0 24.000 13.0 7.0 18.007 9.0 4.9 Spud Mud 2,384.0 9.60 300 46.0 82.000 89.0 86.0 91.038 9.0 5.0 Wellbore APIlUWI Wellbore Name 501032051370 i --- Section CD2-02PB1 .---~-- Size (in) Aci Top (flK6) - _ - --.Start Date r. End Date ~ Act Bim (ftK8) ~ ~ ' -- - - ~ ' Cement _ - -- _ Surface Casin -Started 8/2/2005 Cement Evaluation Results Type Wellbore Cemented String Bond log run (Y!N): N casing CD2-02PB1 Hours between completion of cementing and logging: 2 Remedial cement required (Y!N): N Pressure used to test shoe (psi): 17.3 Test pressure (psi): 2500 Test time (hrs): 30 Top of cement sufficient (Y!N): Y Stg No. Description Top {ftK8) Bottom (ftK8) Q (end) (bbl/... P (finaQ (psi) 770 0 1 Cement Casing _ ' Fluid FLUSH f > = Class :_ Amount (sacks} ~ 0 . 36.9 3,856.0 4 ~--~-- :Est Btm (RKB) V (bbI)~ Density.(Ib/gai) Yield (fNJSack} _ Est Top (ftKBj _ __ 40.0 8.30 0.00 r S 0 50.0 10.50 0.00. pace 655 70 4.45 36.9 3,356.0 0 10 519 LEAD G G 240 . . 3,356.0 3,856.0, 50.0 15.80 1.17 TAIL - - _ . Tubin Stnn s_ ~__.-~ g_ __ - - __ -. TIjBING set at 15,488.OftK6 on 8/2/2005 00:00 OD (in) Weight/Length (Ibsfft) String Grade Set Depth (ftK8) Tubing Description TUBING 4 112 12.60 L-80 15,488.0 Page 213 Report Printed: 4/21/2008 • • Security Level: Development ~ 6+-s 7.~... -- Daily Drilling Report k r~~- f , Report Number: 4 • i • ~ Report Date: 8/2/2005 Rig: DOYON 19 ~ her In_Hole - Description T OD (ink ~- ~ ID (in) _ _ ' ~ _T -_, Top (ftK8) - _...~ Btm (ftK6) HANGER 7 4.500 33.0 34.0 NIP 5.62 3.812 2,321.0 2,322.0 PACKER 5.97 3.875 15,414.0 15,415.0 WLEG 5 3.875 15,488.0 15,489.0 5 725 3 15,476.0 15,477.0 NIP . Page 313 Report Printed: 4/21/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-02 Rig: Doyon 19 Date: 8/2/2005 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Burley /Hill Pump used: #z Mud Pump ~ Strokes ~ 0.1005 Bbls/strk ~ 8•U strk/min ~ Type of Test: Casing Shoe Test LOT/FIT ~ Pumping down annulus and ~P. ~ Casin g Test ressure In tegri Test Hole Size: B-i/z" ~ RKB-CHF: 36.9 Ft Casing Shoe Depth 3,856 Ft-MD 2,381 Ft-TVD Hole Depth 3,886 Ft-MD .2,393 Ft-TVD Pum Strks ping si Shu Min t-in si Pumping Strks psi Shut-in Min psi Casing Size and Description: 9-s/B" 36#/Ft J-55 BTC ~ 0 0 0 2590 0 0 0 1000 Casin Test 6 ht: 9 Mud Wei ppg Pressure Int Mud Weight: e ri Tes 9.5 1 ppg 2 4 90 150 1 2 2590 2590 1 2 70 140 0.25 0.5 900 850 g l: i G d 10 M . 80 0 Lb/100 Ft2 Mud 10 min Gel: 60.0 Lb/100 Ft2 6 _300 3 2590 3 220 1 ' 800 m n e u t Pressure: T . 2 500 psi Rotating Weight: 130,000 Lbs 8 475 4 2585 4 300 1.5 775 es Wei ht: tin R t , 74 000 Lbs Blocks/Top Drive Weight: 74,000 Lbs 10 675 5 2585 5 380 2 765 g g o a Wei ht: D i k /T Bl , 000 74 Lbs Desired PIT EMW: 18.0 ppg 12 875 6 2585 6 470 2.5 755 , ve g r s op oc Estimates for Test: 2.8 bbls Estimates for Test: 1052 psi 1.1 bbls 14 1000 7 2580 7 570 3 745 ~ . 16 1150. 8 2580 8 650 3.5 735 EM = eak-o ressure + ud eight = 820 PIT 15 Second 18 .1300- 9 25.80 9 740 4 725 + 9 052 x TVD 0.052 x 2381 0 Shut-in Pressure, psi 20 1425 10 ' 2580 10 820 4.5 715' ,~ . EMW at 3856 Ft-MD (2381 Ft-TVD) = 16.1 900 22 1600. 15 2575 11 870 5 `705 si Lost 20 durin g test held 24 1725 20 .2575 12 920 5.5 705 3000 p , 695 99.2% of te st pre ssure. 26 1900. 25 2570 13 960 6 28 2050 30 2570 14 980 6.5 695 ~ ,~,~y.~,~~~~~,~ ~~ ~, ~ 5 1000 7 690 zsoo 30 2175 1 32 2350 7 5 690 . 34 2530 8 685 zooo 8.5 685 w ~ 9 685 ~ 5 9 685 . N lsoo 10 685 w o: a 1000 500 0 so o , z Barrels 3 a s o s , Shut-I o , n tim s z e, M o z inut s es Vol Pum ume ed Vol Bled ume Back Vo Pu lume m ed Vo Bled lume Back ~~CASI NG TEST - ~-•LEAK-OFF TEST O P IT Po int s s s s Comments: Casing tested after bumping plug on surface cmt job __ • • ConocoPh~~~sp$ Casing Detail 7 Casing DRAFT Well: CD2-02 Date: 8/9/2000 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.72 FMC Gen V Hanger 2.31 34.72 Jts 3 to 377 375 Jts 7" 26# L-80 BTCM Csg 15924.86 37.03 Weatherford Float Collar 1.26 15961.89 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 83.34 15963.15 Ray Oil Tools "Silver Bullet" Float Shoe 2.08 16046.49 16048.57 TD 8 3J4" Hole 16063.00 8-3/4" Hole TD @ 16,063' MD /' TVD 7260' 7" Shoe @ 16,048.57' MD I' TVD 7260' Total Centralizers: 60 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 288,289,290 Straight blade cent. one every other joint #'s 292 - 376 Tap Alpine C -15,920' MD - 7252 ' TVD 390 joints in shed - 377 total jts. to run Last 13 jts. Out Use Run & Seal i e dope Average make up torque 8000 ftJlbs Remarks: Up Wt - 400. k DnVVt-150k .Block Wt - 75k' Supervisor. D. Burley/L. Hill • • ~`` " Cement Detail Report ~'"' Y ~' _~~' CD2-02 <; .... I' Intermediate Casing/Liner --- --- -~ - l -- - _ - -- Cement Details _ __ _ _ Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing/Liner 8/10/2005 21:08 8/10/2005 23:00 CD2-02P61 Comment Cement 7" csg as follows: Pumped 5 bbls CW-100 -tested lines to 3700 psi -pumped 45 bbls CW-100 @ 4.3 bbls/min @ 400 psi -Pumped 40 bbls MudPush 5 bbls/min @ 470 psi -Dropped btm plug - Mixed & pumped 33 bbls tail slurry @ 15.8 ppg - 4.5 bbls/min @ 400 psi -dropped top plug w/ 20 5 ppg - 4 II @ 10 . . bbls water f/ Dowell Displaced with 591.4 Bbls mud from rig pump @ 6 BPM. Increased to 7 BPM when cement went through shoe. Reduced to 4 BPM and bumped plug. CIP @ 2300 Hrs. Floats held. Good returns. --- - - - - - ICementStages '' - - --, --- -- ~~ - - ` - - - e # Stag 1 - -- - - --- Descnptton Objective Top (ftKB) - Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Cement Casing 12,867.0 16,049.0 0.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 550.0 1,100.0 0.00 Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Found Between Shoe and Collar (Y/N): Y Cement found on liner tool (Y/N): N Annular flow after cement job (Y/N): N Pressure before cementing (psi): 710 Hours circulated between stages: 3 Bbls cmt to surf: 0 Method used to measure density: Densometer Method used for mixing cement in this stage: Tub Returns (pct): 100 Time cementing mixing started: 21:08 - --- - - _- - Cement Fluids 8 Additives ___ Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) _ _ _- Amount (sacks) _.-- Class Volume Pumped {bbl) FLUSH CW100 12,867.0 14,201.0 0 50.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 8.30 0.00 0.0 Additives Type Concentration Conc Unit label Additive .- - - - - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) - _ ~ Amount (sacks) - -- Class Volume Pumped (bbl) PRIMARY MUDPUSH XL 14,201.0 15,268.0 0 40.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 10.50 0.00 0.0 Additives Type Concentration Conc Unit label Additive _._ Fluid Fluid Type Fluid Description. E mated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) TAIL 15,268.0 16,049.0 160 G 33.0 Yield (fY/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (IbJgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 0.00 15.80 0.00 0.0 Additives Type Concentration Conc Unit label Additive 0-46 DEFOAMER 0.2 %BWOC Type Concentration Conc Unit label Additive D-65 DISPERSANT 0.3 °!°BWOE Type Concentration Conc Unit label Additive D-167 Fluid loss 0.4 %BWOC Type Concentration Conc Unit label Additive d R t 0.1 %BWOC 6155 ar er e Page 111 Report Printed: 4!2112008 • • Security Level: Development ~, ~' , `- ,. .~ Daily Drilling Report ~. ~. ~_: CD2-02 Report Number: 12 ~. i { Report Date: 8/10/2005 I Rig: DOYON 19 I - - T ~AEE+sup __-- ~~- AEE Type o,a t~ietwortc/ID tt --- - -- 5 _ T_ - 886 00 694 - 10088238 , . , Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-02PB1 Development ALPINE 12.00 12.0 0.00 16,063.0 16,063.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 503,439.00 2,774,416.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/30!2005 7/30/2005 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Production, 16,048.OftK6 Ops and Depth @ Morning Report "" 24hr Forecast LD DP. PU 4" DP and BHA. Test BOP LO DP DP from derrick. Laying down 5 . . Last 24hr Summary Ran and cemented 7"" casing @ 1 6,049'. Tested casing 3500 psi. General Remarks Weather Head Count 48 0 . Temp 57 Wind E @ 9 mph _ - - -- - - - $UpeNISDr T - - „ - vita _ _- --- -._ -. __ Vern Johnson, Engineer IEngtneer D. Lutrick / L Hill, Supervisor Supervisor _ _ _ _ _ :Time Log _ Start End~ Dur e l (hrs) e ~i Ph e T _ _ __ ~ ~ Time , 'Depth Start Depth End SutrCode ~ P-N-? Trbl Code Trbl Class (ftKB) I (ftKB) Operation ; Code I O O m -. im as 00:00 03:00 3.00 iNTRM1 p - p CASE RUNG P 3,828.0 6,776.0 RIH wl7"" 26# L-80 BTCM csg from ' ' to 6776 . 3828 03:00 03:45 0.75 INTRMI CASE CIRC P 6,776.0 6,776.0 Circ and condition mud at 5 bpm at 600 psi. 03:45 06:45 3.00 INTRMI CASE RUNC P 6,776.0 9,751.0 RIH w/ 7"" 2li# L-80 BTCM csg from ' ' . 6776 to 9751 06:45 08:15 1.50 INTRMI CASE CIRC P 9,751.0 9,751.0 Circ and condition mud at 5 bpm at 500 psi. 08:15 12:45 4 50 INTRMI CASE RUNC P 9,751.0 14,014.0 RIH w/ 7"" 26# L-80 BTCM csg from ' . . 9751' to 14,014 12:45 15:00 2.25 INTRM1 CASE CIRC P 14,014.0 14,014.0 CBU. 4.5 BPM 520 psi. 15:00 17:30 2 50 INTRM1 CASE RUNC P 14,014.0 16,049.0 RIH w/ 7"" 26# L-80 BTCM csg from ' . . Landed casing. 14,014' to 16,049 17:30 17:45 0.25 INTRM1 CEMENT RURD P 16,049.0 16,049.0 Made up cement head. 17:45 20:45 3 00 INTRMI CEMENT CIRC P 16,049.0 16,049.0 Circulated and conditioned mud prior to . cementing. Worked pumps up to 6 BPM @ 710 PSI. Unable to work pipe up. PJSM for cementing. 20:45 21:30 0.75 INTRMI CEMENT PUMP P 16,049.0 16,049.0 Cement 7"" csg as follows: Pumped 5 bbls CW-100 -tested lines to 3700 psi - pumped 45 bbls CW-100 @ 4.3 bbls/min @ 400 psi -Pumped 40 bbls MudPush II @ 10.5 ppg - 4.5 bbls/min @ 470 psi - Dropped btm plug - Mixed & pumped 33 bbls tail slurry @ 15.8 ppg - 4.5 bbls/min @ 400 psi -dropped top plug w/ 20 bbls water f/ Dowell 21:30 23:00 1.50 INTRM1 CEMENT DISP P 16,049.0 0.0 Displaced with 591..4 Bbls mud from rig pump @ 6 BPM. Increased to 7 BPM when cement went through shoe. Reduced to 4 BPM and bumped plug. CIP @ 2300 Hrs. Floats held. Good returns. 23:00 00:00 1.00 INTRM1 CASE MIT P 0.0 0.0 Rigged up and tested casing 3500 PSI for 30 min. Latest BOP Test Data -.--- -- - -- Comment - Page 112 Report Printed: 4/21/2008 • • Security Level: Development z; - ~' ~ ~ Daily Drilling Report . t . CD2-02 Report Number: 12 • .. Report Date: 8/10/2005 Rig: bOYON 19 Mud Check Data _ 1 ~ ~ ~- r Type Depth (ftKB) Dens (Iblsal) ! Vas (s/qt) PV Calc (cp) LSND / 7,259.0 10.00 43 8.0 _ YP-Galt -Gel (SOS) ~ Gel (70m) Gelel {30mj ~ HTHP Ftlt~ DensityTemp Solids, Corr. (Ibf/100ft~ i (1bfl10Dft~- (Ibfl100ff~) (Ibf/100ft°) MBT (!b/bbl)tmLl30mi~) pH (°F) ~ (~) -. 22.000 11.0 13.0 14.006 18.7 6.6 8.6 5.4 Glydril ~ I ~ ~ _ - _ Well6ores - Wellbore Name - - _ _ - - --~- Wellbore API/UWI - - - - - , --- --- CD2 02P61 0 50103205137 --- --- - ~ Section _~ Size (in) '. _._ ~ _ ~ Acf Btm ftKB) Act TOp (ftKB) __ ( _ -~ Start Date :End Date -~-_---- -- --- - - -- Cement --- -- -- ~_ - __ - ' -- ' - _ Intermediate Casin !Liner -Started 8/10/2005 Cement Evaluation Results Type Wellbore Cemented String Bond log run (Y/N): N casing CD2-02PB1 Remedial cement required (Y/N): N Pressure used to test shoe (psi): 12.5 Test pressure (psi): 3500 Test time (hrs): 30 Top of cement sufficient (Y/N): Y Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 550 0 1 Cement Casing - Rwd ' Class 12,867.0 ~-mount (sacks) ~ V (bDlj-- : Densify (hbJga_T) . 16 049.0 4 Yetd (fN/s'ack) ~- Est'fop (ftF(~) ~~~Esl Btm (ftKB) - FLUSH 0 50.0 8.30 0.00 12,867.0 14,201.0 PRIMARY 0 40.0 10.50 0.00 14,201.0 15,268.0 TAIL G 160 33.0 15.80 1.16 15,268.0 16,049.0 Page 2/2 Report Printed: 4t21l2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-02 Rig: Doyon 19 Date: 8/11/2005 volume Input Pump Rate: Drilling Supervisor: Lutrick /Hill Pump used: Cement unit ~ Barrels ~ Bbls/strk ~ 0.8 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin g Test Pressure In tegrity Test Hole Size: RKB-CHF: s-i/2" ~ 34.7 Ft Casing Shoe Depth 3,856 Ft-MD 2,381 Ft-TVD Hole Depth 15,268 Ft-MD 7,047 Ft-TVD Pum Bbls ping psi Shu Min t-in psi Pum Bbls ping psi Shut-in Min psi Casing Size and Description : T 9-5/8" 36 #/Ft J-55 BTC Pressure Int e rit Test ~ 0 1 0 0.5 65 92 0 0.25 585 538 Chan es for Annula r Ade u es ac omments i Mud Weight: 10.0 ppg 2 1 °140 0.5 534 outer casing shoe test result: n c strin in Inner casing OD 7.0 In. 3 1.5 184 1 526 Description references oute g g cas in 4 2 219 1.5 517 ize is that drilled below oute g. cas 5 2.5 241 2 .515 timated TOC for Hole Depth. Desired PIT EMW: 14.5 ppg 6 3 261 2.5 ` 508 Enter inner casing OD at righ Estimates for Test: 557 psi 0.8 bbls 7 3.5 292 3 504 ' i ht = d ~ PIT 15 Second 692 ~ 8 9 4 4.5 314 345 3.5 4 503 _-' 501. g e EM =Leak-off Pressure + Mu + 10 052 x 2381 0 Shut-in Pressure, psi 10 > 5 370 4.5 500 . 0.052 x TVD 6 t 3856 Ft-MD (2381 Ft-TVD) = 15 EMW 53$ 15 5.5 385 5 498 . a 20 6 419 5.5 '` 495 iooo 25 6.5 432 6 492 6 5 492 30 7 461 . 7.5 490 7 490 4 8 523 7.5 490 8.5 538 8 490 9 570 8.5 488 8 9 485 ~ 9:5 58 ~ 10 614 9.5 485 ~ soo ~ 10.5 - 639 10 483 W ~ 11 646 a ` 11.5 -''670 12 692 12.5 670 13 627 13.5 . 599 14 601 591 o 14.5 0 2 a e s ,o ,z ,a ,s o s ,o ,s zo zs so Barrels Shut-In time, Minutes Vol Pu ume m ed Vo Bled lume Back Vo Pu lume m ed Vo Bled lume Back ~I~CASING TEST ~^-BLEAK-OFF TEST O PIT Point s s s s Comments: 9 5/8" Surface casin shoe LO = 17.3 ppc CD2-72 • Note to File Apri123, 2008 Page 5 of 5 Injected Fluid vs Affected Radial Distance CD2-72 Wellbore (assumes 20' aggn3gate injection zone thickness and 29% porosity) 300 d 250 w m 0 200 E 0 m ~ 150 O 'v 100 m v m 50 a 5,000 10,000 15,000 20,000 25,000 Amount of Injected Fluid (barrels) 30,000 35,000 Figure 4. Radial Distance Potentially Impacted by CD2-72 Injection Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous layers of shale, claystone, mudstone and minor amounts of siltstone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath CD2-Pad. The open annulus that will be used for disposal injection lies inside the Colville River Unit, well away from. any external property lines, so correlative rights will not be a concern. I re mmend approval of this annular disposal project. 7`. . ~~ ~ ._. Steve Davies Senior Petroleum Geologist ~ ~~. ' ~~/ ~ • Note to File CD2-72 (207-057...308-153) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc ConocoPhitlips has made application for annular disposal for the subject well. This document examines the pertinent information for the wet! and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was commented to surface. No problems were reported. Approximately 148 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 59°!o XS of the calculated hole volume. -- On the initial leak off test, the pressure rises relatively smoothly to 15.9 EMW. 0.8 bbl was pumped after the break at a different slope to a maximum of 16.8 EMW. The pressure declined during the observation period to about 13.6 EMW. Two slopes are not unusual at Alpine. The initial leak off indicates that the surface casing shoe is we{I cemented. ----No problems are reported drilling the intermediate hole, The 7-5/8" casing was run and successfully cemented. Full re#ums were noted and the casing was reciprocated. --An infectivity test down 10-3/4" x 7-5/8" annulus was conducted. Pump in was realized fairly quickly at 11.8 ENINV. The pressure increased some while pumping an additional 5.5 bbl to 12.3 EM1N. During the observation period, the pressure declined to 11.6 EMVN. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of a{I surface casing shoes within%4mile radius of CD2-72. The surface shoe of CD2-18 is ~-400' distant. The shoes of CD2-21 and CD2-31 are about 550' and 650' distant respectively. GPAI has not applied for AD in any of 3 most proximate wells. There are 7 other wells over 900' distant. Examination of the cementing information did not reveal anything #o preclude gran#ing CPAI's request. Based on examination of the submitted infom~a~tion, t recommend approval of GonocoPhillips' request for the subject well. Due to the proximity of GD2-18, CPAI should monitor the outer annulus pressures on this well while pumping on CD2-72. Tom Maunder, PE Sr. Petroleum Engineer April 15, 2008 G:\common\tommaunder\Well Information~By SubjectlAnnu~lar Disposa1~080425--CD2-72.doc • • Note to File CRU CD2-72 (PTD 2070570) Apri123, 2008 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD2-72 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus surrounding the 7" casing within well CD2-72. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-518" surface casing shoe is set in this well at 3,318' measured depth (-2,334' true vertical depth subsea, or "TVDSS"}, near the base of a 470-foot thick shale and claystone interval that persists throughout the area. This interval will provide confinernent to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 100' from the welibore. Discussion CPAI's application was reviewed along with records from nearby wells Nuigsut 1, Alpine 1, Alpine lA, and Alpine 3. The discussion that follows is based on well logs and the mud logs from Nuiqsut 1, Alpine lA, and Alpine 3. An index map is provided in Figure 1, below. Drilling wastes will be disposed in an open annulus that extends downward from the 9-5/8" surface casing shoe, which is set at 3,318' measured depth (-2,334' TVDSS), to the top of cement for the T' casing string, which is estimated to lie at about 15,660' measured depth (-6,910' TVDSS}. This annulus spans the boundaries Section 2 of TI 1N, R4E, UM and Sections 35, 34 and 33 of T12N, R4E, UM (see Figure 1), and it lies more than 8,500' from the current boundary of the CRU. The section of open annulus that will most likely accept the injected waste fluids is a 90-foot thick portion of the Seabee formation that extends from 3,450' to 3,705' measured depth (-2,384' and -2,477' TVDSS; see Figure 2, below). This interval contains several 1- to 3-foot thick beds of siltstone and sandy siltstone that are separated by clay and claystone. The aggregate thickness of the siltstone and sandy siltstone beds is about 20'. The apparent siltstone that lies immediately beneath the 9-5/8" casing shoe of CD2-72 is likely an artifact caused by circulating and cementing. In offset exploratory wells, the correlative C NF~DENT~~L ~~~ ~--~r ~ ~-- ~ ~~ z - ~z CD2-72 • ~ Apri123, 2008 Note to File Page 2 of 5 sediments to those surrounding the 9-5/8" casing shoe consist of shale, claystone, and minor amounts of siltstone (see Figure 3, below). The 9-5/8" surface casing shoe lies near the base of a 470-foot thick interval that is dominated by shale and claystone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely injection interval is a 60-foot thick zone of claystone and mudstone that is also continuous throughout the area. This interval, which lies between 3,845' and 4,018' measured depth (-2,528' and -2,590' TVDSS), will provide lower confinement for injected wastes. ~ ~ c&-a~ ~-F_'r o~ c~a3u '-~'-u, -C~ ~~-~, ~q3„~ ' ~~~, ~ ~~:-,o # Alpine 3 \ A~p~NE 3 29 ' ct'v'~ r_ ~ i 3 \~$ 27 ~ 2~ ' ~ `~5 { '/4 Mile ~ ~~ Buffer ~ c8z-,~ ~° -16 ~ ; `: ~, ~ ~3 _ _ _ \I` c -'=1s; ~\ - ~ J \ ' chi. ~g+- ti s ~~ ~ ~ .,~ ~ -' c r3 ~. 32 ~ ~ 'r'~ 4 '~ c z ~ ~~~~~. r~'3t~-+''~ ''~~ ~ ,, c~-se ~ se ` ~ ~.~ ~ , , ~ ~ ~ Open CD2-72 ~ ~; "~`-'~ ~ ~ ° ~ Annulus -~~ , ~~; ~ ~~ __ Q. '-` + ~~~ ~ '~ -- - \ 5 \ + - ~ ""',~'-'T ' Likely ,~ 4, ~.:, ,:~ Nuigsut 1 ~ ~' - ~ ~ Disposal , ~ ~ ~~~ ~' ~ ~ ~ _ ~~~E , ~-19 `~-~" `~.~ Interval ~~ Alpine lA ,: ~. ~ ~ c~ ~~, Figure 1. Index Map (CRU CD2-72 open annulus highlighted with red; cross-section path highlighted with magenta) In vicinity of Drill Site CD2, the base of permafrost occurs at about -1,200' TVDSS, which is about 1,200' above the top of the proposed injection interval. Conclusion 3 of Area Injection Order 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Alpine lA is the nearest exploratory well to Drill Site CD2. In Alpine lA, methane was first encountered at 760' measured depth (about -700' TVDSS), and it was encountered in significant quantities (more than 1% methane in air, or 50 units) at 1,155' measured depth (about -1,075' TVDSS). So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil shows encountered in Alpine 1 A were two trace shows observed between 2,985' and 3,380' measured depth (from -2,208' to -2,358' TVDSS). However, the descriptions of these shows note a lack of oil staining; the shows were noted based on sample and solvent cut fluorescence. The shallowest record of visible oil staining occurs at about 4,630' measured depth (-2,819' TVDSS), which Upper Confining Strata Most Likely Receptor Strata for Disposed Fluids Lower Confining Strata CD2-72 • ~ Apri123, 2008 Note to File Page 3 of 5 is 350 true vertical feet below the likely receptor beds for the injected material. So, at Drill Site CD2, the likely disposal interval does not contain potentially commercial hydrocarbons. Figure 2. CD2-72 Well Log for Affected Intervals CD2-72 • • Apri123, 2008 Note to File Page 4 of 5 NUIOSUT 1 CRU CD2-72 ALPINE 1A ALPINE 3 ~~ 7 ARCO CONOCOPHILLIPS ALASK ARCO ARCO NE S YV 1980250 2070570 1950180 1960070 501032025300 501032054600 501032021101 501032023400 ~ -- -- 3.1 miles ~ 4 1.2 miles ~ 4 2.3 miles _ ~ 1512 FSL 1457 FWL 2208 FNL 1984 FEL 1468 FSL 2248 FWL 2145 FNL 2115 FWL TWP: 11 N - Range: 4 E - Sec. 5 TWP: 11 N - Range: 4 E - Sec?211 N - Range: 4 E -Sec TWP: 12 N - Range: 4 E -Sec. 25 ~~.~": - ~ it-. ~ 1000 1000 i _ __ ( - _ _j - ' - j -- - t - #~ ~ __ _ f k ~ _~ _-~~ -} ~f 500 ~~ ! ( tit 500 ~ - ~~~ _ _I ` 9-5/8" casing shoe it Upper Confining i Zone ~ _ _ - - j _ i -- Disposal Zone ~` _ i ` ~ _~ x o - Lower Confining Zone ~ ` - ~, -~ ° - 1 - 4 _ ~ - ~ - -- r -} ~ -~ __;f -~ _- i - ~r ~ C „ TD=7649 TD=20189 TD=9940 500 -500 TD=7650 Figure 3. Stratigraphic Cross-section from Nuigsut 1 to Alpine 3 The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD2-72 that will be affected by the proposed annular disposal operations. There are about 20' of porous siltstone and sandy siltstone beds within the likely disposal interval, according to a count using the gamma ray curve from CD2-72. Porosity well logs were run across the proposed disposal interval in Alpine 1, which is located about 1 mile to the southeast. Inspection of the neutron and density porosity logs for the likely disposal interval suggests an average porosity of about 29% for the siltstone and sandy siltstone beds. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 100' from the wellbore, as indicated below. • Conoco hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~ SEA ~ 7 2008 ~. • ~' ~. 3 ~, - ~,o$G,~~~,y Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ,~' /% ~~~ M.. Loveland ConocoPhillips Well Integrity Project Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 .205-1Q9 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2!18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2!18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 ~. ~ ~ c~ `7 DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2051090 Well Name/No. COLVILLE RIV UNIT CD2-02 MD 21178 TVD 7241 Completion Date 8/22/2005 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (.!?D D Asc Directional Survey '~`D D Asc Directional Survey ~ED D Asc Directional Survey ~ED , D Asc Directional Survey ~g Cement Evaluation `° ~i D Lis 13432 Induction/Resistivity pt 13432 Induction/Resistivity ~pt 13431 Induction/Resistivity ~D D Lis 13431 Induction/Resistivity ~D C Pdf 13809 "~lnduction/Resistivity Well Cores/Samples Information: Name Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20513-00-00 Completion Status WAGIN Samples No Current Status WAGIN UIC Y Directional Survey Yes ~-~"'"~ (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 16016 21178 Open 9/26/2005 IIFR 16016 21178 Open 9/26/2005 MWD 0 16216 Open 9/26/2005 PB 1 IIFR 0 16216 Open 9/26/2005 PB 1 MWD 5 Blu 1 0 16048 Case 1/6/2006 Memory Cement Bond Log GR/CCL/SCMT 3833 16158 1/31/2006 GR/EWR4/BAT/ROP/PWD/ GP PB 1 3833 16158 1/31/2006 GR/EWR4/BAT/ROP/PWD/ GP PB1 3833 16158 1/31/2006 GR/EWR4/BAT/ROP/PWD/ GP 3833 16158 1/31/2006 GR/EWR4/BAT/ROP/PWD/ GP 114 21178 Open 3/9/2006 ROP DGR EWR graphics (.emf, .pdf) PB 1 114- 16216 DGR EWR Graphics (.emf, .pdf) Sampte Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2051090 Well Name/No. COLVILLE RIV UNIT CD2-02 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20513-00-00 MD 21178 TVD 7241 Completion Date 8/22/2005 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Yf / N Chips Received? ,~- Formation Tops / N Analysis ~'- Received? Comments: ------ ----- - - - -- ii Compliance Reviewed By: __ Date: __,~ J _ _ • ~ onocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~, b~`~0~ Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~!^~~ ~. Gli~ Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annu{us Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31.2007 Well Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 _ 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 318!2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3!8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16!2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18!2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165- 13" na 13" na 6.2 2!18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16!2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068. 6" na 6" na 1 3/8/2007 MEMORANDUM TO: Jim Regg',~ P.LSupervisor `l~%~~% v~~'/~~~ L FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHII,LIPS ALASKA INC CD2-02 COLVII.LE RIV iJNIT CD2-02 Src: Inspector NON-CONFIDENTIAL ~a~.~~©~ U~ Reviewed By- P.I. Suprv `•.J~ Comm Wetl Name• COLVILLE RIV UNIT CD2-02 Insp Num:. mitCS060827191910 Rel Insp Num API Well Number 50-103-20513-00-00 Permit Number: 205-tog-0 Inspector Name Chuck Scheve Inspection Date: 8/27/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cDZ-o2 Type Inj. ~' TVD ztos IA asa za7o zaao zaao P.T. zoslo9o TypeTest SPT Test psi t7~6.2s pA aso sso sso sso Interval 4YRTST pn-, P /~ Tubing 2-00 2too 2l0o zloo Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. Wednesday, August 30, 2006 Page 1 of 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 March 8, 2006 RE: MWD Formation Evaluation Logs: CD2-02 &CD2-02 PB1, AK-MW-3855685 cD2-oz: Digital Log Images: 50-103-20513-00 CD2-02 PB1: Digital Log Images: 50-103-20513-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~® Date: l /eat.- ~ Signed: MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission TO: Tim Re ~ _ DATE: Thursday, March 02, 2006 P.I. Supe~rgisor ~ ~~/C/ ~~(~ ~~` 1'" SUBJECT: Mechanical Integrity Tests 1 !• CONOCOPHILLIPS ALASKA INC CD2-02 FROivI: John Crisp COLVILLE RIV UNIT CD2-02 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv :..~~ Comm Well Name: COLVILLE RIV UNIT CD2-02 Insp Num: mit3Cr060209090142 Rel Insp Num API Well Number 50-103-20513-00-00 Permit Number: 205-109-o Inspector Name: Sohn Crisp Inspection Date: 2/4/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ CD2-02 ~TYpe InJ. ~ W ~ TVD ~ 7035 ~ ~ ~ 550 ~ 2420 ~ 2400 ~ 2390 P.T. ~ 2051090 ~TypeTest ~ SPT I Test pSl ~ 1758.75 ~ QA X00 ~ 650 ~ 650 ~ 650 Interval INITAL PIS' P Tubin~ ~ 1637 ~ 1637 ~ 1637 ~ 1637 Notes IA pressures monitored & stable prior to test. No tubing to IA problems reported by Operator. 2 bbls pumped for test. Thursday, March 02, 2006 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska FIELD /UNIT /PAD: Alpine CRU CD2 DATE: 02!04/06 OPERATOR REP: Dusty Beller-AES AOGCC REP: John Crisp Packer De th Pretest Initial 15 Min. 30 Min. Well CD2-17A T e In'. W TVD 7,496' Tubing 1521 1521 1521 1521 Interval I P.T.D. 2050170 T e test P Test si 1874 Casing 400 2005 1940 1950 P/F P Notes: Initial MIT OA 400 600 550 550 Well CD2-59 T e Inj. W TVD 6,899' Tubin 1826 1826 1826 1826 Interval I P.T.D. 2042480 T e test P Test si 1725 Casing 550 2012 2000 2000 PIF P Notes: Initial MIT OA 700 800 800 810 Well CD2-02 T e In'. W TVD 7,105' Tubing 1637 1637 1637 1637 Interval I P.T.D. 2051090 T e test P Test si 1776 Casing 550 2420 2400 2390 P/F P Notes: Initial MIT OA 500 650 650 650 Well CD2-60 T pe In~. W TVD 7,035' Tubing 1967 1967 1967 1967 Interval I P.T.D. 2050680 T pe test P Test si 1759 Casing 250 2040 2020 2010 P/F P Notes: Initial MIT OA 420 620 620 620 Well Ty e In'. TVD Tubin Interval P.T.D. Ty e test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 911/05 MIT CRU CD2 02-04-06-1.xls Schlumberger ~~~~~v~ JAN p 6 2006 12/20/05 NO. 3620 ^~ ~tl ~x G2S CCi1S' ~Of111t -~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman Attn: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ~ Color Well Job # Log Description Date BL Prints CD CD2-59 11133207 SCMT 11!19/05 1 CD2-02 N/A SCMT 12/13/05 1 CD2-11 11133210 SCMT 12/14/05 1 SIGNED: DAT Please sign and return on opy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. • ConocoPhillips December 16, 2005 G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~.~°~VE Commissioner DEC ~ Z(b05 State of Alaska Alaska Oil & Gas Conservation Commission Alaska Oit & Gas Cons. Comm~ssoors 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-02 /CD2-02PB1 (APD 205-109) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine wells CD2-02 /CD2-02PB1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, . ~ , ~~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~v~ DEC 1 ~ 2005 WELL COMPLETION OR RECOMPLETION REPC~~'~ ~ll'V![~ ~~~'~~I'~'`'` 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG 0 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., orAband.: August 22, 2005 ~ 12. Permit to Drill Number: 205-109 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 30, 2005 ~ 13. API Number: i 50-103-20513-00 J -70~ 4a. Location of Well (Governmental Section): Surface: 1587' FNL, 1561' FEL, Sec. 2, T11 N, R4E, UM ' 7. Date TD Reached: August 20, 2005 ~ 14. Well Name and Number: CD2-02 /CD2-02PB1 At Top Productive Horizon: 72' FSL, 2636' FEL, Sec. 28, T12N, R4E, UM 8. KB Elevation (ft): 36.6' RKB / 52.5' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 801' FNL, 257' FEL, Sec. 29, T12N, R4E, UM 9. Plug Back Depth (MD + TVD): ~ 21178' MD / 7241' TVD ~ Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371683 ' y- 5974771 Zone- 4 10. Total Depth (MD + TVD): ~ 21178' MD / 7241' TVD ~ 16. Property Designation: DL 380075, 387212, 388466, 25530, ASRCNPRA TPI: x- 360163 y- 5981916 Zone- 4 Total Depth: x- 357334 - 5986377 Zone- 4 11. Depth where SSSV set: Land Nipple @ 2321' 17. Land Use Permit: ASRC NPRA02 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2175' MD 21. Logs Run: GR/Res, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 114' Surt. 114' 42" Portland Cement 9-5/8" 36# J-55 Surf. 3856' Surf. 2381' 12.25" s55 sx AS Lite, 240 sx Class G 7" 26# L-80 Surf. 16049' Surf. 7260' 8.75" 40 bbls Mudpush XL, 160 sx Class G 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 4.5" 15488' 15414' open hole completion from 16048' - 21178' MD, 7260' - 7241' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) Injector -waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi 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". NONE 5 ~g'~Z -c?~' BFh ~~c ~ 0 2005 ~. _ . Form 10-407 Revised 12/2003 - ~ ~ ! ~ ~ ~ ~ CONTINUED ON REVERSE 28. 29. 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". CD2-02 Seabee Form. 3695' 2318' Nanushak 7493' 3849' Gamma Ray Shale 14947' 6918' Kalubik 15452' 7120' Kuparuk Formation 15556' 7159' Miluveach 15726' 7212' Top Alpine D 15857' 7239' Top Alpine C 15857' 7239' Base Alpine C 21178' 7241' N/A TD 21178' 7241' CD2-02PB1 TD 16216' 7254' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name G~./A~lvo-rd Title: Aloine Drilling Team Leader (Z~/G~p~ Signature ,LL_ f (~f~.._ Phone Date INSTRUCTIONS Prepared by Sharon Ailsup-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 • ConacaPhillips #ilaska operations Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Phase Code 7/30/2005 02:30 - 03:00 0.50 MOVE MOVE MOVE 03:00 - 03:30 0.50 MOVE SFTY MOVE 03:30 - 08:00 4.50 MOVE MOVE MOVE 08:00 - 09:30 1.50 DRILL PULD SURFAC 09:30 - 09:45 0.25 DRILL PULD ~ SURFAC 09:45 - 11:15 1.50 RIGMNT RSRV ~ SURFAC 11:15-13:45 2.50, DRILL iPULD (SURFAC 13:45 - 14:00 0.25 DRILL SFTY I SURFAC 14:00 - 14:45 0.75 DRILL PULD f SURFAC 14:45 - 00:00 { 9.251 DRILL DRLG SURFAC 7/31/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 8/1/2005 ~ 00:00 - 04:45 r 4.75! DRILL ;DRLG SURFAC 04:45 - 06:00 i 1.25 !DRILL CIRC ~ SURFAC 06:00 - 11:30 5.50 ~ DRILL WIPR SURFAC 11:30 - 13:00 1.50 ~ DRILL -WIPR SURFAC 13:00 - 14:15 1.251 DRILL i CIRC ~ SURFAC 14:15 - 19:30 f 5.251 DRILL i TRIP !SURFAC 19:30 - 21:30 I 2.001 DRILL I PULD I SURFAC Start: 7/30/2005 Rig Release: 8/22/2005 Rig Number: Page 1 of 8 Spud Date: 7/29/2005 End: 8/22/2005 Group: Description of Operations Prep rig for move - PJSM for rig move Move rig to CD2-02 skid rig over hole -connect service lines and highline power -Accepted rig @ 0800 hrs. NU Riser and flowline, take on spud mud Accept rig @ 0800 hrs. 7/30/2005 PU and stand back 9 joints of 5" drill pipe Slip and cut drilling line -.service Top Drive and Drawworks MU BHA: Bit -motor @ 1.83 ako - FS -stab - nmxo - DM HOC - HCIM - TM HOC UBHO -scribe tools -initiate MWD Held Pre-Spud meeting with crew and support personell MU NM flex DC's fill hole and check for leaks -test mud lines to 3500 psi Spud-in @ 1445 hours -Drill 12 1/4" hole f/ 114' to 748' MD 738' TVD ADT - 4.13 hrs. =ART - 1.28 hrs. AST - 2.85 hrs. WOB 15!25 k RPM 50 GPM 500 @ 1070 psi String wt. PU 105 SO 100 Rot 105 Torque on/off btm. - 6500!5000 ft. lbs. Took 6 gyro surveys @ 80', 169', 258', 348', 440', i~ 529' Drill 12 1/4" hole f/ 748' to 2405' MD 1796' TVD ADT - 7.12 hrs. =ART - 3.37 hrs. AST - 3.75 hrs. WOB 25 k RPM 50!80 GPM 500/650 @ 1070/1950 psi String wt. PU 123 SO 105 Rot 117 Torque onloff btm. - 9000/7000 ft. lbs. Drill 12 1/4" hole f/ 2405' to 3450' MD 2225' TVD ADT - 7.1 hrs.=ART - 6.48 hrs. AST - .62 hrs. WOB 25/35 k RPM 80 GPM 650 @ 2200 psi String wt. PU 135 SO 110 Rot 120 Torque on/off btm. - 9,000/8,000 ft Ibs, Drill 12 1/4" hole f/ 3450' to 3866' MD 2385' TVD ADT - 3.3 hrs.=ART - 3.04 hrs. AST - 0.26 hrs. WOB 25/35 k RPM 80 GPM 650 @ 2300 psi String wt. PU 135 SO 112 Rot 122 Torque on/off btm. - 9,000/8,000 ft Ibs, Circulate hole clean 650 gpm / 2300 psi / 80 rpm Flow check well, static Wipe hole from 3768' to 919' - 600 gpm / 2220 psi / 60 rpm to 1930' - 550 gpm to 1644' - 500 gpm to 1290' - 450 gpm to 919' .Had large amount of cuttings back from 3200' to 919'. Reduced pulling speed on last stand to CBU. Flow check well, static. RIH from 919' to 3769' - no problems -fill pipe at 20 stands - Precautionarywash and ream from 3769' to 3866'. Circ hole clean - 650 gpm / 2210 psi / 80 rpm FCP 2120 psi -Flow check well, static POOH on trip tank from 3768' to 1263' -tight spot @ 1246' pulling 30 over -POOH w/ pump f/ 1263' to 1188' - 450 gpm @ 950 psi -POOH on TT f/ 1188' to 1074' -tight spot -POOH wi pump fl 1074' to 794' - I400 gpm @ 850 psi -POOH on TT f/ 794' to 16T -worked through tight spots @ 620' i;< 524' j Handle BHA -Pump fresh water through BHA -Std back NM flex DC & Printed: 9/20/2005 10:53:10 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase 8/1/2005 19:30 - 21:30 2.00 DRILL PULD SURFAC 21:30 - 00:00 I 2.50 CASE RURD SURFAC 8/2/2005 00:00 - 00:30 0.50 CASE SFTY SURFAC 00:30 - 04:00 3.50 CASE RUNC SURFAC 04:00 - 05:45 1 1.75 CASE RUNC ~ SURFAC 05:45 - 07:30 1.75 CASE RUNC SURFAC 07:30 - 08:15 I 0.75 CASE CIRC SURFAC 08:15 - 10:00 1.75 CASE RUNC SURFAC 10:00 - 10:45 0.75 CASE CIRC SURFAC 10:45 - 11:45 1.00 CASE RUNC SURFAC 11:45 - 12:30 0.75 CASE CIRC SURFAC 12:30 - 14:15 1.75 CASE RUNC SURFAC 14:15 - 14:45 ~ 0.50 CEMEN RURD SURFAC 14:45 - 17:45 3.00 CEMEN CIRC SURFAC 17:45 - 21:15 ~ 3.50 CEMEN PUMP SURFAC 21:15 - 22:00 0.75 CASE MIT i SURFAC 22:00 - 00:00 2.00 CASE RURD SURFAC 8/312005 00:00 - 02:00 i 2.00 CASE NUND SURFAC 02:00 - 05:00 I 3.00 WELCTLI NUND SURFAC 05:00 - 08:45 I 3.75 RIGMNT RGRP SURFAC 08:45 - 09:15 i , 0.50 WELCT OTHR SURFAC 09:15 - 13:00 { 3.75 WELCT BOPE I SURFAC 13:00 - 14:00 f 1.001 DRILL I OTHR I SURFAC 14:00 - 15:00 1.00 DRILL OTHR !SURFAC 15:00 - 16:00 1.00 DRILL PULD SURFAC Start: 7/30/2005 Rig Release: 8/22/2005 Rig Number: Page 2 of 8 Spud Date: 7/29/2005 End: 8/22/2005 Group: Description of Operations jars -down load MWd - LD MWD -motor & bit RU to run 9 5/8" csg - RU fill up line (Frank's fill up tool dressed for 7" ce9) Pre-Job safety and Opts meeting on running 9 5/8" casing Run 9 518" 36# J-55 BTC casing as follows: FS (silver bullet) 2jts.FC - 2 jts.(fill pipe & checked floats -first 4 connections made up w/ BakerLoc) 21 jts -tight spot at 1020' (25 jts. total) Fill pipe every 5 joints RU circ swedge and wash down from 1020' to 1084' 2.6 bpm / 140 psi Run casing from 1084' to 1630' -lost 15K SOW last 2 joints 39 joints total RU circ swedge -stage pumps up to 6 bpm -CBU -FCP 520 psi PUW 123K SOW 90K Run casing from 1630' to 2550' -return % dropping off - 61 joints total Fill pipe - MU circ swedge -stage pumps up to 6 bpm -CBU -FCP 520 psi PUW 125 K SOW 95K Run casing from 2550' to 3180' 76 jts total -return % dropping off Fill pipe - MU circ swedge -stage pumps up to 4 bpm / 420 psi- total pumped 95 bbls, lost 15 bbls of mud. Run 9 5/8" casing from 3180' to 3801' (total of 91 jts.) -MU FMC mandrel hanger and landed casing with FS @ 3856', FC @ 3772'. Fill pipe - MU Dowell cement head Stage pumps up slowly -initial 1.6 bpm / 390 psi -circ and condition mud -final rate 6.5 BPM 270 PSI. PJSM on cementing csg. Test lines to 2700 psi. Pumped 40 bbls bizan/nut plug spacer and drop bottom plug. Pump 50 bbls 10.5 mud push, 519 bbls 10.7 lead cement and 50 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H2O. Rig displaced with 272 bbls 9.6 mud. Bumped plug. Gheck floats. OK. Lost returns after 90 Bb{s displaced. Had partial to no returns throughout job. Worked hanger and flushed stack with black water to regain returns with limited success. Cement was standing at the lower casing valve. When we laid down riser cement was at the hanger. No top job was required. Total mud lost 260 Bbls. CIP 2115 Hrs. 8/2/05. Rigged up and tested casing to 2500 PSI for 30 Min. Laid down Cement head, Landing joint and bails. RD riser and FMC speed adaptor -Install FMC wellhead -test M/M seal to 1000 psi for 10 min. NU BOP stack. Changed annular preventer. Install test plug and fill stack with water Installed test plug. Test BOPE - Hydril to 250 & 3500 psi -Pipe rams, choke & kill line valves, choke manifold valves, IBOP and floor valves to 250 & 5000 psi -performed accumutator closure test. Witiness of test by AOGCC waived by John Crisp (AOGCC). Pulled test plug and set wear bushing. Install drilling bails on top drive -change Iron roughneck heads to 4" - pu 4" elevators RIH with 30 stands of 4" drill pipe POOH laying down drill pipe Printed: 9!20!2005 10:53:10 AM r1 U ConocoPhilGps Alaska Page 3 of 8 Operations Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Spud Date: 7/29/2005 Event Name: ROT -DRILLING Start: 7/30/2005 End: 8/22/2005 Contractor Name: Doyon Drilling Inc Rig Release: 8/22/2005 Group: Rig Name: Doyon 19 Rig Number: Date From - To Hours Code Code Phase 8/3/2005 ~ 16:00 - 16:30 ~ 0.50 ~ DRILL ~ OTHR ~ SURFAC 16:30 - 18:30 2.00 DRILL PULD SURFAC 18:30 - 19:30 1.00 DRILL PULD 1 SURFAC 19:30 - 22:30 3.00 DRILL PULD SURFAC 22:30 - 00:00 1.50 DRILL TRIP SURFAC 8/4/2005 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 04:00 3.50 DRILL PULD SURFAC 04:00 - 06:30 2.50 DRILL PULD SURFAC 06:30 - 09:30 3.00 i DRILL PULD ~ SURFAC 09:30 - 12:30 3.00 DRILL TRIP SURFAC 12:30 - 14:00 1.50 RIGMNT RSRV SURFAC 14:00 - 14:45 0.75 CEMEN DSHO SURFAC 14:45 - 17:00 2.25 CEMEN~DSHO SURFAC 17:00 - 17:15 0.25 DRILL DRLG SURFAC 17:15 - 17:30 0.25 DRILL I CIRC I SURFAC 17:30 - 18:15 0.75 CEMEN~FIT SURFAC 18:15 -00:00 5.75 DRILL ~ DRLG INTRMI 8/5/2005 100:00 - 12:00 12.00 DRILL DRLG i INTRM1 12:00 - 00:00 I 12.001 DRILL I DRLG I INTRM1 8/6/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I INTRM1 12:00 - 00:00 I 12.001 DRILL I DRLG I INTRM1 Description of Operations Respond to spill: Hole fill line washed out under rig floor resulting in 30 gal in rig and 5 gallons of water base mud onto matting boards -crew located and secured source -cleaned up matting boards POOH laying down 4"drill pipe. Rigged up and laid down 8" drill collars from the derrick. Picked up and RIH 114 Jts 5"drill pipe. POOH and stood back 5" drill pipe. POOH -stand back 5" drill pipe RIH - PU 114 joints of 5" drill pipe -POOH stand back drill pipe RIH - PU 66 joints of 5"drill pipe -POOH stand back drill pipe MU BHA #2: Bit, 7600 GeoPilot, pony flex, stab. GR/PWD, stab, HCIM, TM HOC, fs -initialise tools -RIH with nmfc's and hwdp - 1 jnt 5" drill pipe -shallow test tools 546 gpm / 1320 psi -pressure test GeoSpan skid to 4000 psi RIH -picked up 93 joints of 5" drill pipe from shed to 3669'. Slip and cut drilling line -service top drive and Drawworks Break in bearings on GeoPilot -wash down and clean out cement from 3740' to wiper plugs @ 3769'. Drill out plugs, FC -cement - FS - rathole to 3866' 550 gpm / 1920 psi / 65 rpm Drill 8 3/4" hole f/ 3866' to 3886' MD 2391' ND ADT - .2 hrs. WOB 15 k RPM 80 GPM 550 @ 1200 psi String wt. PU 150 SO 95 Rot 112 Torque on/off btm. - 9,000/8,000 ft Ibs, CBU. Rigged up and did FIT to 17.3 PPG EMW. Drill 8 3/4" hole f/ 3886' to 4526' MD 2665' ND ADT - 2.87 hrs. WOB 10!18 k RPM 130 GPM 650 @ 1720 psi String wt. PU 155 SO 100 Rot 120 Torque on/off btm. - 11,500!10,000 ft Ibs, ECD 11 PPG. Drill 8 3/4" hole f/ 4,526' to 6239' MD 3356' ND ADT - 7.22 hrs. WOB 15/18 k RPM 150 GPM 670 @ 2100 psi String wt. PU 180 SO 105 Rot 135 Torque on/off btm. - 13,000/12,000 ft Ibs, ECD 11.4 - 11.9 PPG. Drill 8 3/4" hole f/ 6,239' to 7,762' MD 3968' ND ADT - 7.54 hrs. WOB 10/25 k RPM 170 GPM 670 @ 2670 psi String wt. PU 185 SO 117 Rot 145 Torque on/off btm. - 15,000114,500 ft Ibs, ECD 11.4 - 11.8 PPG. Drill 8 3!4" hole f! 7,762' to 9,286' MD 4598' ND ADT - 6.65 hrs. WOB 25 k RPM 150 GPM 670 @ 2350 psi String wt. PU 245 SO 113 Rot 155 Torque on/off btm. - 18,500/17,500 ft Ibs, ECD 11.4 - 11.8 PPG. Drill 8 3/4" hole f! 9,286' to 10,998' MD 5302' ND ADT - 8.28 hrs. WOB 25 k RPM 150 GPM 670 @ 2460 psi String wt. PU 245 SO 130 Rot 170 Torque on/off btm. - 19,000/18,500 ft Ibs, Printed: 9/20/2005 10:53:10 AM ConocoPhiiiips Alaska Page 4 of 8 Operations Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Spud Date: 7/29/2005 Event Name: ROT -DRILLING Start: 7/3012005 End: 8/22/2005 Contractor Name: Doyon Drilling Inc Rig Release: 8/22/2005 Group: Rig Name: Doyon 19 Rig Number: Date From - To Hours Code Phase Description of Operations Code 8/6/2005 12:00 - 00:00 ~ 12.00 DRILL DRLG INTRM1 _ECD 11.2 - 11.5 PPG 8/7/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 3/4" hole f/ 10,998' to 12,712' MD 6000' TVD ADT - 7.75 hrs. WOB 20/28 k RPM 150 GPM 670 @ 2700 psi String wt. PU 215 SO 150 Rot 180 Torque on/off btm. - 18,000/17,000 ft Ibs, ECD 10.9 - 11.1 PPG. 12:00 - 00:00 12.00 DRILL DRLG INTRMI Drill 8 314" hole fJ 12,712' to 14,658' MD 6796' TVD ADT - 7.91 hrs. WOB 25/30 k RPM 160 GPM 670 @ 3040 psi String wt. PU 250 SO 155 Rot 195 Torque on/off btm. - 21,500/20,500 ft Ibs, ECD 10.9 - 11.2 PPG. 8!8/2005 00:00 - 12:15 12.25 DRILL DRLG INTRM1 Drill 8 314" hole f/ 14,658' to 16,063' MD 7259' TVD ADT - 8.79 hrs. WOB 28130 k RPM 150 GPM 600 @ 2550 psi String wt. PU 265 SO 155 Rot 202 Torque on/off btm. - 22,000/19,500 ft Ibs, ECD 10.8 - 11.1 PPG. 12:15 - 15:15 3.00 DRILL CIRC INTRM1 Pump 40 bbls high vis sweep - circ and condition mud for 3X BU 600 gpm / 2490 psi / 160 rpm set back 1 stand/hr to 15726'. Monitor well @ 15,978' slight flow initial -static in 15 min. 15:15 - 17:00 1.75 DRILL WIPR INTRM1 Wipe hole from 15,726' to 14,837' - 550 gpm / 2110 psi / 120 rpm No problems -flow check weH, slight flow, static in 10 minutes. 17:00 - 18:00 i 1.00 DRILL WIPR INTRMI RIH to 15,979', no problems -precautionary wash and ream to 16,063' 18:00 - 19:45 1.75 DRILL CIRC INTRMI Pumped pill and circulated out. 19:45 - 22:00 2.25 DRILL WIPR INTRM1 Wipe hole from 15,726' to 14,837' - 550 gpm / 2110 psi / 120 rpm No problems -flow check well. RIH to 16,063'. 22:00 - 00:00 2.00 DRILL ~ CIRC INTRM1 Circulated and raised MW to 10 PPG. 8!9/2005 00:00 - 01:00 1.00 DRILL CIRC INTRM1 Circulate and conditioned mud for casing: 01:00 - 03:00 2.00 DRILL TRIP INTRMI POOH spotting lube pills to 14,800'. 03:00 - 13:45 10.75 DRILL TRIP INTRM1 POOH on trip tank to 711'. 13:45 - 15:30 1.75 DRILL PULD INTRM1 Stood back DC's and laid down BHA. 15:30 - 17:45 2.25 CASE NUND INTRM1 Pulled wear bushing and set test plug. Changed rams to 7" and tested. I Pulled test plug and ran thin wear ring. 17;45 - 19:15 1.50 CASE RURD INTRMI Rigged up to run casing. PJSM with crew. 19:15 - 23:30 4.25 CASE RUNC INTRM1 Ran 90 Jts 7" 26# L-80 BTCM casing to 3,828'. 23:30 - 00:00 0.50 CASE CIRC INTRMI Circulated casing volume, worked pumps up to 4 BPM w 300 PSI. 8/10/2005 00:00 - 03:00 I 3.00 CASE RUNC INTRMI RIH w/ 7" 26# L-80 BTCM csg from 3828' to 6776'. 03:00 - 03:45 0.75 CASE CIRC INTRM1 Circ and condition mud at 5 bpm at 600 psi. 03:45 - 06:45 3.00 CASE RUNC INTRM1 RIH w/ 7" 26# L-80 BTCM csg from 6776' to 9751'. 06:45 - 08:15 1.50 CASE CIRC INTRM1 ~ Circ and condition mud at 5 bpm at 500 psi. i 08:15 - 12:45 4.50 CASE RUNG INTRM1 RIH w/ 7" 26# L-80 BTCM csg from 9751' to 14,014'. 12:45 - 15:00 2.25 CASE CIRC ~ INTRM1 CBU. 4.5 BPM 520 psi. 15:00 - 17:30 2.50 CASE ~ RUNC INTRM1 ~ RIH w/ 7" 26# L-80 BTCM csg from 14,014' to 16,049'. Landed casing. 17:30 - 17:45 0.25 CEMEN RURD INTRM1 Made up cement head. 17:45 - 20:45 3.00 CEMEN CIRC INTRM1 Circulated and conditioned mud prior to cementing. Worked pumps up Ito 6 BPM @ 710 PSI. Unable to work pipe up. PJSM for cementing. 20:45 - 21:30 0.75 CEMEN PUMP INTRM1 Cement 7" csg as follows: Pumped 5 bbls CW-100 -tested lines to 3700 psi -pumped 45 bbls CW-100 @ 4.3 bbls/min @ 400 psi - f Pumped 40 bbls MudPush II @ 10.5 ppg - 4.5 bbls/min @ 470 psi - Dropped btm plug - Mixed & pumped 33 bbls tail slurry @ 15.8 ppg - 4.5 bbls/min @ 400 psi -dropped top plug w/ 20 bbls water f/ Dowell Printed: 9/20/2005 10:53:10 AM • ConocoPhiliips Alaska Operations Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling tnc Rig Name: Doyon 19 Date From - To Hours Code Code Phase `' 8/10/2005 ~ 21:30 - 23:00 ~ 1.50 ~ CEMENl~ DISP ~ INTRM1 23:00 - 00:00 1.00 CASE ~ MIT INTRMI 8!1112005 00:00 - 00:15 0.25 CASE MIT INTRM1 00:15 - 01:00 0.75 CASE RURD INTRM1 01:00 - 01:30 0.50 CASE OTHR INTRM1 01:30 - 02:00 0.50 CASE OTHR INTRM1 02:00 - 03:30 1.50 WELCT EQRP INTRMI 03:30 - 08:00 08:00 - 12:30 4.50 DRILL 4.50 WELCT PULD BOPE INTRM1 INTRMI 12:30 - 19:45 7.25 DRILL PULD INTRM1 19:45 - 20:45 1.00 DRILL RIRD INTRMI ~ 20:45 - 23:15 2.50 DRILL PULD INTRM1 23:15 - 23:30 0.25 DRILL CIRC INTRM1 23:30 - 00:00 0.50 DRILL TRIP INTRM1 8/12/2005 00:00 - 01:00 1.00 DRILL TRIP INTRM1 01:00 - 05:00 4,00 DRILL PULD INTRM1 05:00 - 05:30 0.50 DRILL CIRC INTRMI 05:30 - 07:15 1.75 DRILL PULD ~ INTRMI 07:15 - 08:30 I 1.25 RIGMNT RSRV INTRM1 X 08:30 - 17:45 ~ 9.25 DRILL PULD INTRMI 17:45 - 18:15 0.50 LOG OTHR INTRM1 18:15 - 18:45 0.50 DRILL PULD I INTRM1 18:45 - 21:00 2.25 LOG ' OTHR INTRMI 21:00 - 21:15 0.25 DRILL PULD INTRMI 21:15 - 22:00 0.751 DRILL CIRC INTRMI 22:00 - 00:00 ~ 2.00 CEMEN COUT INTRM1 8/13/2005 00:00 - 03:30 3.50 ~ CEMENI ~ DSHO INTRM1 03:30 - 04:00 I 0.50 ~ DRILL DRLG INTRM1 04:00 - 05:30 I 1.50 DRILL ' CIRC INTRM1 05:30 - 06:00 ~ 0.50 DRILL FIT INTRM1 ii 06:00 - 08:30 2.50 DRILL CIRC I PROD 08:30 - 12:00 3.50 ~ DRILL DRLH ~ PROD 12:00 - 13:30 I 1.50 I DRILL I DRLH I PROD Start: 7/30!2005 Rig Release: 8/22J2005 Rig Number: Page 5 of 8 Spud Date: 7/29/2005 End: 8122!2005 Group: Description of Operations Displaced with 591.4 Bbls mud from rig pump @ 6 BPM. Increased to 7 BPM when cement went through shoe. Reduced to 4 BPM and bumped plug. CIP @ 2300 Hrs. Floats held. Good returns. Rigged up and tested casing 3500 PSI for 30 min. Finish test 7" csg to 3500 psi for 30 min, RD csg equipment. Pul{ thin wear bushing. Install packoff and test to 5000 psi. Change top pipe rams from 7" to 3 1/2" x 6' varibles. LD 5" drill pipe from derrick. Installed test plug. Test BOPE - Hydril to 250 8~ 3500 psi -Pipe rams, choke & kill line valves, choke manifold valves, !BOP and floor valves to 250 & 5000 psi -performed accumutator closure test. Witiness of test by Chuck Sheive (AOGCC). Pulled test plug and set wear bushing. LD 5" drill pipe from derrick. Changed out handling tools and Iron roughneck. Loaded 4" pipe in pipe shed. Picked up and RIH 120 joints 4" DP. CBU. POOH and stood back 4" DP. POOH and stood back 4" DP. Picked up and RIH with BHA. Tested MWD and Geo Span. RIH with BHA picking up 4" DP from pipe shed to 2324'. Filled pipe. Slipped and cut drilling line. RIH with BHA picking up 4" DP from pipe shed to 14,052'. Filled pipe every 2000'.. MADD pass for cement evaluation baseline 14052' to 14147'. RIH with BHA picking up 4" DP from pipe shed to 15,100'. Filled pipe every 2000'.. MADD pass for cement evaluation 15100' to 15600'. RIH with BHA picking up 4" DP from pipe shed to 15,861'. Filled pipe every 2000'.. Spotted casing lube pill. Cleaned out cement from 15950' to 15,958' (FC). Drilling on FC. Drilled out shoe track and cleaned out rat hole to 16063'. Drill 6 1!8" hole f! 16,063' to 16,083' MD 7259' TVD ADT - .3 hrs. WOB 5/10 k RPM 70 GPM 220 @ 2180 psi String wt. PU 220 SO 135 Rot 170 Torque on/off btm. - 14,500/13,500 ft Ibs, ECD 10 CBU. FIT to 12.5 PPG EMW. Displaced well to 9.2 PPG FlowPro. Cleaned out shakers. Drill 6 1/8" hole f/ 16,083' to 16,205' MD 7253' TVD ADT - 3.37 hrs. WOB 5/10 k RPM 100 GPM 224 @ 2100 psi String wt. PU 220 SO 135 Rot 170 Torque on/off btm. - 14,500113,500 ft Ibs, ECD 10.1. Drill 6 1/8" hole f/ 16,205' to 16,216' MD 7253.47' TVD ADT - 1.44 hrs. Printed: 9120/2005 10:53:10 AM ConocoPhifiips Alaska Operations Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase 8/13/2005 ~ 12:00 - 13:30 ~ 1.50 ~ DRILL f DRLH ~ PROD 13:30 - 13:45 0.25 DRILL TRIP PROD 13:45 - 18:30 4.75 DRILL DRLH PROD 18:30 - 22:00 3.50 DRILL DRLH PROD 22:00 - 22:30 0.50 DRILL CIRC PROD 22:30 - 23:00 0.50 DRILL TRIP PROD 23:00 - 23:15 0.25 DRILL TRIP PROD 23:15 - 00:00 0.75 DRILL CIRC PROD 8/14/2005 00:00 - 01:00 1.00 DRILL CIRC PROD 01:00 - 09:30 8.50 DRILL TRIP PROD 09:30 - 13:15 13:15 - 15:30 15:30 - 16:00 16:00 - 19:00 19:00 - 00:00 3.75 DRILL TRIP 'PROD 2.25 DRILL TRIP PROD 0.501 DRILL I TRIP i PROD 3.001 DRILL I CIRC I PROD 5.001 DRILL TRIP {PROD 8/15/2005 100:00 - 05:00 05:00 - 14:00 14:00 - 14:30 14:30 - 14:45 14:45 - 15:15 15:15 - 22:00 22:00 - 00:00 5.00 j DRILL j PULD j PROD 9.00 DRILL (TRIP (PROD 0.50 RIGMNT RSRV PROD 0.25 DRILL REAM PROD 0.50 DRILL REAM PROD 6.751 DRILL DRLG PROD 2.00 I DRILL I DRLH I PROD 8/16/2005 { 00:00 - 12:00 j 12.001 DRILL DRLH I PROD 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD 8/17/2005 j 00:00 - 12:00 { 12.001 DRILL I DRLH PROD Start: 7/30/2005 Rig Release: 8!22/2005 Rig Number: Page G of 8 Spud Date: 7/29/2005 End: 8!22/2005 Group: Description of Operations WOB 24 k RPM 70 GPM 224 @ 2150 psi String wt. PU 220 SO 135 Rot 170 Torque on/off btm. - 14,500113,500 ft Ibs, ECD 10.1. Unable to turn well path down drilled into shale. POOH to 16,110' for open hole sidetrack. Attempted to sidetrack well with Geopilot with no success. Reamed and time drilled to sidetrack no success. Survey and ABI indicated no departure from old hole. Unable to hold tool face and had i housing roll. Circulated and preyed to POOH. POOH to casing shoe with pump. Flow Checked well slight flow. RIH to 116,205'. CBU to check for gas in mud. CBU No Gas observed. POOH with pump @ 3 BPM to maintain hole fill from 16,205' to 9,275'. Attempted to pull on trip tank several times with limited success. POOH from 9,275' to 5,458' on TT. Hole fill was light. Flow check well was dead. Continued to POOH with pump from 5,458' to 4,503'. Hole fill was short with pump on. Checked well. Slight flow diminishing as we observed. RIH to 6,030'. Raised MW to 10.5 PPG to provide an additional 215 PSI trip margin. Flow checked before and after weight up well was dead. POOH from 6,030' to 782'. Pulled first 5 stands with pump and then pulled on TT. Hole fill was good. Stood back HWDP. Changed BHA laid down Geopilot and sonic tool. Picked up MM and new bit. RIH to 577' and tested MWD. RIH filling pipe every 2000' to 16,042'. Serviced rig and top drive. Washed to 16,110'. Trenching for sidetrack. ~ Time drilled and sidetracked hole @ 16,110' to 16.167'. AST 5.96 Hrs TVD 7250'. Drill 6 1/8" hole f/ 16,167' to 16,210' MD 7243' TVD ADT - 1.31 hrs. AST .8 ART .51 WOB 5/6 k RPM 50 GPM 233 @ 2410 psi String wt. PU 205 SO 130 Rot 170 Torque on/off btm: - 11,500/10,500 ft Ibs, ECD 10.6. Drilled 6 1/8" horiz hole w/ motor f/ 16,210' to 16,597' MD 7246' TVD ADT - 4.49 hrs. =ART 2.08 hrs. AST 2.41 hrs. ~ WOB 5/7 k RPM 0/60 GPM 233 @ 2760 psi String wt. PU 215 SO 130 Rot. 170 Torque on/off btm. - 12,000/10,000 ft. lbs. f ECD - 10.7 to 10.9 f Drilled 6 1/8" horiz hole w/ motor f/ 16,597' to 17,215' MD 7264' TVD ADT 7.79 hrs. =ART 5.41 hrs AST 2.38 hrs WOB 10 RPM 0160 GPM 233 @ 2950 psi String wt. - PU 220 SO 135 Rot. 172 !Torque on/off btm. - 12,500!10,500 ft. lbs. 'ECD-10.8 to 11.0 i Drilled 6 112" horiz hole w1 motor fJ 17,215' to 17,985' MD 7266' TVD ADT 8.44 hrs.=ART 6.2 hrs. AST 2.24 hrs. Printed: 9/20/2005 10:53:10 AM • ConocoPlillips Alaska Operations Summary .Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date' ' Fram - To Hours Code Code Phase 8/17/2005 00:00 - 12:00 I 12.00 I DRILL DRLH PROD 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD 8/18/2005 100:00 - 12:00 I 12.00 I DRILL DRLH PROD 12:00 - 00:00 I 12.00 I DRILL I DRLH I PROD 8/19!2005 100:00 -12:00 I 12.001 DRILL I DRLH 1 PROD 12:00 - 00:00 I 12.001 DRILL I DRLH PROD 8/20/2005 100:00 - 01:30 J 01:30 - 03:30 03:30 - 06:00 106:00 - 09:30 J 09:30 - 10:30 10:30 - 12:30 1.50 I DRILL I DRLH I PROD 2.00 DRILL CIRC PROD 2.50 DRILL CIRC PROD 3.501 DRILL !TRIP l PROD 1.001l DRILL CIRC PROD 2.00 i RIGMNT RSRV PROD 12:30 - 17:30 5.00 DRILL TRIP PROD 17:30 - 18:00 0.50 DRILL CIRC PROD 18:00 - 23:00 5.00 DRILL I TRIP PROD 23:00 - 00:00 1.00 DRILL I TRIP PROD Start: 7/30/2005 Rig Release: 8/22/2005 Rig Number: Page r of 8 Spud Date: 7/29/2005 End: 8/22!2005 Group: Description of Operations WOB 8112 k RPM 0160 GPM 233 @ 3100 psi String wt. - PU 220 SO 130 Rot. 167 Torque onloff btm. - 12,000/10,500 ft. lbs. ECD - 10.8 to 11.3 Drilled 6 1/8" horiz. hole w/ motor f/ 17,985' to 18,529' MD 7264' TVD ADT 7.56 hrs. =ART 5.74 hrs. AST 1.82 hrs. WOB 10/13 k RPM 0160 GPM 233 @ 3160 psi String wt. - PU 225 SO 130 Rot. 170 Torque on/off btm. - 13,000/11,500 ft. lbs. ECD - 10.9 to 11.1 Drilled 6 1/8" horiz. hole w/ motor f/ 18,529' to 19,251' MD 7256' ND ADT - 8.56 hrs. =ART 6.93 hrs. AST 1.63 hrs. 1 WOB 9/12 k RPM O/60 GPM 233 @ 3250 psi String wt. PU 225 SO 125 Rot 168 Torque on/off btm. - 13,500/11,500 ft. lbs. ECD - 10.9 to 11.2 ppg Drilled 6 1/8" horiz. hole wl motor f! 19,251' to 19,952' MD 7256' TVD ADT - 7.46 hrs.=ART 6.16 hrs. AST 1.30 hrs. WOB 10/12 k RPM 0160 GPM 233 @ 3250 psi Torque on/off btm. - 14,500112,000 ft. lbs. ECD - 10.9 to 11.3 ppg Drilled 6 1/8" horiz hole f/ 19,952' to 20,606 MD 7254' TVD ADT - 8.40 hrs. =ART 6.40 hrs. AST 2.00 hrs. WOB 8111 k RPM 0160 GPM 233 @ 3260 psi Srring wt. PU 230 SO 120 Rot 165 Torque on/off btm. - 14,000112,500 ft lbs. ECD - 11.1 to 11.4 ppg Drilled 6 118" horiz. hole w/ motor f/ 20,606' to 21,140' MD 7241' TVD ADT - 9.86 hrs. =ART 7.4 hrs AST 2.46 hrs. WOB 7112 k RPM 0/60 GPM 233 @ 3400 psi String wt. PU 235 SO 115 Rot 165 Torque on/off btm. - 15,000/13,000 ft. lbs. ECD 11.2 to 11.4 ppg Drilled 6 1/8" horiz. hole w/ motor f/ 21,140' to 21,178' MD 7241' TVD ADT - 1.38 hrs. =ART 1.38 hrs AST - 0 hrs. WOB 8/12 k RPM 60 GPM 233 @ 3300 psi ~ String wt. PU 255 So 140 Rot 160 Torque on/off btm - 15,000/13,000 ft. lbs. ECD - 11.2 to 11.3 ~ Circ hole clean for change over - 228 gpm @ 3000 psi w/ 60 rpm's ~ PJSM -Displace well f/ 9.3 ppg FloPro to 9.3 ppg brine - 228 gpm @ 1780 psi w/ 60 rpm's -spot LCM pill Monitor well -fluid level dropping -static losses 10 bbls/hr. -POOH on TT to 16,025' -hole in good condition - no over pulls -hole took proper I, fill + 100% excess (10 bbls/ hr losses) Monitor well on TT @ 7" shoe -loss rate 10112 bbls/hr (static) Spot j LCM pill - 233 gpm @ 1500 psi PJSM -Cut & slip drill line -Service TD, draw works & roughneck I Monitored well on TT -loss rate 6 bbls/hr. I POOH on TT fl 16,025' to 6575' -hole still taking excess fill Flow check well -observed fluid level dropping slowly -pumped dry job Continue to POOH on TT f/ 6575' to 376' -laying down 4" DP (195 jts.) Flow check -fluid !eve{ dropping slowly -Handle BHA -change out Printed: 9/20/2005 10:53:10 AM L~ Conac©PhiUips Alaska Opera#ions Summary Report Legal Well Name: CD2-02 Common Well Name: CD2-02 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date ~ Prom - To Hours ' Code ~ de ~ Phase 8/20/2005 ; 23:00 - 00:00 8/21/2005 00:00 - 02:00 02:00 - 02:30 02:30 - 03:00 103:00 - 17:00 1.001 DRILL I TRIP I PROD 2.00 DRILL PULD PROD 0.50 CMPLTN OTHR CMPLTN 0.50 CMPLTN OTHR CMPLTN 14.00 CMPLTNI RUNT CMPLTN 17:00 - 18:00 ~ 1.00 ~ CMPLTNI SEAT CMPLTN 18:00 - 18:30 0.50 CMPLTN OTHR ~ CMPLTN 18:30 - 20:00 1.50 CMPLTN NUND CMPLTN 20:00 - 21:00 1.00 CMPLTN NUND CMPLTN 21:00 - 22:00 1.00 CMPLTN OTHR CMPLTN 22:00 - 00:00 8/22/2005 {00:00-01:30 01:30 - 04:00 2.00; CMPLTNI CIRC CMPLTN 1.50 CMPLTNI FRZP CMPLTN 2.501 CMPLTNI PCKR CMPLTN 04:00 - 05:00 1.00 CMPLTNI OTHR CMPLTN 05:00 - 15:00 10.00 CMPLTNI OTHR CMPLTN 15:00 - 16:00 I 1.001 CMPLTNI OTHR i CMPLTN Start: 7/30/2005 Rig Release: 8122!2005 Rig Number: Page 8 of 8 Spud Date: 7/29/2005 End: 8/22/2005 Group: Description of Operations drilling jars -stand back HWDP -Flush BHA w/ brine + Conqor 404 Hole took 253 bbls brine total during displacement & trip out of hole Std back NM flex DC's -down load MWD -break bit - LD MWD & motor Clean up rig floor - Pufl wear bushing RU to run 4 1/2" completion -PJSM Run 4 1/2" completion (all jts. 4 1/2" 12.6# L-80 IBTM) as follows: WLEG - pup jt - XN nipple w/ RHC plug installed - 1 jt. tbg -pup jt - Baker Premier packer -pup jt. - 2 jts. tbg - pup jt. -Camco GLM w! dummy valve installed - pup jt. - 300 jts. tbg -Camco DB nipple - 53 jts. tbg (356 jts total) - MU hanger & landing jt. -land tbg in wellhaed on FMC tbg hanger w/shoe @ 15,488' - XN nipple @ 15,476' -packer @ 15,415' -GLM @ 15,301' - DB nipple @ 2321' Run in lock down screws - LD landing jt. A -set TWC - MU landing jt. B - test hanger seals to 5000 psi - LD landing jt. B Wash stack -blow down pump lines -kill & choke lines ND riser ~ BOPE -change saver sub in TD NU tree & test to 5000 psi -Pull TWC PJSM - Ru hard lines to tbg & annulus - RU squeeze manifold on rig floor PJSM -Test lines to 3500 psi -Circulated 234 bbls 9.3 ppg inhibited brine - 3 bbls/min @ 250 to 700 psi -followed by 54 bbls (of 290 bbls to pump) diesel @ 3 bbls/min @ 800 psi Continue pumping diesel @ 2.7 bbls/min @ 1150 psi -pumped total of 290 bbls (tbg vol + 2000' TVD into annulus) RU lubricator -drop packer setting rod/ball - RD lubricator -Test lines to 5000 psi -Pressure up on tbg to 4800 psi to set packer -test tbg for 30 mins. Initial pressure 4800 psi -final pressure 4484 psi - monitor annulus 0 psi - U-tube pressure from tbg to annulus -pressure equailzed @ 2000 psi -bleed tbg down to 850 psi -Pressure up on 7" x 4 1/2" annulus to 3500 psi & test for 30 mins. Initial pressure 3500 psi - final pressure 3455 psi -Bleed off annulus to 0 psi -Shut in well - tbg pressure 750 psi -Annulus pressure 0 psi Flush out hard lines & manifold w/ water & air - RD hard lines & manifold - RU FMC lubricator & set BPV - RD lubricator & secure well Install mouse hole -PJSM -Lay down excess 4" drill pipe via mouse hole (309 jts.) derrick management (move 6 3/4" DC's to drillers' side to wt. balance) LD mouse hole Check service lines for rig move Release Rig @ 1600 hrs. Move rig to CD2-01 Printed: 9/20/2005 10:53:10 AM ConocoPhillips Alaska, lnc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-02 Job No. AK ZZ-0003855685, Surveyed; 20 August 2005 Survey Report 8 September, 2005 ' Your Ref: API 501032051300 Surface Coordinates: 5974770.84 N,' 371682.85E (70° 20' 21.4931 " N, 151 ° 02' 28.5386" Vlg Grid Coordinate System: NAD27 Alaska Sfate Planes, Zone 4 Surface Coordinates relative fo Project H Reference: 974770.84 N, 128317.15 W (Grid) Surface Coordinates relafive to Structure: 327.29 N, 40.25 W (True) ' Kelly Bushing Elevation: 52.SOft above Mean Sea Level Kelly Bushing Elevation: 52.50ft above Project V Reference Kelly Bushing Elevation: 52.50ft above Structure ~ ~--~- ~ ~ ~ ~ ~ ~ t ~ ~ Survey Ref.- svy503 A NirNibuttprt Cpmpaxty ConocoPhillips Alaska, lnc. Survey Report for Alpine CD-2 - CD2-02 Your Ref; API 501032051300 Job No. AK ZZ-0003855685, Surveyed: 20 August, 2005 Alaska North Siope North Slope, A/asks Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 16016.41 88.590 304.180 7206.81 7259.31 7032.47 N 11800.45 W 5982004.22 N 360004.48E 13620.82 Tie-On Point 16110.00 92.020 309.660 7206.31 7258.81 7088.65 N 11875.23 W 5982061.68 N 359930.67E 6.907 13714.33 Window Point 16169.41 87.910 312.950 7206.35 7258.85 7127.85 N 11919.85 W 5982101.64 N 359886.73E 8.861 13773.64 16264.99 89.390 317.060 7208.60 7261.10 7195.41 N 11987.39 W 5982170.34 N 359820.35E 4.569 13868.50 16360.50 91.720 316.710 7207.67 7260.17 7265.12 N 12052.66 W 5982241.16 N 359756.29E 2.467 13962.92 16408.43 90.310 314.550 7206.82 7259.32 7299.38 N 12086.17 W 5982275.98 N 359723.37E 5.381 14010.44 16455.67 90.360 316.030 7206.55 7259.05 7332.95 N 12119.40 W 5982310.12 N 359690.72E 3.135 14057.32 16501.17 86.610 316.010 7207.75 7260.25 7365.67 N 12150.98 W 5982343.38 N 359659.70E 8.242 14102.38 16551.25 87.230 315.320 7210.44 7262.94 7401.44 N 12185.93 W 5982379.74 N 359625.37E 1.851 14151.97 16597.16 89.390 315.080 7211.80 7264.30 7434.00 N 12218.26 W 5982412.85 N 359593.60E 4.734 14197.52 16646.86 89.620 315.150 7212.23 7264.73 7469.21 N 12253.33 W 5982448.65 N 359559.14E 0.484 14246.86 16692.52 89.450 314.510 7212.60 7265.10 7501.40 N 12285.71 W 5982481.39 N 359527.31E 1.450 14292.22 16742.36 89.750 315.180 7212.94 7265.44 7536.55 N 12321.05 W 5982517.14 N 359492.58E 1.473 14341.73 16837.95 90.290 318.040 7212.91 7265.41 7606.01 N 12386.71 W 5982587.71 N 359428.12E 3.045 14436.29 16933.27 89.990 317.770 7212.68 7265.18 7676.74 N 12450.61 W 5982659.52 N 359365.44E 0.423 14530.26 17028.62 90.610 320.050 7212.18 7264.68 7748.59 N 12513.27 W 5982732,44 N 359304.02E 2.478 14623.96 17123.82 90.060 321.590 7211.62 7264.12 7822.38 N 12573.41 W 5982807.25 N 359245.15E 1.718 14716.87 17219.33 90.160 323.160 7211.44 7263.94 7898.03 N 12631.72 W 5982883.88 N 359188.14E 1.647 14809.49 17314.66 90.380 325.640 7210.99 7263.49 7975.53 N 12687.21 W 5982962.33 N 359133.99E 2.612 14901.05 17409.66 88.830 330.450 7211.64 7264.14 8056.11 N 12737.47 W 5983043.75 N 359085.11E 5.319 14990.41 17505.42 89.200 331.700 7213.29 7265.79 8139.91 N 12783.78 W 5983128.33 N 359040.25E 1.361 15078.66 17600.84 89.130 331.700 7214.68 7267.18 8223.92 N 12829.01 W 5983213.10 N 358996.46E 0.073 15166.19 17696.45 88.990 330.980 7216.25 7268.75 8307.80 N 12874.86 W 5983297.76 N 358952.05E 0.767 15254.13 17792.04 92.100 333.400 7215.34 7267.84 8392.33 N 12919.44 W 5983383.03 N 358908.92E 4.122 15341.47 17887.56 89.920 333.450 7213.66 7266.16 8477.74 N 12962.17 W 5983469.16 N 358867.66E 2.283 15427.90 17983.10 89.450 333.530 7214.18 7266.68 8563.23 N 13004.81 W 5983555.37 N 358826.49E 0.499 15514.32 18078.58 88.960 333.410 7215.51 7268.01 8648.65 N 13047.45 W 5983641.51 N 358785.31E 0.528 15600.69 18173.96 90.070 332.300 7216.31 7268.81 8733.52 N 13090.97 W 5983727.11 N 358743.26E 1.646 15687.40 18269.70 91.480 331.310 7215.02 7267.52 8817.89 N 13136.20 W 5983812.24 N 358699.48E 1.799 15775.16 18365.14 90.500 329.900 7213.37 7265.87 8901.02 N 13183.03 W 5983896.17 N 358654.07E 1.799 15863.41 18460.77 90.560 330.330 7212.49 7264.99 8983.93 N 13230.68 W 5983979.88 N 358607.85E 0.454 15952.16 18554.89 90.310 329.870 7211.77 7264.27 9065.52 N 13277.60 W 5984062.26 N 358562.34E 0.556 16039.51 18650.60 89.510 329.560 7211.92 7264.42 9148.17 N 13325.86 W 5984145.72 N 358515.50E 0.896 16128.58 18746.04 89.880 328.280 7212.43 7264.93 9229.91 N 13375.13 W 5984228.29 N 358467.63E 1.396 16217.88 18841.54 90.190 328.380 7212.37 7264.87 9311.19 N 13425.27 W 5984310.41 N 358418.89E 0.341 16307.57 8 September, 2005 -10:21 Page 2 of 4 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report forA/pioe CD-2 - CD2-02 Your Ref.• AP/ 501032051300 Job No. AK ZZ-0003855685, Surveyed: 20 August 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coord inates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 18937.09 91.970 330.640 7210.57 7263.07 9393.50 N 13473.74 W 5984393.54 N 358371.84E 3.010 16396.60 19032.66 91.790 330.450 7207.43 7259.93 9476.67 N 13520.71 W 5984477.51 N 358326.30E 0.274 16484.97 19128.23 90.920 330.980 7205.17 7257.67 9560.00 N 13567.44 W 5984561.63 N 358281.00E 1.066 16573.27 19223.64 90.490 329.860 7204.00 7256.50 9642.97 N 13614.54 W 5984645.39 N 358235.33E 1.257 16661.61 19319.30 90.250 329.390 7203.38 7255.88 9725.50 N 13662.91 W 5984728.73 N 358188.38E 0.552 16750.69 19414.78 90.680 331.130 7202.61 7255.11 9808.40 N 13710.27 W 5984812.43 N 358142.45E 1.877 16839.21 19510.02 90.130 332.210 7201.93 7254.43 9892.22 N 13755.46 W 5984897.02 N 358098.69E 1.273 16926,60 • 19605.09 90.300 332.850 7201.58 7254.08 9976.57 N 13799.31 W 5984982.11 N 358056.29E 0.697 17013.26 19700.52 90.070 333.240 7201.27 7253.77 10061.64 N 13842.57 W 5985067.90 N 358014.49E 0.474 17099.89 19795.96 89.570 331.780 7201.57 7254.07 10146.30 N 138$6.62 W 5985153.30 N 357971.90E 1.617 17186.90 19891.42 89.190 331.700 7202.60 7255.10 10230.37 N 13931.82 W 5985238.14 N 357928.15E 0.407 17274.45 19986.89 90.290 332.060 7203.04 7255.54 10314.57 N 13976.81 W 5985323.09 N 357884.60E 1.212 17361.91 20081.80 89.880 331.920 7202.89 7255.39 10398.37 N 14021.39 W 5985407.64 N 357841.47E 0.456 17448.79 20177.38 89.250 331.290 7203.62 7256.12 10482.44 N 14066.84 W 5985492.48 N 357797.46E 0.932 17536.53 20272.94 89.260 331.360 7204.86 7257.36 10566.28 N 14112.69 W 5985577.08 N 357753.05E 0.074 17624.44 20368.56 91.960 334.190 7203.85 7256.35 10651.28 N 14156.42 W 5985662.83 N 357710.78E 4.090 17711.41 20464.13 91.520 333.510 7200.94 7253.44 10737.03 N 14198.52 W 5985749.28 N 357670.15E 0.847 17797.56 20559.64 89.020 332.990 7200.49 7252.99 10822.31 N 14241.51 W 5985835.28 N 357628.63E 2.674 17884.12 20655.20 88.710 332.170 7202.39 7254.89 10907.12 N 14285.50 W 5985920.83 N 357586.10E 0.917 17971.17 20750.33 88.650 331.820 7204.58 7257.08 10991.08 N 14330.16 W 5986005.55 N 357542.88E 0.373 18058.23 20845.77 88.280 331.600 7207.13 7259.63 11075.10 N 14375.38 W 5986090.32 N 357499.11E 0.451 18145.75 20941.40 91.150 329.450 7207.61 7260.11 11158.33 N 14422.42 W 5986174.35 N 357453.50E 3.750 18234.23 21036.69 95.040 328.560 7202.47 7254.97 11239.88 N 14471.41 W 5986256.73 N 357405.91E 4.187 18323.18 21129.76 95.760 328.250 7193.71 7246.21 11318.80 N 14519.95 W 5986336.47 N 357358.72E 0.842 18410.17 21178.00 95.760 328.250 7188.87 7241.37 11359.62 N 14545.21 W 5986377.71 N 357334.17E 0.000 18455.27 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.5' MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are rel ative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees pe r 100 feet (US Survey). Vertical Sectio n is from Well and calculated along an Azimuth of 308.251° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 21178.OOft., The Bottom Hole Displacement is 18455.46ft., in the Direction of 307.989° (True}. 8 September, 2005 - 10:21 Page 3 of 4 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report forA/pine CD-2 -CD2-02 Your Ref.• AP/ 501032051300 Job No. AK ZZ-0003855685, Surveyed: 20 August, 2005 Alaska North S/ope North S/ope, Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 16016.41 7259.31 7032.47 N 11800.45 W Tie-On Point 16110.00 7258.81 7088.65 N 11875.23 W Window Point " 21178.00 7241.37 ~ 11359.62 N 14545.21 W . Projected Surrey Survey tool program for CD2-02 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 529.40 526.68 CB-SS-Gyro (CD2-02PB1) 529.40 526.68 21178.00 7241.37 MWD+IIFR+MS+SAG (CD2-02P61) • 8 September, 2005 - 10:21 Page 4 of 4 DrillQuest 3.03.06.008 ConocoPhillips A/aska, lnc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-02P61 Job No. AK ZZ-0003855685, Surveyed: 13 August, 2005 Survey Report 8 September, 2005 Your Ref: API 501032051370 • Surface Coordinates: 5974770.84 N, 371682.85E (70° 20' 21.4931 " N, 151 ° 02' 28.5386" IN) Grid Coordinate Sysfem: NAD2T A/aska State Planes, Zone 4 Surface CooMinates relative to Project H Reference: 974770.84 N, 128317.15 W (Grid) Surface Coordinates relative to Structure: 327.29 N, 40.25 W (True) Kelly Bushing Elevation: 52.50ft above Mean Sea Level Kelly Bushing Elevation: 52.50ft above Project V Reference Kelly Bushing Elevation: 52.50ft above Sfructure ~ ~ ~ ~- L- ~ ~ ~ ~ ~/ ~ ~ ~ Survey Ref: svy502 A HaUlburtar Goattpa~y ConocoPhillips Alaska, lnc. Survey Report forA/pine CD-2 - CD2-02PB1 Your Ref: APl 501032051370 Job No. AK ZZ-0003855685, Surveyed: 13 August, 2005 Alaska North Slope Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -52.50 0.00 0.00 N 0.00E 5974770.84 N 371682.85E ~ 0.00 80.85 0.500 98.000 28.35 80.85 0.05 S 0.35E 5974770.78 N 371683.20E 0.618 -0.30 169.23 0.500 256.000 116.73 169.23 0.20 S 0.36E 5974770.64 N 371683.20E 1.111 -0.40 258.03 2.300 270.000 205.50 258.00 0.29 S 1.80 W 5974770.58 N 371681.04E 2.048 1.23 348.52 5.800 286.000 295.75 348.25 0.97 N 8.01 W 5974771.95 N 371674.85E 4.027 6.89 440.60 9.600 298.000 386.99 439.49 5.86 N 19.27 W 5974777.03 N 371663.68E 4.459 18.76 529.40 12.200 299.000 474.18 526.68 13.89 N 34.02 W 5974785.31 N 371649.08E 2.936 35.31 567.79 13.380 297.830 511.62 564.12 17.93 N 41.49 W 5974789.47 N 371641.67E 3.147 43.68 657.61 14.610 300.030 598.77 651.27 28.45 N 60.49 W 5974800.32 N 371622.85E 1.492 65.12 746.54 16.740 294.950 684.39 736.89 39.47 N 81.82 W 5974811.70 N 371601.72E 2.847 88.69 836.93 21.140 294.870 769.87 822.37 51.82 N 108.42 W 5974824.51 N 371575.33E 4.868 117.22 933.54 25.280 300.370 858.65 911.15 69.58 N 142.04 W 5974842.84 N 371542.02E 4.833 154.63 1028.62 29.560 301,800 943.03 995.53 92.22 N 179.51 W 5974866.12 N 371504.94E 4.554 198.06 1123.42 36.830 301.440 1022.30 1074.80 119.40 N 223.68 W 5974894.05 N 371461.24E 7.672 249.58 1218.28 37.740 302.420 1097.78 1150.28 149.79 N 272.45 W 5974925.27 N 371413.00E 1.145 306.69 1313.45 38.680 299.570 1172.56 1225.06 180.09 N 322.91 W 5974956.43 N 371363.07E 2.099 365.07 1408.33 46.450 300.640 1242.39 1294.89 212.29 N 378.36 W 5974989.57 N 371308.18E 8.224 428.56 1504.30 48.580 301.090 1307.20 1359.70 248.60 N 439.11 W 5975026.92 N 371248.06E 2.246 498.74 1598.67 51.290 301.130 1367.94 1420.44 285.91 N 500.94 W 5975065.28 N 371186.88E 2.872 570.40 1693.85 54.770 300.840 1425.17 1477.67 325.05 N 566.12 W 5975105.53 N 371122.37E 3.664 645.82 1788.98 58.520 300.110 1477.47 1529.97 365.33 N 634.60 W 5975146.9$ N 371054.60E 3.994 724.53 1884.31 62.280 298.810 1524.55 1577.05 406.08 N 706.76 W 5975188.95 N 370983.14E 4.118 806.43 1979.40 64.940 299.350 1566.81 1619.31 447.48 N 781.19 W 5975231.62 N 370909.43E 2.843 890.51 2074.66 66.670 299.570 1605.85 1658.35 490.21 N 856.85 W 5975275.64 N 370834.52E 1.828 976.38 2169.76 68.080 299.180 1642.44 1694.94 533.27 N 933.34 W 5975320.00 N 370758.77E 1.530 1063.11 2264.84 65.340 298.580 1680.03 1732.53 575.45 N 1009.80 W 5975363.48 N 370683.04E 2.939 1149.27 2360.54 65.350 298.890 1719.95 1772.45 617.26 N 1086.07 W 5975406.60 N 370607.50E 0.295 1235.05 2455.62 65.400 299.110 1759.56 1812.06 659.16 N 1161.66 W 5975449.79 N 370532.64E 0.217 1320.36 2550.47 64.920 299.500 1799.41 1851.91 701.29 N 1236.72 W 5975493.20 N 370458.31E 0.629 1405.38 2644.50 64.940 300.400 1839.25 1891.75 743.81 N 1310.52 W 5975536.97 N 370385.25E 0.867 1489.66 2739.86 64.460 299.980 1880.01 1932.51 787.17 N 1385.04 W 5975581.60 N 370311.49E 0.642 1575.02 2835.74 66.830 300.160 1919.54 1972.04 830.93 N 1460.62 W 5975626.65 N 370236.66E 2.478 1661.47 2930.70 66.260 300.080 1957.34 2009.84 874.65 N 1535.98 W 5975671.64 N 370162.07E 0.605 1747.71 3024.90 65.860 300.120 1995.56 2048.06 917.83 N 1610.46 W 5975716.09 N 370088.33E 0.426 1832.94 3120.05 65.970 299.480 2034.39 2086.89 960.99 N 1685.84 W 5975760.54 N 370013.70E 0.625 1918.86 North Slope, Alaska Comment CB-SS-Gyro MWD+IIFR+MS+SAG • • 8 September, 2005 - 10:10 Page 2 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report forA/plne CD-2 - CD2-02P61 Your Ref: AP/ 501032051370 Job No. AK-ZZ-0003855685, Surveyed: 13 August, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 3215.01 65.060 300.170 2073.75 2126.25 1003.97 N 1760.81 W 5975804.80 N 369939.48E 1.164 2004.35 3309.58 64.930 299.580 2113.73 2166.23 1046.66 N 1835.13 W 5975848.76 N 369865.90E 0.582 2089.14 3404.26 65.920 299.890 2153.10 2205.60 1089.37 N 1909.89 W 5975892.74 N 369791.88E 1.087 2174.29 3500.90 67.930 299.930 2190.98 2243.48 1133.70 N 1986.96 W 5975938.38 N 369715.59E 2.080 2262.25 3595.37 67.350 300.910 2226.92 2279.42 1177.94 N 2062.30 W 5975983.90 N 369641.01E 1.139 2348.80 3691.23 67.190 301.780 2263.96 2316.46 1223.93 N 2137.81 W 5976031.17 N 369566.30E 0.854 2436.58 3786.43 67.020 302.220 2300.99 2353.49 1270.40 N 2212.18 W 5976078.91 N 369492.73E 0.462 • 2523.75 3819.62 66.870 302.450 2313.99 2366.49 1286.74 N 2237.98 W 5976095.69 N 369467.21E 0.782 2554.13 3927.44 67.050 302.000 2356.19 2408.69 1339.64 N 2321.92 W 5976150.02 N 369384.20E 0.419 2652.80 4022.28 66.650 301.820 2393.47 2445.97 1385.74 N 2395.94 W 5976197.38 N 369310.97E 0.456 2739.47 4117.09 66.360 300.950 2431.27 2483.77 1431.02 N 2470.17 W 5976243.92 N 369237.53E 0.895 2825.80 4213.46 65.490 300.980 2470.58 2523.08 1476.29 N 2545.62 W 5976290.48 N 369162.87E 0.903 2913.07 4307.87 65.080 299.950 2510.06 2562.56 1519.77 N 2619.54 W 5976335.22 N 369089.71E 1.082 2998.04 4402.52 65.090 301.670 2549.93 2602.43 1563.74 N 2693.26 W 5976380.44 N 369016.75E 1.648 3083.16 4497.82 64.740 301.760 2590.34 2642.84 1609.11 N 2766.68 W 5976427.06 N 368944.11E 0.377 3168.91 4592.80 66.720 303.990 2629.38 2681.88 1656.12 N 2839.38 W 5976475.31 N 368872.22E 2.988 3255.10 4688.67 66.230 303.260 2667.65 2720.15 1704.79 N 2912.58 W 5976525.23 N 368799.87E 0.865 3342.71 4783.56 66.630 301.170 2705.59 2758.09 1751.15 N 2986.16 W 5976572.84 N 368727.10E 2.062 3429.20 4878.84 67.520 300.230 2742.71 2795.21 1795.95 N 3061.61 W 5976618.92 N 368652.42E 1,303 3516.19 4973.68 67.230 299.850 2779.19 2831.69 1839.78 N 3137.39 W 5976664.04 N 368577.40E 0.480 3602.83 5068.54 66.650 298.940 2816.35 2868.85 1882.62 N 3213.44 W 5976708.17 N 368502.10E 1.074 3689.07 5163.55 65.820 298.690 2854.64 2907.14 1924.53 N 3289.62 W 5976751.38 N 368426.64E 0.906 3774.85 5258.82 64.880 299.420 2894.37 2946.87 1966.57 N 3365.31 W 5976794.72 N 368351.68E 1.208 3860.32 5354.16 65.010 299.130 2934.75 2987.25 2008.81 N 3440.65 W 5976838.24 N 368277.08E 0.307 3945.63 5449.92 64.850 300.120 2975.32 3027.82 2051.68 N 3516.05 W 5976882.40 N 368202.43E 0.951 4031.39 5544.93 64.000 301.030 3016.34 3068.84 2095.27 N 3589.83 W 5976927.24 N 368129.40E 1.244 4116.32 5639.95 64.010 300.920 3057.99 3110.49 2139.23 N 3663.06 W 5976972.44 N 368056.93E 0.105 4201.04 5735.31 65.170 301.490 3098.90 3151.40 2183.86 N 3736.73 W 5977018.33 N 367984.04E 1.331 4286.52 5830.24 66.780 301.490 3137.55 3190.05 2229.15 N 3810.67 W 5977064.87 N 367910.89E 1.696 4372.62 5925.46 66.440 302.060 3175.35 3227.85 2275.17 N 3884.96 W 5977112.16 N 367837.39E 0.655 4459.46 6021.03 65.690 303.260 3214.13 3266.63 2322.30 N 3958.50 W 5977160.55 N 367764.67E 1.390 4546.39 6116.36 65.420 302.430 3253.58 3306.08 2369.37 N 4031.41 W 5977208.86 N 367692.58E 0.842 4632.79 6211.39 66.040 302.550 3292.64 3345.14 2415.91 N 4104.48 W 5977256.63 N 367620.31E 0.663 4718.98 6306.84 66.710 302.850 3330.89 3383.39 2463.15 N 4178.07 W 5977305.13 N 367547.54E 0.759 4806.02 6402.59 67.780 302.750 3367.92 3420.42 2510.98 N 4252.29 W 5977354.22 N 367474.15E 1.122 4893.92 8 September, 2005 -10:10 Page 3 of 7 DrillQuest 3,03,06.008 ConocoPhillips Alaska, lnc. Survey Report for A/pine CD-2 - CD2-02P81 Your Ref.• AP/ 501032051370 Job No. AK ZZ-0003855685, Surveyed: 13 August 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section 6497.70 69.040 301.530 3402.92 3455.42 2558.02 N 4327.18 W 5977402.54 N 367400.08E 1.783 4981.85 6592.61 68.910 299.730 3436.98 3489.48 2603.16 N 4403.40 W 5977448.97 N 367324.64E 1.776 5069.65 6687.36 67.850 300.320 3471.89 3524.39 2647.23 N 4479.66 W 5977494.35 N 367249.14E 1.260 5156.83 6782.66 67.290 298.650 3508.25 3560.75 2690.59 N 4556.34 W 5977539.01 N 367173.22E 1.723 5243.89 6877.63 67.590 298.560 3544.68 3597.18 2732.58 N 4633.34 W 5977582.31 N 367096.95E 0.328 5330.35 6973.53 66.830 298.560 3581.83 3634.33 2774.85 N 4710.99 W 5977625.90 N 367020.03E 0.792 5417.50 7067.80 66.290 298.650 3619.33 3671.83 2816.26 N 4786.93 W 5977668.60 N 366944.82E 0.579 5502.77 7163.54 65.760 299.280 3658.23 3710.73 2858.62 N 4863.46 W 5977712.27 N 366869.02E 0.817 5589.10 7258.61 65.690 300.030 3697.32 3749.82 2901.50 N 4938.78 W 5977756.43 N 366794.45E 0.723 5674.79 7353.73 64.930 300.580 3737.05 3789.55 2945.11 N 5013.39 W 5977801.31 N 366720.59E 0.956 5760.38 7449.14 64.470 301.460 3777.83 3830.33 2989.56 N 5087.31 W 5977847.02 N 366647.44E 0.963 5845.95 7544.39 64.130 300.580 3819.13 3871.63 3033.79 N 5160.86 W 5977892.50 N 366574.66E 0.906 5931.10 7639.53 63.790 300.670 3860.90 3913.40 3077.33 N 5234.42 W 5977937.30 N 366501.86E 0.367 6015.82 7734.80 63.590 300.340 3903.13 3955.63 3120.68 N 5308.00 W 5977981.90 N 366429.03E 0.375 6100.45 7829.85 64.600 302.610 3944.66 3997.16 3165.33 N 5380.91 W 5978027.79 N 366356.90E 2.397 6185.34 7924.83 63.520 302.750 3986.20 4038.70 3211.44 N 5452.80 W 5978075.13 N 366285.81E 1.145 6270.35 8020.05 64.350 301.740 4028.04 4080.54 3257.08 N 5525.14 W 5978121.99 N 366214.25E 1.291 6355.41 8115.13 65.910 302.370 4068.03 4120.53 3302.86 N 5598.25 W 5978169.02 N 366141.94E 1.747 6441.17 8210.40 66.120 301.930 4106.75 4159.25 3349.18 N 5671.95 W 5978216.59 N 366069.05E 0.476 6527.72 8305.41 65.840 302.860 4145.43 4197.93 3395.67 N 5745.22 W 5978264.33 N 365996.58E 0.941 6614.04 8399.93 66.510 303.160 4183.61 4236.11 3442.78 N 5817.73 W 5978312.67 N 365924.89E 0.766 6700.15 8495.70 67.780 301.550 4220.81 4273.31 3490.00 N 5892.28 W 5978361.16 N 365851.16E 2.039 6787.92 8592.06 66.840 299.180 4257.98 4310.48 3534.94 N 5968.97 W 5978407.41 N 365775.25E 2.470 6875.98 8687.10 66.520 299.200 4295.61 4348.11 3577.50 N 6045.17 W 5978451.27 N 365699.79E 0.337 6962.17 8782.68 66.090 297.960 4334.02 4386.52 3619.37 N 6122.02 W 5978494.45 N 365623.67E 1.270 7048.44 8877.95 65.890 299.300 4372.78 4425.28 3661.07 N 6198.40 W 5978537.45 N 365548.01E 1.302 7134.24 8973.35 65.270 299.340 4412.22 4464.72 3703.61 N 6274.14 W 5978581.27 N 365473.01E 0.651 7220.05 9068.74 65.220 299.440 4452.17 4504.67 3746.12 N 6349.62 W 5978625.07 N 365398.27E 0.109 7305.64 9163.36 64.620 299.860 4492.28 4544.78 3788.51 N 6424.10 W 5978668.73 N 365324.53E 0.751 7390.38 9258.75 65.500 300.000 4532.50 4585.00 3831.67 N 6499.05 W 5978713.17 N 365250.32E 0.932 7475.96 9353.89 65.630 301.720 4571.86 4624.36 3876.10 N 6573.41 W 5978758.86 N 365176.74E 1.652 7561.86 9449.05 65.220 302.010 4611.43 4663.93 3921.78 N 6646.90 W 5978805.80 N 365104.03E 0.512 7647.86 9544.25 64.950 302.990 4651.54 4704.04 3968.17 N 6719.72 W 5978853.43 N 365032.02E 0.976 7733.76 9639.53 65.680 301.630 4691.33 4743.83 4014.44 N 6792.89 W 5978900.94 N 364959.66E 1.506 7819.87 9734.80 65.960 302.270 4730.35 4782.85 4060.43 N 6866.63 W 5978948.19 N 364886.71E 0.680 7906.25 North Slope, Alaska Comment • 8 September, 2005 - 10:10 Page 4 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, /nc. Survey Report forA/pine CD-2 - CD2-02P61 Your Ref: APl 501032051370 Job No. AK-ZZ-0003855685, Surveyed: 13 August, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9829.52 66.160 302.380 4768.79 4821.29 4106.72 N 6939.79 W 5978995.72 N 364814.36E 0.236 7992.36 9925.23 66.180 300.650 4807.46 4859.96 4152.48 N 7014.42 W 5979042.76 N 364740.52E 1.654 8079.30 10020.27 66.290 300.620 4845.76 4898.26 4196.81 N 7089.26 W 5979088.35 N 364666.45E 0.119 8165.52 10115.54 66.160 301.120 4884.17 4936.67 4241.54 N 7164.10 W 5979134.36 N 364592.39E 0.499 8251.98 10210.62 66.690 300.710 4922.20 4974.70 4286.31 N 7238.86 W 5979180.41 N 364518.40E 0.683 8338.41 10305.24 66.690 301.930 4959.64 5012.14 4331.48 N 7313.09 W 5979226.84 N 364444.95E 1.184 8424.67 10400.64 66.240 299.520 4997.74 5050.24 4376.17 N 7388.27 W 5979272.80 N 364370.55E 2.364 8511.37 10495.88 64.660 299.210 5037.31 5089.81 4418.65 N 7463.77 W 5979316.57 N 364295.79E 1.685 8596.96 10590.64 64.000 299.260 5078.36 5130.86 4460.36 N 7538.29 W 5979359.55 N 364221.99E 0,698 8681.31 10685.84 64.950 299.650 5119.38 5171.88 4502.60 N 7613.10 W 5979403.07 N 364147.92E 1.064 8766.21 10781.55 65.000 300.130 5159.86 5212.36 4545.82 N 7688.29 W 5979447.57 N 364073.48E 0.457 8852.01 10876.70 65.550 301.340 5199.66 5252.16 4589.99 N 7762.57 W 5979493.00 N 363999.97E 1.292 8937.69 10972.05 65.230 301.700 5239.37 5291.87 4635.31 N 7836.47 W 5979539.58 N 363926.85E 0.480 9023.78 11067.40 66.450 302.870 5278.40 5330.90 4681.78 N 7910.01 W 5979587.30 N 363854.12E 1.700 9110.31 11162.48 66.780 301.950 5316.14 5368.64 4728.56 N 7983.69 W 5979635,33 N 363781.25E 0.954 9197.12 11257.87 65.550 300.420 5354.68 5407.18 4773.74 N 8058.33 W 5979681.78 N 363707.40E 1.953 9283.71 11352.92 65.700 300.630 5393.91 5446.41 4817.71 N 8132.90 W 5979727.03 N 363633.58E 0.256 9369.50 11447.89 65.890 300.180 5432.85 5485.35 4861.55 N 8207.61 W 5979772.14 N 363559.64E 0.476 9455.31 11543.33 66.430 301.750 5471.43 5523.93 4906.47 N 8282.46 W 5979818.33 N 363485.57E 1.608 9541.90 11638.86 65.630 301.990 5510.24 5562.74 4952.56 N 8356.59 W 5979865.68 N 363412.23E 0.868 9628.65 11733.70 65.580 301.800 5549.41 5601.91 4998.19 N 8429.93 W 5979912.56 N 363339.69E 0.190 9714.49 11828.90 66.300 299.760 5588.22 5640.72 5042.67 N 8504.61 W 5979958.31 N 363265.79E 2.098 9800.68 11924.22 66.320 299.310 5626.52 5679.02 5085.70 N 8580.55 W 5980002.64 N 363190.59E 0.433 9886.96 12018.83 66.450 300.160 5664.42 5716.92 5128.69 N 8655.82 W 5980046.91 N 363116.06E 0.835 9972.69 12114.29 65.430 300.340 5703.34 5755.84 5172.61 N 8731.12 W 5980092.11 N 363041.53E 1.082 10059.00 12209.38 64.820 300.410 5743.34 5795.84 5216.23 N 8805.55 W 5980137.00 N 362967.86E 0.645 10144.46 12304.48 65.750 300.760 5783.10 5835.60 5260.18 N 8879.91 W 5980182.22 N 362894.25E 1.033 10230.07 12400.00 66.460 301.440 5821.79 5874.29 5305.29 N 8954.69 W 5980228.60 N 362820.26E 0.988 10316.72 12495.38 66.860 302.260 5859.58 5912.08 5351.51 N 9029.08 W 5980276.08 N 362746.67E 0.894 10403.75 12590.69 66.240 302.630 5897.51 5950.01 5398.42 N 9102.87 W 5980324.25 N 362673.70E 0.742 10490.74 12685.60 65.700 301.430 5936.16 5988.66 5444.39 N 9176.36 W 5980371.47 N 362601.01E 1.287 10576.91 12780.79 66.030 300.380 5975.08 6027.58 5489.01 N 9250.89 W 5980417.36 N 362527.25E 1.065 10663.07 12876.21 66.370 301.150 6013.59 6066.09 5533.67 N 9325.91 W 5980463.29 N 362453.01E 0.820 10749.63 12971.19 66.860 300.070 6051.29 6103.79 5578.05 N 9400.94 W 5980508.96 N 362378.75E 1.164 10836.03 13066.63 65.700 299.900 6089.68 6142.18 5621.72 N 9476.62 W 5980553.92 N 362303.83E 1.226 10922.50 North Slope, Alaska Comment • • 8 September, 2005 - 10:10 Page 5 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report forA/p/ne CD-2 - CD2-02PB1 Your Ref.- API 501032051370 Job No. AK ZZ-0003855685, Surveyed: 13 August 2005 Alaska North Slope Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 13161.50 65.420 300.120 6128.93 6181.43 5664.92 N 9551.41 W 5980598.39 N 362229.79E 0.363 11007.97 13256.60 64.820 299.280 6168.94 6221.44 5707.67 N 9626.35 W 5980642.41 N 362155.59E 1.020 11093.29 13351.89 65.300 299.430 6209.12 6261.62 5750.02 N 9701.66 W 5980686.05 N 362081.02E 0.524 11178.65 13446.94 65.100 299.610 6248.99 6301.49 5792.54 N 9776.74 W 5980729.84 N 362006.67E 0.272 11263.94 13541.57 66.710 302.490 6287.63 6340.13 5837.10 N 9850.73 W 5980775.66 N 361933.46E 3.258 11349.63 13636.83 67.170 302.780 6324.94 6377.44 5884.36 N 9924.54 W 5980824.18 N 361860.47E 0.558 11436.85 13732.47 66.700 302.450 6362.41 6414.91 5931.79 N 9998.66 W 5980872.87 N 361787.17E 0.585 11524.42 13827.54 64.540 301.650 6401.65 6454.15 5977.75 N 10072.04 W 5980920.08 N 361714.58E 2.398 11610.50 13923.01 64.950 300.940 6442.39 6494.89 6022.60 N 10145.82 W 5980966.18 N 361641.58E 0.798 11696.21 14018.36 65.640 301.910 6482.24 6534.74 6067.76 N 10219.74 W 5981012.60 N 361568.45E 1.174 11782.22 14113.33 65.610 302.570 6521.43 6573.93 6113.91 N 10292.91 W 5981060.00 N 361496.08E 0.634 11868.25 14208.55 65.610 299.290 6560.76 6613.26 6158.47 N 10367.28 W 5981105.83 N 361422.48E 3.137 11954.25 14303.91 66.380 299.630 6599.56 6652.06 6201.32 N 10443.13 W 5981149.96 N 361347.38E 0.871 12040.34 14399.20 65.910 299.160 6638.09 6690.59 6244.09 N 10519.06 W 5981194.03 N 361272.19E 0.668 12126.45 14494.51 66.160 299.580 6676.81 6729.31 6286.81 N 10594.96 W 5981238.04 N 361197.03E 0.481 12212.49 14589.51 64.470 299.100 6716.48 6768.98 6329.10 N 10670.20 W 5981281.62 N 361122.53E 1.837 12297.77 14684.64 64.560 301.250 6757.42 6809.92 6372.26 N 10744.43 W 5981326.04 N 361049.04E 2.042 12382.78 14779.44 64.940 301.280 6797.86 6850.36 6416.76 N 10817.72 W 5981371.79 N 360976.53E 0.402 12467.89 14874.50 66.600 302.720 6836.87 6889.37 6462.70 N 10891.23 W 5981418.98 N 360903.82E 2.227 12554.05 14969.82 66.380 303.480 6874.89 6927.39 6510.44 N 10964.45 W 5981467.96 N 360831.42E 0.767 12641.11 15064.76 66.780 301.860 6912.63 6965.13 6557.46 N 11037.78 W 5981516.23 N 360758.91E 1.621 12727.81 15160.36 65.770 301.960 6951.09 7003.59 6603.72 N 11112.07 W 5981563.76 N 360685.41E 1.061 12814.79 15255.47 66.090 300.460 6989.89 7042.39 6648.71 N 11186.34 W 5981610.02 N 360611.93E 1.479 12900.97 15350.79 66.870 301.300 7027.93 7080.43 6693.57 N 11261.35 W 5981656.15 N 360537.70E 1.150 12987.65 15446.23 66.640 302.170 7065.59 7118.09 6739.70 N 11335.93 W 5981703.55 N 360463.91E 0.872 13074.78 15540.11 68.990 300.820 7101.04 7153.54 6785.10 N 11410.06 W 5981750.21 N 360390.58E 2.835 13161.09 15635.26 71.930 302.650 7132.86 7185.36 6832.27 N 11486.30 W 5981798.68 N 360315.16E 3.582 13250.17 15730.70 74.330 302.530 7160.56 7213.06 6881.46 N 11563.25 W 5981849.18 N 360239.06E 2.518 13341.05 15824.41 77.950 301.930 7183.00 7235.50 6929.97 N 11640.20 W 5981899.00 N 360162.95E 3.913 13431.52 15921.37 82.520 302.150 7199.45 7251.95 6980.65 N 11721,18 W 5981951.06 N 360082.85E 4.719 13526.49 16016.41 88.590 304.180 7206.81 7259.31 7032.47 N 11800.45 W 5982004.22 N 360004.48E 6.732 13620.82 16110.97 92.060 309.720 7206.27 7258.77 7089.27 N 11875.98 W 5982062.31 N 359929.93E 6.912 13715.30 16174.99 93.050 308.560 7203.42 7255.92 7129.64 N 11925.58 W 5982103.53 N 359881.03E 2.381 13779.25 16216.00 93.050 308.560 7201.24 7253.74 7155.17 N 11957,60 W 5982129.60 N 359849.45E 0.000 13820.20 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.5' MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. North Slope, A/aska Comment • • Projected Survey 8 September, 2005 -10:10 Page 6 of T DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report forA/pine CD-2 -CD2-02PB1 Your Ref.• APl 501032051370 Job No. AK-ZZ-0003855685, Surveyed: 13 August 2005 Alaska North Slope North Slope, Alaska The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 308.251° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16216.OOft., The Bottom Hole Displacement is 13934.87ft., in the Direction of 300.895° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 16216.00 7253.74 7155.17 N 11957.60 W Projected Survey Survey tool program for CD2-02PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 529.40 526.68 GB-SS-Gyro 529.40 526.68 16216.00 7253.74 MWD+IIFR+MS+SAG • 8 September, 2005 -10:10 Page 7 of 7 DriOQuesf 3.03.06.008 r - ~ a~ s - ~ ~ MEC:~A.NICAL INTEGRITY REPORT °UD L'.: ~ : ~ OPER ~ FZELD L.P ~ ~ ~~~~h~ =.. G r S ~ :. ~ ~ ~, . ~ iiLL NU2rID ER ~..~ ~ O ~-- n~ LL DAT~_ TD : a ~\~~,?~.. °Zl~s~i T'V~D ; ?BTD : 5;,,r~,~ ?ID TVD ~~ S 5 Cas i^g : ~1 Shoe : l(oU'-1,~6 MD '~l~O'1 TVD ; uV : ~pr ?~1? ~ ~.I'~~i __:~eT . ~~. Shoe . '~ T`TD ; '~CP . '~~ 'i~ -'uo'--- v ~~~~ Packer t54'1l '~ ~~\~`~ TVD; Set « ~.~~- ~-`~~~ ole Sipe ~j ~~~ and ~ ~~~y ; Perks O ~t...t~, to ~p\C~ 1 ~ C~'-t.4S -- a ~ t ~~' '~C'r'.~?~_C~7J 1NTEGRTTY - P?.RT #} acp~ ;~~- pt~Q\r-~c 0 S~,a-~ rnnnlus Press Test: l~ `' ~-rim: ~~ 15 nin 3~t'1O :,0 min 355. Con~e:~ts : ~~~- .~,,hccr, c.n~,fl~ ~~c v.~E« + w~~r.Ss_~ ~~` l,-' ~rc.CSc_ 5 " C'~... '~'CHP?~TICc"_!.. ! 3~1TEGRTT~ _ PST #2 ~"--~' 3 3 ~p~O~S Cement Voltanes :~ Amt. Liner 1'~ D.. Csg ~(o~.. S~ DV~~ C.ut :rol to cover oers `~ ~. Ste. 5~.1~~ C.'Z2tiSc ~O Cf J~~ ~~ e o r e t i c a l T O C ~ ~~~p ~iC ~, `~'~ C.. ' ;- ~ ~-{c1 c~-~ \ `{' S ~( sz ~ ~c-~ct~ a~,.~ c-. Cement Bond Log (Yes or No) ~,rc,5„ ; In AOGCC Fide C5L Evaluation, zone above perfs -}~ -~-Jh'~. ~~-~;,~ t _ Production Log; "Pype Evaluation CONGLJSI ?art 11 ?ar~ l2. ~~~ y~~~ t~~aa`flS~ Re: CD2-02: Approval Request to Commence Injection • Subjects: Re: CD2-02: Approval Request to Commence lnjectio~~ From: Thoirlas Maunder <tom maunder@adminatate.ak. a s=> Dater Thu, 22 Dec 2005 11:08:25 -0900.. To: "I~ianson, Kcili L" ~'KeIIi.L.Hanson(ci~coni~cophillips.com-~ C(': "Sehn~idcr, Cim S." -~ I~im.~.Schnciciet~'u'ri~n~~co~hillips.eom= ",Mono. Chris~~ °~-C}Iris.,~lon~oi~iconoco~hillips.com >. "~~llsup-Drake.. Sharon h" -~Sharun.K.Vlsup-Dail.er~~'corlc,cophillips.com'-~. "Johnson, Vern" ~~~~~`crn..lo{~nsc,n ~i~.conoeophillihs.conl=~. "i'ierson, Chris IZ" ~ _Chris.K.l'icrsou~iilconocophillips.cons%, ~IOGC(' North Slof~c Office ~=au~~cc__pruciho~ bay;"u,~a~i~~in.state.ak_us= Kelli, et al: ~~~ ~i~~ I have examined the information with regard to CD2-02 and concur with your assessment. By copy of this email, you have approval to place the well in service. Once the well has warmed up, please make arrangements for the Inspector to witness a MIT. Call or message with any questions. Tom Maunder, PE ~~~~~~~,~~~~ ~~~ t Lr~ AOGCC ~ Hanson, Kelli L wrote, On 12/21/2005 2:06 PM: Mr. Maunder, CPAI requests approval to commence injection into CD2-02. The SCMT fog is attached. The log was run on December 13th and indicates good bond across the logged interva4 from 15,850MD {7,188' TVD SS) to the tubing tail at 15,488' MD (7,0$2' TVD SS}. The packer is located at 15,414' MD {7,053' TVD SS) @ 67 deg. The top of the Alpine A sand is located at 18,920' MD {7,199' TVD SS} 82 deg. The 7" casing shae is located at 16;048' MD {7,207' TVD SS) 90 deg. PBTD is located at 21,178' MD {7,189" TVD SS) @ 96 deg, The casing was run to 16,048' MD (7,207' TVD SS} below the top of the Alpine A interval (top at 15,920' MD; 7199° SS TVD) and cemented on August 10, 2005. The cement job went well with full returns throughout the job. Cement Job summary is noted below. Description of 7" Casing Cement Job Pumped on 819C11A5: Completed RIH to 16,048' with casing. Made up the cement head. Established circulation at 8 BPM a~ 710 psi. Unable to work pipe up- Held PJSM for cement job Cemented 7'" casing as follows: Pumped 5 bbls CV11 100 -Test lines to 3700 psi -pumped 45 bbls C1N-100 at 4.3 BP 400 psi - Dropped btm plug -Mixed & pumped 40 bbls of 10.5 ppg MudPush Il 4.5 BPM 470 psi- Dropped btm plug-Mixed & pumped 33 bbls of 15.8 ppg Class (1.16 ft3/sk) tail slurry @ 4,5 BPM @ 400 psi -Dropped top plug w/ 20 bbls water fl Dowell. Displaced,with 591.4 Bbls mud from rig pump a~ 6 BPM, increased to 7 BPM when cement went through shoe. Reduced to 4 BPM and bumped plug. CIP a~ 2300 Hrs. Floats held, Good returns. RU ~ pressure test 7'° casing to 3500 psi for 30 rains. - RD The tubing and casing were successfully lllllT'd on 8!22105 as documented below: RU lubricator -drop packer setting rodlbaii - RD lubricator -Test lines to 5000 psi -Pressure up on tbg to 4800 psi to set packer -test tbg for 30 miss. initial pressure 4800 psi -final pressure 4484 psi - monitor annulus 0 psi - U-tube pressure from tbg to annulus -pressure equaliz~;d 2000 psi -bleed 1 of 2 12/22/2005 11:17 AM Re: CD2-02: Approval Request to Commence Injection tbg dawn to 850 psi -Pressure up on 7" x 4 1/2" annulus to 3500 psi & test for 30 mina. Initial pressure 3500 psi -final pressure 3455 psi -Bleed off annulus to 0 psi -Shut in well - tbg pressure 750 psi -Annulus pressure 0 psi We would like to place this well on injection as soon as the facility tie-in work is complete. The tie-in work should be finished this week, Based on this information I've concluded the Alpine interval is adequately isolated in CD2-02. Please let me know if you have any questions. Kelli L. Hanson Production Engineer Alpine Engineering WNS Subsurface Development 907.265.6945 ~.~s _ ~~~ «MIT CD2-02 OS-22-05.x1s» «CD2-02 1320 View.pdf» «CD2-02 Tbg detail.xls» «CD2-02 SCMT Print 13dec2005.PDS» «CD2-02 Log.pdf» 2 of 2 12122J2005 ] 1:17 AM • .~., .r~ r'~i ~+ ` ~ CD2-02 API: 501032051300 X Location: 1511715.66 Y Location: 5974517.41 Spud Date: 07/30/05 KB: 52.5 a-~5 -~~~ TD X Location: 1497367.58 TD Y Location: 5986125.01 7" SHOE CASING: 16048' TD: 21178' OH RP%_MWD 5_1 pH~.1la 100 OH.RPS MWD 5 1 ~ m _ _ _ onrwn tao yN y2 I OH RPM_MWD_S_t CHMM tm GAMMA RA'I eH RF::..ws'r','-s..i "5° '~7°° ILV A ALPINE 775 '~°° ALP A ,6,DD ,8200 -- _ ,6300 ,moo ,~ 18700 18800 18900 1]100 17200 1]300 n oo a 17800 1 noo 17800 17900 tetoo 16zoo 18300 18400 18800 18700 BB00 1 19900 19100 19200 19300 19400 19800 19700 19800 19900 20100 20200 20300 20600 20600 20700 20900 20900 UJU r: WELL LOG TRANSMITTAL • To: State of Alaska November 4, 2005 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7`h Avenue, Suite 100 ~ ~ 4 Anchorage; Alaska 99501-3539 ~ ~ ~~~- ~ ~ ~ RE: MWD Formation Evaluation Logs: CD2-02, AK-MW-3855685 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103 -20513 -00. • • WELL LOG TRANSMITTAL To: State of Alaska November 4, 2005 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 ~ Anchorage, Alaska 99501-3539 / 7J" ~ ~ O o ~-- J ~ RE: MWD Formation Evaluation Logs. CD2-02 PBI, ~ AK-MW-3855685 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20513-70. ~,~ ~~~ o ~ X005 cam'' ,~laska pil ~` A e t~ • • 25-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-02 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *,PDF files. Tie-on Survey: 16,016.41' MD Window /Kickoff Survey: 16,110.00' MD (if applicable) Projected Survey: 21,178.00' 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 690E Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~~-lob • • 25-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-02 MWD Dear Dear Sir/Madam: Enclosed is one disk with the'~.PTT and ~`.PDF files. Tie-on Survey: 16,016.41' MD Window /Kickoff Survey: 16,110.00' MD (if applicable) Projected Survey: 21,178.00' 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 S Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ ~ ~6~ • • 25-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-02 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 16,216.00' 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 ~~ ~~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~'fL~~ • • 25-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-02 PB1 MWD Dear Dear SirlMadam: Enclosed is one disk with the *.PTT and ~.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 16,216.00' 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 ~ ~ ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Re: CD2-02--(205-109) Subject: Re: CD2-02--(205-1.09) From: Thomas Maunder <tonl_r~iaunder a admin.state.ak.us> Date: Tue, 16 Auk 2005 12:28:50 -0800. To: ".fohn~~~n_ ~'crn" '~`crn.Johnsen<«conocophillih,.com> CC:St~ticDa~ics=~ste~e ~la~~ies~cra~lmin.stat~.ak.us> Vern, Steve and I have discussed this matter and we agree that this short section be called PB1. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 8/16/2005 9:57 AM: Tom, After drilling out of 7" casing (16049' MD 8-3/4" hole TD C~16063'MD), we drilled 153' of new hole to 16216'MD. Our drilling assembly built more angle than we were expecting and we drilled into the Alpine D shale at 16180' MD. We had difficulty turning down and elected to attempt an open hole sidetrack. We achieved our sidetrack late yesterday, sidetrack point at 16110' MD. Due to the reason for the sidetrack and the relatively short interval, I propose we consider the "abandoned" hole to be a plug back, PB1. Let me know what you think. Vern Johnson 907-265-6081 -----Original Message----- From: Thomas Maunder [mail~o:tom maundertx~admin.state.ak.us] Sent: Tuesday, August 16, 2005 8:01 AM To: Johnson, Vern Subject: CD2-02 Vern, Could you send me a message relating the information on the potential lateral section in CD2-02?? Thanks, Tom Maunder, PE AOGCC 1 of 1 8/16/2005 12:29 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Jilr> >;.>gg~.~?;;cfr.3i. ~?ae;.ak.~ EicE~ 'ireLker3stci~:%z~acfr:3:~.:;?~€s.sk.~~s OPERATOR: ConocoPhillips FIELD 1 UNIT 1 PAD: Alpine/CD2 DATE: 8/22/2005 OPERATOR REP: Don Mickey AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-02 In'. Tye N TVD 7,105' Tubin 850 1,100 1,150 1,150 Interval I P.T.D. 205-109 Test T P Test si 3500 IA 1,800 3,500 3,470 3,455 P/F P Notes: ,~--T OA MIT Report Form Revised: 03/18/04 MIT CD2-02 08-22-05.x1s ~' c,ra4aronr4.6,o4: MYinumCUrwWe ConocoPhillips a r~~~iSH::f csaere o.wm raotvn MROCOri corns) Mapnetlc Ma4tl: Btxi620o6 H A LLI B V R TO N Ground LeRKB: C02-02 ~ 62.90R (CD2-02 ~ 526 above MSL) -.. - -- Northing/ASP Y: 5974770,66 Sperry Drilling Services ea,6ngrASax: s7isa2s6 wn. asa. 966' 9818 >•. , si¢• ern Wesq-WFast(+) (2000 ftlin) -20000 -18000 -16000 -14000 -12000 -10000 -ssuuu -ouuu -~,uu., -~~~~ Tubing Detail 4 1I2" Tbg Detail ConocoPhillips Alaska, Inc. Si ihsidia N of CnnncnPhil lips Com oanv Well: CD2-02 Date: 8112005 ass-~~~ DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 32.76 FMC 4 1!2" Tbg hanger. 3.76 32.76 Jts 304 to 356 53 Jts 4 1/2" 12.6# L-80 IBTM Tbg 2285.19 36.52 Camco 4 112" DB nipple 5.62" OD x 3.812" ID 1.52 2321.71 Jts 4 to 303 300 Jts 4 112" 12.6# L-FA IBTM Tbg 12967.56 2323.23 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 10.62 15290.79 Camco 4 1!2" KBG-2 GLM w/dummy 5.984" OD x 3.938" fD 6.56 15301.41 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 9.82 15307.97 Jts 2 to 3 2 Jts 4 1/2" 12.6# L-80 IBTM Tbg 87.28 15317.79 Pup - 4112" 12.6# L-80 IBTM Tbg 9.79 15405.07 4.5" X 7" Baker Premier packer 5.97" OD X 3.875" ID 7.80 15414.86 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 9.55 15422.66 Jts 1 to 1 1 Jts 4 1/2" 12.6# L-80 IBTM Tbg 43.88 15432.21 4.5" "XN"NIPPLE 5" OD x 3.725 "ID 1.20 15476.09 Pup - 4 1!2" 12.6# L-80 IBTM Tbg 9.81 15477.29 4 1/2" WLEG 5" OD 5" OD x 3.875" ID 1.35 15487.10 4 1/2" tbg tail @ 15488.45 390 jts. total in pipe shed 356 jts. to run -34 last jts. Out GLM @15301.41' MD -7061 'TVD Packer 15,414.86' MD -710.'. 'TVD XN Nipple @ 15,476.09' MD - i'130' TVD - 66 degrees Tbg tail @ 15,488' MD - 7135' TVD Top of Alpine °'A" -15,920' MD - 7259 'TVD Used Jet Lube Run-N-Seal ipe do e Make up torque - 3000 All jts. drifted to 3.843" Remarks: Up wt - 193 k Dnwt-115k Blocks - 75k Supervisor : D. Mickey • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein~admin.state.ak.us; Jim_Regg~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhi-lips Alpine /CD2 08/21 /05 Don Mickey Packer De th Pretest Initial 15 Min. 30 Min. Well CD2-02 T e In'. N TVD 7,105' Tubing 750 4,800 4,571 4,484 Interva I P.T.D. 205-109 T e test P Test si 4800 Casing 100 P/F Notes: Well CD2-02 T e In'. N TVD 7,105' Tubin 850 1,100 1,150 1,150 Interva I P.T.D. 205-109 T e test P Test si 3500 Casin 1,800 3,500 3,470 3,455 P/F Notes: Well T e In'. TVD Tubin Interva P.T.D. T e tes Test si Casing P/F Notes: Well T e In' TVD Tubin Intena P.T.D. T e tes Test si Casin P/F Notes: Well T e In'. TVD Tubin Intena P.T.D. T e tes Test si Casin P/F Notes: Test Details: Displaced tubing with diesel and tested against ball on seat in RHC plug / "XN" nipple. U-tubed pressure f/ tbg to annulus -pressure equailzed @ 2000 pis -bleed tbg down to 850 psi and tested 7" X 4 1/2" annulus. TYPE INJ Codes F =Fresh Water Inj G =Gas Inj S =Salt Water Inj N =Not Injecting TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form Revised: 06/19/02 CD2-02 MIT Form.xls STATE OF ALASKA ~~iosioa OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: jim regg~ti~adn:i:~.state.ak.us• ac~c~.,.p`~_4d~oe b:v ~ad:~nn.stae.ak.us brl~ €scker~~tein:;ti~arrrrsi:~.stute.a>i.~t~• Contractor: Doyon Rig No.: 19 DATE: 8/11/2005 Rig Rep.: Krupa/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick/Hill Field/Unit & Well No.: Colville Rv CD2-02 PTD # ~ft6-109 Operation: Drlg: x Workover: Test: Initial: Weekly: Test Pressure: Rams: 250/5000 Annular: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec.. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1 /8 P Check Valve 0 NA MUD SYSTEM: Vi sual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Number of Failures: 0 Test Time: 3.5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: iirn reg~g :yadrr:in.stute.a>i.~~s• Remarks: Good test. Base flange on stack began leaking on the third test. Tightened it ug and it held iust fine. CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: TimelPressure Test R System Pressure 2975 P Pressure After Closure 1550 P 200 psi Attained 28 P Full Pressure Attained 2 min 44 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2200 Test Results Explor.: Bi-Weekly x Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P 24 HOUR NOTICE GIVEN YES X NO Date 08/10/05 Time 08:OOAM Waived By not waived Test start Finish Witness Chuck Scheve BOP Test (for rigs) BFL 11/09/04 Doyon19 08-11-05 CD2-02.x1s '~ STATE OF ALASKA ' 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~ir:~ re~~~;yadn:in.state.ak.us~ aog~ ~~;€,4d€os hr:~~aJs~n.state.ak.us brl::ecken:~tA:n :~~orr:€:~.state.a~.~~r Contractor: Doyon Rig No.: 19 DATE: 8/3/2005 Rig Rep.: Lupton/Sena Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD2-02 PTD # .245-1d9 Operation: Test: Test Pressure: Drlg: x Initial: x Rams: 250/5000 Workover: Explor.: Weekly: Bi-Weekly Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIO NS: 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 H azard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFO LD: Annular Preventer 1 13-5/8 P Quantity Test Result Pipe Rams 1 3-1/2x 6 P No. Valves 16 P Lower Pipe Rams 1 3-1/2x 6 P Manual Chokes 1 P Blind Rams 1 blinds P Hydraulic Chokes 1 P Choke Ln. Valves 1 3-118 P HCR Valves 2 3-1/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8 P Time/Pressure Test Result Check Valve 0 NA System Pressure 2950 P Pressure After Closure 1650 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 31 P Trip Tank P P Full Pressure Attained 2 min 50 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4 @2250 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 3.75 Hours Components tested 28 Repair or replacement of equipment will be made within n/a _ days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ~i~ €-eg~~:~adrr:i:~.state.a>i.us~ Remarks: Test went very well. 24 HOUR NOTICE GIVEN YES X NO Waived By John Crisp Date 08/01/05 Time 08:OOAM Witness Lupton/Burley Test start 09:15:00 AM Finish 1:00:00 PM BOP Test (for rigs) BFL 11/09/04 Doyon19 08-03-05 CD2-02.x1s i ~ a i ~ d ~ ~ s +~ ~ "~}` ' ~+ ~ FRANK H. MURK W ~~ 0 SKI, GOVERNOR ~~~ OI~ ~ ti0-7 333 W. 7'" AVENUE, SUITE 100 COI~TSFRQAI'IO1~T COI~IDTISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD2-02 ConocoPhillips Alaska, Inc. Permit No: 205-109 Surface Location: 1587' FNL, 1561' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 663' FNL, 295' FEL, SEC. 29, T12N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced stratigraphic test well. This permit to drill does not exempt you from obtaining additional permits or approvals 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 petroleum field inspector at (907) 659- 3607 (paler). ~~ ` DATED this day of July, 2005 Sincere , Daniel T. Seamount, Jr. Commissioner cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Envir. onmental Conservation w/ o encl. • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 13, 2005 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-02 Dear Sir or Madam: ConocoPhilli„s M ~~*'f""~ J(j ~r"Jr ~~ app ~~~. C ~,qe ~mia~;a~ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Alpine CD2 drilling pad. The intended spud date for this well is August 2, 2005. It is intended that Doyon Rig 19 be used to drill the well. The well will be landed horizontally in the Alpine C formation, then 7" casing will then be run and cemented in place. The horizontal section will be drilled and completed as an open hole injector. At the end of the work program the well will be shut in awaiting surface connection. Note that it is planned to drill the surface hole without a diverter. There have been 41 wells drilled on CD1 pad and 56 wells drilled on CD2 pad with no significant indication of gas or shallow gas hydrates. It is also requested that the packer placement requirement be relaxed to place the completion packer /~ 250 ft TVD above the Alpine formation. This will place the completion at a maximum inclination less than 70° and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 {a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of Riser set up. k ° .~ ~ ~ '. ~~ `~.. ,~ ~ d '~ ~ • If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Si ely~ ~. ~ ~~iS~o~ Vern Johnson Drilling Engineer Attachments cc: CD2-02 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Chris Alonzo Steve Moothart Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1770 ATO-1756 Kuukpik Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~w~r~~ JUG. ~ 5 2Q05 '~(~~ 1a. Type of Work: Drill ~ Redrill 1b. Current Well Class: Exploratory Develo • ~ . e Re-entry ~ Stratigraphic Test ~ Service ~ Development Gas lone 2 . Operator Name: 5. Bond: Blanket ~ Single Well [] 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' CD2-02 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 100360, Anchorage AK 99510-0360 MD: 21359 °' TVD: 723$ Colville River Field 4a. Location of Well (Governmental Section): 7. Property esignation: ~ ~ Alpine Oil Pool ~ , Surface: 1587' FNL, 1561' FEL ,Sec. 2, T11 N R4E UM ADL 380475, 387212, 388466, 25530, ASRCNPRAI Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: ' 5144 FNL 2803' FEL Sec. 28 T12N R4E ASRC NPRA02 2-Au -05 Total Depth: 9. Acres in Property: 14. Distance to Nearest 663' FNL 295' FEL Sec. 29 T12N R4E ~ 2560 Property: gg3 FNL L32197 4b. Location o~VY~lI State Base ~~~ o ~~ ates): `~ ,~ t9 ~- 10. KB Elevation 15. Distance to Nearest Well /"' `~> Surface:x- _ y- Zone- ~ (Height above GL): 36.7 feet Within Pool: CD2_~g 607 16. Deviated wells: Kickoff depth: -feet ~ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: /~ 90 degrees Downhole: 3293 ~ Surface: 2607 ~ 18. Casing Program: .~• ~`l,w Setting Depth Quantity of Cement Specifications Size Top Bottom c.f. or sacks Hole " Casing " Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42 16 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" " 9.625" 36# J55 BTC 3823 37 37 3860 2390 733 Sx AS Lite & 230 sx L+tecrete 8.75 " 7" 26# L80 BTC-M 16055 37 37 16092 7277 165 Sx 15.8 ppg class G 6.125 4.5" 12.6# L80 IBT-M 15480 32 32 15512 7165 Tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redri{I and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Pl ugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Si ze Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner 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 ARC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge . Contact V. Johnson 265-0681 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature z ~C ~ CtE, p ~L Jv~ ~ Phone 907-265-6120 Date 13-Jul-05 Commission Use Only Permit to Drill ~~ ~ ~ l~ Number: API Number: 50- ~~~~ ~~~~ "-~ Permit Approval ~ See cover letter for other Date: requirements, Conditions of approval : M `~' ~~~} ~~` `,~~ `p Samples required Yes ~ o Mud log required Yes [~ No ~ Hydrogen sulfide measures Ye ~ No Directional survey required Yes ~ No Other:3S~QS~ t~itL. V~~'4'~5~. n~vQC~F~WC%N~~OAACas,cl.35Ch~~a~ Poc4s?~~~©~~ ~aAaeaS Sa~ ~ ~ 4 t ~ ~~~CC~-~~O~b c~,rt~,~to~~ p~~ q~0 l~ ~S , APPROVED BY 'Approved by: ~, THE COMMISS{ON Date: Form 10-401 Revised 0612004 Y (~ L ~~~ J Suhmit inl7iinliraYa .r • s w • • ~rU • CD2-02 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low .- Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations ' >2000' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material use of low densit cement slurries 8-3/4" Hole / 7"_Casinq Interval Event Risk Level Miti ation Strate Abnormal Pressure in low ROPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure ' mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low ~ H2S drills, detection systems, alarms, standard well control radices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure ~ Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control radices mud scaven ers J~161NAL • Alpine: CD2-02 Procedure 1. Move on Doyon 19, dewater cellar as needed. 2. Nipple up riser. 3. Drill 12'/." hole to the surface casing point as per the directional plan. 4. Run and cement 9 5/8" surface casing. 5. Pressure test casing to 2500 psi. 6. Install and test BOPE to minimum 5000 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Dril18 3/;' hole to the intermediate casing point in the Alpine Sand. (LWD tools, GR/RES/PWD)~ 9. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 10. ROPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and pertorm formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD)~ 16. Circulate the hole clean and pull out of hole. 17. Run 4-'/Z, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrels and packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi ! 30 mins. 22. Set BPV and secure well. Move rig off. - S S ~ ORIGINAL • Well Proximity Risks: • Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-03 is the closest well. Well separation is 9.9' @ 300' MD. Drillins~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally f as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumains~ Operations: Incidental fluids developed from drilling operations on well CD2-02 will be injected into the class 2 disposal .- well on CD1 pad, or a permitted annulus on CD2. The CD2-02 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1700' TVD. The only significant hydrocarbon zone is the Alpine reservoirs and there will be more than 500' of cement fill above the top of the Alpine as per regulations. Upon completion of CD2-02 form 10-403, Application for Sundry Operations -Annular Disposal,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85°lo collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi OR161NAL CD2-02 DRILLING FLUID PROGRAM • SPUD to 9-518"surface casing oint-12'/1' Intermediate hole to 7" casing point - 8 %Z" Production Hole Section - 6 1/$" Density 8.8 - 9.6 ppg ~ 9.6 - 9.8 ppg 9.0-9.3 Ppg PV 10-25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc 130 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc130 min PH 8.5 - 9.0 9.0 - 1 0.0 9.0 - 9.5 KCL 6 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep low line viscosity at t 200 sec/gt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB calcium carbonate bridging material to minimize formation damage. Ffo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL i Alpine CD2-02 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 1752' TVD = 2300' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3860' MD / 2390' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT ID) w/dummy Camco KBG-2 GLM (3.909" DRIFT ID) w/dummy Updated 07/13/05 Sperry Sun Directional Plan WP02 Com len lion M~ Iu?/ Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 2300' 1752' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) 10104' 4950' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) 15340' 7095' 4-112", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 15440' 7136' 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-63.7° inc 15500' 7160' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 15512' 7165' Baker Premier Packer +/- 15440' MD/ 7161' ND < 250' ND from top of Alpine A TOC @ +/- 15268' MD / 7066' TVD (516' MD above top Alpine A) Well TD at 21360' MD / ~ ' 7238' TVD Top Alpine A at 15784' MD / 7246' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 16092' / 7277' TVD @+/- 87° ORIGINAL • • CD2-02 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: ~ ,`l E MvJ ~~-/ NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. Z(~~ PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surtace as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psUft 0.1 =Gas gradient in psUft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1Jx114=53 psi OR ASP =FPP - (0.1 x D) = 1081 - (0.1 x 2390') = 842 psi 2. Drilling below surtace casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2390 = 1563 psi OR ASP =FPP - (0.1 x D) = 3293 - (0.1 x 7277') = 2607 psi ~ i 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3275 - (0.1 x 7238') = 2551 psi Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3860 / 2390 14.5 10 1640 7" 16228 / 7277 16.0 3293 2565 N/A 21359 / 7238 16.0 5 N/A ORIGINAL • Cementing Program: • 9 5/8" Surface Casing run to 3860' MD / 2390' TVD. " Cement from 3860' MD to 3360' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3360' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (+/-2175' MD). Lead slurry: (3360'-2175') X 0.3132 ft3/ft X 1.5 (50% excess) = 556.7 ft3 below permafrost 2175' X 0.3132 ft3/ft X 4 (300% excess) = 2724.8 ft3 above permafrost Total volume = 556.7 + 2724.8 = 3281.5 ft3 => 733 Sx @ 4.48 ft3/sk System: 733 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 16092' MD J 7277' TVD ' Cement from 16092' MD to +/-15268' MD (50% more cement above the packer as there is between the packer and the Alpine A) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (16092' -15268') X 0.1503 ft3/ft X 1.4 (40% excess) = 173.4 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 173.4 + 17.2 = 190.5 ft3 => 165 Sx @ 1.16 ft3/sk System: 165 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ORIGINAL ... Melfv4: MYJtinCUVr~a ConocoPhillips ~'""~ `~~"~' W~'Np MMOe:~ea~i4 OdMk o,4,c NOD 1927 QY~OCONCpAL9 .H 7 -.I'.~ Mapr6c M°4st BOOMA65 HALLIBURTON 'rain°~: cozo @sz.9001t 1cOZOZ~s29'ab°.. M6L7 ~:o.rni~yASP v: 597m9.e4o9 Sperry Drilling Services ~asmyASV x: 371682.8500 Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-02 Welltare: Plan: CD2-02 Plan: CD2-02wp02 Target (Tce); 21359' MD, 7237 TVD, 663' FNL 8296' FEL; Sec29 T7 Start GeoSteer; 90.376° INC,17236' MD, 7269' TVD ANNOTATIONS TVD MD Anrafa8on 37.000 37.000 SHL. 1587 FNL 8 1581' FEL; Sec02-711 N-RO4E 200.000 200.000 Begin Dir, 3° DLS, 295° TFO. 20d MD, 20d TVD 597.082 800.000 Corrtinue Dir, 4° DLS, 8.5° TFO, 800' MD, 59T ND 1807.340 1948.855 Start Sail; 85.808° INC, 1948' MD, 1807 ND 2390.000 3858.559 9.518" Csg Pt; 3858' MD, 2394 ND 7157.12115176.222 Begin Dir; 4° DLS, 0° TFO, 15478' MD, 7157 ND 7177.07218030.000 7' Csg Pt; 18030' MD, 7277' TVD; 5144' FNL 8 280.7 FEL; $er38•T12N-R01E 7177.90018092.081 Target (Heel1; 18092 MD, 7277 ND 7277.90018092.081 Continue Dir, 2.74° DLS, 90° TFO, 18092' MD, 7277 ND 7289.54217238.808 Start GeoS[eer; 90.378° INC, 17238' MD, 7289' ND 7237.90021359.527 Tanwt lTrwl~ 2'1359' MD 7237 TVD. 883' FNL R 2%' FEI-. Ser.29-712N-RO4E SFS.'nON DEfAIS Sec MD Ytc Aa 71ID MYS +EFW OLeg TFace VSec Target 1 37.000 0.000 0.0000 37.000 0.000 0.000 0.00 0.0000 0.000 2 200.000 0.000 0.0000 200.000 D.000 0.000 0.00 0.0000 0.000 3 600.00012.000295.0000 597.082 17.638 ]7.625 3.00295.0000 40.624 4 1946b55 65.806300.7848 1607.340 421.401 -745.354 4.00 6.5359 646224 5 15476]22 65.806300.7848 7152.122 6737.69511347.411 0.00 0.000013082.553 6 16092.081 90.440300.7849 7277.900 7043.78311661.186 4.00 0.000113675.525 CD2-02wp02 Hcel 7 17238.827 90.3753322065 7269.529 7865.13912640.739 2.74 90.000014796221 B 21359.535 90.504331.4875 7237.90011498.19814584.932 0.02.79.856618572258 CD2-0Zv4><12 Tce r ~. k'.~ i4 ~M1 ii iP UE I a~L.i G9-x' OEU45 - NDPa81 MDPath Fortnahon 2105.900 3895.356 C-30 11° 1YD MD Nn. m 1 7 ~~ ~~ e,M, s6a 7 2773.900 4793.282 C-20 2 ~~ ~~ 7. 7 ;3-73.900 7404.102 K-3 Marw,;r a TISl~U ~~y,,qr eta 1 t~)33.900 7867.705 Basal K-3 5a~,u ~ 7050 900 7933 588 K-2 Marker 8 4145.900 8140.987 Ba58 K•2 CYCIe Corltinlle Dir, 2.74° DLS, 90° TF0, 16092' MD, 7277 TVD 7 5060.90010373.604 Albian 97 8 5810.90012203.816 Albian % 9 8869.90014787.597 HRZ 10 7041.90015207.280 Base HRZ Ta eel)' 16092• MD, 7277• TVD 11 7093.90015334.181 K-1 Marker 12 7136.90015439.082 Kuparuk Fm - --- - - - --- - -- _ 13 7185.90015564.792 LCU-Miluveach ~ 14 7223.90015686.382 Miluveach A 15 7227.90015701.340 Alpine D 7277 TVD; 5144' FNL 8 2803' FEL; See,28-T12N~204E T' Csg P1; 16030' MD 16 7236.90015737.381 Alpine C , 17 7246.90015781.329 Alpine A C 0 0 0 N t L O Z L 7 O N -Begin Dir; 4° DLS, 0° TF0,15476' MD, 7157 TVD Start Sail; 65.806° INC, 1946' MD,160T TVD Corttinue Dir; 4° DLS, 6.5° TFO, 600' MD, 597 10'B~ Begin Dir; 3° DLS, 295° TFO, 200' M SHL;158T FNL 81561' FEL; Sec02 711 Nat04E 9~b/8" Csg Pt; 3856' MD, 2390' TVD -16000 -14000 -12000 -10000 ~DOO 6000 -0000 -2000 0 2000 West(-YEastt+) (200o tt/in) CakuWOn G~Ihod: MlnNniltn Gl,rvrha~ ConocoPh~ ~ ~ i ~ EnorSya4nn. I6GY/8A Project: Colville River Unit Scrr MWwd: Tm. Cyid~r North AAII ` ANNOTATIONS 7VD MD Anrldation 31.000 37.000 $NL; 158T FNL 81581' FF1; $8002-T71N4i04E ,~,,ne CD2 Eer«surfrw: Elliplkal Conic S Ite: , ~1" 2(10' TVD 200000 200000 Begin Dr, 3° DLS 295° TFO 200' MD w Mq ~: ~~ ~~ hlli:Sl(c3 4+.°e.m Drtun: NI1D t9Z71ruocoN cONU51 Well: Plan: ~.~~ , , , 59782 800ll00 Canbnte Dir, 4° DLS. 8.5° TFO. 800' MD, 59T 7VD MgtwOc 44odN: 900rnato5 Wellbore: PIan:CD2-02 18W.340 1948.855 Stan Sai: BS.BOB° INC. 1948' Nq. 180T TVD 723Q1ooro 1 ~~~a ~o ~i°sa78TVDi •tD 7lsrrw , . . nn.o3x 1eo3nooo r csg R 1eo3a Mo, nTr TvD; s14a• FNL 8 zeoa FEL; Str28•n2Nai01E c.-,~ ~ ~ ~I I r ~..i 1s9oo HALLIBUFiTON ms~+ Plan: CD2-0~~,••,~,~2 s2 ~ t r `^ V nn9ro 1ew2o91 ragetlr~eeq;lewrMD,nrrrvD 9 , >o~r- RKB coza2 s29oonicoz-0 u Y ~ ASP Y ' 974770&1(U N rtt~ n77.900 18092081 CatBrNre Dk, 2.74° DLS, 90° TFO, 18092' MD, n7T TVD ° ' . . u n y Sperry Drilling Services E.3 Y.gASP x P1fi@6500 n89.542 17238808 Stag GeoStear, 90.378 NC, 17238 MD, 728fY TVD 7237900 213SBSt7 Target (Taal: 21359' MO, n3T TVD, 883 FNL 8298'FEL; Sec29•T12NJ204E SECTION DETALS Sx MD Y70 Ati TVD +WS +E/-W aL'g TFaoe VSec TarpM ~~ 1 37000 ODW 00000 37.000 0000 0000 0.00 O00W 0000 2 700000 0000 0.0000 200.OOD ODOD 0.000 ODO OD000 OD00 3 800DOD 12000 2%.0000 9J7D82 17.Q8 .T782.r 3.00 85.0000 40.624 4 1946855 6SID6 300.7848 1607340 421AD1 -745354 400 65193 8467V 5 15476712 65806 300.7848 7152122 6737095-11347.411 000 00000 1308L'S3 6 16082.081 90440 300.7840 T1T7900 7043783 -11861.186 400 00001 13675.45 CD2d2wp02 Htxl 7 17238827 90375 3327066 7789.49 78~1~-1264(L730 274 900000 14796221 0 21359535 90504 331A875 7737900 1'1488198-14584A'i2 002 79E566 18S275B CD202Np02Tce SHL; 158T FNL 8 1561' FEL; Sec02-T11Na204E "'~'"°°~T""~ 1 _, r.. t- .- ,, D No T11) MD Nrr~ 8~e o 200' TVD 295° TFO 200' MD Begin Dir 3 DLS 1 x1!0.090 1434.139 B SA' 94Nf W 1WPytn AT>P:A~ , r x 7n7.osx lsoso.oo4 r 7 t z4os:3oo 3a9s.3s6 ~ r. , ,,,,~ „~„~. ,,,,, ,.,rz -_ , , , , ,, .773-900 4793282 C-d~ '843.900 7404.102 K'. '.'..n,.r w33.9ao 7867.705 ea,,,i ~_~ S.r<t Continue Dir, 4° DL$, 6.5° TFO, 600' MD, 59T TVD LNA.900 7933.566 K.2 ~'slarMer 4, 4s 9oo a,4o.%7 Bas°K2 Cytle ' 1060 900 10373 504 Alba 97 . n . 5810.900 72207.618 Albian% Start Sail; 65.806° INC, 1946' M0,160T TVD 60900 ,47eTS97 1R2 '041.900 15207280 Base Ni7Z '093900 15334151 K 1 M h 2D~ _..--. ' - at er '136900 154,79-082 ~kFrn C~ 't 85.900 15564.792 LCLLM4tn9 ch C ~ ~ '223.900 ;5586 ~i~' ad,A ~ C ZO i 95/8" Csg Pt; 3856' MD, 2390' TVD ~ -z369oo ,573735, Aln„ec 0 0 K 3 M k - ar er t Basal K-3 Sand a K-2 Marker Begin Dir, 4° DLS, 0° TFO, 15476' MD, 7152' TVD o - \ 4000 .-.- _ - _. __ - -- - _ -~ - --- -- 7" Csg Pt; 16030' MD, 727T TVD; 5144' FNL 8 2803' FEL; Sec28-T12N-R04E I d Base K-2 Cyde ~ > Albian 97 Continue Dir, 2.74° DLS, 90° TFO, 16092' MD, 727T TVD a1 ~ - ~ -T -- F Albian 96 Start GeoSteer, 90.376° INC, 17236' MD, 7269' TVD 6000 ~- HRZ -- ---- _ _ -- __ __ ._ Base HRZ K-1 Marker Kuparuk Fm -_ LCU-Miluveach I - - - CD2-02wp02 -- Miluveach A ~ Alpine D , i i 800° _ . ine C - ` - Al - - - - - - - - -- -~ - -- -' -- - p 2-02wpo2 Toe Target (Haag; 16092' MD, 7277 TVD CD . Alpine A I ', Target (Toe); 21359' MD, 7237' TVD, 663' FNL 8296' FEL; Sec29-T12N-R04 0 2000 4000 sooo eooo looo0 12000 14000 lsooo 18000 ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-02 Plan: CD2-02 • Plan: CD2-02wp02 Proposal Report 14 July, 2005 1-~ALL.IBtJRTC]~N Sperry Drifting Services ORIGINAL • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-02 Welibore: Plan: CD2-02 Design: CD2-02Wp02 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: MALL{BURTON Sperry Drilling Services Well Plan: CD2-02 CD2-02 ~ 52.900ft (CD2-02 ~ 52.8' above MSL) CD2-02 (d152.900ft (CD2-02 ~ 52.9' above MSL) True Minimum Curvature Project Colville 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 Welt Plan: CD2-02 Well Position +N/-S 0.000 ft Northing: 5,974,770.8400 ft Latitude: 70° 20' 21.493" N +E/-W 0.000 ft Easting: 371,682.8500 ft Longitude: 151° 02' 28.538" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 15.900 ft Wellbore Plan: CD2-02 Magnetics Model Name Sample Date Declination Dip Angle FieM Strength (°) (°) ( BGGM2005 7/1312005 23.6305 80.6397 57,495 Design CD2-02wp02 Audit Notes: Version: 1 Phase: PLAN Tie On Depth: 37.000 Vertical Section: Depth From (ND) +N/S +Ef-W Direction l~j (ft! (f~) (°) 37.000 0.000 0.000 308.2509 Plan Summary Measured Vertical Dogleg Build Turn Depth {nclination Azimuth Depth +N!-S +E/-W Rate Rate Rate ~0 (ft) {°) (•) ($) (g) (ft) (°/100ft) (°HOOft) (°/100ft) (*j 37.000 0.000 0.0000 37.000 0.000 0.000 0.00 0.00 0.00 0.0000 200.000 0.000 0.0000 200.000 0.000 0.000 0.00 0.00 0.00 0.0000 600.000 12.000 295.0000 597.082 17.638 -37.825 3.00 3.00 0.00 285.0000 1,946.855 65.806 300.7848 1,607.340 421.401 -745.354 4.00 3.99 0.43 6.5359 15,476.222 65.806 300.7848 7,152.122 6,737.685 -11,347.411 0.00 0.00 0.00 0.0000 16,092.081 80.440 300.7849 7,277.900 7,043.783 -11,861.186 4.00 4.00 0.00 0.0001 17,238.827 90.375 332.2065 7,269.529 7,865.139 -12,640.739 2.74 -0.01 2.74 90.0000 21,358.535 90.504 331.4875 7,237.900 11,498.198 -14,584.932 0.02 0.00 -0.02 -79.8566 7/14/2005 9:33:42AM Page 2 of 9 COMPASS 2003.11 Build 50 ~~~~~L ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Locaf Co-ordinate Reference: Well Plan: CD2-02 Company: ConocoPhillips Alaska Inc. TVD Reference: CD2-02 (~ 52.900ft (CD2-02 (~ 52.9' above MSL) Project: Colville River Unit MD Reference: CD2-02 (ci3 52.900ft (CD2-02 ~ 52.9' above MSL) Site: Alpine CD2 North Reference: True Well: Plan: CD2-02 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-02 Design: CD2-02wp02 Planned Survey CO2-02wp02 Map Map MD inclination Azimuth TVD SSTVD +NiS +E!-W Northing Easting DL$EV Vert Section ttU (•) (°) Iftl tft) (ft) (ft) t~ (~) C/100ft) tftl 37.000 0.000 0.0000 37.000 -15.80 0.000 0.000 5,974,770.8400 371,682.8500 0.00 0.00 SHL; 1587' FNL & 1561' FEL; Sec02-T1 1N-R04E ~ 100.000 0.000 0.0000 100.000 47.10 0.000 0.000 5,974,770.8400 371,682.8500 0.00 0.00 200.000 0.000 0.0000 200.000 147.10 0.000 0.000 5,974,770.8400 371,682.8500 0.00 0.00 Begin Dir; 3° DLS, 295° TFO, 200' MD, 200' TVD 300.000 3.000 295.0000 289.954 247.05 1.106 -2.372 5,974,771.9865 371,680.4973 3.00 2.55 400.000 6.000 295.0000 398.635 346.73 4.422 -9.482 5,974,775.4229 371,673.4457 3.00 10.18 500.000 8.000 295.0000 498.768 445.87 9.937 -21.311 5,974,781.1397 371,661.7144 3.00 22.89 600.000 12.000 295.0000 597.082 544.18 17.638 -37.825 5,974,789.1212 371,645.3357 3.00 40.62 Continue Dir; 4° DLS, 6.5° 7F0, 600' MD, 597' TVD 700.000 15.980 296.6526 694.097 641.20 28.211 -59.558 5,974,800.0633 371,623.7884 4.00 64.24 800.000 19.968 297.6587 789.197 736.30 42.318 -86.996 5,974,814.6366 371,586.5882 4.00 94.52 900.000 23.960 298.3408 881.920 829.02 ~ 58.890 -120.005 5,974,832.7701 371,563.8976 4.00 131.32 1,000.000 27.954 298.8376 971.814 818.91 80.843 -158.424 5,974,854.3756 371,525.8460 4.00 174.46 1,100.000 31.950 299.2189 1,058.441 1,005.54 105.074 -202.065 5,974,879.3477 371,482.6286 4.00 223.74 1,200.000 35.946 298.5234 1,141.378 1,088.48 132.465 -250.718 5,974,907.5648 371,434.4560 4.00 278.90 1,300.000 39.943 299.7744 1,220.223 1,167.32 162.882 -304.144 5,974,938.8894 371,381.5630 4.00 339.69 1,400.000 43.841 299.9867 1,294.589 1,241.69 196.178 -362.082 5,974,973.1689 371,324.2072 4.00 405,80 1,500.000 47.938 300.1703 1,364.117 1,311.22 232.189 -424.252 5,975,010.2363 371,262.6681 4.00 476.92 1,600.000 51.937 300.3321 1,428.466 1,375.57 270.742 -490.349 5,975,049.9110 371,197.2454 4.00 552.69 1,700.000 55.935 300.4771 1,487.323 1,434.42 311.647 -560.053 5,875,091.9997 371,128.2579 4.00 632.76 1,800.000 59.933 300.6090 1,540.401 1,487.50 354.706 -633.022 5,975,136.2974 371,056.0418 4.00 718.72 1,900.000 63.932 300.7307 1,587.442 1,534.54 399.708 -708.903 5,975,182.5882 370,980.9487 4.00 804.17. 1,946.855 65.806 300.7848 1,607.340 1,554.44 421.401 -745.354 5,975,204.9000 370,944.8773 4.00 846:22 Start Sail; 65.8 06° INC, 1946' MD, 1607 ' TVD 2,000.000 65.806 300.7848 1,629.121 1,576.22 446.213 -787.000 5,975,230.4182 370,903.6651 0.00 `894.29 2,100.000 65.806 300.7848 1,670.104 1,617.20 492.898 -865.363 5,875,278.4344 370,826.1185 0.00 9$4.73 2,200.000 65.806 300.7848 1,711.087 1,658.19 538.584 -943.726 5,975,326.4505 370,748.5720 0.00 1,075.18 2,300.000 65.806 300.7848 1,752.071 1,689.17 586.270 -1,022.090 5,975,374.4666 370,671.0255 0.00 1,165.62 2,400.000 65.806 300.7848 1,793.054 1,740.15 632.956 -1,100.453 5,975,422.4828 370,593.4788 0.00 1,256.06 2,500.000 65.806 300.7848 1,834.037 1,781.14 679.642 -1,178.816 5,975,470.4988 370,515.8324 0.00 1,346.50 2,600.000 65.806 300.7848 1,875.020 1,822.12 726.327 -1,257.180 5,975,518.5151 370,438.3858 0.00 1,436.95 2,700.000 65,806 300.7848 1,916.004 1,863.10 773.013 -1,335.543 5,975,566.5312 370,360.8393 0.00 1,527.39 2,800.000 65.806 300.7848 1,956.987 1,804.09 819.699 -1,413.906 5,975,614.5473 370,263.2927 0.00 1,617.83 2,800.000 65.806 300.7848 1,997.970 1,945.07 866.385 -1,492.269 5,975,662.5635 370,205.7462 0.00 1,708.27 3,000.000 65.806 300.7848 2,038.954 1,986.05 913.071 -1,570.633 5,975,710.5786 370,128.1897 0.00 1,798.72 3,100.000 65.806 300.7848 2,079.937 2,027.04 959.756 -1,648.896 5,975,758.5958 370,050.6531 0.00 1,889.16 3,200.000 65.806 300.7848 2,120.920 2,068.02 1,006.442 -1,727.359 5,975,806.6119 369,873.1066 0.00 1,879.60 3,300.000 65.806 300.7848 2,161.904 2,109.00 1,053.128 -1,805.723 5,975,854.6280 369,895.5600 0.00 2,070.05 3,400.000 65.806 300.7848 2,202.887 2,149.99 1,099.814 -1,884.086 5,975,802.6442 369,818.0135 0.00 2,160.49 3,500.000 65.806 300.7848 2,243.870 2,190.97 1,146.500 -1,962.449 5,975,950.6603 369,740.4669 0.00 2,250.93 3,600.000 65.806 300.7848 2,284.853 2,231.95 1,193.185 -2,040.812 5,975,998.6765 369,662.8204 0.00 2,341.37 3,700.000 65.806 300.7848 2,325.837 2,272.94 1,239.871 -2,119.176 5,976,046.6926 369,585.3739 0.00 2,431.82 3,800.000 65.806 300.7848 2,366.820 2,313.92 1,286.557 -2,187.539 5,976,094.7087 369,507.8273 0.00 2,522.26 3,856.558 65.806 300.7848 2,390.000 2,337.10 1,312.962 -2,241.861 5,976,121.8664 368,463.9674 0.00 2,573.41 9-bJ8" Csg Pt; 38b6' MD, 2390' TVD - 9 5/8" Sperry Drilling Services Planning Report -Geographic HALLIBURTOfN Sperry Drilling Services 7l14J2005 9:33:42AM Page 3 of 9 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD2-02 Company: ConocoPhillips Alaska Inc. TVD Reference: CD2-02 ~ 52.900ft (CD2-02 ~ 52.9' above MSLj Project: Coivilie River Unit MD Reference: CD2-02 (~ 52.900ft (CD2-02 ~ 52.9' above MSL) 51te: Alpine CD2 North Reference: True Well: Plan: CD2-02 Survey Calculation Method: Minimum Curvature Weiibore: Plan: CD2-02 Deaign: CD2-02wp02 Planned Survey CD2-02wp02 Map Map MD Inclination Azimuth ND SSTVD +N/-S +ELW Northing EaetinS DLSEY Vert Section tft- (°) (°) tftf tftl itt) (ft) (tt) iff) t°i~oortl tfu 3,895.356 65.806 300.7848 2,405.900 2,353.00 1,331.075 -2,272.263 5,976,140.4949 369,433.8823 0.00 2,608.50 C-30 3,800.000 65.806 300.7848 2,407.803 2,354.90 1,333.243 -2,275.902 5,976,142.7249 369,430.2808 0.00 2,612.70 4,000.000 65.806 300.7848 2,448.787 2,395.89 1,379.929 -2,354.266 5,876,180.7410 369,352.7342 0.00 2,703.14 4,100.000 65.806 300.7848 2,489.770 2,436.87 1,426.614 -2,432.629 5,976,238.7572 369,275.1877 0.00 2,783.59 4,200.000 65.806 300.7848 2,530.753 2,477.85 1,473.300 -2,510.992 5,976,286.7733 369,197.6411 0.00 2,884.03 4,300.000 65.806 300.7848 2,571.737 2,518.84 1,518.986 -2,589.355 5,976,334.7894 369,120.0946 0.00 2,974.47 4,400.000 65.806 300.7848 2,612.720 2,559.82 1,566.672 -2,667.719 5,876,382.8056 369,042.5481 0.00 3,064.92 4,500.000 65.806 300.7848 2,653.703 2,600.80 1,613.358 -2,746.082 5,976,430.8217 368,865.0015 0.00 3,155.36 4,600.000 65.806 300.7848 2,694.686 2,641.79 1,660.043 -2,824.445 5,876,478.8379 368,887.4550 0.00 3,245.80 4,700.000 65.806 300.7848 2,735.670 2,682.77 1,706.729 -2,902.809 5,976,526.8540 368,808.9084 0.00 3,336.24 4,793.282 65.806 300.7848 2,773.900 2,721.00 1,750.278 -2,975.908 5,976,571.6446 368,737.5712 0.00 3,420.61 C-20 4,800.000 65.806 300.7848 2,776.653 2,723.75 1,753.415 -2,981.172 5,976,574.8702 368,732.3619 0.00 3,426.69 4,900.000 65.806 300.7848 2,817.636 2,764.74 1,800.101 -3,059.535 5,976,622.8863 368,654.8153 0.00 3,517.13 5,000.000 65.806 300.7848 2,858.620 2,805.72 1,846.787 -3,137.888 5,976,670.8024 368,577.2688 0.00 3,607.57 5,100.000 65.806 300.7848 2,899.603 2,846.70 1,893.472 -3,216.262 5,976,718.9186 368,499.7223 0.00 3,698.01 5,200.000 65.806 300.7848 2,940.586 2,887.69 1,940.158 -3,294.625 5,976,766.9347 368,422.1757 0.00 3,788.46 5,300.000 65.806 300.7848 2,981.570 2,928.67 1,986.844 -3,372.888 5,976,814.9509 368,344.6292 0.00 3,878.90 5,400.000 65.806 300.7848 3,022.553 2,969.65 2,033.530 -3,451.352 5,876,862.9670 368,267.0826 0.00 3,969.34 5,500.000 65.806 300.7848 3,063.536 3,010.64 2,080.216 -3,529.715 5,976,910.8831 368,189.5361 0.00 4,059.79 5,600.000 65.806 300.7848 3,104.520 3,051.62 2,126.901 -3,608.078 5,976,958.9993 368,111.9895 0.00 4,150.23 5,700.000 65.806 300.7848 3,145.503 3,092.60 2,173.587 -3,686.442 5,977,007.0154 368,034.4430 0.00 4,240.67 5,800.000 65.806 300.7848 3,186.486 3,133.59 2,220.273 -3,764.805 5,977,055.0316 367,956.8965 0.00 4,331.11 5,900.000 65.806 300.7848 3,227.469 3,174.57 2,266.959 -3,843.168 5,977,103.0477 367,879.3499 0.00 4,421.56 6,000.000 65.806 300.7848 3,268.453 3,215.55 2,313.645 -3,921.531 5,977,151.0638 367,801.8034 0.00 4,512.00 6,100.000 65,806 300.7848 3,309.436 3,256.54 2,360.330 -3,999.895 5,877,199.0800 367,724.2568 0.00 4,602.44 6,200.004 65.806 300.7848 3,350.419 3,297.52 2,407.016 -4,078.258 5,977,247.0961 367,646.7103 0.00 4,692.88 6,300.000 65.806 300.7848 3,391.403 3,338.50 2,453.702 -4,156.621 5,877,295.1123 367,569.1637 0.00 4,783.33 6,400.000 65.806 300.7848 3,432.386 3,379.49 2,500.388 -4,234.885 5,977,343.1284 367,491.6172 0.00 4,873.77 6,500.000 65.806 300.7848 3,473.369 3,420.47 2,547.074 -4,313.348 5,977,391.1445 367,414.0707 0.00 4,964.21 6,600.000 65.806 300.7848 3,514.353 3,461.45 2,593.759 -4,391.711 5,977,439.1607 367,336.5241 0.00 5,054.66 6,700.000 65.806 300.7848 3,555.336 3,502.44 2,640.445 -4,470.074 5,977,487.1768 367,258.9776 0.00 5,145.10 6,800.000 65.806 300.7848 3,596.319 3,543.42 2,687.131 -4,548.438 5,877,535.1830 367,181.4310 0.00 5,235.54 6,900.000 65.806 300.7848 3,637.302 3,584.40 2,733.817 -4,626.801 5,977,583.2091 367,103.8845 0.00 5,325.98 7,000.000 65.806 300.7848 3,678.286 3,625.39 2,780.503 -4,705.164 5,977,631.2252 367,026.3379 0.00 5,416.43 7,100.000 65.806 300.7848 3,718.269 3,866.37 2,827.188 -4,783.528 5,977,679.2414 366,948.7914 0.00 5,506.87 7,200.000 65.806 300.7848 3,760.252 3,707.35 2,873.874 -4,861.891 5,977,727.2575 366,871.2449 0.00 5,597.31 7,300.000 65.806 300.7848 3,801.236 3,748.34 2,820.560 -4,940.254 5,977,775.2737 366,793.6983 0.00 5,687.75 7,400.000 65.806 300.7848 3,842.219 3,788.32 2,967.246 -5,018.617 5,977,823.2898 366,716.1518 0.00 5,778.20 7,404.102 65.806 300.7848 3,843.900 3,791.00 2,969.161 -5,021.832 5,977,825.2593 366,712.9709 0.00 5,781.91 K-3 Marker 7,500.000 65.806 300.7848 3,883.202 3,830.30 3,013.932 -5,086.981 5,977,871.3059 366,638.6052 0.00 5,868.64 7,600.000 65.806 300.7848 3,924.186 3,871.29 3,060.617 -5,175.344 5,977,918.3221 366,561.0587 0.00 5,959.06 7,700.000 65.806 300.7848 3,965.169 3,912.27 3,107.303 -5,253.707 5,977,967.3382 366,483.5121 0.00 6,049.53 7,800.000 65.806 300.7848 4,006.152 3,953.25 3,153.989 -5,332.071 5,978,015.3544 366,405.9656 0.00 6,139.97 7,867.705 65.806 300.7846 4,033.900 3,981.00 3,185.598 -5,385.127 5,978,047.8638 366,353.4625 0.00 6,201.20 Basal K-3 Sand ~ i Sperry Drilling Services Planning Report -Geographic HALLIBURTON Sperry Drilling Services 7/14/2005 9:33:42AM Page 4 of 9 COMPASS 2003.11 Build 50 ORIGINAL • ~.- ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska lnc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-02 Weilbore: Plan: CD2-02 Design: CD2-02wp02 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TW Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBURTON Spsrry Drilling Services Well Plan: CD2-02 CD2-02 ~ 52.800ft (CD2-02 ~ 52.9' above MSL) CD2-02 (~ 52.900ft (CD2-02 (~ 52.8' above MSL) True Minimum Curvature Planned Survey CD2-02wp02 Map Map MD Inclination Azimuth TVD SSTVD +N/S +E/-W Northing Easting pISEV Vert 8ecUon (ft) (% (°) (ft1 Ift1 (ft) (ftj (ftj (~l (°l100ft) tftl' 7,900.000 65.806 300.7848 4,047.135 3,994.24 3,200.675 -5,410.434 5,978,063.3705 366,328.4191 0.00 8,230.41 7,933.586 65.806 300.7848 4,060.900 4,008.00 3,216.355 -5,436.753 5,878,079.4971 366,302.3744 0.00 6,260.79 K-2 Marker 8,000.000 65.806 300.7848 4,088.119 4,035.22 3,247.361 -5,488.797 5,978,111.3867 366,250.8725 0.00 8,320.85 8,100.000 65.806 300.7848 4,129.102 4,076.20 3,294.046 -5,567.160 5,978,159.4028 366,173.3260 0.00 6,411.30 8,140.987 65.806 300.7848 4,145.900 4,093.00 3,313.182 -5,599.279 5,978,178.0833 366,141.5417 0.00 6,448.37 Base K-2 Cycle 8,200.000 65.806 300.7848 4,170.085 4,117.19 3,340.732 -5,645.524 5,978,207.4189 366,085.7794 0.00 6,501.74 8,300.000 65.806 300.7848 4,211.069 4,158.17 3,387.418 -5,723.887 5,878,255.4351 366,016.2329 0.00 6,592.18 8,400.000 65.806 300.7848 4,252.052 4,199.15 3,434.104 -5,802.250 5,978,303.4512 365,940.6863 0.00 6,682.62 8,500.000 65.806 300.7848 4,293.035 4,240.14 3,480.790 -5,880.614 5,978,351.4674 365,863.1398 0.00 6,773.07 8,600.000 65.806 300.7848 4,334.019 4,281.12 3,527.475 -5,858.977 5,878,399.4835 365,785.5933 0.00 6,863.51 6,700.000 65.806 300.7848 4,375.002 4,322.10 3,574.161 -6,037.340 5,978,447.4896 365,708.0467 0.00 8,953.95 8,800.000 65.806 300.7848 4,415.985 4,363.09 3,620.847 -6,115.703 5,978,495.5158 365,630.5002 0.00 7,044.40 8,900.000 65.806 300.7848 4,456.968 4,404.07 3,667.533 -6,194.067 5,978,543.5319 365,552.9536 0.00 7,134.84 9,000.000 65.806 300.7848 4,497.952 4,445.05 3,714.219 -6,272.430 5,978,591.5481 365,475.4071 0.00 7,225.28 8,100.000 65.806 300.7848 4,538.935 4,486.04 3,760.904 -6,350.793 5,978,639.5642 365,397.8605 0.00 7,315.72 9,200.000 65.806 300.7848 4,579.818 4,527.02 3,807.590 -6,429.157 5,978,687.5803 365,320.3140 0.00 7,406.17 9,300.000 65.806 300.7848 4,620.902 4,568.00 3,854.276 -6,507.520 5,978,735.5965 365,242.7675 0.00 7,486.61 8,400.000 65.806 300.7848 4,661.885 4,608.98 3,900.962 -6,585.883 5,978,783.6126 365,165.2209 0.00 7,587.05 9,500.000 65.806 300.7848 4,702.868 4,649.97 3,847.648 -6,664.246 5,978,831.6288 365,087.6744 0.00 7,677.49 9,600.000 65.806 300.7848 4,743.852 4,690.95 3,994.333 -6,742.810 5,978,879.6449 365,010.1278 0.00 7,767.94 9,700.000 65.806 300.7848 4,784.835 4,731.93 4,041.019 -6,820.973 5,878,927.6610 364,932.5813 0,00 7,858.38 8,800.000 65.806 300.7848 4,825.618 4,772.82 4,087.705 -6,899.336 5,978,975.6772 364,855.0347 0.00 7,948.82 9,900.000 65.806 300.7848 4,866.801 4,813.90 4,134.391 -6,977.700 5,979,023.6933 364,777.4882 0.00 8,039.27 10,000.000 85.806 300.7848 4,807.785 4,854.88 4,181.077 -7,056.063 5,979,071.7095 364,689.9417 0.00 8,129.71 10,100.000 65.806 300.7848 4,948.768 4,895.87 4,227.762 -7,134.426 5,979,119.7256 364,622.3951 0.00 8,220,15 10,200.000 65.806 300.7848 4,989.751 4,936.85 4,274.448 -7,212.788 5,979,167.7417 364,544.8486 0.00 8,310.58 10,300.000 65.806 300.7848 5,030.735 4,977.83 4,321.134 -7,291.153 5,979,215.7579 364,467.3020 0.00 8,401.04 10,373.604 65.806 300.7848 5,060.900 5,008.00 4,355.497 -7,348.831 5,979,251.0997 364,410.2247 0.00 8,467.61 Albian 97 10,400.000 65.806 300.7848 5,071.718 5,018.82 4,367.820 -7,369.516 5,979,263.7740 364,388.7555 0.00 8,491.48 10,500.000 65.806 300.7848 5,112.701 5,059.80 4,414.506 -7,447.879 5,979,311.7902 364,312.2089 0.00 8,581.92 10,600.000 65.806 300.7848 5,153.685 5,100.78 4,461.191 -7,526.243 5,979,359.8063 364,234.6624 0.00 8,672.36 10,700.000 65.806 300.7848 5,194.668 5,141.77 4,507.877 -7,604.606 5,979,407.8224 364,157.1159 0.00 8,762.81 10,800.000 65.806 300.7848 5,235.651 5,182.75 4,554.563 -7,682.869 5,979,455.8386 364,078.5693 0.00 8,853.25 10,900.000 65.806 300.7848 5,276.634 5,223.73 4,601.249 -7,761.332 5,978,503.8547 364,002.0228 0.00 8,943.69 11,000.000 65.806 300.7848 5,317.618 5,264.72 4,647.935 -7,839.696 5,979,551.8709 363,924.4762 0.00 9,034.14 11,100.000 65.806 300.7848 5,358.601 5,305.70 4,694.620 -7,818.059 5,979,599.8870 363,846.9297 0.00 9,124.58 11,200.000 65.806 300.7848 5,389.584 5,346.68 4,741.306 -7,996.422 5,979,647.9031 363,768.3831 0.00 9,215.02 11,300.000 65.806 300.7848 5,440.568 5,387.67 4,787.892 -8,074.786 5,978,695.9193 363,691.8366 0.00 9,305.46 11,400.000 65.806 300.7848 5,481.551 5,428.65 4,834.678 -8,153.149 5,979,743.9354 363,614.2900 0.00 8,385.91 11,500.000 65.806 300.7848 5,522.534 5,469.63 4,881.364 -8,231.512 5,979,781.9516 363,536.7435 0.00 8,486.35 11,600.000 65.806 300.7848 5,563.518 5,510.62 4,928.049 -8,309.876 5,979,839.9677 363,458.1970 0.00 9,578.79 11,700.000 65.806 300.7848 5,604.501 5,551.60 4,974.735 -8,388.239 5,979,887.9839 363,381.6504 0.00 8,667.23 11,800.000 65.806 300.7848 5,645.484 5,592.58 5,021.421 -8,466.602 5,979,936.0000 363,304.1038 0.00 8,757.68 11,900.000 65.806 300.7848 5,686.467 5,633.57 5,068.107 -8,544.965 5,979,984.0161 363,226.5573 0.00 9,848.12 12,000.000 65.806 300.7848 5,727.451 5,674.55 5,114.783 -8,623.329 5,980,032.0323 363,148.0108 0.00 8,938.56 12,100.000 65.806 300.7848 5,768.434 5,715.53 5,161.478 -8,701.692 5,980,080.0484 363,071.4642 0.00 10,029.01 7/14/2005 9:33:42AM Page 5 of 9 COMPASS 2003.11 Build 50 OR1~IN~L a • / Sperry Drilling Services HALL{BURTON ConocoPhiNips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: We{I Plan: CD2-02 Company: ConocoPhillips Alaska Inc. TVD Reference: CD2-02 ~ 52.800ft (CD2-02 ~ 52.9' above MSL) Project: Colville River Unit MD Reference: CD2-02 ~ 52.800ft (CD2-02 (~ 52.9' above MSL) Sits: Alpine CD2 North Reference: True Well: Plan: CD2-02 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-02 Design: CD2-02wp02 Planned Survey CD2-02wp02 Map Map MD Inclination Azimuth ND SSTVD +N/S +E(•W Northing Easting pLSEV Vert Section tft) (°) (') (ftI ttt} (tt} (ft} (~1 (fU °/100ft} tft) ; 12,200.000 65.806 300.7848 5,809.417 5,756.52 5,208.164 -8,780.055 5,980,128.0646 362,993.9177 0.00 10,119.45 12,203.618 65.806 300.7848 5,810.900 5,758.00 5,209.853 -8,762.690 5,980,129.8018 362,991.1124 0.00 10,122.72 Albian 96 12,300.000 65.806 300.7848 5,850.401 5,797.50 5,254.850 -8,858.419 5,980,176.0807 362,916.3712 0.00 10,208.89 12,400.000 65.806 300.7848 5,891.384 5,838.48 5,301.536 -8,936.782 5,980,224.0968 362,838.8246 0.00 10,300.33 12,500.000 65.806 300.7848 5,832.367 5,879.47 5,348.222 -9,015.145 5,980,272.1130 362,761.2781 0.00 10,390.78 12,600.000 65.806 300.7848 5,973.351 5,920.45 5,394.907 -9,093.508 5,980,320.1291 362,683.7315 0.00 10,481.22 12,700.000 65.806 300.7848 6,014.334 5,961.43 5,441.593 -9,171.872 5,980,368.1453 362,606.1850 0.00 10,571.66 12,800.000 65.806 300.7848 6,055.317 6,002.42 5,488.279 -9,250.235 5,980,416.1614 362,528.6384 0.00 10,662.10 12,900.000 65.806 300.7848 6,086.301 6,043.40 5,534.965 -9,328.598 5,980,464.1775 362,451.0819 0.00 10,752.55 13,000.000 65.806 300.7848 6,137.284 6,084.38 5,581.651 -9,406.962 5,980,512.1937 362,373.5454 0.00 10,842.89 13,100.000 65.806 300.7848 6,178.267 6,125.37 5,628.337 -9,485.325 5,980,560.2098 362,285.9988 0.00 10,933.43 13,200.000 65.806 300.7848 6,219.250 6,166.35 5,675.022 -9,563.688 5,980,608.2260 362,218.4523 0.00 11,023.88 13,300.000 65.806 300.7848 6,260.234 6,207.33 5,721.708 -9,642.051 5,980,656.2421 362,140.9057 0.00 11,114.32 13,400.000 65.806 300.7848 6,301.217 6,248.32 5,768.394 -9,720.415 5,880,704.2582 362,063.3592 0.00 11,204.76 13,500.000 65.806 300.7848 6,342.200 6,289.30 5,815.080 -9,798.778 5,880,752.2744 361,885.8126 0.00 11,285.20 13,600.000 65.806 300.7848 6,383.184 6,330.28 5,861.766 -9,877.141 5,980,800.2805 361,908.2661 0.00 11,385.65 13,700.000 65.806 300.7848 6,424.167 6,371.27 5,908.451 -9,955.505 5,980,848.3067 361,830.7196 0.00 11,476.09 13,800.000 65.806 300.7848 6,465.150 6,412.25 5,955.137 -10,033.868 5,980,896.3228 361,753.1730 0.00 11,586.53 13,900.000 65.806 300.7848 6,506.134 6,453.23 6,001.823 -10,112.231 5,980,944.3389 361,675.6265 0.00 11,656.97 14,000.000 65.806 300.7848 6,547.117 6,494.22 6,048.509 -10,190.594 5,980,992.3551 361,598.0799 0.00 11,747.42 14,100.000 65.806 300.7848 6,588.100 6,535.20 6,095.185 -10,268.958 5,981,040.3712 361,520.5334 0.00 11,837.86 14,200.000 65.806 300.7848 6,629.083 6,576.18 6,141.880 -10,347.321 5,981,088.3874 361,442.9868 0.00 11,928.30 14,300.000 65.806 300.7848 6,670.067 6,617.17 6,188.566 -10,425.684 5,981,136.4035 361,365.4403 0.00 12,018.75 14,400.000 65.806 300.7848 6,711.050 6,658.15 6,235.252 -10,504.048 5,981,184.4196 361,287.8838 0.00 12,109.18 14,500.000 65.806 300.7848 6,752.033 6,699.13 6,281.938 -10,582.411 5,881,232.4358 361,210.3472 0.00 12,188.63 14,600.000 65.806 300.7848 6,793.017 6,740.12 6,328.624 -10,660.774 5,981,280.4519 361,132.8007 0.00 12,290.07 14,700.000 65.806 300.7848 6,834.000 6,781.10 6,375.309 -10,739.137 5,981,328.4681 361,055.2541 0.00 12,380.52 14,787.597 65.806 300.7848 6,868.900 6,817.00 6,416.205 -10,807.781 5,981,370.5287 380,987.3258 0.00 12,458.74 HRZ 14,800.000 85.806 300.7848 6,874.983 6,822.08 8,421.995 -10,817.501 5,981,376.4842 360,877.7076 0.00 12,470.96 14,900.000 65.808 300.7848 6,915.967 6,863.07 6,468.681 -10,895.864 5,981,424.5004 360,900.1610 0.00 12,561.40 15,000.000 65.806 300,7848 6,956.950 6,904.05 6,515.367 -10,874.227 5,981,472.5165 360,822.6145 0.00 12,651.84 15,100.000 65.806 300.7848 6,997.933 6,945.03 6,562.053 -11,052.591 5,981,520.5326 360,745.0680 0.00 12,742.29 15,200.000 65.806 300.7848 7,038.916 6,886.02 6,608.738 -11,130.954 5,981,568.5488 360,667.5214 0.00 12,832.73 15,207.280 65.806 300.7848 7,041.900 6,989.00 6,612.137 -11,136.659 5,981,572.0443 360,661.8761 0.00 12,838.31 Base HRZ 15,300.000 65.806 300.7848 7,079.900 7,027.00 6,655.424 -11,209.317 5,981,616.5649 360,589.9749 0.00 12,923.17 15,334.161 65.806 300.7848 7,093.800 7,041.00 6,671.372 -11,236.087 5,981,632.9677 360,563.4843 0.00 12,954.07 K-1 Marker 15,400.000 65.806 300.7848 7,120.883 7,067.98 6,702.110 -11,287.680 5,981,664.5811 360,512.4283 0.00 13,013.62 15,439.082 65.806 300.7848 7,136.900 7,084.00 6,720.356 -11,318.306 5,881,683.3466 360,482.1219 0.00 13,048.86 Kuparuk Fm 15,476.222 65.806 300.7848 7,152.122 7,099.22 6,737.695 -11,347.411 5,981,701.1801 360,453.3205 0.00 13,082.55 Begin Dir; 4° DLS, 0° TFO, 15476' MD, 7152' ND 15,500.000 66.754 300.7848 7,161.686 7,108.79 6,748.837 -11,366.112 5,981,712.6392 360,434.8139 3.99 13,104.14 7/1412005 9:33:42AM Page 6 of 9 COMPASS 2003.11 Build 50 OR~1C~. • Cono~oPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Bite: Alpine CD2 Wafl: Plan: CD2-02 Wellbore: Plan: CD2-02 Deaign: CD2-02wp02 Sperry Drilling Services HALLtBURTON Planning Report -Geographic Sperry Drilling Services Local Co-onitnate Reference: Well Plan: CD2-02 TVD Reference: CD2-02 (~ 52.900ft (CD2-02 ~ 52.9' above MSL) MD Reference: CD2-02 ~ 52,900ft (CD2-02 ~ 52.9' above MSL) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey CD2-02wp02 MD Inclination Azimuth Ift) (°) (°) 15,564.792 89.348 300.7849 LCU-Miluveach 15,600.000 70.754 300.7849 15,686.362 74.211 300.7849 Miluveach A 15,700.000 74.754 300.7849 15,701.340 74.810 300.7849 Alpine D 15,737.361 76.251 300.7849 Alpine C 15,741.595 76.421 300.7849 Map Map TVD 3SND +N/S +E/-W Northing Easting DI.SEY veK Sactio~t (R) (R) (ft) (ft) (Rj (ff) (°l100ft) (ftT 7,185.800 7,133.00 6,779.592 -11,417.736 5,981,744.2710 360,383.7282 4.00 13,163.72 7,197.911 7,145.01 6,796.531 -11,446.168 5,981,761.6924 360,355.5825 3.99 13,196.53 7,223.800 7,171.00 6,838.676 -11,516.911 5,981,805.0390 360,285.5874 4.00 13,278.18 7,227.548 7,174.65 6,845.402 -11,528.200 5,981,811.9564 360,274.4158 3.98 13,291.21 7,227.900 7,175.00 6,846.064 -11,529.311 5,981,812.6372 360,273.3163 4.19 13,282.49 7,236.900 7,184.00 6,863.915 -11,559.274 5,981,830.9968 360,243.6653 4.00 13,327.07 7,237.800 7,185.00 6,866.020 -11,562.808 5,981,833.1621 360,240.1684 4.00 13,331.15 15,782.329 78.050 300.7849 7,246.900 7,194.00 6,886.353 -11,596.937 5,981,854.0743 Alpine A 15,800.000 78.754 300.7849 7,250.452 7,197.55 6,895.212 -11,611.808 5,981,863.1861 15,800.000 82.754 300.7849 7,266.511 7,213.61 6,945.719 -11,696.584 5,961,915.1321 16,000.000 86.754 300.7849 7,275.648 7,222.75 6,996.678 -11,782.117 5,981,967.5413 16,030.000 87.857 300.7848 7,277.032 7,224.13 7,012.014 -11,807.862 5,981,983.3162 7" Csg Pt; 15030' MD, 72 77' TVD; 5144 ' FNL & 2803' F EL; Sec28-T1 2N-R04E - 7" 16,092.081 90.440 300.7849 7,277.900 7,225.00 7,043.783 -11,861.186 5,982,015.9900 Target (Heel); 15092' MD , 7277' TVD -Continue Dir; 2. 74° DLS, 90° TFO, 16092' MD, 7277' TVD -CD2-02wp02 Heel 16,100.000 90.440 301.0001 7,277.839 7,224.94 7,047.849 -11,667.981 5,982,020.1711 16,200.000 90.439 303.7402 7,277.072 7,224.17 7,101.383 -11,952.430 5,982,075.1387 16,300.000 90.438 306.4803 7,276.306 7,223.41 7,158.894 -12,034.223 5,982,134.0357 16,400.000 90.435 309.2203 7,275.544 7,222.64 7,220.249 -12,113.173 5,982,196.7276 16,500.000 90.432 311.9604 7,274.787 7,221.89 7,285.307 -12,188.089 5,982,263.0711 16,600.000 90.427 314.7005 7,274.038 7,221.14 7,353.922 -12,261.829 5,982,332.9143 16,700.000 90.422 317.4405 7,273.287 7,220.40 7,425.935 -12,331.195 5,982,406.0977 16,800.000 90.415 320.1806 7,272.567 7,219.6? 7,501.181 -12,397.040 5,982,482.4538 16,900.000 90.408 322.9206 7,271.848 7,218.95 7,579.489 -12,458.212 5,982,561.8082 17,000.000 90.399 325.6607 7,271.145 7,218.24 7,660.680 -12,517.570 5,982,643.9793 17,100.000 90.390 328.4007 7,270.456 7,217.56 7,744.568 -12,571.980 5,982,728.7793 17,200.000 90.380 331.1407 7,269.784 7,216.88 7,830.962 -12,622.317 5,982,816.0142 17,236.806 90.376 332.1511 7,269.542 7,216.64 7,863.351 -12,639.796 5,982,848.6954 Start GeoSteer; 90.376° I NC, 17236' MD, 7269' TVD 17,238.827 90.375 332.2065 7,269.529 7,216.63 7,865.139 -12,640.739 5,982,850.4987 17,300.000 90.377 332.1958 7,269.127 7,216.23 7,919.250 -12,869.268 5,982,905.0863 17,400.000 90.381 332.1784 7,268.465 7,215.57 8,007.686 -12,715.825 5,982,994.3102 17,500.000 90.384 332.1609 7,267.798 7,214.90 8,096.127 -12,762.610 5,983,083.5204 17,600.000 90.387 332.1435 7,267.126 7,214.23 8,184.545 -12,809.321 5,983,172.7167 17,700.000 90.390 332.1260 7,266.448 7,213.55 8,272.947 -12,856.059 5,983,261.8993 17,800.000 90.383 332.1086 7,265.765 7,212.87 8,361.336 -12,902.825 5,883,351.0680 17,900.000 90.396 332.0912 7,265.077 7,212.18 8,449.710 -12,949.617 5,983,440.2230 18,000.000 90.389 332.0737 7,264.383 7,211.48 8,538.071 -12,986.436 5,883,529.3641 18,100.000 90.402 332.0563 7,263.683 7,210.78 8,626.416 -13,043.282 5,983,618.4914 18,200.000 90.405 332.0388 7,262.978 7,210.08 8,714.748 -13,090.154 5,983,707.6049 360,206.3951 4.00 13,370.54 360,191.6794 3.89 13,387.71 360,107.7862 4.00 13,485.55 360,023.1450 4.00 13,584.27 359,997.6684 4.01 13,613.98 359,944.9000 4.00 13,675.53 359,938.1759 2.72 13,683.38 359,854.6627 2.74 13,782.84 359,773.8728 2.74 13,882.68 359,695.9907 2.74 13,982.66 359,621.1947 2.74 14,082.57 359,549.6557 2.74 14,182.16 359,481.5373 2.74 14,281.22 359,416.9953 2.74 14,379.51 359,356.1772 2.74 14,476.82 359,299.2221 2.74 14, 572.91 359,246.2602 2.74 14,667.58 359,197.4127 2.74 14,760.59 359,180.4922 2.75 14,794.37 359,179.5797 2.74 14,796.22 359,151.8837 0.02 14,852.13 359,106.8503 0.02 14,943.52 359,081.6897 0.02 15,034.83 359,016.5020 0.02 15,126.36 358, 971.2871 0.02 15,217.79 358, 926.0451 0.02 15, 3 09.24 358,880.7759 0.02 15,400.70 358,835.4797 0.02 15,492.17 358,790.1583 0.02 15,583.65 358,744.8057 0.02 15,675.15 7/14/2005 9:33:42AM Page 7 of 9 COMPASS 2003.11 Build 50 ~R~G~~AL ConocoPhillips Alaska • Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Sita: Alpine CD2 Well: Plan: CD2-02 Wellbore: Plan: CD2-02 Design: CD2-02wp02 Sperry Drilling Services Planning Report -Geographic Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBUR70N Sperry Drilling Services Well Plan: CD2-02 CD2-02 ~ 52:800ft (CD2-02 ~ 52.9' above MSL) CD2-02 ~ 52.900ft (CD2-02 ~ 52.9' above MSL) True Minimum Curvature Planned Survey C02-02wp02 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEY Vert Seetfgsf (ft) (°) (°) (ft) (ftl (ft) (ft) (ft) (~ (°/100ft) (>~ 18,300.000 90.409 332.0214 7,262.268 7,209.37 8,803.065 -13,137.054 5,983,796.7045 358,699.4281 0.02 15,766.66 18,400.000 90.412 332.0039 7,261.552 7,208.65 8,891.368 -13,183.980 5,983,885.7902 358,654.0234 0.02 15,858.18 18,500.000 90.415 331.9865 7,260.830 7,207.93 8,979.656 -13,230.934 5,983,974.8621 358,608.5915 0.02 15,849.71 18,600.000 90.418 331.9690 7,260.104 7,207.20 9,067.930 -13,277.914 5,984,063.8201 358,563.1325 0.02 16,041.25 18,700.000 90.421 331.9516 7,259.372 7,208.47 9,156.190 -13,324.921 5,984,152.9642 358,517.8465 0.02 16,132.$1 18,800.000 90.424 331.8341 7,258.634 7,205.73 9,244.436 -13,371.955 5,984,241.9945 358,472.1333 0.02 16,224.38 18,900.000 90.427 331.9167 7,257,891 7,204.99 9,332.667 -13,419.016 5,984,331.0108 358,426.5931 0.02 16,315.96 19,000.000 90.430 331.8992 7,257.142 7,204.24 9,420.884 -13,466.103 5,884,420.0132 358,381.0258 0.02 16,407.58 19,100.000 90.434 331.8818 7,256.388 7,203.49 9,509.086 -13,513.218 5,984,509.0017 358,335.4314 0.02 16,499.16 19,200.000 80.437 331.8643 7,255.629 7,202.73 9,597.274 -13,560.359 5,984,597.9763 358,289.8099 0.02 16,590.78 19,300.000 90.440 331.8469 7,254.864 7,201.96 9,685.448 -13,607.527 5,984,686.9370 358,244.1613 0.02 16,682.41 19,400.000 90.443 331.8294 7,254.094 7,201.19 8,773.607 -13,654.722 5,984,775.8837 358,198.4857 0.02 16,774.05 19,500.000 90.446 331.8120 7,253.318 7,200.42 8,861.751 -13,701.944 5,884,864.8165 358,152.7830 0.02 16,865.71 19,600.000 90.449 331.7945 7,252.537 7,199.64 9,949.882 -13,749.193 5,984,953.7353 358,107.0532 0.02 16,957.37 19,700.000 90.452 331.7771 7,251.750 7,198.85 10,037.988 -13,796.468 5,985,042.6401 358,061.2964 0.02 17,049.05 19,800.000 90.455 331.7597 7,250.958 7,198.06 10,126.099 -13,843.770 5,985,131.5309 358,015.5126 0.02 17,140.74 19,900.000 90.459 331.7422 7,250.160 7,197.26 10,214.186 -13,891.100 5,985,220.4078 357,868.7016 0.02 17,232.45 20,000.000 90.462 331.7248 7,249.357 7,196.46 10,302.258 -13,938.455 5,985,309.2707 357,923.8837 0.02 17,324.16 20,100.000 90.465 331.7073 7,248.549 7,185.65 10,390.317 -13,985.838 5,985,398.1196 357,877.9987 0.02 17,415.89 20,200.000 90.488 331.6899 7,247.735 7,194.83 10,478.361 -14,033.247 5,885,486.9545 357,832.1067 0.02 17,507.63 20,300.000 90.471 331.6724 7,246.916 7,194.02 10,566.390 -14,080.684 5,985,575.7753 357,786.1876 0.02 17,599.38 20,400.000 90.474 331.6550 7,246.091 7,193.19 10,654.404 -14,128.147 5,985,664.5821 357,740.2416 0.02 17,691.14 20,500.000 90.477 331.6375 7,245.261 7,192.36 10,742.405 -14,175.637 5,985,753.3749 357,694.2685 0.02 17,782.92 20,600.000 80.480 331.6201 7,244.425 7,191.52 10,830.390 -14,223.153 5,985,842.1537 357,648.2684 0.02 17,874.71 20,700.000 90.483 331.6026 7,243.584 7,190.68 10,918.361 -14,270.696 5,985,930.9183 357,602.2412 0.02 17,966.51 20,800.000 90.487 331.5852 7,242.737 7,188.84 11,006.318 -14,318.267 5,986,019.6690 357,556.1871 0.02 18,058.32 20,900.000 90.490 331.5677 7,241.885 7,188.88 11,094.260 -14,365.863 5,986,108.4055 357,510.1060 0.02 18,150.14 21,000.000 90.483 331.5503 7,241.028 7,188.13 11,182.188 -14,413.487 5,886,197.1280 357,463.9978 0.02 18,241.98 21,100.000 90.496 331.5328 7,240.165 7,187.26 11,270.101 -14,461.137 5,886,285.8364 357,417.8627 0.02 18,333.83 21,200.000 90.499 331.5154 7,239.297 7,186.40 11,357.898 -14,508.814 5,986,374.5307 357,371.7006 0.02 18,425.69 21,300.000 90.502 331.4979 7,238.423 7,185.52 11,445.883 -14,556.518 5,986,463.2108 357,325.5115 0.02 18,517.56 21,359.535 90.504 331.4875 7,237.900 7,185.00 11,498.198 ~ -14,564.832 ~ 5,986,516.0000 357,298.0000 0.02 18,572.26 Target (Toe); 21359' MD, 7237' TVD, 663' FNL 8 296' FEL; Sec29-T12N-R04E - 6-118" Open Hole -CD2-02wp02 Toe Geologic Targets Plan: CD2-02 ~ TVD Target Name +N/.g +E/.W Northing Fasting (ft) -Shape ft ft (ft) (tU J 7,237.900 CD2-02wp02 Toe 11,498.198 -14,584.932 5,986,516.0000 357,298.0000 - Point 7,277.800 CD2-02wp02 Heel 7,043.783 -11,861.186 5,982,015.9900 358,944.8000 - Point 7/14/2005 9:33:42AM Page 8 of 9 COMPASS 2003.11 Build 50 ~° `--' ConocoPhi{lips Alaska Sperry Drilling Services Planning Report -Geographic HALLIBUF~TON Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Welf Plan: CD2-02 Company: ConocoPhillips Alaska Inc. TW Reference: CD2-02 ~ 52.900ft (CD2-02 (~ 52.9' above MSL) Project: Colville River Unit MD Reference: CD2-02 ~ 52.900ft (CD2-02 ~ 52.9' above MSL) Site: Alpine CD2 North Reference: True Well: Plan: CD2-02 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD2-02 Dsaign: CD2-02wp02 Prognosed Casing Points Measured Vertical Casing Hote Depth Depth Diameter Diameter (ft) (ft) (,.~ (..) 3,856.559 2,390.000 9-5l8 12-1/4 18,030.000 7,277.032 7 8-3/4 21,359.524 7,237.900 4-1/2 6-118 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°I (°) (ft) (tt) Eft) a~ 3,895.356 85.81 300.78 2,405.800 1,331.07 -2,272.26 C-30 4,793.282 65.81 300.78 2,773.900 1,750.28 -2,875.91 C-20 7,404.102 65.81 300.78 3,843.900 2,969.16 -5,021.83 K-3 Marker 7,867.705 65.81 300.78 4,033.900 3,185,60 -5,385.13 Basal K-3 Sand 7,933.586 65.81 300.78 4,060.900 3,216.35 -5,436.75 K-2 Marker 8,140.987 85.81 300.78 4,145.900 3,313.18 -5,599.28 Base K-2 Cycle 10,373.604 65.81 300.78 5,060.900 4,355.50 -7,348.83 Albian 97 12,203.618 65.81 300.78 5,810.900 5,209.85 -8,782.89 Albian 98 14,787.597 65.81 300.78 6,869.900 6,416.20 -10,807.78 HRZ 15,207.280 65.81 300.78 7,041.900 6,612.14 -11,136.66 Base HRZ 15,334.161 65.81 300.78 7,083.900 6,671.37 -11,23(1.09 K-1 Marker 15,438.082 65.81 300.78 7,136.800 6,720.36 -11,318.31 Kuparuk Fm 15,564.792 69.35 300.78 7,185.900 6,779.59 -11,417.74 LCU-Miluveach 15,686.362 74.21 300.78 7,223.900 6,838.68 -11,516.91 Miluveach A 15,701.340 74.81 300.78 7,227.900 6,846.06 -11,529.31 Alpine D 15,737.361 76.25 300.78 7,236.800 6,863.91 -11,559.27 Alpine C 15,782.329 78.05 300.78 7,246.900 6,886.35 -11,596.94 Alpine A 7/14/2005 9:33:42AM Page 9 of 9 COMPASS 2003.11 Build 50 ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-02 Plan: CD2-02 CD2-02wp02 Anticollision Report 13 July, 2005 HA~~.~BU~-ro~v Sperry Drilling. Services OR161NAL 0 z r ConocoPhil~ips H4f~3 HALLIBURTON Sperry Drillitg Services ..".21,"'l7~ ANTI~COLLi510N SETTING; bbrpolatlon MNhod: MD Inbrval: SOSbtkns Gakula0on McOiod: Minimum turvatur• ~~ Da pth Range From 37.000 Te 21358426 Error Model: ISCWSA Maximum RanOa: 5000 .. .m Error SUrtaca: Elliptical Conic R.br•ne.w•IC plan: CD2-02wp02 wamingM.thed: RaksBased SURVEY PROGRAM qrr: 280507-0700:80:00 Vatldakd: V<s Vnsion: 1.000 DepW Fran Deprh Ta Survev/PI•o Tod 37.OOn 9511.000 CD27IZwp02 CR-GYRO-SS 950.000 21759.519 CD2-02wp02 MWD+IFR-AK-CAZSC YAea•: 1.n: ~~ ~ r nrr~n~r.~r..,°„ EM~r:i ~ ; ~.,.. JJO 3D ,~ DD2U0.1 //'~ - . , ,~ 120 J)•~1 300 100 60 1 -._._,..,.:010.1: NO - ' ~ CUP-e)Vq]:. i 1 ` /_ /' - \ - z7o Critical Issues: 2.6' to tolerance line of CD2-03 around 300' MD 20' to tolerance line of CD2-06 around 500' MD 32' to tolerance line of CD2-09 around 750' MD 42' to tolerance line of CD2-09 around 1000' MC 55' to tolerance line of CD2-09 around 1250' M[ 165' to tolerance line of CD2-18 around 15447 I 200' to tolerance line of CD2-21 around 19869' I • \ .. ~~_ ) 210 1 ~ / ~ __ --x.120 .. 1P5~ ~.~ r-ionet 1a\YYY~ ~~ ~~ i cut-+p ~L 1 210 - _ '~.` - 150 _ __. \\ ~- ~fn ~- CD2 tb Sag . \ -,area ~ x ~ nnn. CDP t1 180 PNn'. CDP~1 PA CD].:y ~ ~UP.tS N?M - ..... . , 1 gyn. nm cOS+sPq: cox-u I 'cozm~l u,P~r coz a. a~ - f ravellins Qiinder Azimuth (TFO+A211 ~°~ vs Centre m Centro Separation 120 fl/ink o~ 1eo Ir~~rlliU,l ~Inl~r \im nth I FI/'\/III-~ l'iiri int rnln ~.l~nr,~v~ tl ~n SECTION DETAILS Ser MD Ine Azi TVD +N/-S +Fl-W DIzB TFace VSec Tareel 1 37.000 0.000 O.OUW 37.000 0.000 0.000 0.00 0.0000 0.000 Z 200.000 0.11011 O.W011 2W.000 0.000 0.000 0.00 0.0000 0.000 7 100.000 12.000 295.0000 5)7.085 17.f38 -77.825 }.00 2)5.0000 10.621 1 I9K.tl5c 65.806 300.]878 If07.310 72L001 '15.34 1.00 f.t35) 876.20 5 1_476.222 f5.806 700.7818 7152.122 6737.LM -1131].111 0.00 0.0000 13082.517 f 16092.081 90.170 300.7879 7277.)00 700.783 -1IB61./B6 1.00 0.0001 136]5,525 CD202•'pU3 Heel 7 17735.997 90.776 332.1289 72f9.47 7N62.636 -12639A I8 2.7/ )0.0000 17793.07 tl 21759.525 90.501 331.1655 7237.)00 11798.198 -IIStli.932 0.01 -77.20tl5 18172.218 CD2-02w'p1P2 Tne 7/13/2005 4:30 PM i ,~, ConocoPhiltips Alaska Company: ConocoPhillips Alaska Inc. Proiect: Colville River Unit Reference Site: Alpine CD2 Site Error. O.000ft Reference Well: Plan: CD2-02 Well Error: O.000ft Reference Wellbore Plan: CD2-02 Reference Design: CD2-02wp02 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: HALI_IBURTON Sperry Drilling Services Well Plan: CD2-02 CD2-02 C~ 52.900ft (CD2-02 ~ 52.8' above MSL) CD2-02 ~ 52.900ft (CD2-02 ~ 52.8' above MSLj True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference CD2-02wp02 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method MD Interval 25.000ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of S,000.OOOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma 8urveY Toot Program Date 7/13/2005 From To (gt (fU Survey (Wellbore) Tool Name Description 37.000 950.000 CD2-02wD02 (Plan: CD2-02) CB-GYRO-SS Camera based gyro single shot 850.000 21,359.519 CD2-02wp02 (Plan: CD2-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/13/2005 3:15:02PM Page 2 of 3 COMPASS 2003.11 Build 50 ~-' ~ Sperry Drilling Services' 1B TON ConocoPhilli 5 MALL. tJR p Anticollision Report Alaska Spenry Drilling Services Company: ConocoPhillips Alaska Inc. Local Co-ordinate Reference: Well Plan: CD2-02 Proiect: Colville River Unit ND Reference: CD2-02 ~ 52.800ft (CD2-02 (~ 52.8' above MSL) Reference Site: Alpine CD2 MD Reference: CD2-02 ~ 52.900ft (CD2-02 ~ 52.9' above MSL) Site Error: O.000ft North Reference• True Reference Wetl: Plan: CD2-02 Survey Calculation Method: Minimum Curvature Weil Error: O.000ft Output errors are at 1.00 sigma Reference Welibore Plan: CD2-02 Database: EDM 2003.11 Single User Db Reference Design: CD2-02wp02 Offset TVD Reference: Offset Datum Summary Reference Offaet Centre to No-Go Allowable Measured Measure Centre Distance Deviation Warnirsg Site Name Depth d Distance (ft) from Plan Offset WeII - Wellbore -Design Iftl (ftI (ftl Alpine CD2 CD2-05 -CD2-05 -CD2-05 249.889 250.000 31.246 5.23 26.021 Pass -Major Risk CD2-05 -CD2-05L1 -CD2-05L1 248.889 250.000 31.246 5.23 26.021 Pass -Major Risk CD2-O6 -CD2-06 -CD2-06 544.247 550.000 30.458 10.50 20.169 Pass -Major Risk CD2-07 -CD2-07 -CD2-07 420.561 425.000 43.013 8.88 34.136 Pass -Major Risk CD2-07 -CD2-07P81 -CD2-07P81 420.561 425.000 43.013 8.89 34.027 Pass -Major Risk CD2-07 -CD2-07P82 -CD2-07P62 420.561 425.000 43.013 8.98 34.027 Pass -Major Risk CD2-08 -CD2-08 -CD2-08 347.388 350.000 59.007 7.36 51.653 Pass -Major Risk CD2-08 -CD2-09 -CD2-09 784.052 800.000 48.115 16.23 32.662 Pass -Major Risk CD2-09 -CD2-09L1 -CD2-09L1 784.052 800.000 48.115 16.23 32.662 Pass -Major Risk CD2-09 -CD2-O9P81 -CD2-09PB1 784.052 800.000 48.115 16.23 32.862 Pass -Major Risk CD2-10 -CD2-10 -CD2-10 274.059 275.000 80.381 5.03 75.354 Pass -Major Risk CD2-10 -CD2-10P61 -CD2-10P61 274.059 275.000 80.381 5.18 75.208 Pass -Major Risk CD2-12 -CD2-12 -CD2-12 635.016 649.990 102.790 12.44 90.533 Pass -Major Risk CD2-13 -CD2-13 -CD2-13 393.061 400.000 110.492 8.41 102.086 Pass -Major Risk CD2-13 -CD2-13PB1 -CD2-13PB1 393.061 400.000 110.492 8.41 102.086 Pass -Major Risk CD2-13 -CD2-13P62 -CD2-13PB2 393.061 400.000 110.492 8.41 102.086 Pass -Major Risk CD2-14 -CD2-14 -CD2-14 248.370 250.000 119.874 4.57 115.308 Pass -Major Risk CD2-15 -CD2-15 -CD2-15 272.843 275.000 130.466 5.53 124.940 Pass -Major Risk CD2-15 - GD2-15PB1 -CD2-15PB1 272.843 275.000 130.466 5.64 124.831 Pass -Major Risk CD2-15 -CD2-15PB2 -CD2-15P62 272.843 275.000 130.466 5.64 124.831 Pass -Major Risk CD2-16 -CD2-16 -CD2-16 272.546 275.000 140.118 5.48 134.643 Pass -Major Risk CD2-16 -CD2-16 (Sag) -CD2-16 (Sag) 272.547 275.000 140.119 4.95 135.177 Pass -Major Risk CD2-18 -CD2-18 -CD2-18 320.321 325.000 160.756 6.77 153.984 Pass -Major Risk CD2-18 -CD2-18PB1 -CD2-18P81 320.321 325.000 160.756 6.77 153.984 Pass -Major Risk CD2-18 -CD2-19 -CD2-19 248.360 250.000 169.975 4.56 165.418 Pass -Major Risk CD2-20 -CD2-20 -CD2-20 319.252 325.000 179.876 6.77 173.111 Pass -Major Risk CD2-21 -CD2-21 -CD2-21 271.141 275.000 190.885 5.58 185.313 Pass -Major Risk CD2-21 -CD2-21 P81 -CD2-21 P81 271.141 275.000 190.895 5.69 185.203 Pass -Major Risk CD2-22 -CD2-22 -CD2-22 247.828 250.000 200.156 4.55 185.607 Pass -Major Risk CD2-23 -CD2-23 -CD2-23 341.923 350.000 210.396 6.83 203.472 Pass -Major Risk CD2-23 -CD2-23P61 -CD2-23P61 341.923 350.000 210.386 6.93 203.472 Pass -Major Risk CD2-24 -CD2-24 -CD2-24 247.166 250.000 220.217 4.54 215.675 Pass -Major Risk CD2-24 -CD2-24PB1 -CD2-24P61 247.166 250.000 220.217 4.54 215.675 Pass -Major Risk CD2-25 -CD2-25 -CD2-25 270.565 275.000 230.358 5.32 225.042 Pass -Major Risk CD2-26 -CD2-26 -CD2-26 410.566 425.000 238.851 7.75 232.178 Pass -Major Risk Plan: CD2-01 -Plan: CD2-01 -Plan: CD2-01 (wp01 300.132 299.999 11.350 6.25 5.095 Pass -Major Risk Plan: CD2-03 -Plan: CD2-03 -CD2-03 Rig Surveys 300.473 300.000 9.189 6.45 2.740 Pass -Major Risk Plan: CD2-03 -Plan: CD2-03 -CD2-03wp03 325.318 325.000 8.617 6.81 2.816 Pass -Major Risk Plan: CD2-04 -Plan: CD2-04 -Plan: CD2-04 (wp02 275.463 275.000 20.505 5.12 15.393 Pass -Major Risk Plan: CD2-04 -Prelim: CD2-04PB1 -CD2-04PB1wp 275.463 275.000 20.505 5.12 15.393 Pass -Major Risk Plan: CD2-11 -Plan: CD2-11 -CD2-11wp07 371.624 375.000 91.548 7.85 83.703 Pass -Major Risk Plan: CD2-11 -Prelim: CD2-11PB1 -CD2-11PB1wp 371.624 375.000 81.548 7.85 83.703 Pass- Major Risk Plan: CD2-17 -CD2-17 -CD2-17 272.415 275.000 149.766 5.04 144.733 Pass -Major Risk Plan: CD2-17 -Plan: CD2-17A -Plan: CD2-17A (wp 272.415 275.000 149.766 5.04 144.733 Pass -Major Risk Alpine CD5 Plan: AW22P -Plan: AW22P -Plan: AW22P 16,864.311 17,674.624 1,942.602 687.49 1,257.240 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/13/2005 3:15:02PM Page 3 of 3 COMPASS 2003.11 Build 50 :?RIGINAL WE3IBDRE TARGEr OEfA1S Q~AlW COOf~lATES) / GYadelbn Mrll~ MMnvnGLrvM~e Con xoPhilli s 8°'M°°°a Tnv.Gyidr Nwlh ~~ sue" Project: Colville River Unit Name ND +ws +~-w Northing Fasting snaps p c ~~ ~y ~t Site: Alpine C02 CD2-02Tce lcopyl 7237.900 11498.198 -14584.932 5986516A000 357298.0000 Poin WaNp MMlnd Rb Baed cD2-0zrrpoz roe n37.9o0 11498.198 -14584.932 5986516.0000 357298.0000 porn rUa:,k:a O.oe.ao ¢ ~ ~ Well: Plan: CD2-02 coz-0zwpoz Toe circle 7z37.9o0 11asa.19e -1a5ea.93z seesslsmoo 35729s.oooo C:c~9lRadins: l3zo.oool 6 Welltare: Plan: CD2-02 cozen Heel1~1 7zn.9oo s9ozz3a -1zlzs.rt4 5981879D000 359678.0000 Poirt CD2-0Zwp02 Heel 7277.900 7043.783 -11861.166 5982015.9900 359944.9000 Poin Grwne Leval 1s 9oo CD2-02wp02 Heel Circle 7277.900 7043.763 -11861.186 5882015.9900 759hW.9000 Cicle (Radius: 1320.000) HALLIBURTON . . RKB coz~za;zxKm::z.~: ,,~r.~..,,:~,~ Plan: CD2-02Wp02 N«m~"gASp r s974no Isu+ Sperry Drilling Services ~"^ryasax 37,6e265~"' ANNOTATIONS TVD MD Annodtlon 37.000 SHL - 1588ft FNL d 15828 FEl, Sect-T11Ni24E 299.984 300.010 Begin D'e !~ 3.00 DLS: ]00.0108 MD,300.OtOR ND 597.092 800.010 Corninue Dir ~ 1.00 DLS: 800.0108 MD, 588.7788 1843.752 2035.700 End Dir, Start Sail ®88.154: 2035.700fl MD, 1890. 2381.440 3880.072 9.5/8" Csg PI ... Dnl out b12' Hole :3764.753 7095.80115738.800 Begin Dir ~ 4.00 DLS: 15338.BOOfl MD,7069.081R N 7278.85718228.000 7" Cap Pt ... Begin 61/8" Role: 18228.0008 MD, 7 7275.93916348.100 Tarps[ (Heel) GeoSteer, 18348.t00fl MD, 7277.8008 usr4a~T4as tb iMJ MD Nn. ~ 1 xtoom0 ass sac sae z 791m2 1eW0aC0 r 1 3 rar4m setse~r, la. a1n c V / _ °o 0 z r ~, I L ~, z ~o E (n ~~~' aoy_ay~ GO2;1,~ ~~ Heel ofi~D2=$2wp0~t~ -- Toe of CD2-18 distance: ~:~ 606 feet X03-t5~ -teooo -lsooo -14aoo -12000 -laooo aooo west(-East(+) (2000 Win) sooo -4DOo Spatial Calculator .i~ ..~.... 15447' MD on CD2-02wp02 ~ 18019' MD on CD2-18 Displacement (ft) 2-D Closure Angle (deg from True North) 2-D Closure Distance (ft in horizontal plane) 3-D Distance {ft) Coords. -ASP Lat. ('Y) Dep. (X) (ft) 5981687.15 360475.98 7140.00 5981155.47 360209.65 7259.00 S -536.16 W SW 205.63 594.66 606.45 • • Spatial Calculator Page 1 of 1 (CD2-02wp02 CD2-18 Heel2Toe Spatial Calculator.xls) 7/14/2005 8:02 AM n=uPranoN I CRU CD2-02 T1 ~~, ~~~, U.N1, Proposed Inj. - - "` - - ~ ~ - - -~ - - ~ - - Alpine Oil Pool ~ 2051090 I Confidential wells shown as red I Area of Review SFD 7/19/2005 ~~ Slotted Liner ~~ °°'-°' C:02-02 1p00 „coz-tt - coz--o~ 2-2tPBt C02-07 \ CD2-z1 CDZ-09 4 C02-10 `\ ~9~ ` CD2-zo ~~ 1~p0 coz-IJ ~. ~1p $O ~ GDZ-tz ~c~ o ~CDI-0: a CD2-2J ! CD I -J`,i coz- a ~ cot- t `"~ cot-zt ~CO1-z~ z_ts ~^t-JD ,~ coz ze ,~ ~ C _17q CD2-I 1-32 C01-Ot CD 59 ~G02-Jt ~ oi~.rra \CD2- 4 '•. ~ / \ i~`COt-35 \ ~ ~ T11 N, R4E,\U.M. ~ N~NUIOSUr t ~aG02-34 CD2-OS \~ /~, i -, ~ '' ,rl~ ~`~~ ~ \\ ~ ---- ~.t G'-""~ -45P -J4 ~ ~ , CD2-Ia Coz-2 feet 1`~D I' 0 2,000 4,OOfl 6,000 B,Oflfl ~l .._..-.. ~ -r~Y-i;;6 ... -.:._. 1106 SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ~ ATO 1530 ~' ~ ~ ez-14Isi 1 oAT 700 G ST: ANCHORAGE AK 99501 R THE ~ ~ ~~ ~ ~~51~-/ 1 ~' T Irl ~~~ ~ l '„r• D~ O PAV ¢ ~ / ORDER OF ~ n t ry` ~m ~ ~F~A~S oNexe en Beck.. ~ -- 3 ~ ~ ~~~/~~ L11ase Manhattan Bank USA, N.A. V` 100 Whlte Clay Centex Dr.. Newark, DE 19111 o a .Valid Up To 5000 Dollars ~ /^ ~/ r r ~. ~ . // // G .... __.___-_.~~V ~ _ __ __._- -i-__.._____..-_ ____ MEMO x:03 i i00 L44~:2'L84? L9079 ~76u'_L ~(]6 ~zt,.~;..,,., .~,~.~.~ ~~~..~ _ .,.?.. . ~~~jz •s f° I ~ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~+~~ ~~ 2 ~~~' PTD# ~ GAS - ~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permits for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (ply records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING 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. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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\j ody\trans m ittal_checktist WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL -120100 Well Name: COLVILLE RIV UNIT CD2-02 Program SER ,Well bore seg ^ PTD#: 2051090 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER ! PEND GeoArea 890 Unit 50360 On/Off Share On Annular Disposal ^ Administration 1 Permit_feeattached________-_-_-____-__-___-__--_-__ Yes_ ______________-__-___ - - 2 Lease number appropriate- _ Yes . - Surface location in ADL 380075, top- prgd interval in ASRC NPRA-1 lease; TD in ADL 388466. - - - _ - _ 3 Uniquewell_nameandnumbe[____.__._._._________________________ Yes. .___-_.-_._-._._______-._ 4 Welllgcatedin_a-d_efined_pogl_-__.-____,___________________ __ __ Yes. _.__.-COLVILLE_RIVER,ALPINE_QIL-120.1Q0_____-__-_____-_____-______--_-___-_- 5 Welllgcatedproperdiskancefromdrillingunitboundary_____ __________________ Ye5- __-_-___-___.-__- 6 Welllgcatedp[operdistancefromgtherwells____________________-___-_-_- Yes- --____---___-_ - - - 7 Sufficient acreage available in-drillingun)t__-__________________________ Yes- -___-___-_--______-----__._--_-___--_--___--_--__--_--_----__--_-_- 8 If deviated, is.wellbgre plat_inc_luded - - - - - Yes . - - - - - - - - - - 9 Operakor gnly affected party- - - Yes - - - - - - - - - - 10 Ope[akorhas_appropriate.bondinforce---------- ------------ -- --- -- Yes. .------- -- -- ------- -- ----------- ------------- --------- -- - ---- 11 Pe[mitcanbeissuedwithoutconservationorder_ ________ __________-__-_- Yes_ ___-___--_-._-_-_--_--__________.______-__ --_-__--_-___--_____---__-- Appr Date 12 Permitcanbeissuedwithoutadministrativ_e_approyal_________-________--_-- Yes_ _____________________________-.-____--_____--.___-___--_-_,__-__----- SFD 7/1912005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata author'~zed by Injection Order # (put_IQ# in_comments)_(For_ Yes Area injection Order No.-186_ . _ - - - _ - _ - . _ _ 15 Allwells_within1l4_milearea.ofteyiewidentified(Forserv_icewellgnly)_______________ Yes_ -_....CD2.2iPB1,CD2-18_.--.-._..-_--._-.---.--.__.-._.---..--..-_---_-.-_.--_ 16 Pre-produced injector; duration of preproduction less than_ 3 months_(Forservice well only) _ _N_o- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - . - _ - - _ - - _ - _ _ _ _ - . - - 17 pCMP_FindingofCgnsistency_hasbeenissued-for_thisproject________________-_ NA__ _________-___-_-___._--_-__-,______-_.-_-----___-_----_---_----_ -_ Engineering 18 Conductor string.P-rgvided - - - - - Yes - - - - - - t9 Surface casing_protectsallknown-USDWs___--___-______-__._ NA_ ____Ngaquifers,_perAIQ18Acgnclusion3.-____.__-__---___-_--_-___-______--____ 20 CMT-voladeguake_tgcirculate_onconductor&surf_csg----------------- ------ Yes_ -__,_-._--_-____-_-__.-__-__-__-__.__-_ __--__.-__.___-__--,- --- 21 CMT_vol-adequate_tq tie-in long siring to surf csg- - - -- - - - - - - - - - - - -- - - - - - No- Annular disposal may be proposed..All_hydrgcarbonswill be covered.- - - . - - - - - - - --------------- 22 CMT-will coverall known_prgdugtive horizgns_ - - - - _ - - - - _ _ _ - _ _ _ _ _ - No_ _ - - Open_hole completion planned, - _ _ - -------------- 23 Casing designs adequate for G,T,B&_permafrost__-___________________-_ Yes- __.-_. __-- -_-- 24 Adequate tankage_o_r reserve pit - - - - - - - - - - - - - - - - - - - - - - - - _ - _ Yes - - - - Rig is-equipped with steel_pits. No reserve_pitplanned, All waste to approved annulus or disposal well., - 25 Ifa_re-drill,has-a10-403 for abandonment beenapproved__ ______________-.__ NA_. __ __-- _-_--_--__._-_----_-,--_ -----__.-_--_----_-- 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ - _ . -Proximity analysis performed, Traveling cylinder plotincluded. _Gyros_likely.- , _ - - _ _ _ _ _ _ - ---------- 27 Ifdiverterrequired,doesitmeetregulations___________________________-_ NA__ -_____Diyerterwaive_rhas_beengiyen_for-CD2_pad.___--- --_-___-__-__,__- _-______-___.__-_ Appr Date 28 Drilling fluid_ program schematic & equip list adequate_ - _ Yes _ Maximum expected formation pressure 8,7_EMW._ Planned MW up to 9.8 ppg in 8.5"-hole-and 8.3 ppg in Alpine.- 7EM 7!19 /2005 29 BOPES,dotheymeet_regu_lation__-__-__ Yes , / 1 . ____ __--______-__ _________________-_ ,_- ~(~r/~(~/I f- 30 BOPE-press rating appropriate; test to_(put psig incomments) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ . _ MASP caVculated at 2607 psi. 3500.psi_appr_opriate. CPAI usually_tests to 500Qpsi. - - _ _ . _ _ - _ - - _ _ - - _ 31 Chgke_manifoldcompliesw/API_RP-53(M_ay$4)______ _____________________ Yes_ _-__-__--__-_-___ - - 32 Work will occur without operation shutdown____-___-_-____-__.__-_- _- Yes- _--___-__. _-__-__-_____-____--_--__-,.-_----- _--- 33 Is presence of H2S gas_prgbable - - - - - - - No_ HZS has ngt_been repgrted akAlpine. _Rig is equipped with sensors and alarms.- . - - . - - 34 Mechanical condition of wells within AQR yerifed (For service well only) Yes No penetrations within AOR. Toe ofCD2-1.8_&CD2-21_ pilot in AOR: Plug back acceptable, No ot_her.issues. - _ _ Geology 35 Pe[mit_can be issued wlo_ hydrogen_sulfide measures - - - - - - - - - - - - - - - - - - - - Yes - -- - - - 36 Data_presented on_ pote_ntia-I overpressure zones- - - Yes - . - - - -Expected reservoirpressure is 8:$ppg EMW; will be drilled with 8.8 - 9.8 ppg mud. - . - - Appr Date 37 Seismic analysis-ofshallgw gas zones_ _______________-_____-.__-__- _ NA_ __-_-._--__-____ SFD 7!19!2005 38 Seabed condition survey_(ifoff-share) . - NA - - 39 -Contactna_me/phoneforweeklyprogress-reports[expioratoryonly]____________ ___ NA__ __ _--_- --_-_----_--__-,---__----___- --_----_--_--_---_ Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date • Well History File APPENDIX Inforrrraiion 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 tine Well History file and to simplify finding information, 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. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov 03 13:29:33 2005 Reel Header Service name ........ .....LISTPE Date ................ .....05/11/03 Origin .............. .....STS Reel Name ........... .....UNKNOWN Continuation Number. .....01 Previous Reel Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Tape Header Service name ........ .....LISTPE Date ................ .....05/11/03 Origin .............. .....STS Tape Name... .. ....... .....UNKNOWN Continuation Number. .....01 Previous Tape Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0003855685 LOGGING ENGINEER: M. HANIK OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD >3431 o20S -! D~ Scientific Technical Services Scientific Technical Services CD2-02 501032051300 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-O5 MWD RUN 3 MWD RUN 5 MW0003855685 MW0003855685 M. HANIK M. HANIK D. LUTRICK L. HILL 2 11N 4E 1587 1561 52.50 15.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 3856.0 2ND STRING 6.125 7.000 16048.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) 3. CD2-02 EXITS THE CD2-02 PB1 WELLBORE AT • 16,110'MD/7259'TVD BY MEANS OF AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP) RUN 3 ALSO INCLUDED THE BIMODAL ACOUSTIC TOOL (BAT) FOR A CEMENT BOND LOG EXPERIMENT. RUN 5 ALSO INCLUDED AT-BIT INCLINATION (ABI) RUN 4 WAS A FAILED ATTEMPT AT AN OPEN-HOLE SIDETRACK. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 1-3,5 REPRESENT WELL CD2-02 WITH API#: 50-103-20513-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 21,178'MD/7241'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .05/11/03 Maximum Physical Record. .65535 File Type ............... .LO Previous File Name...... .STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 3824.0 21118.0 RPD 3824.0 21118.0 RPM 3824.0 21118.0 RPS 3824.0 21118.0 RPX 3824.0 21118.0 GR 3833.0 21111.0 ROP 3866.5 21178.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH ~i MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3824.0 16063.0 16063.0 16110.0 16110.0 21178.0 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3824 21178 12501 34709 3824 21178 ROP MWD FT/H 0.02 609.48 187.163 34624 3866.5 21178 GR MWD API 32.7 352.57 100.607 34557 3833 21111 RPX MWD OHMM 0.14 2000 8.63383 34589 3824 21118 RPS MWD OHMM 0.1 2000 9.89593 34589 3824 21118 RPM MWD OHMM 0.1 1812.01 11.6125 34589 3824 21118 RPD MWD OHMM 0.1 2000 17.335 34589 3824 21118 FET MWD HOUR 0.1 116.7 1.09103 34589 3824 21118 First Reading For Entire File..........3824 Last Reading For Entire File...........21178 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..05/11/03 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD • • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 3824.0 16020.0 RPM 3824.0 16020.0 RPS 3824.0 16020.0 RPX 3824.0 16020.0 FET 3824.0 16020.0 GR 3833.0 16028.0 ROP 3866.5 16063.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: OS-AUG-O5 Insite 66.37 Memory 16063.0 3866.0 16063.0 63.5 88.6 TOOL NUMBER 119546 121079 8.750 3856.0 LSND 9.70 37.0 9.0 300 5.6 2.400 70.0 1.180 149.0 2.500 70.0 3.500 70.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value......... .............-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • • DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3824 16063 9943.5 24479 3824 16063 ROP MWD020 FT/H 1.07 609.48 228.442 24394 3866.5 16063 GR MWD020 API 51.68 352.57 115.418 24391 3833 16028 RPX MWD020 OHMM 0.4 2000 6.12457 24393 3824 16020 RPS MWD020 OHMM 0.1 2000 6.1202 24393 3824 16020 RPM MWD020 OHMM 0.1 1809.23 6.69806 24393 3824 16020 RPD MWD020 OHMM 0.1 2000 11.8242 24393 3824 16020 FET MWD020 HOUR 0.1 85.93 0.623436 24393 3824 16020 First Reading For Entire File.... ......3824 Last Reading For Entire File..... ......16063 File Trailer Service name .............STSLI B.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11 /03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI B.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 16020.5 16110.0 RPD 16020.5 16110.0 RPM 16020.5 16110.0 RPS 16020.5 16110.0 RPX 16020.5 16110.0 GR 16028.5 16110.0 ROP 16063.5 16110.0 LOG HEADER DATA DATE LOGGED: 13-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16110.0 TOP LOG INTERVAL (FT) 16063.0 • BOTTOM LOG INTERVAL (FT) 16110.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 92.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBE R DGR DUAL GAMMA RAY 64004 EWR4 Electroma g Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 16048.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 43.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPE RATURE (DEGF) MUD AT MEASURED TEMPERAT URE (MT) .150 70.0 MUD AT MAX CIRCULATING T ERMPERATURE: .080 136.4 MUD FILTRATE AT MT: .120 70.0 MUD CAKE AT MT: .160 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Off set Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16020.5 16110 160 65.3 180 16020.5 16110 ROP MWD030 FT/H 21.6 133.26 87. 5788 94 16063.5 16110 GR MWD030 API 36.14 82.17 65. 1176 164 16028.5 16110 RPX MWD030 OHMM 0.14 1785.56 25. 4644 180 16020.5 16110 RPS MWD030 OHMM 0.16 1785.56 28. 2887 180 16020.5 16110 RPM MWD030 OHMM 1.05 1812.01 165 .928 180 16020.5 16110 RPD MWD030 OHMM 7.66 2000 456 .902 180 16020.5 16110 FET MWD030 HOUR 0.48 116.7 57. 0397 180 16020.5 16110 • First Reading For Entire File..........16020.5 Last Reading For Entire File...........16110 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 05/11/03 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 16050.0 21118.0 RPM 16050.0 21118.0 RPS 16050.0 21118.0 RPX 16050.0 21118.0 FET 16050.0 21118.0 GR 16110.5 21111.0 ROP 16110.5 21178.0 LOG HEADER DATA DATE LOGGED: 20-AUG-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 21178.0 TOP LOG INTERVAL (FT) 16110.0 BOTTOM LOG INTERVAL (FT) 21178.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MAXIMUM ANGLE: 95.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 16048.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 44.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3) 8.0 • ~ RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .120 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 165.2 MUD FILTRATE AT MT: .150 74.0 MUD CAKE AT MT: .160 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO50 FT/H 4 1 68 4 2 GR MWDO50 API 4 1 68 8 3 RPX MWDO50 OHMM 4 1 68 12 4 RPS MWDO50 OHMM 4 1 68 16 5 RPM MWDO50 OHMM 4 1 68 20 6 RPD MWDO50 OHMM 4 1 68 24 7 FET MWDO50 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16050 21178 18614 10257 16050 21178 ROP MWDO50 FTJH 0.02 452.37 88.7425 10136 16110.5 21178 GR MWDO50 API 32.7 118.66 65.071 10002 16110.5 21111 RPX MWDO50 OHMM 2.25 119.83 14.3255 10137 16050 21118 RPS MWDO50 OHMM 3 1313.9 18.6164 10137 16050 21118 RPM MWDO50 OHMM 3.29 127.15 20.6765 10137 16050 21118 RPD MWDO50 OHMM 4.15 109.3 22.746 10137 16050 21118 FET MWDO50 HOUR 0.51 172.82 2.25319 10137 16050 21118 First Reading For Entire File..........16050 Last Reading For Entire File...........21178 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name . ............LISTPE Date ......... ............05/11/03 Origin ....... ............STS Tape Name .... ............UNKNOWN Continuation Number......01 J ~ i Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................05/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov 03 10:06:24 2005 Reel Header Service name ....... ......LISTPE Date ............... ......05/11/03 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......05/11/03 Origin ............. ......STS Tape Name .......... ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library s ~343~- ~Os- /©~' Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS WELL NAME: CD2-02 PBl API NUMBER: 501032051370 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 03-NOV-OS JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0003855685 MW0003855685 LOGGING ENGINEER: M. HANIK M. HANIK OPERATOR WITNESS: D. BURLEY D. LUTRICK SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 1587 FSL: FEL: 1561 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 52.50 GROUND LEVEL: 15.90- # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 3856.0 2ND STRING 6.125 7.000 16048.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD ). 2. ALL VERTICAL DEPTH S ARE TRUE VERTICAL DEPTH (TVD). 3. CD2- 02 EXITS THIS WELLBORE AT 16,110'MD/7259'TVD. • • 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP) RUN 3 ALSO INCLUDED THE BIMODAL ACOUSTIC TOOL (BAT) FOR A CEMENT BOND LOG EXPERIMENT. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 1-3 REPRESENT WELL CD2-02 PB1 WITH API#: 50-103-20513-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16,216'MD/7254'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 3824.0 16165.5 RPD 3824.0 16165.5 RPM 3824.0 16165.5 RPS 3824.0 16165.5 RPX 3824.0 16165.5 GR 3833.0 16158.0 ROP 3866.5 16216.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3824.0 16063.0 MWD 3 16063.0 16216.0 • • REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3824 16216 10020 24785 3824 16216 ROP MWD FT/H 0.69 609.48 226.619 24700 3866.5 16216 GR MWD API 36.14 352.57 114.935 24651 3833 16158 RPX MWD OHMM 0.14 2000 6.27478 24684 3824 16165.5 RPS MWD OHMM 0.1 2000 6.2962 24684 3824 16165.5 RPM MWD OHMM 0.1 1812.01 7.87421 24684 3824 16165.5 RPD MWD OHMM 0.1 2000 15.0659 24684 3824 16165.5 FET MWD HOUR 0.1 116.7 1.03883 24684 3824 16165.5 First Reading For Entire File..........3824 Last Reading For Entire File...........16216 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..05/11/03 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 3824.0 16020.0 • FET 3824.0 16020 .0 RPD 3824.0 16020 .0 RPS 3824.0 16020 .0 RPM 3824.0 16020 .0 GR 3833.0 16028 .0 ROP 3866.5 16063 .0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 08-AUG-OS Insite 66.37 Memory 16063.0 3866.0 16063.0 63.5 88.6 TOOL NUMBER 119546 121079 8.750 3856.0 LSND 9.70 37.0 9.0 300 5.6 2.400 70.0 1.180 149.0 2.500 70.0 3.500 70.0 Data Format Specification Re cord Data Record Type ......... .... .... .0 Data Specification Block Type .... .0 Logging Direction ........ .... .... .DOwn Optical log depth units.. .... .... .Feet Data Reference Point ..... .... .... .Undefined Frame Spacing ............ .... .... .60 .lIN Max frames per record .... .... .... .Undefined Absent value ............. .... .... .-999 Depth Units .............. .... .... . Datum Specification Block sub -type...0 Name Service Order Units Si ze N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 • • FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3824 16063 9943.5 24479 3824 16063 ROP MWD020 FT/H 1.07 609.48 228.442 24394 3866.5 16063 GR MWD020 API 51.68 352.57 115.418 24391 3833 16028 RPX MWD020 OHMM 0.4 2000 6.12457 24393 3824 16020 RPS MWD020 OHMM 0.1 2000 6.1202 24393 3824 16020 RPM MWD020 OHMM 0.1 1809.23 6.69806 24393 3824 16020 RPD MWD020 OHMM 0.1 2000 11.8242 24393 3824 16020 FET MWD020 HOUR 0.1 85.93 0.623436 24393 3824 16020 First Reading For Entire File..........3824 Last Reading For Entire File...........16063 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 16020.5 16165.5 RPM 16020.5 16165.5 RPS 16020.5 16165.5 RPX 16020.5 16165.5 FET 16020.5 16165.5 GR 16028.5 16158.0 ROP 16063.5 16216.0 LOG HEADER DATA DATE LOGGED: 13-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16216.0 TOP LOG INTERVAL (FT) 16063.0 BOTTOM LOG INTERVAL (FT) 16216.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 92.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBjG): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 TOOL NUMBER 64004 59475 6.125 16048.0 Flo Pro 9.20 43.0 9.5 31000 4.0 • 150 70.0 080 136.4 120 70.0 160 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FTjH 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16020.5 16216 16118.3 392 16020.5 16216 ROP MWD030 FT/H 0.69 133.26 81.2838 306 16063.5 16216 GR MWD030 API 36.14 84.36 69.6506 260 16028.5 16158 RPX MWD030 OHMM 0.14 1785.56 18.8654 291 16020.5 16165.5 RPS MWD030 OHMM 0.16 1785.56 21.0497 291 16020.5 16165.5 RPM MWD030 OHMM 1.05 1812.01 106.465 291 16020.5 16165.5 RPD MWD030 OHMM 7.66 2000 286.805 291 16020.5 16165.5 FET MWD030 HOUR 0.48 116.7 35.8589 291 16020.5 16165.5 First Reading For Entire File..........16020.5 Last Reading For Entire File...........16216 File Trailer Service name .............STSLIB.003 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......05/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................05/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File