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201-006
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:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:CD1-07, 21 and 23 non-witnessed MITIA"s on 6-23-25 Date:Wednesday, June 25, 2025 8:04:57 AM Attachments:image001.png MIT CRU CD1-07,21 and 23 06-23-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-07, 21 and 25 that were conducted on 6-23-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2032250 Type Inj N Tubing 540 3350 3270 3238 Type Test P Packer TVD 6595 BBL Pump 5.6 IA 500 3300 3240 3225 Interval V Test psi 3000 BBL Return 5.1 OA 655 670 670 670 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010060 Type Inj N Tubing 1130 1155 1155 1155 Type Test P Packer TVD 6928 BBL Pump 2.5 IA 500 3340 3220 3210 Interval V Test psi 3000 BBL Return 2.5 OA 585 595 595 595 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990630 Type Inj N Tubing 174 375 405 415 Type Test P Packer TVD 6756 BBL Pump 1.6 IA 225 2000 1970 1970 Interval 4 Test psi 1689 BBL Return 1.6 OA 478 480 480 480 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp / Burton 06/23/25 Notes:MITIA to maximum anticipated injection pressure per AIO 18B.006. Well is currently secured with a plug and has an open pocket. Notes: CD1-07 CD1-21 Notes:MITIA to maximum anticipated injection pressure per AIO 18B.007 CD1-23 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0623_MIT_CRU_CD1-21 9 9 9 9 999 99 99 9 9 -5HJJ CD1-21 AIO 18B.007 1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Monday, June 12, 2023 8:59 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Integrity Subject:CPAI 10-426 form for Non-witnessed shut in tests on CD1-07 and 21 on 6/11/23 Attachments:MIT CRU CD1-07 & 21 SI TESTS 06-11-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA’s that were performed at CD1 pad on 6/11/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 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. CRU CD1-21PTD 2010060 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2032250 Type Inj N Tubing 1310 1665 1710 1710 Type Test P Packer TVD 6595 BBL Pump 2.5 IA 430 3320 3235 3220 Interval V Test psi 3000 BBL Return 2.4 OA 686 701 702 702 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2010060 Type Inj N Tubing 3285 3310 3290 3285 Type Test P Packer TVD 6928 BBL Pump 2.4 IA 1310 4120 4000 4000 Interval V Test psi 3000 BBL Return 2.3 OA 636 645 650 650 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 18B.006 Notes: CD1-07 CD1-21 Notes:MITIA to maximum anticipated injection pressure per AIO 18B.007 Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Miller 06/11/23 Form 10-426 (Revised 01/2017)2023-0611_MIT_CRU_CD1-pad_2wells jbr • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 19,2017 P.I.Supervisor ' ? o/2.// 7 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-21 FROM: Bob Noble COLVILLE RIV UNIT CDI-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-21API Well Number 50-103-20362-00-00 Inspector Name: Bob Noble Permit Number: 201-006-0 Inspection Date: 6/10/2017 Insp Num: mitRCN170612083110 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-21 ' Type Inj N 'TVD 6932 r Tubing l 490 600 ' 600 ' 600 - PTD 2010060 - Type Test SPT Test psi 3000 ✓ IA 260 3320 " 3240 " 3220 ' BBL Pumped: 2.9 - BBL Returned: 2.6 ' OA 720 ' 730 ' 730 - 730 - Interval REQVAR P/F P ✓ Notes: MITIA per AIO 18B.007 to max anticapated injection pressure of 3000. '7 SCANNED AUG 2 22017, Monday,June 19,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 16,2015 Jim Regg f-) P.I.Supervisor I? (-,(17(1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD 1-21 FROM: Johnnie Hill COLVILLE RIV UNIT CD1-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDl-21API Well Number 50-103-20362-00-00 Inspector Name: Johnnie Hill Permit Number: 201-006-0 Inspection Date: 6/11/2015 Insp Num: mit1WH150612062334 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-21 Type Inj W TVD 6932 Tubing 2329 2329 - 2329 . 2331 . PTD1—I 2010060 Type Test SPT Test psi 3000 - IA 1110 3300 3260 . 3260- --- -- - — - -- - --- Interval REQVAR P/F P ✓ OA 820 820 - 820 • 820 Notes: MITIA to maximum anticipated injection pressure. AIO 18B.007 2 6bbls diesel { ,1 A \114 V ,11 " : Jat* " Tuesday,June 16,2015 Page 1 of 1 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. c?-ol tJ(J b Well History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 18,2013 TO: Jim Regg �t ■ I .0 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD]-21 FROM: Jeff Turkington COLVILLE RIV UNIT CDI-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-21 API Well Number 50-103-20362-00-00 Inspector Name: Jeff Turkington Permit Number: 201-006-0 Inspection Date: 6/12/2013 Insp Num: mitJATI306I4192824 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD]-21 Type Inj W JTVD 6932 IA 1340 2000 - 1970 - 1960 PTD 2010060 - Type Test SPT Test psi 1733 OA 778 785 785 785 • Interval '4YRTST P/F P - Tubing 1255 1300 1300 1250 • Notes: .5 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of I Ce cat • !' 2M1U0 (oc Regg, James B (DOA) From: Arnold, Bill [BilI.Arnold @conocophillips.com] Sent: Tuesday, March 26, 2013 9:56 AM g 1 1� To: Regg, James B (DOA) Cc: Ovenden, Steve P; jill .a.mcleod @conocophillips.com Subject: Alpine CD1 -21 Future Status Jim, I apologize it has taken so long to get back to you on your request for our future plans for the CD1 -21 well. Our team completed their study and here is our best determination for future status of the well: We expect CD1 - 21 to remain on water injection service for the near -term (1 -2 years), after which it may be reviewed for enriched gas injection service. Again, sorry it has taken a while to get back to you and let me know if you need anything further. Regards, Bill Arnold ConocoPhillips Manager, NS Integrated Operations and Projects 907 - 263 -4822 SCANNED .J °° 2013 G. L. Alvord Alaska Drilling Manager Drilling & Wells P. 0. Box 100360 Anchorage, AK 99510-0360 ConocoPFii I i i ps Phone: 907 - 265 -6120 October 31, 2012 • AOGCC E1ED Commissioner 333 W. 7 Ave, Suite 100 NOV 0 12012 Anchorage, Alaska 99501 AOGCC Subject: Completion Report for CD1 -21 L1 Dear Commissioner: It has come to our attention that the lateral CD1 -21 L1 is not in AOGCC's database. A completion report was submitted on April 19, 2001 for both CD1 -21 and CD1 -21 PH. Although this package of documentation contained the directionals for CD1 -21, CD1- 21 PH and CD1 -21 L1, there wasn't a separate completion report form for CD1 -21 L1. Therefore, the attached completion report should correct this oversight. Also attached with the completion report is a note to the file concerning discussion between AOGCC and ConocoPhillips at the time of initial drilling. A stick drawing of the lateral is also attached. If you have any questions, please feel free to call me at anytime. Sincerely, G. L. Alvord A k o . 'i a-I no I' Alaska Drilling Manager -' (it- r,. ) 5z.f en - CPAI Drilling 61) /-2.1, / S e ret GLA/BN /skad ) Pt iL, L� na �� � p STATE OF ALASKA } ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG El WDSPL ❑ No. of Completions: Service El Stratigraphic Test [I] 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 25, 2001 201 - 006 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 4, 2001 50 103 - 20362 - 60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 365 FNL, 2433' FWL, Sec. 5, T11 N, R5E, UM February 19, 2001 CD1 Top of Productive Horizon: 8. KB (ft above MSL): 36' RKB 15. Field /Pool(s): not applicable GL (ft above MSL): 19.5' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 249' FSL, 2706' FEL, Sec. 30, T12N, R5E, UM 9910' MD / 7039' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 385858 y- 5975764 Zone 4 11782' MD / 6989' TVD ADL 25559, 25558 TPI: x - na y- na Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 380791 y- 5981738 Zone 4 2238' MD / 2006' TVD 2560 18. Directional Survey: Yes Q No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1638' MD / 1547' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD GR/ Res / Neu / Den not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 37' 114' 37' 114' 42" 10 cu yds Portland Type III 9.625" 36# J -55 37' 2718' 37' 2378' 12.25" 405 sx AS 111, 231 sx Class G 7" 26# L -80 34.5' 9049' 34.5' 7043' 8.5" 119 sx Class G 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/ND) na na 8675' MD / 6932' TVD open hole from 8995- 11087' MD 7035' -7024' TVD "--:,,,-..•;-... $ ,-. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. t L ATE DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8950' -8549' plug #1 156 sx 15.8 ppg Class G I MIRK' 8549' -7878' plug #2 159 sx 17 ppg Class G t 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged off Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No is If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RECEIVED RP�Aw MS NOV 0 2 212 NOV 0 12012 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE AOGGC Submit original only 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1638' 1547' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name ®® L. Alvord Title: Drilling Manager Signature c.. Phone 265 -6120 Date (9(31(1°(2,,,, INSTRUCTIONS 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. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Vernon T Johnson 02/26/2001 05:09 PM To: Sharon Allsup- Drake /PPCO @Phillips cc: Meg C Kremer /PPCO @Phillips, Deirdre L Schwartz/PPCO ®Phillips Subject: Re: CD1 -21 API # All, I spoke with Steve Davies at AOGCC again this afternoon, and they have had more discussion internally - the outcome is that they would prefer to see the abandoned sidetrack described as a multilateral, which means the API number should have a "60" suffix, logs and surveys should indicate it is a lateral, ie "CD1 -21 L1 ". The pilot hole and the main 6 -1/8" wellbore keep the same suffix, 70 and 00 respectively. I hope this clears things up. Vern Sharon Allsup -Drake Sharon Allsup -Drake 02/26/2001 02:22 PM To: Vernon T Johnson/PPCO @Phillips, Meg C Kremer /PPCO @Phillips, Deirdre L Schwartz/PPCO @Phillips cc: Subject: CD1 -21 API # Steve Davies at AOGCC said that the pilot hole should have the suffix 70 attached to it. the plugback portion of the well, even if it isn't plugged back but is the abandoned portion of the well should have the suffix 71. The final hole should have the suffix 00 attached to it. Sharon r � CD1 -21 lnj - Completed 02/25/2001 1 "' abandoned hole, pilot hole 8950' MD (above 7" csg point) 7169' tvd 381952, 5978991 CD1 -21 PB1 50- 103 - 20362 -70 7" Shoe 9049'MD 2nd abandoned hole, 11782' MD 6989' tvd 380663, 5981642 CD1 -21 L7 50- 103 - 20362 -60 1" sidetrack point 9910' MD 7039' tvd 381490, 5979965 - Final accessible hole, 11087' MD 7003' tvd 380972, 5981020 CD1 -21 50-103-20362-00 ANADRILL SCHLUMBERGER Survey report 28- Feb -2001 16:09:10 Page 1 of 5 Client • Phillips Alaska, Inc Field • Colville River Well • CD1 -21 L1 Spud date . 04- Feb -01 API number • 50- 103 - 20362 -60 Last survey date • 28- Feb -01 Engineer • Mercier Total accepted surveys...: 109 MD of first survey 0.00 ft COUNTY- • Doyon 19 MD of last survey • 11782.00 ft STATE- • Alaska Survey calculation methods Geomagnetic data Method for positions • Minimum curvature Magnetic model • BGGM version 2000 Method for DLS • Mason & Taylor Magnetic date • 02- Feb -2001 Magnetic field strength..: 1147.22 HCNT Depth reference Magnetic dec ( +E /W -) 25.52 degrees Permanent datum • Mean Sea Level Magnetic dip 80.55 degrees Depth reference • Drill Floor GL above permanent 19.50 ft MWD survey Reference Criteria KB above permanent • 56.3 ft Reference G 1002.68 mGal DF above permanent • 56.30 ft Reference H • 1147.22 HCNT Reference Dip • 80.55 degrees Vertical section origin Tolerance of G • ( + / -) 2.50 mGal Latitude ( +N /S -) 0.00 ft Tolerance of H • ( + / -) 6.00 HCNT Departure ( +E /W -) 0.00 ft Tolerance of Dip • ( + / -) 0.45 degrees Platform reference point Corrections Latitude ( +N /S -) • - 999.25 ft Magnetic dec ( +E /W -) • 25.52 degrees Departure ( +E /W -) • - 999.25 ft Grid convergence ( +E /W -).: 0.00 degrees Total az corr ( +E /W -) 25.52 degrees Azimuth from rotary table to target: 331.94 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y /N) • No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 28- Feb -2001 16:09:10 Page 2 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N /S- +E /W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD - 3 176.00 0.30 339.00 62.00 176.00 0.16 0.15 -0.06 0.16 339.00 0.48 MWD - 4 268.00 1.00 322.00 92.00 267.99 1.19 1.01 -0.64 1.19 327.66 0.78 MWD - 5 355.00, 1.85 314.00 87.00 354.97 3.27 2.58 -2.12 3.34 320.67 1.00 MWD - 6 386.00 2.24 316.72 31.00 385.95 4.34 3.37 -2.89 4.44 319.38 1.30 MWD - 7 476.00 3.64 319.35 90.00 475.83 8.82 6.82 -5.96 9.06 318.85 1.56 MWD - 8 567.00 5.69 321.78 91.00 566.52 16.08 12.56 -10.63 16.45 319.74 2.26 MWD 6 -axis 9 657.00 7.23 316.12 90.00 655.95 25.92 20.14 -17.32 26.57 319.31 1.85 MWD 6 -axis 10 746.00 8.22 317.93 89.00 744.14 37.48 28.90 -25.46 38.52 318.62 1.15 MWD 6 -axis 11 835.00 9.68 316.99 89.00 832.05 50.89 39.10 -34.83 52.36 318.30 1.65 MWD 6 -axis 12 926.00. 11.59 314.02 91.00 921.48 66.98 51.05 -46.62 69.13 317.59 2.18 MWD 6 -axis 13 1015.00 16.26 308.60 89.00 1007.85 86.94 65.04 -62.80 90.41 316.00 5.44 MWD 6 -axis 14 1109.00 21.35 310.04 94.00 1096.80 114.91 84.27 -86.20 120.55 314.35 5.44 MWD 6 -axis 15 1204.00 25.22 311.91 95.00 1184.05 149.99 108.93 - 114.51 158.05 313.57 4.15 MWD 6 -axis 16 1300.00 29.07 311.46 96.00 1269.46 191.07 138.04 - 147.22 201.82 313.16 4.02 MWD 6 -axis 17 1395.00 32.44 310.88 95.00 1351.09 236.48 170.01 - 183.80 250.37 312.77 3.56 MWD 6 -axis 18 1491.00 35.74 310.55 96.00 1430.58 286.63 205.09 - 224.58 304.14 312.40 3.44 MWD 6 -axis 19 1587.00 38.97 310.32 96.00 1506.88 340.81 242.86 - 268.91 362.35 312.09 3.37 MWD 6 -axis 20 1681.00 38.88 308.95 94.00 1580.01 395.45 280.54 - 314.39 421.36 311.74 0.92 MWD 6 -axis 21 1778.00 38.64 307.33 97.00 1655.65 451.01 318.04 - 362.15 481.98 311.29 1.07 MWD 6 -axis 22 1873.00 40.58 307.98 95.00 1728.83 506.22 355.05 - 410.09 542.43 310.88 2.09 MWD 6 -axis 23 1967.00 41.00 309.10 94.00 1800.00 562.58 393.31 - 458.12 603.80 310.65 0.90 MWD 6 -axis 24 2063.00 40.65 309.00 96.00 1872.65 620.39 432.85 - 506.86 666.53 310.50 0.37 MWD 6 -axis 25 2156.00 40.19 309.28 93.00 1943.45 675.98 470.91 - 553.63 726.82 310.38 0.53 MWD 6 -axis 26 2250.00 39.86 309.41 94.00 2015.43 731.80 509.24 - 600.38 787.26 310.30 0.36 MWD 6 -axis 27 2345.00 39.45 309.31 95.00 2088.57 787.77 547.68 - 647.26 847.88 310.24 0.44 MWD 6 -axis 28 2440.00 38.99 309.26 95.00 2162.17 843.21 585.72 - 693.75 907.94 310.17 0.49 MWD 6 -axis 29 2536.00 38.55 309.30 96.00 2237.02 898.68 623.78 - 740.28 968.05 310.12 0.46 MWD 6 -axis 30 2632.00 38.75 309.22 96.00 2311.99 954.00 661.72 - 786.71 1028.00 310.07 0.21 MWD 6 -axis [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 28- Feb -2001 16:09:10 Page 3 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool depth angle angle length depth section +N /S- +E /W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 31 2665.00 38.98 310.18 33.00 2337.69 973.17 674.95 - 802.64 1048.70 310.06 1.95 MWD 6 -axis 32 2838.00 38.31 309.01 173.00 2472.81 1073.09 743.81 - 885.88 1156.73 310.02 0.57 MWD 6 -axis 33 3028.00 39.31 308.93 190.00 2620.86 1182.73 818.70 - 978.46 1275.80 309.92 0.53 MWD 6 -axis 34 3216.00 40.31 307.61 188.00 2765.27 1292.96 893.23 - 1072.96 1396.11 309.78 0.70 MWD 6 -axis 35 3408.00 40.13 306.98 192.00 2911.88 1405.64 968.35 - 1171.59 1519.98 309.57 0.23 MWD 6 -axis 36 3598.00 39.82 308.33 190.00 3057.48 1516.90 1042.92 - 1268.23 1641.97 309.43 0.48 MWD 6 -axis 37 3787.00 38.80 307.38 189.00 3203.72 1626.21 1116.40 - 1362.76 1761.66 309.33 0.63 MWD 6 -axis 38 3978.00 39.35 307.64 191.00 3352.00 1735.82 1189.71 - 1458.26 1882.00 309.21 0.30 MWD 6 -axis 39 4166.00 39.08 308.65 188.00 3497.66 1844.58 1263.12 - 1551.73 2000.84 309.15 0.37 MWD 6 -axis 40 4357.00 39.19 308.54 191.00 3645.81 1955.26 1338.32 - 1645.95 2121.38 309.11 0.07 MWD 6 -axis 41 4549.00 39.44 309.23 192.00 3794.35 2067.19 1414.69 - 1740.64 2243.03 309.10 0.26 MWD 6 -axis 42 4739.00 39.59 307.97 190.00 3940.93 2178.18 1490.10 - 1835.12 2363.91 309.08 0.43 MWD 6 -axis • 43 4930.00 39.70 309.12 191.00 4088.01 2290.02 1566.04 - 1930.43 2485.76 309.05 0.39 MWD 6 -axis 44 5122.00 38.92 308.09 192.00 4236.56 2401.71 1641.94 - 2025.47 2607.39 309.03 0.53 MWD 6 -axis 45 5309.00 39.64 307.96 187.00 4381.31 2509.94 1714.87 - 2118.73 2725.76 308.99 0.39 MWD 6 -axis 46 5501.00 41.18 307.66 192.00 4527.50 2623.52 1791.16 - 2217.07 2850.20 308.93 0.81 MWD 6 -axis 47 5692.00 40.44 307.92 191.00 4672.06 2737.42 1867.65 - 2315.71 2975.00 308.89 0.40 MWD 6 -axis 48 5881.00 39.68 307.26 189.00 4816.72 2848.24 1941.85 - 2412.09 3096.61 308.84 0.46 MWD 6 -axis 49 6072.00 40.61 308.09 191.00 4962.72 2960.50 2017.12 - 2509.55 3219.72 308.79 0.56 MWD 6 -axis 50 6263.00 40.64 306.68 191.00 5107.69 3073.61 2092.62 - 2608.36 3344.04 308.74 0.48 MWD 6 -axis 51 6451.00 41.08 309.39 188.00 5249.89 3186.03 2168.40 - 2705.21 3467.00 308.71 0.97 MWD - 52 6642.00 40.10 309.21 191.00 5394.93 3300.73 2247.11 - 2801.37 3591.27 308.73 0.52 MWD 6 -axis 53 6832.00 40.03 307.78 190.00 5540.34 3412.92 2323.23 - 2897.08 3713.55 308.73 0.49 MWD 6 -axis 54 7021.00 39.75 308.30 189.00 5685.36 3523.74 2397.92 - 2992.54 3834.75 308.71 0.23 MWD 6 -axis 55 7213.00 39.13 307.77 192.00 5833.64 3635.25 2473.07 - 3088.61 3956.71 308.68 0.37 MWD 6 -axis 56 7404.00 40.65 309.24 191.00 5980.19 3747.63 2549.35 - 3184.44 4079.19 308.68 0.94 MWD 6 -axis 57 7594.00 40.86 309.23 190.00 6124.11 3862.06 2627.80 - 3280.51 4203.23 308.70 0.11 MWD 6 -axis 58 7785.00 40.23 308.33 191.00 6269.25 3976.21 2705.57 - 3377.30 4327.38 308.70 0.45 MWD 6 -axis 59 7975.00 39.74 308.32 190.00 6414.83 4088.08 2781.28 - 3473.08 4449.47 308.69 0.26 MWD 6 -axis 60 8164.00 39.77 308.25 189.00 6560.14 4198.79 2856.16 - 3567.95 4570.33 308.68 0.03 MWD 6 -axis [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 28- Feb -2001 16:09:10 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N /S- +E /W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 61 8356.00 39.02 307.65 192.00 6708.51 4310.12 2931.10 - 3664.03 4692.18 308.66 0.44 MWD - 62 8460.00 38.61 307.93 104.00 6789.54 4369.60 2971.05 - 3715.55 4757.36 308.65 0.43 MWD - 63 8492.00 41.95 309.06 32.00 6813.95 4388.58 2983.93 - 3731.74 4778.04 308.65 10.68 MWD 6 -axis 64 8525.00 45.28 311.42 33.00 6837.84 4409.73 2998.64 - 3749.10 4800.79 308.65 11.23 MWD 6 -axis 65 8554.00 47.39 313.68 29.00 6857.87 4429.52 3012.83 - 3764.54 4821.72 308.67 9.20 MWD 6 -axis 66 8588.00 50.20 315.56 34.00 6880.26 4453.94 3030.80 - 3782.74 4847.15 308.70 9.25 MWD 6 -axis 67 8620.00 52.98 317.45 32.00 6900.14 4478.10 3048.99 - 3799.99 4871.99 308.74 9.84 MWD 6 -axis 68 8652.00 55.19 319.58 32.00 6918.92 4503.31 3068.41 - 3817.15 4897.53 308.79 8.76 MWD 6 -axis 69 8683.00 57.34. 321.01 31.00 6936.13 4528.56 3088.24 - 3833.62 4922.79 308.85 7.93 MWD 6 -axis 70 8713.00 59.89 321.98 30.00 6951.75 4553.74 3108.29 - 3849.56 4947.78 308.92 8.94 MWD 6 -axis 71 8744.00 62.65 323.66 31.00 6966.65 4580.58 3129.94 - 3865.98 4974.17 308.99 10.09 MWD 6 -axis 72 8775.00 65.54 325.19 31.00 6980.20 4608.22 3152.62 - 3882.19 5001.05 309.08 10.33 MWD 6 -axis 73 8806.00 68.18 326.92 31.00 6992.38 4636.57 3176.27 - 3898.11 5028.31 309.17 9.94 MWD 6 -axis 74 8839.00 70.82 328.20 33.00 7003.93 4667.39 3202.36 - 3914.68 5057.65 309.28 8.79 MWD 6 -axis 75 8870.00 73.18 329.37 31.00 7013.51 4696.82 3227.57 - 3929.96 5085.45 309.40 8.42 MWD 6 -axis 76 8902.00 75.85 330.44 32.00 7022.06 4727.64 3254.25 - 3945.42 5114.34 309.52 8.94 MWD 6 -axis 77 8934.00 78.37 330.81 32.00 7029.19 4758.82 3281.43 - 3960.72 5143.45 309.64 7.96 MWD 6 -axis 78 8966.00 80.77 331.35 32.00 7034.99 4790.29 3308.97 - 3975.94 5172.75 309.77 7.68 MWD 6 -axis 79 8996.00 83.39 331.93 30.00 7039.12 4820.00 3335.12 - 3990.05 5200.34 309.89 8.94 MWD 6 -axis 80 9132.00 88.56 338.26 136.00 7048.67 4955.34 3458.07 - 4047.11 5323.29 310.51 6.00 IMP 6 -axis 81 9226.00 89.86 336.30 94.00 7049.97 5048.92 3544.76 - 4083.41 5407.36 310.96 2.50 IMP 6 -axis 82 9323.00 90.48 334.22 97.00 7049.68 5145.75 3632.86 - 4124.00 5495.91 311.38 2.24 IMP 6 -axis 83 9414.00 91.20 333.04 91.00 7048.35 5236.70 3714.38 - 4164.41 5580.23 311.73 1.52 IMP 6 -axis 84 9510.00 91.47 332.15 96.00 7046.11 5332.66 3799.58 - 4208.59 5670.01 312.08 0.97 IMP 6 -axis 85 9607.00 91.68 331.16 97.00 7043.44 5429.62 3884.92 - 4254.62 5761.46 312.40 1.04 IMP 6 -axis 86 9699.00 91.51 330.81 92.00 7040.88 5521.58 3965.34 - 4299.23 5848.70 312.69 0.42 IMP 6 -axis 87 9794.00 90.89 331.22 95.00 7038.89 5616.54 4048.42 - 4345.25 5938.93 312.97 0.78 IMP 6 -axis 88 9890.00 91.00 331.75 96.00 7037.31 5712.52 4132.76 - 4391.08 6030.03 313,26 0.56 IMP 6 -axis 89 9985.00 90.24 332.49 95.00 7036.28 5807.52 4216.73 - 4435.50 6120.00 313.55 1.12 IMP 6 -axis 90 10081.00 90.45 332.79 96.00 7035.70 5903.51 4301.99 - 4479.62 6210.80 313.84 0.38 IMP 6 -axis 1(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 28- Feb -2001 16:09:10 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool depth angle angle length depth section +N /S- +E /W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 91 10176.00 90.55 332.21 95.00 7034.88 5998.50 4386.25 - 4523.48 6300.88 314.12 0.62 IMP 6 -axis 92 10272.00 90.58 332.85 96.00 7033.93 6094.49 4471.42 - 4567.76 6392.03 314.39 0.67 IMP 6 -axis 93 10364.00 90.62 332.01 92.00 7032.97 6186.48 4552.97 - 4610.34 6479.57 314.64 0.91 IMP 6 -axis 94 10457.00 90.69 333.34 93.00 7031.90 6279.47 4635.59 - 4653.03 6568.05 314.89 1.43 IMP 6 -axis 95 10551.00 90.89 333.19 94.00 7030.61 6373.43 4719.53 - 4695.31 6657.32 315.15 0.27 IMP 6 -axis 96 10639.00 91.06 333.65 88.00 7029.11 6461.39 4798.22 - 4734.68 6740.93 315.38 0.56 IMP 6 -axis 97 10731.00 88.97 332.78 92.00 7029.08 6553.36 4880.34 - 4776.14 6828.56 315.62 2.46 IMP 6 -axis 98 10826.00 91.10 331.37 95.00 7029.03 6648.35 4964.27 - 4820.62 6919.71 315.84 2.69 IMP 6 -axis 99 10918.00 91.48 331.19 92.00 7026.96 6740.32 5044.93 - 4864.82 7008.41 316.04 0.46 IMP 6 -axis 100 11008.00 91.00 332.19 90.00 7025.01 6830.30 5124.15 - 4907.49 7095.09 316.24 1.23 IMP 6 -axis 101 11102.00 91.27 331.65 94.00 7023.15 6924.28 5207.07 - 4951.73 7185.62 316.44 0.64 IMP 6 -axis 102 11195.00 91.61 330.64 93.00 7020.81 7017.24 5288.50 - 4996.59 7275.58 316.63 1.15 IMP 6 -axis 103 11288.00 93.33 331.73 93.00 7016.80 7110.14 5369.90 - 5041.37 7365.55 316.81 2.19 IMP 6 -axis 104 11379.00 90.93 331.78 91.00 7013.42 7201.07 5450.00 - 5084.41 7453.44 316.99 2.64 IMP 6 -axis 105 11470.00 91.54 330.82 91.00 7011.46 7292.04 5529.80 - 5128.10 7541.62 317.16 1.25 IMP 6 -axis 106 11563.00 94.15 328.23 93.00 7006.84 7384.83 5609.84 - 5175.19 7632.36 317.31 3.95 IMP 6 -axis 107 11656.00 94.77 329.30 93.00 6999.61 7477.40 5689.12 - 5223.27 7723.25 317.44 1.33 IMP 6 -axis 108 11729.00 95.01 331.38 73.00 6993.39 7550.10 5752.32 - 5259.26 7794.17 317.56 2.86 IMP 6 -axis 109 11782.00 95.01 331.38 53.00 6988.76 7602.90 5798.67 - 5284.55 7845.45 317.66 0.00 MWD - [(c)2001 Anadrill IDEAL ID6_1C_08] Time Log & Summary ConocoPhillips Wei!view Web Reporting Report Well Name: CD1 - 21 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 2/4/2001 12:00:00 AM Rig Release: 2/25/2001 12:00:00 AM time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode 1' Comment 02/04/2001 24 hr Summary 00:00 01:30 1.50 0 1,920 MOVE MOVE RURD P Continue rigging up 01:30 03:30 2.00 1,920 1,920 SURFA( DRILL PULD P M/U BHA# 1 03:30 05:00 1.50 1,920 1,920 SURFA( DRILL SFTY P Pre -spud meeting w/ crew - Kick drill - function test diverter system, accu. closure test - fill hole - check for leaks 05:00 00:00 19.00 1,920 1,920 SURFA( DRILL DRLG P Break circ. - Spud- in - Drill 12 1/4" hole f/ 114' to 1920' - 1766 TVD - ADT- 10.86 AST- 8.26 02/05/2001 00:00 08:00 8.00 1,920 2,728 SURFA( DRILL DRLG P Drill 12 1/4 " hole f/1920' to 2728' TD - 2386.66 TVD 08:00 09:00 1.00 2,728 2,728 SURFA( DRILL CIRC P Circ - Pump hi vis sweep 09:00 10:30 1.50 2,728 2,728 SURFA( DRILL WIPR P Monitor well - Wiper trip f/ 2728' to 1640' 10:30 11:00 0.50 2,728 2,728 SURFA( DRILL WIPR P RIH to 2638' - Break circ - safety wash to btm @ 2728' 11:00 13:00 2.00 2,728 2,728 SURFA( DRILL CIRC P Pump hi vis - bump mud wt. to 9.8 ppg - circ & cond. hole for 9 5/8 " csg 13:00 15:00 2.00 2,728 2,728 SURFA( DRILL TRIP P Monitor well - POOH to run csg - pull to 1080' 15:00 17:30 2.50 2,728 2,728 SURFA( DRILL TRIP P Pump out f/ 1080' to 900' improper fill - hole trying to swab - Continue POOH f/ 900' - std back HWDP - L/D remaining BHA for inspectio 17:30 18:00 0.50 2,728 2,728 SURFA( DRILL PULD P clear & clean up rig floor 18:00 19:30 1.50 2,728 2,728 SURFA( CASE RURD P Rig up to run 9 5/8 " csg - PJSM 19:30 23:30 4.00 2,728 2,728 SURFA( CASE RUNC P Ran 64jts. 9 5/8 " 36# J -55 BTC csg w/ shoe @ 2718' - 2379' TVD 23:30 00:00 0.50 2,728 2,728 SURFA( CEMEN" CIRC P Circ and condition for cement job 02/06/2001 00:00 01:00 1.00 2,728 2,728 SURFA( CEMEN" CIRC P Circ & condition hole and mud for cmt job 01:00 02:00 1.00 2,728 2,728 SURFA( CEMEN "CIRC P Blow down top drive - L/d fill -up tool - install cmt head - circ - PJSM Page 1 of 9 • Time Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:00 2.00 2,728 2,728 SURFA( CEMEN" PUMP P Cmt. 9 5/8" csg : 40 bbls Vis water w/ nut plug - test lines to 2500 psi - 50 bbls Arco Spacer - 318 bbls lead slurry @ 10.7 ppg - observed nut plug @ shakers w/ 300 bbls lead pumped - 48 bbls tail @ 15.8 ppg - Displace w/ 20 bbls water & 184 bbls mud - bumped plug - floats held - CIP @ 03:55 hrs. 80 bbls cmt returns to surfac 04:00 05:30 1.50 2,728 2,728 SURFA( CEMEN PULD P L/D cmt head, landing jt. - flush 20" Hydril with fresh water 05:30 07:30 2.00 2,728 2,728 SURFA( WELCTL NUND P Nipple down flow line, riser, 20 "" Hydril, and diverter 07:30 08:30 1.00 2,728 2,728 SURFA( WELCTL NUND P Install FMC Unihead - test seal to 1000 psi 08:30 10:00 1.50 2,728 2,728 SURFA( WELCTL NUND P Nipple 13 5/8 5K BOPE - riser, flow line 10:00 15:00 5.00 2,728 2,728 SURFA( WELCTL BOPE P Install test plug - test BOPE - all rams, choke manifold valves, kill line & choke line valves 250 psi low & 3500 psi high - Hydril 250 psi low - 2500 psi high - Test witnessed & approved by John Crisp AOGCC - pull test plug - L/D test jt. - set wear bushing 15:00 16:30 1.50 2,728 2,728 SURFA( DRILL PULD P P/U & std back 27 jts. 5" DP 16:30 19:00 2.50 2,728 2,728 SURFA( DRILL PULD P M/U BHA #2 - PJSM 19:00 21:30 2.50 2,728 2,728 SURFA( DRILL TRIP P RIH w/ HWDP f /derrick & P/U 5" DP f /shed to 2623' 21:30 22:30 1.00 2,728 2,728 SURFA( DRILL CIRC P Circ for csg test 22:30 23:30 1.00 2,728 2,728 SURFA( CASE DEQT P Pressure test 9 5/8" csg to 2500 psi for 30 mins. 23:30 00:00 0.50 2,728 2,728 SURFA( CEMEN" DSHO P Drill out cmt f/ 2635' to 2638' - drill float collar @ 2638' 02/07/2001 00:00 00:30 0.50 2,728 4,178 SURFA( CEMEN" DSHO P Continue drilling out ctm in shoe track - drill out shoe @ 2718' - C/o rat to to 2728' Drill 20' new hole to 2748' - 2402' ND 00:30 01:30 1.00 4,178 4,178 SURFA( DRILL CIRC P Circ and condition for LOT /FIT test 01:30 02:00 0.50 4,178 4,178 SURFA( DRILL DEQT P Perform FIT to 16.0 ppg EMW 02:00 02:30 0.50 4,178 4,178 INTRM1 DRILL CIRC P Chage well over to 9.6 ppg LSND mud 02:30 15:00 12.50 4,178 4,178 INTRM1 DRILL DRLG P Drill 8 1/2 "" hole from 2748' to 4178' MD - 3507 ND-ADT7.97 AST .69- lost 400 psi pump pressure while drilling - p rate slowed 15:00 15:30 0.50 4,178 4,178 INTRM1 DRILL CIRC P Pump hi vis sweep - monitor well - static 15:30 20:00 4.50 4,178 4,178 INTRM1 DRILL TRIP T POOH looking for wash out Page 2 of 9 • Time Logs Date From - To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:30 1.50 4,178 4,178 INTRMI DRILL PULD T Pull RA source from MWD - pulled to motor - found wash out in body of float sub @ top of motor - do load MWD 21:30 22:00 0.50 4,178 4,178 INTRM1 DRILL PULD T change out mud motor - orient 22:00 23:00 1.00 4,178 4,178 INTRM1 DRILL TRIP T Install RA source in MWD- RIH with BHA 7 1 std HWDP - pulse test MWD 23:00 00:00 1.00 4,178 4,178 INTRM1 DRILL TRIP T RIH w/ BHA & DP to 9 5/8 "" shoe @ 2718' Monitor well 02/08/2001 00:00 01:30 1.50 4,178 6,714 INTRM1 RIGMN1RSRV P Cut & slip 60' drill line 01:30 02:30 1.00 6,714 6,714 INTRMI DRILL TRIP T RIH to 4178' 02:30 00:00 21.50 6,714 6,714 INTRMI DRILL DRLG P Drill 8 1/2 "" hole f/ 4178' to 6714' - 5450' TVD ADT 14.52 AST 1.13 02/09/2001 00:00 01:00 1.00 6,714 8,747 INTRMI DRILL CIRC P Circ sweep for wiper trip - monitor well - static 01:00 03:00 2.00 8,747 8,747 INTRMI DRILL WIPR P Wiper trip f/ 6714' to 4178' - Hole in good shape 03:00 04:30 1.50 8,747 8,747 INTRMI DRILL WIPR P RIH f/ 4178' to 6053' - fill pipe - continue RIH to 6654' 04:30 00:00 19.50 8,747 8,747 INTRMI DRILL DRLG P Break circ. - wash f/ 6654' to 6714' - Drill 8 1/2 hole f/ 6714' to 8747' - 7012' TVD - ADT- 14.6 AST- .83 02/10/2001 00:00 02:30 2.50 8,747 8,549 INTRM1 DRILL DRLG P Drill 8 1/2 hole f/ 8747' to 8950' - 7169' ND - Top Alpine 8750' 7020' ND 02:30 03:30 1.00 8,549 8,549 INTRM1 DRILL CIRC P Pump hi vis swep - circ hole clean - monitor well 03:30 08:00 4.50 8,549 8,549 INTRMI DRILL WIPR P Wiper trip f/ 8950' to 6700' - work tight hole 7625' to 7615 & 7595' to 7510' - RIH f/ 6700 to 8950' 08:00 10:00 2.00 8,549 8,549 INTRMI DRILL CIRC P Circ & condition mud - monitor well - blow down top drive 10:00 12:00 2.00 8,549 8,549 INTRM1 DRILL TRIP P POOH to 7000' - hole in good shape - pump dry job 12:00 16:00 4.00 8,549 8,549 INTRMI DRILL TRIP P Continue POOH - monitor well @ 9 5/8 shoe - pull to BHA - Std back HWDP - remove RA source from MWD - LID MWD, stabs, motro, & bit 16:00 21:00 5.00 8,549 8,549 INTRMI CEMEN "TRIP P M/U mule shoe & run 10 stds 3 1/2 "" DP - change tool - RIH w/ 5 "" DP to 8950' 21:00 22:00 1.00 8,549 8,549 INTRM1 CEMEN" CIRC P Circ and condition for cmt plug 22:00 23:00 1.00 8,549 8,549 INTRMI CEMEN" PLUG P Set cmt plug #1 - 8950' to 8549' w/ 156 Sx (32.3 bbls) Class G @ 15.8 ppg - displace to equalize - CIP @ 23:10 hrs 23:00 00:00 1.00 8,549 8,549 INTRM1 CEMEN" TRIP P R/D cmt lines - PUll out to 8549' Page 3 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/11/2001 24 hr summary 00:00 01:00 1.00 8,549 8,629 INTRM1 CEMEN" CIRC P Circ @ 8549' - R/U cmt line 01:00 02:00 1.00 8,629 8,629 INTRMI CEMEN" PLUG P Set plug # 2 w/ 159 sks Class G (28.3 bbls) @ 17.0 ppg - Displace to equalize - Calc Top 8146' - CIP @01:40hrs 02:00 02:30 0.50 8,629 8,629 INTRMI CEMEN" TRIP P Pull out to 7878' 02:30 03:00 0.50 8,629 8,629 INTRM1 CEMEN" CIRC P Circ btms up @ 7878' - Monitor well - pump dry job 03:00 06:30 3.50 8,629 8,629 INTRM1 CEMEN "TRIP P POOH w/ 5" & 3 1/2" drill pipe & mule shoe 06:30 08:00 1.50 8,629 8,629 INTRM1 DRILL PULD P M/U BHA # 4 - pulse test MWD 08:00 09:00 1.00 8,629 8,629 INTRM1 DRILL TRIP P RIH to 2700' - Monitor well 09:00 10:00 1.00 8,629 8,629 INTRM1 RIGMNT RSRV P Cut & slip drill line 60' 10:00 10:30 0.50 8,629 8,629 INTRM1 RIGMNT RSRV P Service top drive 10:30 13:00 2.50 8,629 8,629 INTRMI DRILL TRIP P Continue RIH f/ 2700' to 7825' 13:00 15:00 2.00 8,629 8,629 INTRMI DRILL REAM P Break circ @ wash & ream f/ 7825' to 8180' - tag cmt 15:00 16:30 1.50 8,629 8,629 INTRMI DRILL DRLG P Drill cmt f/ 8180' to 8460' firm cmt f/ 8190' to 8460' 16:30 20:00 3.50 8,629 8,629 INTRM1 DRILL DRLG P Time drill off cmt plug f/ 8460' to 8490' 20:00 00:00 4.00 8,629 8,629 INTRM1 DRILL DRLG P Drill 8 1/2 "" hole f/ 8490' to 8629' TVD 6906 - AST- 5.56 ART- .48 02/12/2001 00:00 17:00 17.00 8,629 9,060 INTRMI DRILL DRLG P Drill 8 1/2" hole f/ 8629' to 9060' - 7044' ND - Rig pick top of Alpine - 8876' - 7015 ND 17:00 18:30 1.50 9,060 9,060 INTRM1 DRILL CIRC P Pump weighted hi vis pill - circ hole clean - Monitor well - static 18:30 20:00 1.50 9,060 9,060 INTRM1 DRILL WIPR P Wiper trip f/ 9060' to 7160' - no tight hole - monitor well static 20:00 21:00 1.00 9,060 9,060 INTRMI DRILL TRIP P RIH f/ 7160' to 9060' 02/13/2001 00:00 05:00 5.00 9,060 9,060 INTRMI DRILL TRIP P Continue POOH laying down 5 "" DP to 2700' - Flow ck - continue POOH & UD 5 "" DP - std back HWDP 05:00 06:30 1.50 9,060 9,060 INTRMI DRILL PULD P UD BHA # 4 06:30 07:30 1.00 9,060 9,060 INTRM1 DRILL PULD P House keeping rig floor - flush BOP stack w/ wash tool 07:30 08:00 0.50 9,060 9,060 INTRM1 WELCTI EQRP P Pull long Wear bushing - install thin wall WB 08:00 09:00 1.00 9,060 9,060 INTRMI CASE RURD P Rig up to run 7 "" csg - PJSM 09:00 19:30 10.50 9,060 9,060 INTRMI CASE RUNC P Run 223 jts. 7 "" 26# L -80 Mod BTC csg. Circ. casing volume @ 2718' (9 5/8" shoe) - landed w/ shoe @ 9049.74' - FC @ 8969' - Lost returns while RIH @ 8800' Page 4 of 9 Time Logs Date From To - Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:00 1.50 9,060 9,060 INTRMI CASE CIRC P UD fill up tool - M/U circ head - attempt to establish circ.- pumping 2.5 to 5 bbs /min working pipe - lost 188 bbls mud - no returns - Discuss options with Team Leader 21:00 22:00 1.00 9,060 9,060 INTRMI CEMEN" PULD P Break out circ head - M/U cmt head - mix LCM pill - PJSM 22:00 00:00 2.00 9,060 9,060 INTRM1 CEMEN" PUMP P Cement 7 "" csg. - pump 20 bbls LCM pill - 5 bbls water - test line to 3500 psi - pump 50 bbls Arco spacer @ 12.5 ppg - drop btm plug - pump 25 bbls slurry @ 15.8 ppg - Drop top plug w/ 20 bbls water f/ Dowell - displace w/ 325 bbls mud - didn't bump plug - floats held - CIP @ 2330 hrs. - Observed returns w/ 155 bbls of displacement away - obseved pressure increase as cmt rounded corner f/ 860 psi t0 910 psi - monitor annulus slight flow - shut Hydril and monitor pressure 02/14/2001 00:00 04:30 4.50 9,060 9,060 INTRMI CEMEN" PUMP P Shut in well for four hours, bled off zero psi, LD cement head and LJ, pull wear bushing. 04:30 05:30 1.00 9,060 9,060 INTRM1 WELCTI EQRP P Install and test packoff to 5000 psi. 05:30 07:00 1.50 9,060 9,060 INTRMI WELCTI EQRP P Change top pipe rams to 3 -1/2 "" x 6 "" and drive sub on TD to 3 -1/2 IF. 07:00 12:00 5.00 9,060 9,060 INTRMI WELCTI BOPE P RU and test BOPE, choke and surface safety valves 250/3500 psi, annular preventor 250/2500 psi. Remove test plug and install wear bushing. 12:00 13:30 1.50 9,060 9,060 INTRMI DRILL PULD P MU BHA #5. 13:30 15:30 2.00 9,060 9,060 INTRM1 DRILL TRIP P RIH picking up 3 -1/2 "" DP to 1500'. 15:30 16:30 1.00 9,060 9,060 INTRMI DRILL OTHR Np Lost highline power, monitor well. 16:30 17:00 0.50 9,060 9,060 INTRMI DRILL TRIP P Continue to PU DP to 2097'. 17:00 18:00 1.00 9,060 9,060 INTRMI DRILL OTHR Np Lost highline power - monitor well. 18:00 00:00 6.00 9,060 9,060 INTRMI DRILL TRIP P Continue PU DP - tagged cement @ 8745'. 02/15/2001 00:00 01:00 1.00 9,060 9,080 INTRM1 CEMEN" COUT P Clean out cement from 8745' to 8841', located top wiper plug. 01:00 02:00 1.00 9,080 9,080 INTRMI DRILL CIRC P Circ and cond mud. 02:00 03:00 1.00 9,080 9,080 INTRMI CASE DEQT P RU and test casing to 3500 psi for 30 min. Bled off 250 psi, 80 psi in last 5 min. 03:00 05:00 2.00 9,080 9,080 INTRM1 CASE DEQT T Retest casing while isolating various surface equipment components, no good. Last attempt bled off 850 psi in 21 min. Page 5 of 9 ' Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 05:00 07:00 2.00 9,080 9,080 INTRM1 CASE DEQT T Circ and cond mud, develop plan forward. 07:00 08:30 1.50 9,080 9,080 INTRMI CEMEN" COUT P Clean out cement from 8841' to 8967'. 08:30 09:30 1.00 9,080 9,080 INTRM1 DRILL CIRC P CBU and cond mud. 09:30 10:30 1.00 9,080 9,080 INTRMI CASE DEQT T RU and test casing to 3200 psi, bled off to 1850 psi in 12 min. Monitored pressure on 9 -5/8 "" X 7"" annulus zero psi at start of test, 625 psi at end of test. 10:30 12:30 2.00 9,080 9,080 INTRM1 CEMEN" DSHO P Clean out cement and drill 20' of new hole to 9080'. 12:30 13:30 1.00 9,080 9,080 INTRMI DRILL CIRC P CBU and cond mud for FIT. 13:30 14:00 0.50 9,080 9,080 INTRMI DRILL LOT P Perform LOT - established EMW of 11.6 ppg. Observed outer annulus pressure - 300 psi @ start 525 psi with 1070 psi surface pressure on 7"" casing. 14:00 15:30 1.50 9,080 9,080 INTRM1 DRILL TRIP T Monitor well - pump out to 8613'. 15:30 16:00 0.50 9,080 9,080 INTRM1 DRILL CIRC T Pump dry job - tie back block hanging line due to high winds. 16:00 21:00 5.00 9,080 9,080 INTRMI DRILL TRIP T POH - hampered by high winds. 21:00 22:00 1.00 9,080 9,080 INTRMI DRILL PULD T LD BHA. 22:00 00:00 2.00 9,080 9,080 INTRM1 CEMEN" PULD T PJSM. MU 5 1/3 stands of 3 -1/2 "" drill pipe below Baker Retrieve -a -matic packer and RIH. 02/16/2001 00:00 03:00 3.00 9,080 9,080 INTRM1 CEMEN ' TRIP T RIH to 9080'. 03:00 04:30 1.50 9,080 9,080 INTRMI CEMEN "CIRC T CBU and cond mud @ 3 bpm. 04:30 07:00 2.50 9,080 9,080 INTRM1 CEMEN" SQEZ T Set packer @ 8527', tail @ 9054'. Attempted to test 7" casing above Pkr to 3500 psi, bled of 260 psi in 17 min while observing slight returns up the drill pipe. Reset Pkr, @ 8520' and attempted to test casing, continued to observe slight returns out drill pipe. 07:00 08:00 1.00 9,080 9,080 INTRMI CEMEN" CIRC T Circ and cond mud, PJSM with Dowell. 08:00 14:00 6.00 9,080 9,080 INTRM1 CEMEN" PUMP T RU cementers and test lines to 3500 psi. With tail pipe @ 9079', pumped 75 sxs of 15.8 ppg G cement and displaced to equalization. POH to 8216' (ETOC @ 8683') and circ to clear drill pipe. Closed pipe rams and performed hesitation squeeze, max press 2544 psi, est 4 bbls of cement away. Shut in well @ 1145 hrs with 2050 psi on casing. ETOC @ 8787'. Monitored pressure on 9 5/8 X 7" annulus during squeeze, initial 250 psi, max 425 psi. Page 6 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:00 2.00 9,080 9,080 INTRM1 CEMEN "OTHR T Bled off 1550 psi from casing, 1 bbl of mud back, monitor well. CBU, monitor well, pump dry job. 16:00 19:30 3.50 9,080 9,080 INTRM1 CEMEN "TRIP T POH, laid down packer and muleshoe. 19:30 20:30 1.00 9,080 9,080 INTRMI DRILL PULD T MU BHA # 6 and shallow test tools. 20:30 23:30 3.00 9,080 9,080 INTRM1 DRILL TRIP T RIH to 8000'. 23:30 00:00 0.50 9,080 9,080 INTRMI RIGMNT RSRV P Slip and cut drilling line. 02/17/2001 00:00 01:30 1.50 9,080 9,374 INTRMI RIGMNT RSRV P Slip and cut drilling line, service Top Drive. 01:30 03:15 1.75 9,374 9,374 INTRM1 DRILL TRIP T RIH, tagged cement @ 8742', establish circ. 03:15 04:30 1.25 9,374 9,374 INTRMI CASE DEQT P RU and test casing to 3500 psi for 30 min. good test. Monitored 9 -5/8"" X 7 "" annulus, initial pressure 250 psi, max pressure 300 psi. 04:30 07:30 3.00 9,374 9,374 INTRM1 CEMEN" COUT T Clean out stringers to 8772' and cement to 8960', CBU. 07:30 09:30 2.00 9,374 9,374 INTRMI CASE DEQT T RU and test casing top 3500 psi, held solid for 12 min. bled to 3110 psi after 30 min. (outer annulus 250 psi initial, 300 psi final). RD test manifold, blow down equipment. 09:30 12:00 2.50 9,374 9,374 INTRM1 CEMEN" DSHO T Clean out cement from 8960', drill 20' of new hole from 9080' to 9100'. 12:00 13:00 1.00 9,374 9,374 INTRMI DRILL CIRC P CBU. 13:00 14:00 1.00 9,374 9,374 INTRMI DRILL FIT P RU and perform FIT to 12.5 ppg EMW, good. (9 -5/8 X 7 "" annulus press. initial 250 psi, final 250 psi) 14:00 16:00 2.00 9,374 9,374 PROD DRILL CIRC P PJSM. Change well over to 9.2 ppg Flo -Pro mud clean surface equipment. 16:00 00:00 8.00 9,374 9,374 PROD DRILL DRLG P Drill from 9100' to 9374'. ART =3.0 AST =1.9 02/18/2001 00:00 00:00 24.00 9,374 10,734 PROD DRILL DRLG P Drill from 9374' to 10734'. ART =13.7 AST= 2.4 02/19/2001 00:00 23:30 23.50 10,734 11,782 PROD DRILL DRLG P Drill from 10734' to 11782'. ART =13 AST =3.6 23:30 00:00 0.50 11,782 11,782 PROD DRILL CIRC P Circ hole, pump high vis sweeps. 02/20/2001 00:00 03:30 3.50 11,782 11,782 PROD DRILL CIRC P Circ hole clean, change well over to 9.2 ppg KCL Brine, monitor well, initial loss rate 45 BPH. 03:30 04:45 1.25 11,782 11,782 PROD DRILL TRIP P POH to 10342', loss rate 25 bph. 04:45 05:30 0.75 11,782 11,782 PROD DRILL CIRC P Pump 40 bbls High vis Flo -Pro pill and displace into openhole. Page 7 of 9 Time Logs Date From To ` Dur S. Depth E. Depth Phase Code Subcode T Comment . 05:30 07:00 1.50 11,782 11,782 PROD DRILL TRIP P POH to 9000', monitor well, loss rate 13 bph. 07:00 13:00 6.00 11,782 11,782 PROD DRILL TRIP P POH, laid down 240 joints of 3 -1/2 "" drill pipe. 13:00 15:30 2.50 11,782 11,782 PROD DRILL PULD P Handle BHA, download and program LWD, change out motor and standback tools. 15:30 22:30 7.00 11,782 11,782 PROD WELCTL BOPE P Pull wear bushing and install test plug. Test BOPE, choke valves and surface safety valves to 250/3500 psi, Annular preventor to 250/2500 psi. Pull test plug and install wear bushing. 22:30 00:00 1.50 11,782 11,782 PROD DRILL PULD P MU BHA #7, set motor ako @ 1.4, shallow test tools. 02/21 /2001 00:00 06:00 6.00 11,782 10,021 PROD DRILL TRIP P RIH picking up 3 -1/2 "" drill pipe to 7800. 06:00 08:00 2.00 10,021 10,021 PROD RIGMNT RSRV P Slip and cut drilling line 278'. 08:00 09:00 1.00 10,021 10,021 PROD DRILL TRIP P RIH, bit stopped @ 9090'. 09:00 12:30 3.50 10,021 10,021 PROD DRILL REAM P Reamed tightspots from 9090' to 9120', precautionary reamed to 9408'. Took check shots @ 9068', 9132', 9226', and 9323'. 12:30 14:00 1.50 10,021 10,021 PROD DRILL CIRC P Change well over to 9.2 ppg Flo -Pro mud, cond mud. 14:00 14:30 0.50 10,021 10,021 PROD DRILL TRIP P RIH to 9910', pump up survey. 14:30 00:00 9.50 10,021 10,021 PROD DRILL DRLG P Time drill to open hole sidetrack well from 9910' to 9942'. AST =6.2 02/22/2001 00:00 05:00 5.00 10,021 10,227 PROD DRILL DRLG P Time drill to sidetrack openhole from 9942' to 9950'. Drill from 9950' to 10021'. ART =1.1 AST =1.7 05:00 06:00 1.00 10,227 10,227 PROD DRILL CIRC P Pump high vis sweep and circ clean, 06:00 08:15 2.25 10,227 10,227 PROD DRILL TRIP P Monitor well, pump out to 8500' and blow down TD. 08:15 11:30 3.25 10,227 10,227 PROD DRILL TRIP P POH, no problems. 11:30 12:30 1.00 10,227 10,227 PROD DRILL PULD P Handle BHA, change out MWD and bit, shallow test tools. 12:30 17:00 4.50 10,227 10,227 PROD DRILL TRIP P RIH to shoe. 17:00 19:15 2.25 10,227 10,227 PROD DRILL DRLG P Wash down from shoe, Took check shots @ 9183', 9277', 9374', 9465, 9561', 9658, 9750', 9845'. 19:15 00:00 4.75 10,227 10,227 PROD DRILL DRLG P Drill from 10021' to 10227'. ART =2.0 AST =1.3 02/23/2001 00:00 15:30 15.50 10,227 11,087 PROD DRILL DRLG P Drill from 10277' to 11087'. ART =8.0 AST =3.6 Page 8 of 9 " • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 20:00 4.50 11,087 11,087 PROD DRILL CIRC P Pump high /low /high vis sweeps and circ clean. Change well over to 9.2 ppg KCL Brine. Monitor well, initial losses 50 bph. 20:00 21:00 1.00 11,087 11,087 PROD DRILL TRIP P POH to 10073', monitor losses, 42 bph. 21:00 21:45 0.75 11,087 11,087 PROD DRILL CIRC P Pump 40 bbls high vis pill and displace into open hole. 21:45 22:30 0.75 11,087 11,087 PROD DRILL TRIP P POH to shoe, monitor losses, 27 bph. 22:30 23:15 0.75 11,087 11,087 PROD DRILL CIRC P pump 40 bbls high vis pill and displace to bit. 23:15 00:00 0.75 11,087 11,087 PROD DRILL TRIP P POH to 8749' and begin laying down 3 -1/2 "" drill pipe. 02/24/2001 00:00 06:00 6.00 11,087 11,087 PROD DRILL TRIP P POH, laying down 3-1/2" drill pipe. 06:00 07:00 1.00 11,087 11,087 PROD DRILL PULD P Lay down BHA. 07:00 08:30 1.50 11,087 11,087 COMPZ CMPLTP RURD P Pull wear bushing and RU to run tubing. 08:30 16:30 8.00 11,087 11,087 COMPZ CMPLTP RUNT P MU completion equipment and RIH picking up 4-1/2" tubing. MU hanger and land completion with WLEG @ 8746', and top of Pkr. @ 8676'. 16:30 18:00 1.50 11,087 11,087 COMPZ CMPLTP RURD P RILDS, remove LJa and install TWC. MU LJb and test tubing hanger M/M seals to 5000 psi, LD LJb. 18:00 19:00 1.00 11,087 11,087 COMPZ CMPLTP NUND P MU wash sub and flush BOP stack, move 5" hwdp to distribute weight for rig move. 19:00 00:00 5.00 11,087 11,087 COMPZ CMPLTP NUND P ND flowline and riser, ND BOP's, break all flange bolts on preventors in preparation for annual inspection. 02/25/2001 00:00 02:30 2.50 11,087 11,087 COMPZ CMPLTP NUND P ND BOP stack, install and test adaptor flange and tree to 5000 psi. 02:30 05:00 2.50 11,087 11,087 COMPZ CMPLTP SEQT P RU lubricator and pull TWC. RU test manifold and hard lines. 05:00 09:00 4.00 11,087 11,087 COMPZ CMPLTP FRZP P PJSM. Test lines to 4000 psi, change well over with 125 bbls of 9.6 ppg treated brine followed by 180 bbls of diesel. 09:00 11:30 2.50 11,087 11,087 COMPZ CMPLTP PCKR P RU lubricator and drop setting ball and rod. Set Packer and test tubing to 3500 psi, bled down to 1870 psi in 30 min. RU and test 7" x 4 -1/2 "" annulus to 3500 psi for 30 min., good. 11:30 13:30 2.00 11,087 11,087 COMPZ CMPLTP RURD P Blow down lines, RD test manifold and lines. RU lubricator and install BPV, secure wellhead, Released rig @ 13:30 hours. Page 9 of 9 • ConocoP Alaska P.O. BOX 100360 �0 L,. ANCHORAGE, ALASKA 99510 -0360 , a! April 01, 2011 klaska & Gas Con . Commission A APR 0 8 2011 anchorage Commissioner Dan Seamount _ ©O Alaska Oil & Gas Commission ap I 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 a 1 _ a Commissioner Dan Seamount: Enclosed please find a spreadsheet 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 and corrosion inhibitor, 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. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD1 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date _ ft bbls ft gal CD1 -15PB1 50103206190000 2100470 10" n/a 10" n/a 4.3 3/13/2011 CD1 -20 50103205030000 2042400 6" n/a 24" n/a 5.4 3/13/2011 CD1 -21 50103203620000 2010060 6" Na 13" Na 8 3/13/2011 CD1 -30 50103203480000 2001320 6" n/a 20" n/a 6.4 3/13/2011 CD1 -31 50103203470000 2001180 6" n/a 14" n/a 6.4 3/13/2011 CD1 -37 50103203020000 1990670 8" n/a 13" n/a 8.3 3/13/2011 CD1 -38 50103203230000 2000030 4" n/a _ 13" n/a 4.9 3/13/2011 CD1 -39 50103203040000 1990800 4" n/a 15" Na 4.4 3/13/2011 CD1-40 50103202980000 1990440 4" Na 15" n/a 5.2 3/13/2011 • MEMORANDUM To: Jim Regg P.L Supervisor ~~~ 7(ZZj ~ ~ FxoM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-21 COLVILLE RIV LJNIT CDl-21 Src: Inspector NON-CONFIDENTIAL Reviewed By~ P.I. Suprv ~~ Comm Well Name: COLVILLE RN iJNIT CD1-21 Insp Num: mitRCN090617132247 Rel Insp Num: API Well Number: 50-103-20362-00-00 Permit Number: 201-006-0 / Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initiai 15 Min. 30 Min. 45 Min. 60 Min. We~l CDl-21 Type Inj. G 1'~ 6932 jA 1430 2960 ' 2940 2940 ~ P.T.DI 2010060 TypeTest SPT Test psi 2960 QA 790 950 950 950 Interval 4YRTST P~ P / Tubing 3224 3224 3224 3224 Notes: ti4~n,-~G~~ p,~~sw~e.. 1~733~,g; ! ..r~ Lw #e }.'r~,.. f `'~ l~ _. '',+. ~ il~i:~ Monday, June 22, 2009 Page 1 of 1 Message • Maunder, Thomas E (DOA) _ • From: Wiess, JORDAN F [JORDAN.F.Wiess@conocophillips.com] Sent: Thursday, August 02, 2007 12:01 PM To: Roby, David S(DOA); Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Dave, Page 1 of ~ ~ . ~`-Ob~As a result of receiving these interpretations, CPAI has initiated lean gas injection into CD1-02, ~' CD1-05 and CD1-21 (with CD1-06 and CD1-14 previously on lean gas injection). CD1-11 is on long-term continuous miscible gas injection (no WAG) because it is twinned with CD1-05. When it reaches the end of its miscible gas EOR service, it will be converted to continuous lean gas injection as well. Also, after the facility shut down in August, CD2-06 and CD2-07 will start on lean gas WAG. Jordan ~c.~~~`~E~~~% ±~~1!7 4= ~' ~~~~ -----Origin al Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August 01, 2007 3:45 PM To: Wiess, JORDAN F; Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Jordan, One more thing, could you please tell us which three wells have been converted to lean gas injection, and email us when wells are converted in the future, so that we can put a note in the appropriate well files? Thanks again, Dave Roby Phone: 907-793-1232 email: dave.roby~a~alaska.yoy From: Wiess, IORDAN F [mailto:JORDAN.F.Wiess@conocophillips.com] Sent: Wednesday, August O1, 2007 8:18 AM To: Roby, David S(DOA); Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Dave R, Dave Uldrich is out of the office until mid/end of next week. I will ensure he provides you a prompt reply upon his return. Thnnks for your time last week. ~ ~~ Q~~~~ ~~ 8/17/2009 Message • ~ Page 2 of ~ ~-. Jordnn -----Original Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August 01, 2007 8:15 AM To: Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, JORDAN F; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order David, I do have one request for you. During the meeting it was mentioned that normal laboratory testing to demonstrate miscibility wasn't working because of the way the samples were obtained and analyzed and that the MMP values that the lab determined were in error by several hundred psi. Could you please provide a short note, an email would be fine, to explain these problems and what you are doing to ensure miscibility? Thanks in advance, Dave Roby Phone: 907-793-1232 email: dave.ro~~a alaska.~c ov From: Uldrich, David 0 [mailto:David.O.Uldrich@conocophillips.com] Sent: Tuesday, July 31, 2007 4:46 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, JORDAN F Subject: AOGCC Guidance on Alpine Area Injection Order Dave: I wanted to thank you and Tom very much for meeting with Jordan and myself last week. We appreciate your time and efforts to clarify the issues that we raised through the draft request for amendment of the Alpine area injection order. Having confirmation from you that the existing area injection order and State regulations permit post-MWAG lean gas injection, we are moving ahead with the plans we discussed with you. As we discussed with you, CPAI believes that the injection of lean gas in the post-MWAG injectors will enhance the recovery from the Alpine reservoir. As a result of the guidance that we received from you and Tom on behalf of AOGCC, CPAI has started lean gas injection into 3 wells that were previously used for miscible gas injection. These conversions, and several others we intend to implement later this summer, will help us manufacture gas that is miscible for the Alpine reservoir as well as the Fiord and Nanuq-Kuparuk reservoirs. In addition, we anticipate that the expanded lean gas injection will generate increased recovery through pressure maintenance and some reduced residual oil saturations. Thanks again for you help. David Uldrich Staff Reservoir Engineer Alpine Development Engineering ATO-1766 ConocoPhillips Alaska Inc. ~ (907) 265-6828 ~ David.O.Uldrich@conocophillips.com 8/17/2009 . . ~ ConocoPhillips Alaska .'\ on ,c-\ : i ~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 1 0 2007 JDI-Do0 Dear Mr. Maunder: 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 fÌ'om 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, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 ?/16/200? Alpine Field March 31,2007 • • Maunder, Thomas E (DOA) From: Michael D Erwin jmerwin(c~ppco.com] Sent: Thursday, Mardh 01, 2001 3:31 PM To: tom_maunder~adrnin.state.ak.us Cc: Clifford !_ Crabtree Subject: CD1-21 SCMT Attachments: CD1-21_SCMT.zip ~~~-~~~ CDl-21_SCMT.zip (2 KB) Tom Attached (below) is the first look at the cement job on recently completed CDl-21. I believe I can see why the shoe did not test initially - pumped a wet shoe -but I am greatly relieved to report very adequate bonding between the formation top at 887&' and the tubing tail at 8746' MD. Please advise if you concur our cement job is adequate to begin injection. The paper copies will be coming through the normal channels. mike (See attached file: CDl-21_SCMT. zip) ~~tJ~ ~~ ,~ ~~~~ ~ (~ ~ ~-ca~ ~~ 1 • • ~o~-~S~ I~C:3ANZCAL INTEGRITY REPORT ~~UD u_-_,_: - ~ ~+`~°'l~` OPEtZ ~ FIELD ~--~Pr~ ~~v~~~~~~~C.. .G r.....~~~_~_.. - ~~~~}S~_ ~ ~ i::_LL NUMBER ~..~ ~ n r LL DAT ~_ TD : t i~ ~~..?-ID.. 10~ aTVD ; . BTD : ~~~ ~~aID ~2D1~ Z'VD %asi~g: ~ Shoe: 1~~_MD TVD; liJ: N ~?~ ~ ~ -?'4-'li =~_,e= . Shoe : ~ TzTD ; .~Cr .'_-~ ~'~D ::~o^^~ ~,Qz?PaciceY ~~~rv ~} T'J7i Set et ~~~ ole Sire ~~ ~ ~ and ~t~I~SS` ; Perfs ~ ~{y_ to ~~~~ 4f~~"~ 1 ~ ~~~ "~` L C.1~ ~~ . r c-.~, INTEGRITY - ? 4_RT # ? Y`_iliiu.l.i:5 PreSS Test: COG,ylelltS -? ~ 15 nin :, 0 min '~CHAN Z C~ ~. Z NTEGRZ'?'~' -PART # 2 }~ ~ ' ~`'~~`~i Cement Voltmzes :~_ A.mt. Liner ; Csg ~~~S~K- ; DV C.ut :rol to covey oers ~"~4j~~~S •~~ C~~F •-~~~~}~~tl,~ ~eoretical 'T'OC =~= ~~ ~'~~ - Cement Bond Log (Yes or No) ~~(- ~ In AOGCC File ~ ~ CBL Evaluation, -' ~ ~ ~~~ gone ~oove perfs `::4 ~~ Lj~~S~- ~cvs~ ~~~t~~ Production Log: 'T'ype Evaluation CON~LJSZOtdS ?art il. ?art i.~_ ~`'~ ~- e e ":'~--.. "."-. '" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _ Inscrts\Microfilm _ Marker. doc 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: o or Final 0 304-009 1/12/2004 (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of fluids and drill rig approved substances (include days domestic waste water descriptions in block 12) disposal o.ccurred P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added *Freeze protect volumes only and Injectivity Test and Leak-off Test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Previous totals (bbls): o 2004 /1 st 31433 2004 / 2nd o 2004 / 3rd o 2004 / 4th o Total Ending Volume (bbls): 31433 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Form 10-423 Rev. 2/2004 0 467* 467 0 100 0 31533 30 0 0 0 0 0 0 0 0 0 0 0 0 100 467 32000 30 Pressure vs. Time 0 Step Rate Test 0 Date: Randy Thomas Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 201-006 CD1-21 50-103-20362-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 1/21/2004 2/19/2004 CD1-07, CD1-46 "- Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. / ') n n c; '''r' l' ~Hd¡::ñ n Pi~ ¡ 8 LU U",-' ~yf\~'H'lb~" ¡~,. , ~ > f...( It G. (o~ Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 467* 467 0 100 0 31533 30 1/21/2004 2/19/2004 CD1-07, CD1-46 0 0 0 0 0 0 0 0 0 0 0 0 ~ 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 304-009 (h)(3) Other Commission approved substances (include descriptions in block 12) 1/12/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 0 2004/1st 31433 2004 / 2nd 0 2004 / 3rd 0 2004 / 4th 0 Total Ending . Volume (bbls): 31433 100 467 32000 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Descri ption( s): Step Rate Test 0 *Freeze protect volumes only and Injectivity Test and Leak-off Test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ .J \ \ '^-:. - Date: fi:~ Printed Name: Randy Thomas Kuparuk Drilling Team Leader Title: Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-006 CD1-21 8. API Number: 50-103-20362-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .~J 30 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNE[) JAN 1 4 2005 \. (" (0 5- Phone Number: (907) 265-6830 Submit in Duplicate ,~, Previous totals (bbls): 2004/1st 2004 / 2nd 2004 / 3rd 2004 / 4th ,~, Total Ending Volume (bbls): Signature: Printed Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 0 or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 304-009 (h)(3) Other Commission approved substances (include descriptions in block 12) 1/12/2004 Volume (bbls): Number of days disposal occurred 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added 6. Permit to Drill Number: 7. Well Name: 201-006 CD1-21 8. API Number: 50-103-20362-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 0 467* 467 0 31433 100 0 31533 30 1/21/2004 2/19/2004 CD1-07, CD1-46 0 0 0 0 0 0 0 0 0 0 31433 100 467 32000 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): *Freeze protect volumes only and Injectivity Test and Leak-off Test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. '\ ~~ \~ Randy Thomas Step Rate Test 0 Date: Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 30 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNCD NO\: () 4 2004 lo((cr (C:J cr Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 0 or Final 0 304-009 (h)(2) drill rig wash (h)(3) Other Commission fluids and drill rig approved substances (include domestic waste water descriptions in block 12) 1/12/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 0 0 467* 467 2004/1st 31433 100 0 31533 2004/2nd 2004/3rd 2004/4th Total Ending Volume (bbls): 31433 100 467 32000 . Step Rate Test 0 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): *Freeze protect volumes only and Injectivity Test and Leak-off Test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~~ Printed Name: ~--"".,.(ì ~..:::,.............) Title: Date: C'JrlJ lè....- ~",\J Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-006 CD1-21 8. API Number: 50-103-20362-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 30 1/21/2004 CD1-07, CD1-46 2/19/2004 30 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7' 1/6. (0'1 Phone Number: '26 S-' 6-g S Q Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic D Service 0 6. Permit to Drill Number: 201-006 ConocoPhillips Alaska, Inc. Development D Exploratory D 7. Well Name: CD1-21 2. Address: 4b. Well Status: Oil D Gas D WAG0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ D WINJ D WDSPL D 50-103-20362-00 3. (Check one box only) Sa. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal 0 or Continuation of Disposal D 304-009 1/12/2004 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369* 369 totals (bbls): 2003/4th 0 0 98** 98 2004/1st 2004 / 2nd 2004 / 3rd Total Ending Report is due on the 20th Volume 0 467 467 . . (bbls): of the month followmg the fmal month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the Other (Explain) D fourth quarter. 12. Remarks and Approved Substances Description(s): *Freeze protect volumes only **Injectivity Test and Leak-off Test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ Date: \Iu(o'( Printed Name: \<. -~...l ; ~ """-"i: '!i. Title: ~ c- \j "\ "'--- L-c.."J Phone Number: "4S 6 'B ~ 0 "- . '." :'. ,-. J!ì ~p ~)) W 200 ~ Form 10-423 Rev. 9/2bÒY:'-'.: '~~'.~::.:::_.) "ø-~ \(j 6~ ,:! :~ { INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Note to File CD1-21 (201-006.. .304-009) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. Approximately 80 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 90% XS of the calculated hole volume. --On the initial leak off test, it appeared that the wellbore accepted fluid at 15.9 ppg EMW. Minor pressure falloff is observed after shutting down the pump. --No problems are reported drilling the intermediate hole. Lost circulation was experienced while preparing to cement the 7" casing. The drilling report notes that circulation returned during cementing and a positive lift pressure was observed. ' --A new injectivity test was recently conducted. On the injectivity test down 9-5/8" x 7" annulus, the pressure increases steadily until breaking at nearly 1100 psi. While pumping proceeded, the pressure varied between 1100 and 1070 psi. During the 1 O~ minute observation period, the pressure declined to 880 psi. These absolute pressures are high since the annulus essentially contained diesel to the shoe. The EMW where the pressure broke was 15.5 ppg. --CPA provided a listing of all surface casing shoes within X mile of CD1-21. There are 4 wells within 750' with 3 of the wells having been approved for AD. An examination of the files did not reveal any problem that would preclude granting CPA's request for CD2-36. Based on examination of the submitted ConocoPhillips' request for the subject well. t~~~ Sr. Petroleum Engineer January 9, 2004 information, I recommend approval of ~tt~~~ED JAN 1 4 2004 ConocoPhillips Alaska, Inc. Post Office Box 100360 ' Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ConocÓPh i II i pS January 8, 2004 Alaska Oil and Gas Conservation Comm.ission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilline Waste on well CDl.21 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CDl-21 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CDI-21 approximately January 18,2004. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD 1 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within lA mile radius, not already on file at AOGCC; CD 1- 10, CDI-22, CDI-28, CDI-30, and CDI-33 Further details regarding wells on CD 1 pad within lA mile radius should be on file at the AOGCC. The initial annular LOT (15.1 ppg) and recent retest (15.5 ppg 12-31-03) occurred at a lower equivalent mud weight than the casing shoe test (test was stopped at 16.0 ppg). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT /LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081, or Chip Alvord at 265-6120. ~-- Vem Johnson Drilling Engineer cc: CDI-21 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake RECE\VEO JAN () 8 20ü4 Comm\ss\on 0" & Gas Cons. A\aska \ Anchorage A TO-1700 Anadarko A TO-1530 OR I GI NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 3. Permit to Drill No: -~ ß-Il ~--' c-'-- \ J -'iÝ/)( 1. Operator Name: ConocoPhillips Alaska 4. API Number: 2. Address: 700 G Street, Anchorage, Alaska, 99501 5. Well Name: 6. Field: 7. Publicly recorded wells 201-006 50- 103-20362-00 CD1-21 Alpine a) All wells within one- quarter mile: 8. Stratigraphic description: a) Interval exposed to Torok and Seabee formation. Shale, siltstone CD1-10, CD1-22, CD1-28, CD1-30, CD1-33 (see open annulus: and sandstone attached summary) Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, ccement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. b) Waste receiving zone: b) water wells within one mile: NONE c) Confinement: 9. Depth to base of permafrost: 1638' MD/1556' TVD 10. Hydrocarbon zones above waste receiving zone: 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 467 bbl Densities range from diesel to 12#/gal. 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35000 bbl 16. Estimated start date: 1/18/2004 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) Surf. Casing Cementing Data 0 Other 0 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sand layers in the Colville group C-30 in the Seabee formation The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier (Ref. AOGCC Conservation Order No. 443, March 15, 1999) NONE 13. Maximum anticipated pressure at shoe: 1979 psi 0 T Graph 0 Signature: /1 / (¿! ,/\-:1'- L.' \. -, í(6(?4- k O'a & Gas Cons Commission Alas a It . Title: Alpine Drilling Team LeadEAnchOrage Printed Name: Chip Alvord Phone Number: 907-265-6120 Commission Use Onl LOT review and approval: Conditions of approval: Subsequent form :> required:_\ 'C) - '-\ :;). Approval number: Approved by: Original Signed By h Palin COMMISSIONER BY ORDER OF THE COMMISSION " _I Þ"""\ I N A ,< j tJ L Form 10-403AD Rev.9/2003 INSTRUCTIONS ON REVERSE Date: I 2) ?t(- 3tJ1-pð1 MaMSBFL Submit in Duplicate Annular Disposal Transmittal Form 1. Designation of the well or wells to receive drilling wastes. 2. The depth to the base of freshwater aquifers and permafrost, if present. 3. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a comm.ission finding that the waste will be confined and will not come to the surface or contaminate freshwater. CDI-21 There are no USDW aquifers in the Colville River Unit. Base of Permafrost = 1556' TVD (RKB) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) 4. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water wells There are no water wells within 1 mile. within one mile of the well to receive drilling waste. 5. Identify the types and maximum volume of waste to Types of waste may be drilling mud, drilling cuttings, be disposed of and the estimated density of the waste reserve pit fluids, cement-contaminated drilling mud, slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6. Description of any waste sought to be determined as Cement rinsate drilling waste under h (3) of this section 7. An estimate of maximum anticipated pressure at the Maximum anticipated pressure at casing shoe during outer casing shoe during annular disposal operation disposal operations is 1979 psi. See attached and calculations showing how this value was calculation page. determined. 8. Details that show the shoe of the outer casing is set See attached cementing reports, LOT/FIT reports, and below the base of any freshwater aquifer and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. 9. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. 10. Any additional data required by the Comm.ission to NA confirm containment of drilling wastes. See attached casing summary sheet and calculation page. Pressure Calculations for Annular Disposal Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure Well Date CDI-21 1/7/2004 J 1,500 psi 12 ppg 0.4525 psilft 0.11 psilft 2,000 psi Maximum Fluid Density to Burst Surface Casine Pburst85% = PHydrostatic + P Applied - PFonnation MW max 2,992 = ( 2,379 * 0.052 * MW max ) + 1500 - (0.4525 * 2,379) 20.8 ppg = 2,379 TVD Surface Casine Strine ~ Size Weight Grade PburstlOO% Pburst85 % Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure ~ ~ j : g = ~ TOC Est. @ 8,376' MD 6,724' TVD 9.625 in 36 ppf J 55 3,520 psi 2,992 psi 2,379 ft 16 ppg 15.5 ppg 1,500 psi or 1,979 psi Maximum Fluid Density to Collapse 2nd Casine Strine Pcollapse85% = PHydrostatic + P Applied - PGasGradient - PHeader MW max 4,599 =( 6,724* 0.052 * MWmax )+ 1,500 -( 0.1100 * 6,724)- 2,000 7,046 TVD Maximum Allowable Pressure at Surface Casine Shoe P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT P max allowable = ( 2,379 * .052 * 16 ) P max allowable = 1,979 psi = 16.7 ppg 2nd Casine Strine Size 7 in Weight 26 ppf Grade L 80 P collapse 100% 5,410 psi P collapse85 % 4,599 pSI Top of Cement 6,724 ft Gas Gradient 0.11 psilft Max Surf. Pressu 1,500 psi Header Press 2,000 psi CDl-21 Surface Injection Pressures @ 2 BPM Injection Injection Injection MW Pressure MW Pressure MW Pressure (ppg) (psi) (PP2) (psi) (ppg) (psi) (@ 2 BPM) (@ 2 BPM) (@ 2 BPM) ':i;,ü:';6~:"'8:\':",'" 1 ,238 8,.8" 99 1 """1(r'8';;~:' 743 . ,"':'~::>;" ,", » ;'/:::', ""','.:, '":,, ".:"':": ';:-C,',.':."" ,,:.:,' ~';:' ,,' ~;:~\~:6<9;'f: ,~;/:' " :~??:::fíQ;9.::: '::'" 1 ,226 8~'9 " " 978 73 1 ' """~'" ,,', ":, ':', "':{:'::', ",.,' <:'",'" ::::';:'~:;1J;':'O"':"",¿" 1 ,213 ""9':'0 ,.,::" 966 ,,?,:,:,::,"t~t;:'(l'::» 7 19 ,,>~":>:'~";'~':,"""":>'" ' , " ' , :¡."." "";,,.; ,~.; ;'8 ',;"':"> ,. '," "', ., '::'i, .. ,', ",',,' " ,., ... ::>:~:~::7.~l:jt" ; ": ' <":~'::~fl:':::~l."/' 1 ,201 9,.1 ,, 954 706 "'", "," "",0"',' ' , '" , , ",c.' "1' 1':2 ",;.. ':"::."'.:"';2::;':':: ',', 1 1 89 9~2 941 694 ' " ,":"""', ,:.' ," "'" ,"- , "': ' "'" ""', ..,' ,', , , "'" ,:'~ , ",.',," '~':;':"7'3":': 1, 176 9.3' 929 1 f:~"3,':, 68 1 " ,", '.. " , ""::'~74' 1 164 9.4'" 916 "",,11.4.. 669 ' ," , '. , , "":, ",' ' ,,'" -' ',<C," ':7':"5~::\" 1 152 9.5 904 ":1'l":5':':"~,' 657 ' .' , . , "7"'6": " 1 139 9.6 892 ,,1,1"'6":::,;: 644 , ' , .' , " ., ':,It, :' " ' :', " ,.': :f"'l '~7' 'i' .. ,' 9.~l 1 127 '9.7 879 632 " "", , " 7.:.,8 1, 1 14 9.8 867 ,",11,".8 .' 620 7;9 ' "'.. '" 1 102 9.9 855 11..9 -, 607 , " ,,~8,.O " 1 ,090 10.0 842 1,2.0 595 .~:t::~¡';"8:~'i:, >',,': 1,077 10.1 830 ,""':"12'~:'¡"";'::, 582 " , .' ", , ",,' , " - " , ' .. :.8:.2" 1 ,065 10,.2 8 1 8 ',:'l2~~' 570 """',~".g ":3"-:" 1 ,053 '10.'3 805 ',¡ 12:~,3:," 558 ," ',' , , " "", "'"" "',;8":4' : 1 ,040 10.4 793 12.4'" 545 , '" ,.,,"' " , ,'c' ,',' , ". ,,:;:,,:g,~'5',',: 1 ,028 lO~5 780 " 1:2,.5 533 " " "~!"""": "" ",,' " ' .' ," " '~;:j;:i2";'6'::'.;", ',' ""8 "6:'.: 1 ,015 10.6 768 521 ::,'"" r.. ", ,"', ' " , ""," " :"':8"1 ' 1 ,003 1-0.7 756 ""1,2:"7'.-" 508 , " '., "', ':'. ' .'.. ' , ~PHILLIPS Alaska, Inc. Casing Detail 9 5/8" Surface Casing Well: CD1-21 Date: 2/5/2001 A Subsidiary or PHILLIPS PET¡:¡OLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 36.80 FMC Gen V Hanger 2.25 36.80 Jts 3 to 64 62 Jts 9-5/8" 36# J-55 BTC Csg 2599.29 39.05 Davis Lynch Float Collar 1.64 2638.34 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 76.08 2639.98 Davis Lynch Float Shoe 1.75 2716.06 2717.81 TO 12 1/4" Surface Hole 2728.00 RUN TOTAL 37 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #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 Last 9 jts, stay out # 65 to # 73 Use Best-o-Life 2000 pipe dope Remarks: Up Wt -150 k On Wt -135 k Block Wt - 70 Supervisor: Don Mickey Phll" AI k D 11" c f D t 1 I IpS as a rl Ing ernen Ing e al S Well Name: CD1.21 Report Date: 0210612001 Report Number: 1 Rig Name: Doyon 19 AFC No.: 998D01 Field: AIDlne Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 121/4" 39 2718 2638 Centralizers State type used. inteNals covered and spacing Comments: 37 bow spring - 1 on each of first 12 Its. then every other It. to 2 Its below hanger Mud Weight: PV(prior cond): PV(after can d): YP(prior cond): YP(after cond): Comments: 9.9 14 10 40 10 Gels before: Gels after. Total Volume Circulated: 68,54,47 30,20,15 780 bbls Wash 0 Type: Volume: Weight: Comments: Water 40 bbls 8.3 ppg Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 bbls 10.5 ppg Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: ASIII 70 405 10.7 ppg 4.4 cflsk Additives: Class G wI 30% D053, 0.6% D046, 1.5% D079, 1.5% SO01, 50% D124, & 9% BWOW DO44 Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 231 15.8 ppg 1.17 cflsk Additives: Class G wI 0.2% D046, 0.3% D065, & 1% SO01 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 7.5 81M 7.5 87M 150 Reciprocation length: Reciprocation speed: Str. WI. Down: 20' 135 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 204 bbls 204 bbls Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:2I6/01 Yes Yes Time:O400 hrs. Remarks:Full returns through job wI 80 bbls cmt returns to surface Cement Company: Rig Contractor: Approved By: Dowell DOYON Don Mickey If¡1J ~Ÿ" .-- . (b '> I ~ rl -'1 (' ~~.. . r.,) Vl .' 'i' j.)J<., " Phlr AI k D lr D 1 D lr R t I IpS as a rI Ing al y rI Ing epor AFC No. Date RptNo Rig Accept - hIS Days Since Accept/Est: 2.2 11.5 Rig Relase - hIS: 998D01 0210512001 3 0210312001 08:00:00 PM Well: CD1-21 Depth (MDfTVD) 2728/2387 Prey Depth MD: 1920 Progress: 80s Contractor. DOYON Daily Cost $ 101886 Cum Cost $ 304892 Est Cost To Date $ Rio Name: Dovon 19 Last Csa: 16" @ 114' Next Csa: 9 518 @ 2734' Shoe Test: Operation At 0600: Upcoming Operations: Test BOPE . Drill 8 1/2" hole MUD DATA DRilLING DATA BIT DATA EH&S DRillS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL SPUD 1 N TST 0210412001 0210412001 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 150 121/4. VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc 170 HTC N SPACE PVNP SOWT TYPE TYPE TYPE FUEL & WATER I 145 MXC1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2355 I I F91DS APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED 1560 2728 - BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 90 ml/30 min 8000 114 INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 6500 2614 CD1-43 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of -10 Obb! 15401 I I 16.58/8.26 I CD1- 21 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 18 1121 1 10- 30 - 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 90° 5.5161 I 50 - - 1358 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -49.85 % 70170 II .546 Water Base Muds 1845 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 1 0 24712941 I 1011211211811 II1II 60 PERSONNEL 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $ III $11,910 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $ III 113\WTIA III 1905 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 9.1111 E 1'1 ER I TD III 15701 PERSONNEL )1~ò~ TOTAL 50 BHAbËsé¡:IIPTIÖN I DRILLPIPE DATA BHA NO OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 5. 4.281 19.5 G105 4-1/2 IF DATE LAST INSPECTED: HOURS ON JARS: 14.98 "'..TiMÉiq".'eNo. .'.1.' . HOI.¡fi$ . 1.C).pséoöe ... . ffidLE.$ÊÓT '..'. ÞRASS'OR$..' 'I'. " ..øÞSaA;J\IØNS.Ë8ØM.!dØØÖ1ÖØõo. .,'. 12:00 AM 08:00 AM 8.00 DRIL SURF Making Hole Drill 121/4. hole f/1920' to 2728' TD - 2386.66 TVD 08:00 AM 09:00 AM 1.00 CIRC SURF Making Hole Clrc - Pump hi vis sweep 09:00 AM 10:30 AM 1.50 WIPERTRP SURF Making Hole Monitor well- Wiper trip f/2728' to 1640' 10:30 AM 11:00AM 0.50 WIPERTRP SURF Making Hole RIH to 2638' . Break circ - safety wash to btm @ 2728' 11:00 AM 01 :00 PM 2.00 CIRC SURF Making Hole Pump hi vis. bump mud wI. to 9.8 ppg . clrc & condo hole for 9 5/8. csg 01:00 PM 03:00 PM 2.00 TRIP_OUT SURF Making Hole Monitor well - POOH to run csg - pull to 1080' 03:00 PM 05:30 PM 2.50 TRIP_OUT SURF Making Hole Pump out f/1080' to 900' Improper fill. hole trying to swab - Continue POOH f/900' . std back HWDP - UD remaining BHA for Inspection 05:30 PM 06:00 PM 0.50 OTHER SURF Making Hole clear & clean up rig floor 06:00 PM 07:30 PM 1.50 CASG SURF Making Hole Rig up to run 9 5/8. csg 0 PJSM 07:30 PM 11:30 PM 4.00 RUN_CSG SURF Making Hole Ran 64)ts. 9 518. 36# Jo55 BTC csg wI shoe @ 2718' .2379' TVD 11:30 PM 12:00 AM 0.50 CIRC SURF Making Hole Clrc and condition for cement job 24.00 . 1 ¿v-1 ~ I (' ]~. \ C \j c> ;0, /?' l".\"':"" I , ¡' f¿c 'f Daily Drilling Report: CD1.21 02/05/2001 Go' d Supervisor. DON MICKEY Page 1 Phillips Alaska Drilling Daily Drilling Report AFC No. Date RptNo Rig Accept. hrs Days Since AccepUEst: 3.2 13.2 Rig Relase - hrs: 998D01 02/0612001 4 02/0312001 08:00:00 PM Well: CD1-21 Depth (MD/TVD) 2728/2387 Prev Depth MD: 2728 Progress: 0 Contractor. DOYON Daily Cost $ 360386 Cum Cost $ 665278 Est Cost To Date $ 692000 Ria Name: Doyon 19 Last Cso: 9 5/8" @ 2718' Next Csg: 7" @ 9039' Shoe Test: Operation At 0600: Drilling 8 1/2" hole @ 3290' Upcoming Operations: Drill 8 1/2" hole MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO, BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2638 2 N TST 02/04/2001 02/0612001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7000 140 81/2" VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 38sqc 140 HYC N SPACE PVNP SOWT TYPE TYPE TYPE FUEL & WATER 8/9 125 DS70FNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2103 2/8/10 22654 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED 470 14.0 02/0612001 - BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 90 ml/30 min 8500 2728 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.0% 8500 0 CD1-43 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of 3.9 181bbl 2100 I I I I I CD1- 21 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 12 27.5 11211 5 - 10 - 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 190° 7.8 5.5161 I 60. - 1350 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -20.56 5.5% 5215311 .557 Water Base Muds 1007 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 1 120 18312231 I 111111111111111 111I1 90 PERSONNEL 11 Other 712 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 $16586 III $9225 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $27981 III III III 1809 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI 9.7111 III III 19415 PERSONNEL TOTAL 47 BHADESCFlIPTIÖN ....... ... ....1 bit, Navldrlll Mach 1XL wi AKO 1.2, NM stab, GR sub MWD, MWD, Neutron sub MWD, NM stab, 3 NM Comp Srv DP, XO, 3 HWDP, I Jars, 26 HWDP D~II..LrIPE~I; t..\. .......... ; --. -- I I:\I-!A:\O 2 Q[.~ I~) ','.'[!.3t-IT Gi=\,'; )F. C::>\1\;ECTI~)": CLASS 2 U.=:.G¡"I BHA LENGTH 1104.46 5" 4.281 19.5 G105 4-1/2 IF DATE LAST INSPECTED: HOURS O~~ .,IAr-S' 14.98 1II,Ii:: I E\;D I HCUHS ' UPS C'J:ìl::: I t-':.ìLE .::I=t: I ¡:':H';SI~ O;"'S ' ()Pi:Iì."~'.I():'.S FEm! O:)(!': - Ü.:;'~~~_._...__...- ' .....- __n__.- 12:00 AM 01 :00 AM 1.00 CIRC SURF Making Hole Clrc & condition hole and mud for cmt job 01 :00 AM 02:00 AM 1.00 OTHER SURF Making Hole Blow down top drive - Ud fill-up tool - install cmt head - clrc - PJSM 02:00 AM 04:00 AM 2,00 CMT_CSG SURF Making Hole Cmt. 9 5/8" csg : 40 bbls Vis water wI nut plug - test lines to 2500 psl- 50 bbls Arco Spacer - 318 bbls lead slurry @ 10.7 ppg - observed nut plug @ shakers wI 300 bbls lead pumped - 48 bbls tall @ 15.8 ppg - Displace wI 20 bbls water & 184 bbls mud - bumped plug - floats held - CIP @ 03:55 hrs. 80 bbls cmt returns to surface 04:00 AM 05:30 AM 1.50 CEMENT SURF MakIng Hole UD cmt head, landing It. - flush 20" Hydril with fresh water 05:30 AM 07:30 AM 2.00 NU_ND SURF MakIng Hole Nipple down flow line, riser, 20" Hydrll, and diverter 07:30 AM 08:30 AM 1.00 NU_ND P1 Making Hole Install FMC Unlhead - test seal to 1000 psi 08:30 AM 10:00 AM 1.50 NU_ND P1 Making Hole Nipple 13 5/8 5K BOPE - riser, flow line 10:00 AM 03:00 PM 5.00 TEST P1 Making Hole Install test plug. test BOPE - all rams, choke manifold valves, kill line & choke line valves 250 psi low & 3500 psi high - Hydril 250 psi low - 2500 psi high - Test witnessed & approved by John Crisp AOGCC - pull test plug - UD test It. - set wear bushing 03:00 PM 04:30 PM 1.50 OTHER P1 Making Hole P/U & std back 27 Its. 5" DP ~~:~o PM 07:~ PM 2.5~ ~ P1 Making Hole MlU BHA #2 - PJSM Page 4 11: ~ ¡Q¡illilòi ~rt: CD12~ 02/06 IN P1 Making Hole RIH wI HWDP flderrlck & P/U 5" DP fIshed to 2623' 09:30 PM 10:30 PM 11:30 PM 10:30 PM 11:30 PM 12:00 AM 1.00 1.00 0.50 24.00 CIRC TEST_CSG CLN_OUT P1 P1 P1 Making Hole Making Hole Making Hole Clrc for csg test Pressure test 9 5/8" csg to 2500 psi for 30 mlns. 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I- ::) f- Z OC)IC}:J 'Z(j)Z ~ü5I-ü5~ W«O«- Jï~Ot 0 en w ~ gO IX: I- en 0 N 0 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q 000 0 0 0 0 000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000 000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m 00 ~ w ~ ~ M N ~ 0 m 00 ~ w ~ ~ M N ~ 0 m ro ~ w ~ ~ M N ~ M Ñ Ñ Ñ Ñ Ñ Ñ Ñ Ñ Ñ Ñ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ì1~::t;~, PHilliPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 7" Intermediate Casina Well: CD1-21 Date: 2/13/2001 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.45 FMC 11" X 7" Hanger 1.86 34.45 Jts 3 to 223 221 Jts 7" 26# L-80 BTCM Csg 8933.49 36.31 7" Davis Lynch Float Collar 1.44 8969.80 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 76.54 8971.24 7" Davis Lynch Float Shoe 1.69 9047.78 9049.47 TD 8 1/2" hole 9060.00 Top of Alpine @ 8876 . MD. 1 straight blade centralizer per jt. #1 - # 17 33 srraight blade centralizers (1) every other jt. f/ jt. # 157 to jt. # 221 Total- 50 centralizers Use Best-o-Life 2000 pipe dope Remarks: Up Wt -325 k Dn Wt -160 k Supervisor: Don Mickey s Alaska Drillin Cementi n Deta iI s Report Date: 0211412001 AFC No.: 998D01 Report Number: 1 Field: AI Ine Casing Size Hole Diameter. Angle thru KRU: Shoe Depth: LC Depth: % washout: 1" 8 112" 39 9049' 8969 Centralizers State type used. inteNals covered and spacing Comments: Slip on Straight blade on its. 1 to 11 - 1 every other it f/151 to 221 - 50 total Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.8 9 8 20 16 Unable to clrc & condition due Gels before: Gels after. Tolal Volume Circulated: to lost returns - samples from 9/14/18 9/11/15 mud In pits and returns from flow line Wash 0 Type: Volume: Weight: Comments: Pumped 20 bbls LCM pili Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 bbls 12.5 ppg Lead Cemen't 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 10 119 15.8 ppg 1.15 Additives: 0.2% 0046, 0.25% 0065,0.25% D800, and 0.18% 0161 Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: Additives: Displacement 0 Rate(before tail al shoe): Rate(laii around shoe): Sir. WI. Up: Comments: 181M 181M 300 Reciprocation length: Reciprocation speed: Str. WI. Down: 110 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 343.5 bbls 345 bbls Calculated top of cement: CP: Bumped plug: Floats held: 8316' Date:2I13/01 No Ves Time:2330 hrs Remarks: Lost returns to surface while running csg @ 8800' - attempt to clrc - lost 188 bbls - regained clrc with 155 bbls of displacement away - observed god pressure Increase when cmt turn corner - observed slight flow f/ annulus after shutting down - closed Hyrll and monitor pressure Cement Company: Rig Contractor: Approved By: Dowell DOYON Don Mickey Phll" AI k D "II" D 1 D 11" R t I IpS as a n Ing alY ra Ing epor AFC No. Date RptNo Rig Accept - hrs Days Since AccepVEst: 10.2 110.2 Rig Relase - hrs: 998D01 0211312001 11 0210312001 08:00:00 PM Well: CD1-21 Depth (MDITVD) 9060nO44 Prey Depth MD: 9060 Progress: 0 Contractor. DOYON Daily Cost $ 274227 Cum Cost $ 1775519 Est Cost To Date $ 1800000 Ria Name: Dovon 19 last Csa: 7" @ 9049' Next Csg: Shoe Test: Operation At 0600: Prep to test BOP Upcoming Operations: Test BOP - MIU 6 1/8" BHA - Drill 61/8" hole MUD DATA DRILLING DATA BIT DATA EH&S DRILLs/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRill LSND 3 N TST 0211212001 0210612001 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppQ 81/2" 02113/2001 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRill 44sqc HTC N SPACE 0211212001 PVNP SOWT TYPE TYPE TYPE FUEL & WATER 10/20 MX09D GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2050 11/14/17 P95DD APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED 270 4.6 9060 0211312001 - BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 90 11.3m1l30 min 8460 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 7.5% 600 CD1-43 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP OF 14 607bbl 2460 III 18.2/15.87 I CD1- 21 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 18 17.5 1 121 I 5 - 25 - 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 2300 9.2 5.5/61 I 0 - 20 - 1400 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -16.42 3.2% 6716811 .518 Water Base Muds 165 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 1 137 23612861 I 15115115111 1II1I 50 PERSONNEL 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $4798 30140130140 $12825 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $124283 360 1420 1400 I 2121WTIA III 215 480 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 19 MI 9.8111 E III NO I TD III 23825 PERSONNEL TOTAL 51 BHAbESCRIPTION '."':"'1 DRILLPIPE DATA BHA NO OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 5" 4.281 19.5 G105 4-1/2 IF DATE LAST INSPECTED: HOURS ON JARS: 71.77 TIME I END I HOURS OPS CODE HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 05:00 AM 5.00 TRIP_OUT P1 Making Hole Continue POOH laying down 5" DP to 2700' - Flow ck - continue POOH & UD 5" DP - std back HWDP 05:00 AM 06:30 AM 1.50 BHA P1 Making Hole UD BHA # 4 06:30 AM 07:30 AM 1.00 OTHER P1 Making Hole House keeping rig floor - flush BOP stack w/ wash tool 07:30 AM 08:00 AM 0.50 OTHER P1 Making Hole Pull long Wear bushing - Install thin wall WB qo ~I 08:00 AM 09:00 AM 1.00 CASG P1 M.klng Hole Rig lip to <IIn 7" csg " PJ8M ~ 09:00 AM 07:30 PM 10.50 RUN_CSG P1 Making Hole Run 223 Its. 7" 26# L-80 Mod STC csg. Clrc. ca olume <èf\1. \~' (9 5/8" shoe) - landed w/ shoe @ 904 .74' - C @ '<-- 8969' Lost returns while RIH @ 8800' 07:30 PM 09:00 PM 1.50 CIRC P1 Making Hole UD fill up tool - M/U clrc head - attempt to establish clrc.- pumping 2.5 to 5 bbs/mln working pipe -lost 188 bbls mud - no returns - Discuss options with Team Leader 09:00 PM 10:00 PM 1.00 CEMENT P1 Making Hole Break out clrc head - M/U cmt head - mix LCM pili - PJSM 10:00 PM 12:00 AM 2.00 CMT_CSG P1 Making Hole Cement 7" csg. - pump 20 bbls LCM pill - 5 bbls water - test - .Î""..)) (:> ..¡t~~'~<"'"""'~, '::;",~ ",,_..,..,,:) ~:~ (.)-",. i ~~",... line to 3500 psl- pump 50 bbls Arco spacer @ 12.5 ppg - p; d "". to t 6.........p' drop btm plug - pump 25 bbls slurry @ 15.8 ppg - Drop top , plug w/20 bbls water f/ Dowell - displace w/325 bbls mud - K ,<;¿Q~ /r~. {.k didn't bump plug - floats held - CIP @ 2330 hrs. . 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" ~ 1 N - ~ " .1;' ~ ill ~ " g i ~ ~ ~ ~ , " ~ '! SURFACE CASING SHOE SEPARATION FROM CD1-21 CD1-21 x V Surface Casing Shoe ASP 4 Coordinates: 385033.54 5976479.08 ~urrace ~urrace :SUrface csg. Details @ Permit Distance from Shoe csg.Shoe Shoe V Wells AOGCC? Permit # Date Object well* TVD X Coord. Coord. CD1-01 y 399-116 7/12/99 1032 2364 386000.88 5976120.23 CD1-02 1422 2398 386406.59 5976107.32 CD1-03 y 300-005 1/13/00 723 2370 385744.09 5976611.32 CD1-04 1771 2377 386800.96 5976584.44 CD1-05 y 300-022 1/27/00 1762 2387 386752.76 5976091.39 CD1-06 2268 3090 387261.90 5976054.67 CD1-07 CD1-08 CD1-09 y 300-163 6/22/00 2404 2790 387400.42 5976058.56 CD1-10 1146 2403 386080.76 5976013.75 CD1-11 CD1-12 CD1-13 y 399-121 7/19/99 1436 2387 386333.24 5975867.57 CD1-14 3227 2366 388120.50 5975539.11 CD1-15 CD1-16 y 399-213 11/2/99 1884 2399 386666.50 5975539.37 CD1-17 1641 2385 386386.08 5975549.67 CD1-18 CD1-19 y 399-064 4/20/99 1215 2393 386182.40 5976873.16 CD1-20 CD1-21 0 2391 385033.54 5976479.08 CD1-22 1123 3110 385890.63 5975753.64 CD1-23 y 399-141 8/5/99 2644 2398 387499.21 5975525.36 CD1-24 2161 2390 387001.62 5975585.79 CD1-25 y 300-1 02 4/17/00 2227 2398 386816.46 5975145.40 CD1-26 2109 2389 386511.26 5974974.98 CD1-27 y 300-058 3/22/00 2002 2366 386148.85 5974816.28 CD1-28 1045 2372 385780.25 5975747.82 CD1-229 2848 2385 386239.91 5973899.61 CD1-30 360 2387 384814.85 5976193.13 CD1-31 y 300-263 11/24/00 586 2378 385054.61 5975893.22 CD1-32 y 399-245 12/9/99 707 2413 384754.69 5975829.24 CD1-33 1125 2430 385796.34 5975652.73 CD1-34 y 300-133 5/8/00 1206 2361 385543.31 5975386.66 CD1-35 y 399-086 5/21/99 1010 2388 385634.65 5975667.79 CD1-36 y 399-260 1/3/00 867 2406 385189.14 5975626.47 CD1-37 y 399-162 8/27/99 2007 2409 385828.32 5974635.64 CD1-38 y 300-051 2/29/00 2016 2376 385516.01 5974522.02 CD1-39 y 399-181 9/1 0/99 1616 2388 385568.87 5974954.54 CD1-40 y 399-101 6/11/99 2123 2392 385005.59 5974356.58 CD1-41 y 300-104 4/24/00 999 2394 385231.03 5975499.87 CD1-42 y 399-261 1/3/00 1237 2384 384596.37 5975321.88 CD1-43 y 300-241 9/20/00 1614 2386 384753.45 5974889.55 CD1-44 y 300-146 5/31/00 1425 2375 384506.22 5975155.17 CD1-45 y 299-233 11/17/99 1445 2385 384726.63 5975067.43 CD1-46 CD1-47 CD1-48 CD1-49 * Lateral distance in feet, between surface casing shoes, in the X- Y plane, assumes similar TVD Note that this sheet is not the definitive record ./ / ../ r '-Q\"I\~~"'\\n ~ r:: l-o T '\ "b~(J\"\:) ~" ..¡ CQ \, \) X. ,~~<.,,~~ ", - \ ~\._~ ~~~C-~\\)E: \}J~ ~\ -\~ \ C1 , t-~-~ \1<;-0" ./ ~ " ./ Y'^ / ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface easing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, . . . Jerry Dethlefs ConocoPhillips Problem Well Supervisor SCANNED APR 3 0 21303 Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI ~ 8.5 CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD 1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 .-- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 __ CD2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 $~NED ~PR 8 0 2003 -L Subject: Alpine Cement TopOI Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <torn_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cemenL I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/2003 7:55 AM ALPINE cement top outs 04-16-03.xls Name: AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 [-~Cement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak, us> Sr, Petroleum Engineer Alaska Oil and Gas Conservation Commission ... 2003 2of2 4/24/2003 7:55 AM Permit to Drill 2010060 MD 11087 - TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. COLVILLE RIV UNIT CD1-21 Operator CONOCOPHILLIPS ALASKA INC 7003 ~- Completion Dat 2/25/2001 ~ Completion Statu WAGIN Current Status WAGIN APl No. 50-103-20362-00-00 UIC Y REQUIRED INFORMATION Mud Log N_go Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments i~rrectional Survey FINAL A3~'rectional Survey FINAL /J3lrectional Survey FINAL ~ 5 FINAL r...1.0062 FINAL 10063 FINAL (.~Array Res 2/5 ~ z:MD"~ray Res 2/5 "I=~AL '~D Arrey Res 2/5 -F-4NA~ 4~19026 FINAL Q~V.I~A D N 2/5 FINAL /,4~A D N 2/5 FINAL ~"~RC 6 2/5 FINAL L,.~D ARC 6 2/5 FINAL 8460 11782 Open 9910 11039 Open 2718 8950 Open ch 8631 8947 ch 9910 11039 oh 8460 11782 oh 9865 11039 oh ,~::)~0 11782 oh 9060 11782 oh 2718 8950 oh 2718 8906 oh 2718 8906 oh 2718 8906 oh 2718 8906 oh 5/3/2001 5/312001 4/20/2001 2/26/2001 3/1512001 3/16/2001 3/23/2001 5/3/2001 5/3/2001 5/3/2001 5/3/2001 5/3/2001 4/20/2001 4/2012001 4/20/2001 4/20/2001 4/20/2001 c~.0063 r-'8~460-11782 -A'0062 ~"9'910-11039 =.-t'0026 ~2718-8950 Directional Survey Paper Copy Directional Survey Paper Copy Directional Survey Paper Copy 8631-8947 Color Print u '11~062 ~--'g910-11039 Digital Data 41~063 C~'~60-11782 Digital Data 9865-11039 BL, Sepia 9060-11782 BL, Sepia 9060-11782 BL, Sepia 10026/.~718-8950 Digital Data 2718-8906 BL, Sepia 2718-8906 BL, Sepia 2718-8906 BL, Sepia 2718-8906 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments Permit to Drill 2010060 MD 11087 TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. COLVILLE RIV UNIT CD1-21 Operator CONOCOPHILLIPS ALASKA INC 7003 Completion Dat 2/25/2001 Completion Statu WAGIN Current Status WAGIN APl No. 50-103-20362-00-00 UIC Y ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? ~ Analysis ~ Re. ceive, d? Daily History Received? ~/N Formation Tops ~1 N Comments: Compliance Reviewed By: (' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other _X Conversion to WAG 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 364' FNL, 2846' FEL, Sec. 5, T11 N, R5E, UM At top of productive interval 2413' FNL, 1489' FEL, Sec. 31, T12N, R5E, UM At effective depth At total depth 464' FNL, 2516' FEL, Sec. 31, T12N, R5E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X (asp°s 385858, 5975764) (asp's 381975, 5979056) (asp's 380972, 5981020) 6. Datum elevation (DF or KB feet) RKB 36 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-21 9. Permit number / approval number 201-006 / 10. APl number 50-103-20362 11. Field / Pool Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical 11087 feet Plugs (measured) 7003 feet Effective depth: measured true vertical 11087 feet Junk (measured) 7003 feet Casing CONDUCTOR SURF CASING PROD CASING OPEN HOLE OPEN HOLE Length 114' 2717' 9049' Size Cemented 16" 10 cu yds Portland Type 3 9-5/8" 40S sx AS III, 231 sx Class G 7" 119 sx Class G Perforation depth: measured open hole completion from 9049' - 11087' true vertical open hole completion Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8745' MD. Packers & SSSV (type & measured depth) BAKER 'S-3' PACKER @ 8675' MD. CAMCO A-1 INJECTION VALVE, ORIFICE = 1.25" @ 2238' MD Measured Depth 1'14' 2717' 9049' True ve~ical Depth 114' 2378' 7043' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily AveraRe Production or Iniection Data Gas-Md Water-Bbl N/A Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Oil i Gas I Suspended Service _WAG Injector XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ignedchris Pierson ~~/~ Title Alpine Engineer Form 10-404 Rev 06/15/88 · ORIGINAL Questions? Call Chris Pierson 265.6112 Date ]/~//~ ~'~ Prepared by Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLiCAT~(~ 51212001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tt ATTN: Sherrie NO. 1106 Company: Alaska Oil & Gas Cons Comm Attn:- Lisa Weepie . 333 west 7th Ave, Suite 100 Anchorage, AK 99501 Field:' -Alpine (Open Hole) Color Well Job # Log Description Date BL Sepia Prints CD .. ICD1-21 ~ 21128 ARC ADN & IMP (PDC) 02/2310t 1 !CD1-21 ~ 21128 MD ARRAY RES 02123/01 I . 1 CD1-21 ~,Y' 21129 ARC ADN & IMP (PDC) 02/19101 1 CD1-21 ~ 21129 MD ARRAY RES 02/t 9101 t 1 CDt -21.,.L4' 21129 TVD ARRAY RES 02/19101 . · . .. .I 0 3 2001- Sl~FO.. ~~/~t ~~~~/ DATE: ,, .... ~e, e ~.. ~.--.. ~--mieabu~ Anc~0rage Please sign and ~turn one copy of this transmi~l to SherHe at the above address or fax to (907) 561-8317, Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned [~ Service [~],~ WAG injector 2. Name of Operator ~~ 7. Permit Number Phillips Alaska, Inc. ~ 201-006 3. Address ~_~~ ~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ..."- ~ 50-103-20362-00/50-103-20362-70 '., 4. Location of well at surface 19. Unit or Lease Name 365' FNL, 2433' FWL, Sec. 5, T11 N, RSE, UM (ASP: 385858, 5975764) *?' ?'.'~'~,,;..'.,'-'.~' .':'.'-":',':;'~,i ~ Colville River Unit At Top Producing Interval ~_ ~,~!~.~ .":"",: ,' i10. Well Number 2413' FNL, 1489' FEL, Sec. 31, T12N, R5E, UM (ASP: 381975, 5979056) ~ =i ;CD1-21 & CD1-21PH At Total Depth ~.~ E ..... ~.~ ~ 11. Field and Pool ;) 466' FNL, Lae46~ FW~I_, Sec. 31, T12N, RSE, UM (ASP:380972, 5981020) ~' --~-~'-- ~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feetI ADL 25559 / 25558 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions February 4, 2001 February 23, 2001 February 25, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11087' M D / 7003' TVD 11087' M D / 7003' TVD YES r~ No r~ I N/A feet MD 1638' 22. Type Electric or Other Logs Run GR/Res/Neu/Den 23. CASIN(3, LINER AND CEMENT!N(3 RECORD SETTIN(3 DEPTH MD CASIN(3 SIZE WT. PER FT. GRADE TOP .BOTTOM'." HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2718' 12.25" 405 sx AS III & 231 sx Class 7" 26# L-80 Surface 9049' 8.5" 119 sx Class cement plug #2: 8549'-7878' cement plug #1: 8950'-8549' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBIN(3 RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 8746' 8676' Open Hole completion 6.125" OH from 9049'-11087' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8950'-8549' Plug #1' 156 sx 15.8 ppg Class (3 cement 8549'-7878' Plug #2:159 sx 17 ppg Class G cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL (3AS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL (3AS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECF_ VE[) N/A APR 2 ZOO1 Alaska Oil & Gas Cons, Commission Anchorage Form 10-407 Rev. 7-1-80 Submit in duplicate 29. [ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alpine D 8818' 6997' Alpine 8877' 7016' N/A 31. LIST OF A'I-rACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed ~-L,J,- -~ ~ Title Alpine Drillin.q Team Leader Date '/ "' Gl. C. Alvord Prepared by Sharon AIIsup-Drake INSTRUCTIONS 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertir{ent to such interval. Item 21: Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Shut-in, Other-explain. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, E' ,VED Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL APR Alaska Oil & Gas Cons. Commission Anchorage Operations Summary CD1-21 Rpt Date 02/03/01 12:00 AM 02/03/01 12:00 AM 02/03/01 12:00 AM 02/03/01 12:00 AM 02/04/01 12:00 AM 02/04/01 12:00 AM 02/04/01 12:00 AM Begin 12:00 17:30 18:00 21:30 00:00 01:30 03:30 Time End Time 17:30 18:00 21:30 00:00 01:30 03:30 05:00 Comments Move rig f/CD1-NQ1 to CD1-21 Install surface stack on CD1-21 Move rig over well - move pits, motors, & GIS in psoition Rigging up Continue rigging up M/U BHA # 1 Pre-spud meeting w/crew - Kick drill - function test diverter system, accu. closure test - fill hole - check for leaks 02/04/01 12:00 AM 02/05/01 12:00 AM 05:00 00:00 00:00 08:00 Break circ.- Spud-in -Drill 12 1/4" hole f/114' to 1920'- 1766 TVD - ADT- 10.86 AST- 8.26 Drill 12 1/4" hole f/1920' to 2728' TD - 2386.66 02/05/01 12:00 AM 02/05/01 12:00 AM 02/05/01 12:00 AM 02/05/01 12:00 AM 02/05/01 12:00 AM 02/05/01 12:00 AM 08:00 09:00 10:30 11:00 13:00 15:00 09:00 10:30 11:00 13:00 15:00 17:30 TVD Circ - Pump hi vis sweep Monitor well - Wiper trip f/2728' to 1640' RIH to 2638' - Break circ - safety wash to btm @ 2728' Pump hi vis - bump mud wt. to 9.8 ppg - circ & cond. hole for 9 5/8" csg Monitor well - POOH to run csg - pull to 1080' Pump out f/1080' to 900' improper fill - hole trying to swab - Continue POOH f/900' - std back HWDP - L/D remaining BHA for inspectio 02/05/01 12:00 AM 02/05/01 12:00 AM 02/05/01 12:00 AM 02/05/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 17:30 18:00 19:30 23:30 00:00 01:00 02:00 04:00 18:00 19:30 23:30 00:00 01:00 02:00 04:00 05:30 clear & clean up rig floor Rig up to run 9 5/8" csg - PJSM Ran 64jts. 9 5/8" 36# J-55 BTC csg w/shoe @ 2718' - 2379' TVD Circ and condition for cement job Circ & condition hole and mud for cmt job Blow down top drive - L/d fill-up tool - install cmt head - circ - PJSM Cmt. 9 5/8" csg: 40 bbls Vis water w/nut plug - test lines to 2500 psi - 50 bbls Arco Spacer - 318 bbls lead slurry. @ 10.7 ppg - observed nut plug @ shakers w/300 bbls lead pumped - 48 bbls tail @ 15.8 ppg - Displace w/20 bbls water & 184 bbls mud - L/D cmt head, landing jt. - flush 20" Hydril with fresh water 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 05:30 07:30 08:30 10:00 15:00 16:30 19:00 07:30 08:30 10:00 15:00 16:30 19:00 21:30 Nipple down flow line, riser, 20" Hydril, and diverter Install FMC Unihead - test seal to 1000 psi Nipple 13 5/8 5K BOPE - riser, flow line Install test plug - test BOPE - all rams, choke manifold valves, kill line & choke line valves 250 psi Iow & 3500 psi high - Hydril 250 psi Iow - 2500 psi high - Test witnessed & approved by John Crisp AOGCC - pull test plug - L/D test jt. - set wear bush, P/U & std back 27 its. 5" DP M/U BHA #2 - PJSM RIH w/HWDP f/derrick & P/U 5" DP f/shed to 2623' Operations Summary CD1-21 02/06/01 12:00 AM 02/06/01 12:00 AM 02/06/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/08/01 12:00 AM 02/08/01 12:00 AM 02/08/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 21:30 22:30 23:30 00:00 00:30 01:30 02:00 02:30 15:00 15:30 20:00 21:30 22:00 23:00 00:00 01:30 02:30 00:00 01:00 03:00 04:30 00:00 02:30 03:30 08:00 10:00' 12:00 16:00 21:00 22:00 22:30 23:30 00:00 00:30 01:30 02:00 02:30 15:00 15:30 20:00 21:30 22:00 23:00 00:00 01:30 02:30 00:00 01:00 03:00 04:30 00:00 02:30 03:30 08:00 10:00 12:00 16:00 21:00 22:00 23:00 Circ for csg test Pressure test 9 5/8" csg to 2500 psi for 30 mins. Drill out cmt f/2635' to 2638' - drill float collar @ 2638' Continue drilling out ctm in shoe track - drill out shoe @ 2718' - C/o rat to to 2728' Drill 20' new hole to 2748' - 2402' 'I'VD Circ and condition for LOT/FIT test Perform FIT to 16.0 ppg EMW Chage well over to 9.6 ppg LSND mud Drill 8 1/2" hole from 2748' to 4178' MD - 3507 TVD - ADT 7.97 AST .69 - lost 400 psi pump pressure while drilling - p rate slowed Pump hi vis sweep - monitor well - static POOH looking for wash out Pull RA source from MWD - pulled to motor - found wash out in body of float sub @ top of motor -dn load MWD change out mud motor - orient Install RA source in MWD- RIH with BHA 7 1 std HWDP - pulse test MWD RIH w/BHA & DP to 9 5/8" shoe @ 2718' Monitor well Cut & slip 60' drill line RIH to 4178' Drill 8 1/2" hole f/4178' to 6714' - 5450' TVD ADT 14.52 AST 1.13 Circ sweep for wiper trip - monitor well - static Wiper trip f/6714' to 4178' - Hole in good shape RIH f/4178' to 6053' - fill pipe - continue RIH to 6654' Break circ. - wash f/6654' to 6714' - Drill 8 1/2" hole f/6714' to 8747' - 7012' TVD - ADT- 14.6 AST- .83 Drill 8 1/2" hole f/8747' to 8950' - 7169' TVD - Top Alpine 8750' 7020' TVD' Pump hi vis swep - circ hole clean -monitor well Wiper trip f/8950' to 6700' - work tight hole 7625' to 7615 & 7595' to 7510' - RIH f/6700 to 8950' Circ & condition mud - monitor well - blow down top drive POOH to 7000' - hole in good shape - pump dry job Continue POOH - monitor well @ 9 5/8 shoe - pull to BHA - Std back HWDP - remove RA source from MWD - L/D MWD, stabs, motro, & bit M/U mule shoe & run 10 stds 3 1/2" DP - change tool - RIH w/5" DP to 8950' Circ and condition for cmt plug Set cmt plug #1 - 8950' to 8549' w/156 Sx (32.3 bbls) Class G @ 15.8 ppg - displace to equalize - ClP @ 23:10 hrs 02/10/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 23:00 00:00 01:00 00:00 01:00 02:00 R/D cmt lines - PUll out to 8549' Circ @ 8549' - R/U cmt line Set plug # 2 w/159 sks Class G (28.3 bbls) @ 17.0 ppg - 02/11/01 12:00 AM 02/11/01 12:00 AM 02:00 02:30 02:30 03:00 Displace to equalize - Calc Top 8146' - CIP @ 01:40hrs Pull out to 7878' Circ btms up @ 7878' - Monitor well - pump dry job Operations Summary CD1-21 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/12/01 12:00 AM 02/12/01 12:00 AM 02/12/01 12:00 AM 02/12/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 03:00 06:30 08:00 09:00 10:00 10:30 13:00 15:00 16:30 20:00 00:00 17:00 18:30 20:00 00:00 05:00 06:30 07:30 08:00 09:00 19:30 21:00 06:30 08:00 09:00 10:00 10:30 13:00 15:00 16:30 20:00 00:00 17:00 18:30 20:00 21:00 05:00 06:30 07:30 08:00 09:00 19:30 21:00 22:00 POOH w/5" & 3 1/2" drill pipe & mule shoe M/U BHA # 4 - pulse test MWD RIH to 2700' - Monitor well Cut & slip drill line 60' Service top drive Continue RIH f/2700' to 7825' Break circ @ wash & ream f/7825' to 8180' - tag cmt Drill cmt f/8180' to 8460' firm cmt f/8190' to 8460' Time drill off cmt plug f/8460' to 8490' Drill 8 1/2" hole f/8490' to 8629' TVD 6906 - AST- 5.56 ART. .48 Drill 8 1/2" hole f/8629' to 9060' - 7044' TVD - Rig pick top of Alpine - 8876' - 7015 TVD Pump weighted hi vis pill - circ hole clean - Monitor well- static Wiper trip f/9060' to 7160' - no tight hole - monitor well static RIH f/7160' to 9060' Continue POOH laying down 5" DP to 2700' - Flow ck - continue POOH & L/D 5" DP - std back HWDP L/D BHA # 4 House keeping rig floor - flush BOP stack w/wash tool Pull long Wear bushing - install thin wall WB Rig up to run 7" csg - PJSM Run 223 jts. 7" 26# L-80 Mod BTC csg. Circ. casing volume @ 2718' (9 5/8" shoe) - landed w/shoe @ 9049.74' - FC @ 8969' - Lost returns while RIH @ 8800' L/D fill up tool - M/U circ head - attempt to establish circ.- pumping 2.5 to 5 bbs/min working pipe - lost 188 bbls mud - no returns - Discuss options with Team Leader Break out circ head - M/U cmt head - mix LCM pill - PJSM 02/13/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 22:00 00:00 04:30 05:30 07:00 12:00 13:30 15:30 16:30 17:00 18:00 00:00 04:30 05:30 07:00 12:00 13:30 15:30 16:30 17:00 18:00 00:00 Cement 7" csg. - pump 20 bbls LCM pill - 5 bbls water - test line to 3500 psi - pump 50 bbls Arco spacer @ 12.5 ppg - drop btm plug - pump 25 bbls slurry @. 15.8 ppg - Drop top plug w/20 bbls water f/Dowell - displace w/325 bbls mud - didn't bump plug - Shut in well for four hours, bled off zero psi, LD cement head and LJ, pull wear bushing. Install and test packoff to 5000 psi. Change top pipe rams to 3-1/2" x 6" and drive sub on TD to 3-1/2 IF. RU and test BOPE, choke and surface safety valves 250/3500 psi, annular preventor 250/2500 psi. Remove test plug and install wear bushing. MU BHA #5. RIH picking up 3-1/2" DP to 1500'. Lost highline power, monitor well. Continue to PU DP to 2097'. Lost highline power- monitor well. Continue PU DP - tagged cement @ 8745'. Operations Summary CD1-21 02/15/01 12:00 AM 00:00 02/15/01 12:00 AM 01:00 02/15/01 12:00 AM 02:00 02/15/01 12:00 AM 03:00 02/15/01 12:00 AM 05:00 02/15/01 12:00 AM 07:00 02/15/01 12:00 AM 08:30 02/15/01 12:00 AM 09:30 02/15/01 12:00 AM 10:30 02/15/01 12:00 AM 12:30 02/15/01 12:00 AM 13:30 02/15/01 12:00 AM 14:00 02/15/01 12:00 AM 15:30 02/15/01 12:00 AM 16:00 02/15/01 12:00 AM 21:00 02/15/01 12:00 AM 22:00 02/16/01 12:00 AM 00:00 02/16/01 12:00 AM 03:00 02/16/01 12:00 AM 04:30 02/16/01 12:00 AM 07:00 02/16/01 12:00 AM 08:00 02/16/01 12:00 AM 14:00 02/16/01 12:00 AM 16:00 02/16/01 12:00 AM 19:30 02/16/01 12:00 AM 20:30 02/16/01 12:00 AM 23:30 02/17/01 12:00 AM 00:00 02/17/01 12:00 AM 01:30 02/17/01 12:00 AM 03:15 02/17/01 12:00 AM. 04:30 01:00 02:00 03:00 05:00 07:00 08:30 09:30 10:30 12:30 13:30 14:00 15:30 16:00 21:00 22:00 00:00 03:00 04:30 07:00 08:00 14:00 16:00 19:30 20:30 23:30 00:00 01:30 03:15 04:30 07:30 Clean out cement from 8745' to 8841', located top wiper plug. Circ and cond mud. RU and test casing to 3500 psi for 30 min. Bled off 250 psi, 80 psi in last 5 min. Retest casing while isolating various surface equipment components, no good. Last attempt bled off 850 psi in 21 min. Circ and cond mud, develop plan forward. Clean out cement from 8841' to 8967'. CBU and cond mud. RU and test casing to 3200 psi, bled off to 1850 psi in 12 min. Monitored pressure on 9-5/8" X 7" annulus zero psi at start of test, 625 psi at end of test. Clean out cement and drill 20' of new hole to 9080'. CBU and cond mud for FIT. Perform LOT - established EMW of 11.6 ppg. Observed outer annulus pressure - 300 psi @ start 525 psi with 1070 psi surface pressure on 7" casing. Monitor well - pump out to 8613'. Pump dry job - tie back block hanging line due to high winds. POH - hampered by high winds. LD BHA. PJSM. MU 5 1/3 stands of 3-1/2" drill pipe below Baker Retrieve-a-matic packer and RIH. RIH to 9080'. CBU and cond mud @ 3 bpm. Set packer @ 8527', tail @ 9054'. Attempted to test 7" casing above Pkr to 3500 psi, bled of 260 psi in 17 min while observing slight returns up the drill pipe. Reset Pkr, @ 8520' and attempted to test casing, continued to observe slight returns out drill Circ and cond mud, PJSM with Dowell. RU cementers and test lines to 3500 psi. With tail pipe @ 9079', pumped 75 sxs of 15.8 ppg G cement and displaced to equalization, POH to 8216' (ETOC @ 8683') and circ to clear drill pipe. Closed pipe rams and performed hesitation squeeze, max press 2544 Bled off 1550 psi from casing, I bbl of mud back, monitor well. CBU, monitor well, pump dry job. POH, laid down packer and muleshoe. MU BHA # 6 and shallow test tools. RIH to 8000'. Slip and cut drilling line. Slip and cut drilling line, service Top Drive. RIH, tagged cement @ 8742', establish circ. RU and test casing to 3500 psi for 30 min. good test. Monitored 9-5/8" X 7" annulus, initial pressure 250 psi, max pressure 300 psi. Clean out stringers to 8772' and cement to 8960', CBU. Operations Summary CD1-21 02/17/01 12:00 AM 07:30 09:30 RU and test casing top 3500 psi, held solid for 12 min. bled to 3110 psi after 30 min. (outer annulus 250 psi initial, 300 psi final). RD test manifold, blow down equipment. 02/17/01 12:00 AM 02/17/01 12:00 AM 02/17/01 12:00 AM 02/17/01 12:00 AM 02/17/01 12:00 AM 02/18/01 12:00 AM 02/19/01 12:00 AM 02/19/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM. 02/22/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 09:30 12:00 13:00 14:00 16:00 00:00 00:00 23:30 00:00 03:30 04:45 05:30 07:00 13:00 15:30 22:30 00:00 06:00 08:00 09:00 12:30 14:00 14:30 00:00 05:00 06:00 08:15 11:30 12:00 13:00 14:00 16:00 00:00 00:00 23:30 00:00 03:30 04:45 05:30 07:00 13:00 15:30 22:30 00:00 06:00 08:00 09:00. 12:30 14:00 14:30 00:00 05:00 06:00 08:15 11:30 12:30 Clean out cement from 8960', drill 20' of new hole from 9080' to 9100'. CBU. RU and perform FIT to 12.5 ppg EMW, good. (9-5/8 X 7" annulus press, initial 250 psi, final 250 psi) PJSM. Change well over to 9.2 ppg FIo-Pro mud clean surface equipment. Drill from 9100' to 9374'. ART=3.0 AST=1.9 Drill from 9374' to 10734'. ART=13.7 AST= 2.4 Drill from 10734' to 11782'. ART=13 AST=3.6 Circ hole, pump high vis sweeps. Cim hole clean, change well over to 9.2 ppg KCL Brine, monitor well, initial loss rate 45 BPH. POH to 10342', loss rate 25 bph. Pump 40 bbls High vis FIo-Pro pill and displace into openhole. POH to 9000', monitor well, loss rate 13 bph. POH, laid down 240 joints of 3-1/2" drill pipe. Handle BHA, download and program LWD, change out motor and standback tools. Pull wear bushing and install test plug. Test BOPE, choke valves and surface safety valves to 250/3500 psi, Annular preventor to 250/2500 psi. Pull test plug and install wear bushing. MU BHA #7, set motor ako @ 1.4, shallow test tools. RIH picking, up 3-1/2" drill pipe to 7800. Slip and cut drilling line 278'. RIH, bit stopped @ 9090'. Reamed tightspots from 9090' to 9120', precautionary reamed to 9408'. Took check shots @ 9068', 9132', 9226', and 9323'. Change well over to 9.2 ppg FIo-Pro mud, cond mud. RIH to 9910', pump up survey. Time drill to open hole sidetrack well from 9910' to 9942'. AST=6.2 Time drill to sidetrack openhole from 9942' to 9950'. Drill from 9950' to 10021'. ART=I.1 AST=I.7 Pump high vis sweep and cim clean, Monitor well, pump out to 8500' and blow down TD. POH, no problems. Handle BHA, change out MWD and bit, shallow test tools. 02/22/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 02/23/01 12:00 AM 12:30 17:00 19:15 00:00 17:00 19:15 00:00 15:30 RIH to shoe. Wash down from shoe, Took check shots @ 9183', 9277', 9374', 9465, 9561', 9658, 9750', 9845'. Drill from 10021' to 10227'. ART=2.0 AST=1.3 Drill from 10277' to 11087'. ART=8.0 AST=3.6 Operations Summary CD1-21 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 15:30 20:00 21:00 21:45 22:30 23:15 00:00 06:00 07:00 08:30 16:30 18:00 19:00 00:00 02:30 05:00 20:00 21:00 21:45 22:30 23:15 00:00 06:00 07:00 08:30 16:30 18:00 19:00 00:00 02:30 05:00 09:00 Pump high/Iow/high vis sweeps and circ clean. Change well over to 9.2 ppg KCL Brine. Monitor well, initial losses 50 bph. POH to 10073', monitor losses, 42 bph. Pump 40 bbls high vis pill and displace into open hole. POH to shoe, monitor losses, 27 bph. pump 40 bbls high vis pill and displace to bit. POH to 8749' and begin laying down 3-1/2" drill pipe. POH, laying down 3-1/2" drill pipe. Lay down BHA. Pull wear bushing and RU to run tubing. MU completion equipment and RIH picking up 4-1/2" tubing. MU hanger and land completion with WLEG @ 8746', and top of Pkr. @ 8676'. RILDS, remove LJa and install TWC. MU LJb and test tubing hanger M/M seals to 5000 psi, LD LJb. MU wash sub and flush BOP stack, move 5" hwdp to distribute weight for rig move. ND flowline and riser, ND BOP's, break all flange bolts on preventors in preparation for annual inspection. ND BOP stack, install and test adaptor flange and tree to 5000 psi. RU lubricator and pull TWC. RU test manifold and hard lines. PJSM. Test lines to 4000 psi, change well over with 125 bbls of 9.6 ppg treated brine followed by 180 bbls of diesel. 02/25/01 12:00 AM 09:00 11:30 RU lubricator and drop setting ball and rod. Set Packer and test tubing to 3500 psi, bled down to 1870 psi in 30 min. RU and test 7" x 4-1/2" annulus to 3500 psi for 30 min., good. 02/25/01 12:00 AM 11:30 13:30 Blow down lines, RD test manifold and lines. RU lubricator and install BPV, secure wellhead, Released rig @ 13:30 hours. SENT BY' 4-24- 1 ' 2:31Phi ' PHILLIPS AK INC-,, 907 27(] 7542;# 2/ 2 .vi o^~ i ay ,'Dc i,'^p,./ u--,p.o. ,m~., ~,.,~.,,.,. ,,~ ,-.-.- , ......... ALL CONDUCTORS ARE LOCATED IN SEC ..5.T 11 N, R 5 E. UMI^T MERIDIAN Sec Line O/S Well 'Y' 'X' Lot. n I~L Gild Pod CD1-1 _ 5,975. g04.'92 .385.999.99 70' 20' ~.4.~22" 15.~;'55' .30.~.68."'222' 2,572' 1,3.0' _19.5, i · II . · ~ ~ - 1 ' CD1-12 5,975,897.B9 .385,992.91 70' 20' .t4.852" 150' 55' .tl.071 229' 2,565' 1~.0' 9.5 CD1-`1 ,5.975.890.99 ..'t85,.985.8270'~20' 34..783" 150' 55' .'31.275" .2.36' 2.558:. 13.1' 19.5'., CD1-4. 5.975.883.8.3 .185,978.79 70' 20' .34..711" !.50' 5.5' 31.47'8" 24,3' 2.55.1' 13.2' 19.5' CD1-5 5,975~876.67 385,971.58 7,0' 20"',3,4,.640" 150' 55' 3,1.685'. 2,51: 2,544' 1,3..5'_1_9.5' CD1-6 5.975,8.69.89 .385.964,.8.1 70: 20' 54,.57,,2" 150' 55'. ,31.879". 258' 2,538: 1,3.4' 1_9.5' C.01 -'7 . i ' : ~D1-8 CD1,,79 '5,975..848.¢2 ,385,94.,3.41 70' 20' ,3¢..358" 150' 55: 32.49~'' .279' 2,5i7' 1,3.'i'.19.5' COl-lO, 5.975,.84.1..,34,385,936.18 70: 20' ,34.287". 150' 55' .3..2.703" 28.6' 2.510' 1.t.0' 19,.5' CD1-11 i ii iii i ii CD1-1.2 CD1-1.3,, 5.975.820.00 .t85,~15.06,. 70'"20' 3~.,..074" 150' 55:, `1.31,311" 308' 2,_4.89' 12,7;' _!9.5' CD1-14. 5,97.5.812.97 ..!.85,908.oo 7..0- 20' ]4,004" 150' 55' ],,],514" .31.5' 2,482' , 12.6: 19.5' CD1'15 CD1-15 5,975,?,,98.86 ,~85,89,4..0.8?0'.2O: 33.86'~" 150' 55' .33:914' `1.~0',,2,468' I' 12.4.,' ~ 19.5' C01-,17 5,g75,791.81 .385,.8.86.84.70' 20' 3.1.793' 15~:..: 55' 3¢.12,3',. .1.17' 2,461' . 12.,3' 1.9.5' CD1-18. .5,975.784.91 .185,879.88. 70' 20?...13.724". 1507.55'..~,4,,,32,3" .344' 2,',4.,54-'... 12.2' 1~..5, _CDI-19 5.975.??'7,,.92 ,.'.'t85,872..81 70' 20: .13.854" 150' 55' `14,526.."_. 351' 2,44.?~ 12.1' 19.5'. CD1..20 5,975,770.66 385.865,67. 70' 20' 3.3...,.,581' 150' $5' 34.7'~2" ,3,58' 2,4,4.0: 12.0' 19.5: CD1-21 5,9. 75.763.76,.385,85B. 49 70"20' 3~.q12' i50' 55' ,~4.g`18" . ,365' ,. 2.433' 11..9' 19.5" 'CD1-2~ 5,97§,,.75§.46 385.851',.10 ?0: '.20' 33,'440" 1.50' 55' .34:,! 5,1" . 375' 2.426? 1.1.9' .! 19.5' CD1-_2.1 5.9.?.5.749.]1 .385.844.4.4..?0",'20' `1`1.~68" 150' 55' 3.5,,:,342~""_ .t80' I 2.419'. i2.0' 19.5' CDI-24 '5.975,74~.40 385,8,57.30 .70' 20: ,33.299" 15.0' §,5' `15,,5'48', 387' 2,412'' 12.2' 19.5' CD1,:2,5 5,975,735.34 `185, 830. 26 70' 20' 'q3.229" 150' ~5' .35,750" 394' 2,40,5.' 12.4' 19:5' CD1-26 5,975,728.10 .385,B2.3.14. ..'7.0' 20' ,3,3.156:: 150' 55' ~5.955" 4,01' 2.398' 12.6' ,19.5' ICD1-27 5.975:721.21. ~B5.816,08 70' 20' ,3.3.08_8' 150' 55' 36.1'5B.". 4,08' .2.39.1' 12.8' .1_9..5' ~CD1-28 5,975.714,1.5. ]85,809,10 70' 20: `13, 01,7,,"150' 55' 36.359" 41Q' ..2.384:' 1`1.0'. ..19.5' .C_D1.29 .5.975.707.1.4 385.802.20. 70' 20' ~2,947'" 150'.55' 36.5~8" 422' L2.377' 1.3.2' 19.5' CD1-`10 5,975.,.700.17 ;,385.,._794.75 70' :ZO" ,.t2.877' 15.0' 55' ,t8.772" .,4.30' 2.3?0' 13.4' 19.5' C01.~1 CD1-'~: 5.975,~85.,92 .185.7'8,0.66 70'.20;'~2..7~.5" 150'""55' ';i.,,.¢' 2. ,58' ,i3.2' CD1.-~3 . . ..... .;.... .. ' CD1-34 .' C01-,35 5~,975.664.72 ~85,759.6~ '70' ,:~0' '32.5'~24" 15.0' 55' ,,.','57.782" ' 4,66' 2~335' ?' 1,.2,.9'19.5' CD1'.36 5,,97,5.657.4,9,385,7q2.52 70' .20' 32.451" 150' 55' ~7.987" 4,7]' 2,.`328' 12.8', 19.5' ..CD1-~7 5,975,,650..51 .I85,7,4,.5.4.0 70' 20'.3.;~..!8!.' 150'55'.38.191". 480' ..2,321' 12.7' 1.9.5' CDI-~B 5,975,64.&79_. 385,?,38.4-4 70' 201 32,.315" 1.50' 55' 38.391" 487' 2.3,14.' .. 12.6' 19.5' CD1.-`39 5.975.6,36..34.`385,7`11.37 ?0.,' 20' `12.240" 15,0' 55' `18.595'" 495' 2,,30?' . i2.5'lg.5' C01-40. 5.975.629.19 .~85,.724.,32 70',.20' .]2.168" 15.0.".55' `18.797" 502' 2,300' 12,.4_'.. 19:5' C01-,,41 5,975.622.,37 385.717..40 '70' 20: 132.!01" 150' 55,,.i.".38.997"509', ,.2,293' 12.3' !..9.,5' . CD1.-'42 5,97, 57615.01 `185,?'I...0.21' 70' 20' 3,2.027" '~50' ,55' 39,.204" 5'16'.2,2~_6? 12.2' 19.5' CD1-4`1 5.975,607.63 385.?02.97 70' 20',,.31.954," 150' 55' .39,41.2.,,",, 52.,]' ~,27.9" ,.i2.1'._lg. 5' .CD1-4,4. .. .C. D1-45 5,975,5~i~.74 ~B5,689.04. 70' 20' ,31.815" 1.50: 5,5' ;39..81;5' "~.,38' 2,265' 12'.0,'~'_ '19.5' * CD1- 22 CONDUCTOR WAS AS-BUILT 2/lt/98.. ARCO, AIsBka, Inc..' Subsidiary of Atlantic Richfield Comp=ny .' NO.I ........ . LK863D1 ' . 3/,5/99 .. I I IIIII -. : III __ I ....... ,, .LOUNSBURY & ASSOCIATES; INC. ALPINE. PRO.CT ' CD1 WELL CONDUCTORS ,. AS'BUILT LOCATIONS cE-CD10-66301' ' I ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-21 API number ............... : 50-103-20362-00 Engineer ................. : Mercier COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 56.30 ft DF above permanent ....... : 56.30 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.94 degrees 24-Feb-2001 22:28:14 Page 1 of 5 Spud date ................ : 04-Feb-01 Last survey date ......... : 23-Feb-01 Total accepted surveys...: 101 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11087.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 02-Feb-2001 Magnetic field strength..: 1147.22 HCNT Magnetic dec (+E/W-) ..... : 25.52 degrees Magnetic dip ............. : 80.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.22 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.52 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [ (C) 2001 Anadrill IDEAL ID6_IC_08] ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 22:28:14 Page 2 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 176.00 0.30 339.00 4 268.00 1.00 322.00 '5 355.00 1.85 314.00 6 386.00 2.24 316.72 7 476.00 3.64 319.35 8 567.00 5.69 321.78 9 657.00 7.23 316.12 10 746.00 8.22 317.93 11 835.00 9.68 316.99 12 926.00 11.59 314.02 13 1015.00 16.26 308.60 14 1109.00 21.35 310.04 15 1204.00 25.22 311.91 16 1300.00 29.07 311.46 17 1395.00 32.44 310.88 18 1491.00 35.74 310.55 19 1587.00 38.97 310.32 20 1681.00 38.88 308.95 0.00 114.00 62.00 92.00 87.00 31.00 90.00 91.00 90.00 89.00 89.00 91.00 89.00 94.00 95.00 96.00 95.00 96.00 96.00 94.00 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool c/ual (ft) -(ft) (ft) (ft) (ft) (deg) i00f) type type 0.00 114.00 176.00 267.99 354.97 385.95 475.83 566.52 655.95 744.14 832.05 921.48 1007.85 1096.80 1184.05 1269.46 1351.09 1430.58 1506.88 1580.01 21 1778.00 38.64 307.33 97.00 1655.65 22 1873.00 40.58 307.98 95.00 1728.83 23 1967.00 41.00 309.10 94.00 1800.00 24 2063.00 40.65 309.00 96.00 1872.65 25 2156.00 40.19 309.28 93.00 1943.45 26 2250.00 39.86 309.41 27 2345.00 39.45 309.31 28 2440.00 38.99 309.26 29 2536.00 38.55 309.30 30 2632.00 38.75 309.22 94.00 95.00 95.00 96.00 96.00 2015.43 2088.57 2162.17 2237.02 2311.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.16 0.15 -0.06 0.16 1.19 1.01 -0.64 1.19 3.27 2.58 -2.12 3.34 4.34 3.37 -2.89 4.44 8.82 6.82 -5.96 9.06 16.08 12.56 -10.63 16.45 25.92 20.14 -17.32 26.57 37.48 28.90 -25.46 38.52 50.89 39.10 -34.83 52.36 66.98 51.05 -46.62 69.13 86.94 65.04 -62.80 90.41 114.91 84.27 -86.20 120.55 149.99 108.93 -114.51 158.05 191.07 138.04 -147.22 201.82 236.48 170.01 -183.80 250.37 286.63 205.09 -224.58 304.14 340.81 242.86 -268.91 362.35 395.45 280.54 -314.39 421.36 451.01 318.04 -362.15 481.98 506.22 355.05 -410.09 542.43 562.58 393.31 -458.12 603.80 620.39 432.85 -506.86 666.53 675.98 470.91 -553.63 726.82 731.80 509.24 -600.38 787.26 787.77 547.68 -647.26 847.88 843.21 585.72 -693.75 907.94 898.68 623.78 -740.28 968.05 954.00 661.72 -786.71 1028.00 0.00 0.00 TIP 0.00 0.00 MWD 339.00 0.48 MWD 327.66 0.78 MWD 320.67 1.00 MWD 319.38 1.30 MWD 318.85 1.56 MWD 319.74 2.26 MWD 319.31 1.85 MWD 318.62 1.15 MWD 318.30 1.65 MWD 317.59 2.18 MWD 316.00 5.44 MWD 314.35 5.44 MWD 313.57 4.15 MWD 313.16 4.02 MWD 312.77 3.56 MWD 312.40 3.44 MWD 312.09 3.37 MWD 311.74 0.92 MWD 311.29 1.07 MWD 310.88 2.09 MWD 310.65 0.90 MWD 310.50 0.37 MWD 310.38 0.53 MWD 310.30 0.36 MWD 310.24 0.44 MWD 310.17 0.49 MWD 310.12 0.46 MWD 310.07 0.21 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 22:28:14 Page 3 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2665.00 38.98 310.18 33.00 32 2838.00 38.31 309.01 173.00 33 3028.00 39.31 308.93 190.00 34 3216.00 40.31 307.61 188.00 35 3408.00 40.13 306.98 192.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 2337.69 2472.81 2620.86 2765.27 2911.88 36 3598.00 39.82 308.33 190.00 3057.48 37 3787.00 38.80 307.38 189.00 3203.72 38 3978.00 39.35 307.64 191.00 3352.00 39 4166.00 39.08 308.65 188.00 3497.66 40 4357.00 39.19 308.54 191.00 3645.81 41 4549.00 39.44 309.23 192.00 3794.35 42 4739.00 39.59 307.97 190.00 3940.93 43 4930.00 39.70 309.12 191.00 4088.01 44 5122.00 38.92 308.09 192.00 4236.56 45 5309.00 39.64 307.96 187.00 4381.31 973.17 674.95 -802.64 1073.09 743.81 -885.88 1182.73 818.70 -978.46 1292.96 893.23 -1072.96 1405.64 968.35 -1171.59 1516.90 1626.21 1735.82 1844.58 1955.26 2067.19 2178.18 2290.02 2401.71 2509.94 46 5501.00 41.18 307.66 192.00 4527.50 2623.52 47 5692.00 40.44 307.92 191.00 4672.06 2737.42 48 5881.00 39.68 307.26 189.00 4816..72 2848.24 49 6072.00 40.61 308.09 191.00 4962.72 2960.50 50 6263.00 40.64 306.68 191.00 5107.69 3073.61 51 6451.00 41.08 309.39 188.00 5249.89 3186.03 52 6642.00 40.10 309.21 191.00 5394.93 3300.73 53 6832.00 40.03 307.78 190.00 5540.34 3412.92 54 7021.00 39.75 308.30 189.00 5685.36 3523.74 55 7213.00 39.13 307.77 192.00 5833.64 3635.25 5980.19 6124.11 6269.25 6414.83 6560.14 56 7404.00 40.65 309.24 191.00 57 7594.00 40.86 309.23 190.00 58 7785.00 40.23 308.33 191.00 59 7975.00 39.74 308.32 190.00 60 . 8164.00 39.77 308.25 189.00 3747.63 3862.06 3976.21 4088.08 4198.79 1042.92 -1268.23 1116.40 -1362.76 1189.71 -1458.26 1263.12 -1551.73 1338.32 -1645.95 1414.69 -1740.64 1490.10 -1835.12 1566.04 -1930.43 1641.94 -2025.47 1714.87 -2118.73 1791.16 -2217.07 1867.65 -2315.71 1941.85 -2412.09 2017.12 -2509.55 2092.62 -2608.36 2168.40 -2705.21 2247.11 -2801.37 2323.23 -2897.08 2397.92 -2992.54 2473.07 -3088.61 2549.35 -3184.44 2627.80 -3280.51 2705.57 -3377.30 2781.28 -3473.08 2856.16 -3567.95 1048.70 1156.73 1275.80 1396.11 1519.98 Srvy tool type 1641.97 1761.66 1882.00 2000.84 2121.38 310.06 1.95 MWD 310.02 0.57 MWD 309.92 0.53 MWD 309.78 0.70 MWD 309.57 0.23 MWD 2243.03 2363.91 2485.76 2607.39 2725.76 309.43 0.48 MWD 309.33 0.63 MWD 309.21 0.30 MWD 309.15 0.37 MWD 309.11 0.07 MWD 2850.20 2975.00 3096.61 3219.72 3344.04 309.10 0.26 MWD 309.08 0.43 MWD 309.05 0.39 MWD 309.03 0.53 MWD 308.99 0.39 MWD 3467.00 3591.27 3713.55 3834.75 3956.71 308.93 0.81 MWD 308.89 0.40 MWD 308.84 0.46 MWD 308.79 0.56 MWD 308.74 0.48 MWD 4079.19 4203.23 4327.38 4449.47 4570.33 308.71 0.97 MWD 308.73 0.52 MWD 308.73 0.49 MWD 308.71 0.23 MWD 308.68 0.37 MWD 308.68 0.94 MWD 308.70 0.11 MWD 308.70 0.45 MWD 308.69 0.26 MWD 308.68 0.03 MWD Tool c/ual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 22:28:14 Page 4 of 5 Seq Measured Incl Azimuth Course S depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) Srvy tool type Tool qual type 61 8356.00 39.02 307.65 62 8460.00 38.61 307.93 63 8492.00 41.95 309.06 64 8525.00 45.28 311.42 65 8554.00 47.39 313.68 192.00 104.00 32.00 33.00 29.00 6708.51 6789.54 6813.95 6837.84 6857.87 4310.12 4369.60 4388.58 4409.73 4429.52 2931.10 -3664.03 2971.05 -3715.55 2983.93 -3731.74 2998.64 -3749.10 3012.83 -3764.54 4692.18 4757.36 4778.04 4800.79 4821.72 308.66 0.44 MWD 308.65 0.43 MWD 308.65 10.68 MWD 308.65 11.23 MWD 308.67 9.20 MWD 6-axis 6-axis 6-axis 66 8588.00 50.20 315.56 67 8620.00 52.98 317.45 68 8652.00 55.19 319.58 69 8683.00 57.34 321.01 70 8713.00 59.89 321.98 34.00 32.00 32.00 31.00 30.00 6880.26 6900.14 6918.92 6936.13 6951.75 4453.94 4478.10 4503.31 4528.56 4553.74 3030.80 -3782.74 3048.99 -3799.99 3068.41 -3817.15 3088.24 -3833.62 3108.29 -3849.56 4847.15 4871.99 4897.53 4922.79 4947.78 308.70 9.25 MWD 308.74 9.84 MWD 308.79 8.76 MWD 308.85 7.93 MWD 308.92 8.94 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 71 8744.00 62.65 323.66 72 8775.00 65.54 325.19 73 8806.00 68.18 326.92 74 8839.00 70.82 328.20 75 8870.00 73.18 329.37 31.00 31.00 31.00 33.00 31.00 6966.65 6980.20 6992.38 7003.93 7013.51 4580.58- 3129.94 -3865.98 4608.22 3152.62 -3882..19 4636.57 3176.27 -3898.11 4667.39 3202.36 -3914.68 4696.82 3227.57 -3929.96 4974.17 5001.05 5028.31 5057.65 5085.45 308.99 10.09 309.08 10.33 309.17 9.94 309.28 8.79 309.40 8.42 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 76 8902.00 75.85 330.44 77 8934.00 78.37 330.81 78 8966.00 80.77 331.35 79 8996.00 83.39 331.93 80 9132.02 88.63 333.80 81 9226.03 90.00 333.73 82 9323.02 90.65 331.02 83 9414.04 91.20 329.46 84 9510.02 91.51 328.87 85 9607.01 91.72 330.37 32.00 32.00 32.00 30.00 136.02 94.01 96.99 91.02 95.98 96.99 7022.06 7029.19 7034.99 7039.12 7048.58 7049.71 7049.16 7047.69 7045.42 7042.68 4727.64 4758.82 4790.29 4820.00 4955.62 5049.57 5146.55 5237.51 5333.35 5430.22 3254.25 -3945.42 3281.43 -3960.72 3308.97 -3975.94 3335.12 -3990.05 3455.83 -4051.91 3540.15 -4093.46 3626.07 -4138.43 3705.07 -4183.60 3787.46 -4232.78 3871.10 -4281.81 5114.34 5143.45 5172.75 5200.34 5325.48 5411.94 5502.27 5588.39 5679.90 5772.29 309.52 8.94 MWD 309.64 7.96 MWD 309.77 7.68 MWD 309.89 8.94 MWD 310.46 4.09 IMP 310.85 1.46 IMP 311.22 2.87 IMP 311.53 1.82 IMP 311.82 0.69 IMP 312.12 1.56 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 86 9699.20 91.65 330.57 87 9794.35 90.86 329.59 88 9967.03 87.15 331.12 89 10021.00 88.08 330.54 90 10113.00 92.09 333.23 92.19 95.15 172.68 53.97 92.00 7039.97 7037.89 7040.89 7043.13 7043.00 5522.34 5617.42 5789.97 5843.88 5935.85 3951.28 -4327.23 4033.73 -4374.68 4183.75 -4460.06 4230.83 -4486.34 4311.95 -4529.68 5859.82 5950.52 6115.22 6166.62 6253.88 312.40 0.23 IMP 312.68 1.32 IMP 313.17 2.32 IMP 313.32 2.03 IMP 313.59 5.25 IMP 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 22:28:14 Page 5 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 10206.00 93.40 334.47 92 10298.00 92.64 334.43 93 10390.00 93.19 333.93 94 10483.00 91.82 332.17 95 10574.00 92.30 331.98 96 10665.00 91.23 332.17 97 10761.00 91.75 331.99 98 10853.00 92.50 334.06 99 10948.00 91.88 335.50 100 11034.00 92.85 332.73 Projected 101 11087.00 92.85 332.73 93.00 92.00 92.00 93.00 91.00 91.00 96.00 92.00 95.00 86.00 53.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 7038.54 7033.69 7029.02 7024.95 7021.68 7018.88 7016.38 7012.97 7009.34 7005.79 7003.15 6028.69 6120.47 6212.28 6305.17 6396.11 6487.07 6583.03 6674.95 6769.76 6855.62 6908.55 4395.34 -4570.62 4478.22 -4610.25 4560.93 -4650.26 4643.75 -4692.37 4724.10 -4734.96 4804.46 -4777.55 4889.26 -4822.49 4971.19 -4864.19 5057.07 -4904.64 5134.37 -4942.15 5181.42 -4966.40 Srvy tool type 6341.10 313.88 1.94 IMP 6427.20 314.17 0.83 IMP 6513.60 314.44 0.81 IMP 6601.72 314.70 2.40 IMP 6688.57 314.93 0.57 IMP 6775.54 315.16 1.19 IMP 6867.41 315.39 0.57 IMP 6955.08 315.62 2.39 IMP 7044.81 315.88 1.65 IMP 7126.47 316.09 3.41 IMP 0.00 7177.20 316.21 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-21~'/' API number ............... : 50-103-20362-F~8-- Engineer ................. : Mercier COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... :-Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 56.3 ft DF above permanent ....... : 56.30 ft Vertical section origin Latitude (+N/S-)...2 ..... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ..... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.94 degrees 28-Feb-2001 16:09:10 Page 1 of 5 Spud date ................ : 04-Feb-01 Last survey date ......... : 28-Feb-01 Total accepted surveys...: 109 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11782.00 ft Geomagnetic data ....................... Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 02-Feb-2001 Magnetic field strength..: 1147.22 HCNT Magnetic dec (+E/W-) ..... : 25.52 degrees Magnetic dip ............. : 80.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.22 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.52 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 28-Feb-2001 16:09:10 Page 2 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 176.00 0.30 339.00 4 268.00 1.00 322.00 5 355.00 1.85 314.00 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 6 386.00 2.24 316.72 7 476.00 3.64 319.35 8 567.00 5.69 321.78 9 657.00 7.23 316.12 10 746.00 8.22 317.93 0.00 0.00 0.00 0.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 62.00 176.00 0.16 0.15 -0.06 0.16 92.00 267.99 1.19 1.01 -0.64 1.19 87.00 354.97 3.27 2.58 -2.12 3.34 11 835.00 9.68 316.99 12 926.00 11.59 314.02 13 1015.00 16.26 308.60 14 1109.00 21.35 310.04 15 1204.00 25.22 311.91 31.00 385.95 4.34 3.37 -2.89 4.44 90.00 475.83 8.82 6.82 -5.96 9.06 91.00 566.52 16.08 12.56 -10.63 16.45 90.00 655.95 25.92 20.14 -17.32 26.57 89.00 744.14 37.48 28.90 -25.46 38.52 .00 .00 .00 .00 .00 16 1300.00 29.07 311.46 17 1395.00 32.44 310.88 18 1491.00 35.74 310.55 19 1587.00 38.97 310.32 20 1681.00 38.88 308.95 89 91 89 94 95 0.00 0.00 339.00 327.66 320.67 21 1778.00 38.64 307.33 22 1873.00 40.58 307.98 23 1967.00 41.00 309.10 24 2063.00 40.65 309.00 25 2156.00 40.19 309.28 96 95 96 96 94 319.38 318.85 319.74 319.31 318.62 26 2250.00 39.86 309.41 27 2345.00 39.45 309.31 28 2440.00 38.99 309.26 29 2536.00 38.55 309.30 30 2632.00 38.75 309.22 97 95 94 96 93 832.05 50.89 39.10 -34.83 52.36 318.30 921.48 66.98 51.05 -46.62 69.13 317.59 1007.85 86.94 65.04 -62.80 90.41 316.00 1096.80 114.91 84.27 -86.20 120.55 314.35 1184.05 149.99 108.93 -114.51 158.05 313.57 .00 1269.46 191.07 138.04 -147.22 201.82 313.16 .00 1351.09 236.48 170.01 -183.80 250.37 312.77 .00 1430.58 286.63 205.09 -224.58 304.14 312.40 .00 1506.88 340.81 242.86 -268.91 362.35 312.09 .00 1580.01 395.45 280.54 -314.39 421.36 311.74 481.98 542.43 603.80 666.53 726.82 .00 .00 .00 .00 .00 1655.65 451.01 318.04 -362.15 1728.83 506.22 355.05 -410.09 1800.00 562.58 393.31 -458.12 1872.65 620.39 432.85 -506.86 1943.45 675.98 470.91 -553.63 311.29 310.88 310.65 310.50 310.38 94.00 2015.43 731.80 509.24 -600.38 787.26 310.30 95.00 2088.57 787.77 547.68 -647.26 847.88 310.24 95.00 2162.17 843.21 585.72 -693.75 907.94 310.17 96.00 2237.02 898.68 623.78 -740.28 968.05 310.12 96.00 2311.99 954.00 661.72 -786.71 1028.00 310.07 DLS (deg/ 100f) 0.00 0.00 0.48 0.78 1.00 1.30 1.56 2.26 1.85 1.15 1.65 2.18 5.44 5.44 4.15 4.02 3.56 3.44 3.37 0.92 1.07 2.09 0.90 0.37 0.53 0.36 0.44 0.49 0.46 0.21 Srvy tool type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_lC_08] ANADRILL SCHLUMBERGER Survey Report 28-Feb-2001 16:09:10 Page 3 of 5 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 31 2665.00 38.98 310.18 33.00 2337.69 973.17 32 2838.00 38.31 309.01 173.00 2472.81 1073.09 33 3028.00 39.31 308.93 190.00 2620.86 1182.73 34 3216.00 40.31 307.61 188.00 2765.27 1292.96 35 3408.00 40.13 306.98 192.00 2911.88 1405.64 36 3598.00 39.82 308.33 190.00 3057.48 1516.90 37 3787.00 38.80 307.38 189.00 3203.72 1626.21 38 3978.00 39.35 307.64 191.00 3352.00 1735.82 39 4166.00 39.08 308.65 188.00 3497.66 1844.58 40 4357.00 39.19 308.54 191.00 3645.81 1955.26 41 4549.00 39.44 309.23 192.00 42 4739.00 39.59 307.97 190.00 43 4930.00 39.70 309.12 191.00 44 5122.00 38.92 308.09 192.00 45 5309.00 39.64 307.96 187.00 46 5501.00 41.18 307.66 192.00 47 5692.00 40.44 307.92 191.00 48 5881.00 39.68 307.26 189.00 49 6072.00 40.61 308.09 191.00 50 6263.00 40.64 306.68 191.00 3794.35 3940.93 4088.01 4236.56 4381.31 4527.50 4672.06 4816.72 4962.72 5107.69 51 6451.00 41.08 309.39 188.00 5249.89 52 6642.00 40.10 309.21 191.00 5394.93 53 6832.00 40.03 307.78 190.00 5540.34 54 7021.00 39.75 308.30 189.00 5685.36 55 7213.00 39.13 307.77 192.00 5833.64 56 7404.00 40.65 309.24 191.00 5980.19 57 7594.00 40.86 309.23 190.00 6124.11 58 7785.00 40.23 308.33 191.00 6269.25 59 7975.00 39.74 308.32 190.00 6414.83 60 8164.00 39.77 308.25 189.00 6560.14 2067.19 2178.18 2290.02 2401.71 2509.94 2623.52 2737.42 2848.24 2960.50 3073.61 3186.03 3300.73 3412.92 3523.74 3635.25 3747.63 3862.06 3976.21 4088.08 4198.79 674.95 -802.64 1048.70 743.81 -885.88 1156.73 818.70 -978.46 1275.80 893.23 -1072.96 1396.11 968.35 -1171.59 1519.98 1042.92 -1268.23 1116.40 -1362.76 1189.71 -1458.26 1263.12 -1551.73 1338.32 -1645.95 1414.69 -1740.64 1490.10 -1835.12 1566.04 -1930.43 1641.94 -2025.47 1714.87 -2118.73 1791.16 -2217.07 1867.65 -2315.71 1941.85 -2412.09 2017.12 -2509.55 2092.62 -2608.36 2168.40 -2705.21 2247.11 -2801.37 2323.23 -2897.08 2397.92 -2992.54 2473.07 -3088.61 2549.35 -3184.44 2627.80 -3280.51 2705.57 -3377.30 2781.28 -3473.08 2856.16 -3567.95 Srvy tool type 1641.97 1761.66 1882.00 2000.84 2121.38 310.06 1.95 MWD 310.02 0.57 MWD 309.92 0.53 MWD 309.78 0.70 MWD 309.57 0.23 MWD 2243.03 2363.91 2485.76 2607.39 2725.76 309.43 0.48 MWD 309.33 0.63 MWD 309.21 0.30 MWD 309.15 0.37 MW/) 309.11 0.07 MWD 2850.20 2975.00 3096.61 3219.72 3344.04 309.10 0.26 MWD 309.08 0.43 MWD 309.05 0.39 MWD 309.03 0.53 MWD 308.99 0.39 MWD 3467.00 3591.27 3713.55 3834.75 3956.71 308.93 0.81 MWD 308.89 0.40 MWD 308.84 0.46 MWD 308.79 0.56 MWD 308.74 0.48 MWD 308.71 0.97 MWD 308.73 0.52 MWD 308.73 0.49 MWD 308.71 0.23 MWD 308.68 0.37 MWD 4079.19 308.68 0.94 4203.23 308.70 0.11 4327.38 308.70 0.45 4449.47 308.69 0.26 4570.33 308.68 0.03 MWD MWD I~F~D MWD M~D Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 28-Feb-2001 16:09:10 Page 4 of 5 Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 61 8356.00 39.02 307.65 192.00 62 8460.00 38.61 307.93 104.00 63 8492.00 41.95 309.06 32.00 64 8525.00 45.28 311.42 33.00 65 8554.00 47.39 313.68 29.00 66 8588.00 50.20 315.56 34.00 67 8620.00 52.98 317.45 32.00 68 8652.00 55.19 319.58 32.00 69 8683.00 57.34 321.01 31.00 70 8713.00 59.89 321.98 30.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 6708.51 4310.12 2931.10 -3664.03 4692.18 6789.54 4369.60 2971.05 -3715.55 4757.36 6813.95 4388.58 2983.93 -3731.74 4778.04 6837.84 4409.73 2998.64 -3749.10 4800.79 6857.87 4429.52 3012.83 -3764.54 4821.72 6880.26 6900.14 6918.92 6936.13 6951.75 4453.94 3030.80 -3782.74 4847.15 4478.10 3048.99 -3799.99 4871.99 4503.31 3068.41 -3817.15 4897.53 4528.56 3088.24 -3833.62 4922.79 4553.74 3108.29 -3849.56 4947.78 71 8744.00 62.65 323.66 31.00 6966.65 4580.58 3129.94 -3865.98 4974.17 72 8775.00 65.54 325.19 31.00 6980.20 4608.22 3152.62 -3882.19 5001.05 73 8806.00 68.18 326.92 31.00 6992.38 4636.57 3176.27 -3898.11 5028.31 74 8839.00 70.82 328.20 33.00 7003.93 4667.39 3202.36 -3914.68 5057.65 75 8870.00 73.18 329.37 31.00 7013.51 4696.82 3227.57 -3929.96 5085.45 76 8902.00 75.85 330.44 32.00 7022.06 4727.64 3254.25 -3945.42 5114.34 77 8934.00 78.37 330.81 32.00 7029.19 4758.82 3281.43 -3960.72 5143.45 78 8966.00 80.77 331.35 32.00 7034.99 4790.29 3308.97 -3975.94 5172.75 79 8996.00 83.39 331.93 30.00 7039.12 4820.00 3335.12 -3990.05 5200.34 80 9132.00 88.56 338.26 136.00 7048.67 4955.34 3458.07 -4047.11 5323.29 81 9226.00 89.86 336.30 82 9323.00 90.48 334.22 83 9414.00 91.20 333.04 84 9510.00 91.47 332.15 85 9607.00 91.68 331.16 86 9699.00 91.51 330.81 87 9794.00 90.89 331.22 88 9890.00 91.00 331.75 89 9985.00 90.24 332.49 90 10081.00 90.45 332.79 94.00 97.00 91.00 96.00 97.00 7049.97 5048.92 3544.76 -4083.41 5407.36 7049.68 5145.75 3632.86 -4124.00 5495.91 7048.35 5236.70 3714.38 -4164.41 5580.23 7046.11 5332.66 3799.58 -4208.59 5670.01 7043.44 5429.62 3884.92 -4254.62 5761.46 7040.88 5521.58 3965.34 -4299.23 5848.70 7038.89 5616.54 4048.42 -4345.25 5938.93 7037.31 5712.52 4132.76 -4391.08 6030.03 7036.28 5807.52 4216.73 -4435.50 6120.00 7035.70 5903.51 4301.99 -4479.62 6210.80 92.00 95.00 96.00 95.00 96.00 Srvy tool type 308.66 0.44 MWD 308.65 0.43 MWD 308.65 10.68 MWD 308.65 11.23 MWD 308.67 9.20 MWD 308.70 9.25 MWD 308.74 9.84 MWD 308.79 8.76 MWD 308.85 7.93 MWD 308.92 8.94 MWD 308.99 10.09 309.08 10.33 309.17 9.94 309.28 8.79 309.40 8.42 309.52 8.94 MWD 309.64 7.96 MWD 309.77 7.68 MWD 309.89 8.94 MWD 310.51 6.00 IMP 310.96 2.50 IMP 311.38 2.24 IMP 311.73 1.52 IMP 312.08 0.97 IMP 312.40 1.04 IMP 312.69 0.42 IMP 312.97 0.78 IMP 313.26 0.56 IMP 313.55 1.12 IMP 313.84 0.38 IMP Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 28-Feb-2001 16:09:10 Page 5 of 5 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) Srvy tool type Tool qual type 91 10176.00 90.55 332.21 92 10272.00 90.58 332.85 93 10364.00 90.62 332.01 94 10457.00 90.69 333.34 95 10551.00 90.89 333.19 96 10639.00 91.06 333.65 97 10731.00 88.97 332.78 98 10826.00 91.10 331.37 99 10918.00 91.48 331.19 100 11008.00 91.00 332.19 95.00 96.00 92.00 93.00 94.00 88.00 92.00 95.00 92.00 90.00 7034.88 7033.93 7032.97 7031.90 7030.61 7029.11 7029.08 7029.03 7026.96 7025.01 5998.50 6094.49 6186.48 6279.47 6373.43 6461.39 6553.36 6648.35 6740.32 6830.30 4386.25 -4523.48 4471.42 -4567.76 4552.97 -4610.34 4635.59 -4653.03 4719.53 -4695.31 4798.22 -4734.68 4880.34 -4776.14 4964.27 -4820.62 5044.93 -4864.82 5124.15 -4907.49 6300.88 314.12 0.62 6392.03 314.39 0.67 6479.57 314.64 0.91 6568.05 314.89 1.43 6657.32 315.15 0.27 6740.93 6828.56 6919.71 7008.41 7095.09 IMP IMP IMP IMP IMP 315.38 0.56 IMP 315.62 2.46 IMP 315.84 2.69 IMP 316.04 0.46 IMP 316.24 1.23 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 101 11102.00 91.27 331.65 102 11195.00 91.61 330.64 103 11288.00 93.33 331.73 104 11379.00 90.93 331.78 105 11470.00 91.54 330.82 94.00 93.00 93.00 91.00 91.00 7023.15 7020.81 7016.80 7013.42 7011.46 6924.28 7017.24 7110.14 7201.07 7292.04 5207.07 -4951.73 5288.50 -4996.59 5369.90 -5041.37 5450.00 -5084.41 5529.80 -5128.10 7185.62 7275.58 7365.55 7453.44 7541.62 316.44 0.64 IMP 316.63 1.15 IMP 316.81 2.19 IMP 316.99 2.64 IMP 317.16 1.25 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 106 11563.00 94.15 328.23 107 11656.00 94.77 329.30 108 11729.00 95.01 331.38 109 11782.00 95.01 331.38 93.00 93.00 73.00 53.00 7006.84 6999.61 6993.39 6988.76 7384.83 7477.40 7550.10 7602.90 5609.84 -5175.19 5689.12 -5223.27 5752.32 -5259.26 5798.67 -5284.55 7632.36 7723.25 7794.17 7845.45 317.31 3.95 IMP 317.44 1.33 IMP 317.56 2.86 IMP 317.66 0.00 MWD 6-axis 6-axis 6-axis -- [ (c) 2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-21PH API number ............... : 50-103-20362-70 Engineer ................. : M. Brown COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : MEAN SEA LEVEL Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.30 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point- Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 308.74 degrees 10-Feb-2001 02:58:44 Page 1 of 4 Spud date ................ : 04-Feb-01 Last survey date ......... : 10-Feb-01 Total accepted surveys...: 66 MD of first survey ....... : 0.00 ft MD of last survey ........ : 8950.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 02-Feb-2001 Magnetic field strength..: 1147.22 HCNT Magnetic dec (+E/W-) ..... : 25.52 degrees Magnetic dip ............. : 80.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.22 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.52 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 10-Feb-2001 02:58:44 Page 2 of 4 Seq Measured Incl Azimuth S depth angle angle - (ft) (deg) (deg) i 0.00 0.00 0.00 2 114.00 0.00 0.00 3 176.00 0.30 339.00 4 268.00 1.00 322.00 5 355.00 1.85 314.00 6 386.00 2.24 316.72 7 476.00 3.64 319.35 8 567.00 5.69' 321.78 9 657.00 7.23 316.12 10 746.00 8.22 317.93 11 835.00 9.68 316.99 12 926.00 11.59 314.02 13 1015.00 16.26 308.60 14 1109.00 21.35 310.04 15 1204.00 25.22 311.91 16 1300.00 29.07 311.46 17 1395.00 32.44 310.88 18 1491.00 35.74 310.55 19 1587.00 38.97 310.32 20 1681.00 38.88 308.95 21 1778.00 38.64 307.3'3 22 1873.00 40.58 307.98 23 1967.00 41.00 309.10 24 2063.00 40.65 309.00 25 2156.00 40.19 309.28 26 2250.00 39.86 309.41 27 2345.00 39.45 309.31 28 2440.00 38.99 309.26 29 2536.00 38.55 309.30 30 2632.00 38.75 309.22 Course length (ft) 0.00 114.00 62.00 92.00 87.00 31.00 90.00 91.00 90.00 89.00 89.00 91.00 89.00 94.00 95.00 96.00 95.00 96.00 96.00 94.00 97.00 95.00 94.00 96.00 93.00 94.00 95.00 95.00 96.00 96.00 TVD depth (ft) 0.00 114.00 176.00 267.99 354.97 385.95 475.83 566.52- 655.95 744.14 832.05 921.48 1007.85 1096.80 1184.05 1269.46 1351.09 1430.58 1506.88 1580.01 1655.65 1728.83 1800.00 1872.65 1943.45 2015.43 2088.57 2162.17 2237.02 2311.99 Vertical section (ft) 0.00 0.00 0.14 1.13 3.27 4.37 8.92 16.15 26.11 37.95 51.64 68.31 89.69 119.97 157.48 201.22 249.75 303.52 361.73 420.78 481.50 542.05 603.46 666.22 726.52 786.97 847.59 907.66 967.77 1027.72 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool c/ual (ft) (ft) (ft) (deg) 100f) type type .00 .00 .15 .01 .58 0.00 0.00 -0.06 -0.64 -2.12 3 6 12 20 28 .37 .82 .56 .14 .90 -2.89 -5.96 -10.63 -17.32 -25.46 39 51 65 84 108 .10 .05 .04 .27 .93 -34.83 -46.62 -62.80 -86.20 -114.51 138 170 205 242 280 .04 .01 .09 .86 .54 -147.22 -183.80 -224.58 -268.91 -314.39 318 355 393 432 470 .04 .05 .31 .85 .91 -362.15 -410.09 -458.12 -506.86 -553.63 509.24 547.68 585.72 623.78 661.72 -600.38 -647.26 -693.75 -740.28 -786.71 0.00 0.00 0.16 1.19 3.34 0.00 0.00 TIP 0.00 0.00 MWD 339.00 0.48 MWD 327.66 0.78 MWD 320.67 1.00 MWD 4.44 9.06 16.45 26.57 38.52 319.38 1.30 MWD 318.85 1.56 MWD 319.74 2.26 MWD 319.31 1.85 MWD 318.62 1.15 MWD 52.36 69.13 90.41 120.55 158.05 318.30 1.65 MWD 317.59 2.18 MWD 316.00 5.44 MWD 314.35 5.44 MWD 313.57 4.15 MWD 201.82 250.37 304.14 362.35 421.36 313.16 4.02 MWD 312.77 3.56 MWD 312.40 3.44 MWD 312.09 3.37 MWD 311.74 0.92 MWD 481.98 542.43 603.80 666.53 726.82 311.29 1.07 MWD 310.88 2.09 MWD 310.65 0.90 MWD 310.50 0.37 MWD 310.38 0.53 MWD 787.26 847.88 907.94 968.05 1028.00 310.30 0.36 MWD 310.24 0.44 MWD 310.17 0.49 MWD 310.12 0.46 MWD 310.07 0.21 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 10-Feb-2001 02: 58: 44 Page 3 of 4 Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 31 2665.00 38.98 310.18 33.00 32 2838.00 38.31 309.01 173.00 33 3028.00 39.31 308.93 190.00 34 3216.00 40.31 307.61 188.00 35 3408.00 40.13 306.98 192.00 TVD depth (ft) 2337.69 2472.81 2620.86 2765.27 2911.88 Vertical section (ft) 1048.43 1156.45 1275.52 1395.88 1519.82 36 3598.00 39.82 308.33 190.00 3057.48 1641.86 37 3787.00 38.80 307.38 189.00 3203.72 1761.57 38 3978.00 39.35 307.64 191.00 3352.00 1881.94 39 4166.00 39.08 308.65 188.00 3497.66 2000.79 40 4357.00 39.19 308.54 191.00 3645.81 2121.34 41 4549.00 39.44 309.23 192.00 3794.35 2242.98 42 4739.00 39.59 307.97 190.00 3940.93 2363.87 43 4930.00 39.70 309.12 191.00 4088.01 2485.73 44 5122.00 38.92 308.09 192.00 4236.56 2607.36 45 5309.00 39.64 307.96 187.00 4381.31 2725.74 46 5501.00 41.18 307.66 192.00 47 5692.00 40.44 307.92 191.00 48 5881.00 39.68 307.26 189.00 49 6072.00 40.61 308.09 191.00 50 6263.00 40.64 306.68 191.00 4527.50 4672.06 4816.72 4962.72 5107.69 5249.89 5394.93 5540.34 5685.36 5833.64 51 6451.00 41.08 309.39 188.00 52 6642.00 40.10 309.21 191.00 53 6832.00 40.03 307.78 190.00 54 7021.00 39.75 308.30 189.00 55 7213.00 39.13 307.77 192.00 56 7404.00 40.65 309.24 191.00 5980.19 57 7594.00 40.86 309.23 190.00 6124.11 58 7785.00 40.23 308.33 191.00 6269.25 59 7975.00 39.74 308.32 190.00 6414.83 60 8164.00 39.77 308.25 189.00 6560.14 2850.18 2974.99 3096.61 3219.72 3344.04 3467.00 3591.27 3713.55 3834.75 3956.71 4079.19 4203.22 4327.38 4449.47 4570.33 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool c/ual (ft) (ft) (ft) (deg) 100f) type type 674.95 -802.64 1048.70 743.81 -885.88 1156.73 818.70 -978.46 1275.80 893.23 -1072.96 1396.11 968.35 -1171.59 1519.98 1042.92 -1268.23 1116.40 -1362.76 1189.71 -1458.26 1263.12 -1551.73 1338.32 -1645.95 1414.69 -1740.64 1490.10 -1835.12 1566.04 -1930.43 1641.94 -2025.47 1714.87 -2118.73 1791.16 -2217.07 1867.65 -2315.71 1941.85 -2412.09 2017.12 -2509.55 2092.62 -2608.36 2168.40 -2705.21 2247.11 -2801.37 2323.23 -2897.08 2397.92 -2992.54 2473.07 -3088.61 2549.35 -3184.44 2627.80 -3280.51 2705.57 -3377.30 2781.28 -3473.08 2856.16 -3567.95 310.06 1.95 MWD 310.02 0.57 MWD 309.92 0.53 MWD 309.78 0.70 MWD 309.57 0.23 MWD 1641.97 1761.66 1882.00 2000.84 2121.38 309.43 0.48 MWD 309.33 0.63 MWD 309.21 0.30 MW/) 309.15 0.37 MWD 309.11 0.07 MWD 2243.03 2363.91 2485.76 2607.39 2725.76 309.10 0.26 MWD 309.08 0.43 MWD 309.05 0.39 MWD 309.03 0.53 MWD 308.99 0.39 MWD 2850.20 2975.00 3096.61 3219.72 3344.04 308.93 0.81 MWD 308.89 0.40 MWD 308.84 0.46 MW/) 308.79 0.56 MWD 308.74 0.48 MWD 3467.00 3591.27 3713.55 3834.75 3956.71 308.71 0.97 MWD 308.73 0.52 MWD 308.73 0.49 MWD 308.71 0.23 MWD 308.68 0.37 MWD 4079.19 4203.23 4327.38 4449.47 4570.33 308.68 0.94 MWD 308.70 0.11 MWD 308.70 0.45 MWD 308.69 0.26 MWD 308.68 0.03 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 10-Feb-2001 02:58:44 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) lOOf) type type 61 8356.00 39.02 307.65 192.00 6708.51 4692.17 2931.10 -3664.03 4692.18 308.66 0.44 MWD 6-axis 62 8460.00 38.61 307.93 104.00 6789.54 4757.35 2971.05 -3715.55 4757.36 308.65 0.43 MWD 6-axis 63 8642.00 39.10 309.82 182.00 6931.28 4871.52 3042.71 -3804.42 4871.52 308.65 0.70 MWD 6-axis 64 8832.00 39.59 309.65 190.00 7078.21 4991.96 3119.71 -3897.06 4991.96 308.68 0.26 MWD 6-axis 65 8878.00 39.72 309.75 46.00 7113.63 5021.31 3138.46 -3919.64 5021.31 308.68 0.31 MWD 6-axis 66 8950.00 39.72 309.75 72.00 7169.01 5067.31 3167.88 -3955.02 5067.31 308.69 0.00 MWD Projected.~'~. [(c)2001 Anadrill IDEAL ID6_iC_08] 4/18/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tt ATTN: Sherrie NO. TTO Company: Field: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alpine (Open Hole) Color Well Job # Log Description Date BL Sepia Prints CD CDI-21 PBI 21097 ARC ADN LWD 02/10101 CD1-21 PBI 21097 MD ADN (PDC) 02/t0101 CDt-21 PBI 21097 TVD ADN (PDC) 02/10/0t CDt-21 PBI 21097 MD ARC6 (PDC) 021t010t CDI-21 PBI 21097 TVD ARC 6 (PDC) 02/1 ECE VED o^ e: APR. 20 2_001 Alaska Oil & Gas Cons. C0mmisd0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 661-8317. Thank Scklumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. T5 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-21 21125 SCMT 02/28101 1 CD1-229 21101 CDR/ADN/IMP LWD 01/31/01 1 CD1-229 21101 MD ARRAY RES 01/31/01 I 1 CD1-229 21101 TVD ARRAY RES 01/31/01 1 1 , Ap~ 5o-/o..,~o,5 ~;~'- oo · RECEIVED SIGN~ DATE: MAD 9 ~ 9t~t~¶ I ill'ti % ~ ~ &.,v V · Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-~~~. st~C°mm~ 3/22/01 MWDILWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-21 L1 Date Dispatche 9-Mar-01 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received By: ~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 . ,~..~.. ;.. ~.~--.~., nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MAR I /UU I , Alaska Oil ~,= ""' Cons. Commission ~,r~chc,~t'age MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-21 Date Dispatche 9-Mar-01 Installation/Rig Doyen 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) c~c)I-OC)~, 2 r~o ~i, sioO Received By: ~ Please sign and return to: Anadrill LWD Division 3940 Amtic Blvd, Suite 300 Anchorage, Alaska 99503 nmsel ~slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-21 PH Date Dispatche 16-Feb-01 Installation/Rig Do¥on 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) {~' 2 Received By: ~ Please sign and retum to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ~t ~KA OIL AND GAS CONSERVATION COPlPIISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 · Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ,aLASKA 99501-3539 PHONE (907) 279-14,.'33 FAX (9O7) 276- 7542 Colvillc River Unit CDI-21 Phillips Alaska, Inc. Permit No: 201-006 W. Sur. Loc. 365'FNL, 2433'F~L, Sec. 5, T11N, R5E, uM Btmhole Loc. 644'FNL, 1747' FWL, Sec. 30, T12N, R5E, UM Dear Mr. Alvord: ., Enclosed is the approved application for permit to drill the above referenced well. .. The permit to drill does not exempt you from obtaining additional' permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all. other required permitting determinations...are made. .. Annular disp°Sal of drilling wastes Will not be approved for this well until sufficient data is submitted to ensure that the requ~ments of 20 AAC'25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT).. Cementing records, FIT data, subsequent LOT data following setting production casing, and nay CQLs must be submitted to the Commission on form 10-403 prior to the approval of disposal operations. ,, , In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD1-21 PH) and APl number (50-103-20362-70) from records, data and logs acquired for well CD1-21. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035'~ and the /nechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 .AAC 25.030(g)(3)'. Sufficient notice (approximately 24 hours) of.the MI test before operation, and of the BOPE test performed before drilling beloxv the surface casing shoe, must be given so that a representative of the Commission may witness the tests~ Notice may be given by contacting the C .ommission petroleum field inspector on the North Slope pager at 659-3607. .' Sincerely, J. M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~1 ~ day of. January, 2001 dl~Enciosures cc: Depamnent offish & cram=, Habitat Section wlo encl. Dcpmtment of Environmental Conservation w/o end. ( .... RECEIVED STATE OF ALASKA DEC g 8 ?000 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska 0il & Gas Cons. Commission 20 AAC 25.005 Anchorage la. TypeofWork Drill X Redrill I lb. TypeofWell Exploratory StratigraphicTest Development Oil ::~/~1~ Re-Entry Deepen[ Service ,~.,~.b Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 56' feat Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25559 Oz~'~;7>-~ ~ 7. Unit or property Name / 11. Type Bond (see 20 AAO 25.025) 4. Location of well at 365' FNL, 2433' F'~[-I.., Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7' casing point ) 8. Well number Number 2268' FNL, 1569' FEL, Sec. 31 T12, R5E, UM CD1-21 #59-52-180 At total depth 9. Appro~mate spud date Amount 644' FSL, 1747' FWL, Sec. 30, T12N, RSE, UM 01/22/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 1VD) Property line Alpine CD1- 22 12340' MD. Crosses .'1'11N to feat 8.6' @ 350' Feet 2560 7021' TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 2S.035(e)(2)) Kickoff depth F#: 250' feat Maximum hole angle 90.53 Maximum smface, 2483 pslg At total depth (WD) 3163 at P~o · cr~-zl ,, ~ y'&l' 6990' ,~ TVD. SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Ca,!nfl Weight ~Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC' 2697' 37' 37' 2734' 2400'. 526 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9002' 37' 37' 9039' 7046' 119 sx Class G N/A 4.5" 12.6# L-80 IBT-M 8696' 32' 32' 8728' 6965' Tubincj 19. To be'completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet . Plugs{measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production . Liner " Perforation depth: ' measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid Program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X~ 21.' I hereby certi~ that the foregoing is trUe and correct to the best of my knowledge Signed Title Drilli_'~l Team Leader __8.oo ,/' Commission Use Only . · Permit Number 50; /0~'~ ,,~...,}'~'Z..'"C)C~ IApprOvaldate I-,~i'...0~i ISeeceverletterf°r - . Other requirements Conditions of approval Samples required Yes ~_~ . Mud log required Yes (:~ Hydrogen sulfide measures ~ No Directional survey required ~ ' No Required worldng pressure for BOPE 2M 3M 5M ' 1OM 15M .. by order of / "',5/- / ' Approved I~y Commissioner the commission Date ......... .,, Form 10-401 Rev. 7-24-89 ORIGI'I AL Submit in tripli cate (" Drilling Area Risks: POST IN DOGHOUSE Drilling Area Risks: 12-114" SURFACE HOLE: · ' There are no high-risk events (e.g. over-pressures zones). formations has not occurred in this hole section. RECEIVED DEC 2 8 2000 Alaska Oil & Gas Cons. Commi~ Anchorage Historically, lost circulation do to weak 8-112" PRODUCTION HOLE: · There are no high-risk events (e.g. over-pressures zones). · The 8-1/2" hole section penetrates a normally pressured reservoir that has a pore pressure of 8.8 ppg. (3215 psi @ 7000' TVD-SS). The planned mud weight of 9.8 ppg is more then adequate to keep.the well in an overbalanced state.' Do not allow the mud weight to drop below 9.2 ppg. · Lost circulation: .'Faulting within the Alpine reservoir section near the TD of the 8-1/2" hole section is considered .to be the most likely cause of lost circulation in this hole section. Standard LCM 'material has proved effective in dealing with lost circulation in previous development wells. There is no indication of faulting near the 8-112" hole TD. 6-118" PRODUCTION HOLE: · .The mud weight must be maintained at 9.2 ppg to provide for a 150 psi overbalance of the 8.8 ppg reservoir pore pressure. · Lost circulation: Faulting within the 'Alpine reservoir, section is considered to be the most likely cause of " lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. There is a NW-SE trending fault 500' West of the planned wellbore. No loss circulation is expected., ' · Additional. care and attention will be .given to the higher potentiaI of inducing a kick when drilling horizontally as opposed to vertiCally. Good drilling practices will be stressed to minimize the potential'. of taking swabbed kicks.. Alpine: CD1-21PH (Pilot Hole) & CD1-21 RECEIVED . Procedure Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Alaska Oil 8, Gas Cons. Commission Anchorage 3. Run and cement 9 5/8 surface casing. 4. Install and test BOPE to 3500 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. .Drill 8 ½" hole to a point +/- 100' TVD below the base of the Alpine Sand. 8. Set 500 ft cement plug #1 from TD to +/- 8449'. . 11. Set 250 ft cement plug #2 from +/- 6708' to +/- 8199'. RIH with drilling assembly. Dress off'plug #2. Kick off at +/- 8461' and drill sidetrack to intermediate casing point .in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement + 500 feet MD above Alpine reservoir.. 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.' 12, !4. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to' 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. ., Drill 6 1/8" horizontal section to well TD. 15. 16. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. 1,7. 18. 19. 20. 21. 221 Run 4 ~, 12.6 #, L-80 tubing with SSSV nipple and production packer. Land hanger. Install 2 way check and pressure test 'hanger seals 'to 5000 psi. Nipple down BOP'. Install tubing head adapter assembly.' Pressure test adapter assemblY to 5000 psi.' Remove 2 way check. Circulate tubing to diesel and install freeze protection in the annulus. Drop'ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 'mins. .. Set BPV and secure well. Move rig off. Well Proximity Risks:' Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-22 will be the closest well to CD1-21 (10.3' at 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.6' at 350' MD. Annular Pumpinq Operations: Incidental fluids developed from drilling operations on well CD1-21 will be injected into the annulus of another permitted well on the CD1 pad.. The CD1-21 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-21 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. 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 below the base of the Schrader Bluff Formation .(C-30). 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. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (surf. Shoe TVD) + 1,500 psi' -- (12.0 ppg) * (0.052) * (2400'). 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 -- 1912 psi. .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% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of oD (ppf) Grade Range Type . .Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020' psi 1,717 psi 3,520 psi 2.992 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi RECEIVED DEC '2'8 ZOO0 Alaska 0il & Gas Cons. Commission. Anchorage .. CD1-21 & CD1-21 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 W' Section - 6 1/8" point- 12 ¼" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 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 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 PH 6 % KCL Surface Hole: A standard high viscosity fresh water / gel' spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt 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 FIo-Pro drill-in fluid. The base fluid will conSist of ·6%'KCI, with + 30PPB calcium carbonate bridging material to minimize formation damage..FIo-Vis Polymer and DuaI-FIo starch Will be used for viscosity and fluid loss control ~espectively. RECEIVED, ,. DEC 2, 8 ?.001] Alaska Oil & Gas Cons, Commission Anchorage Colville River Field CD1-21PH Pilot Hole - Prior to Sidetracking RKB - GL = 37' Updated 12/20/00 Wellhead 9.8 ppg drilling mud in hole I Top Alpine Reservoir at 8753' MD/,7021' TVD Pilot Hole TD at 8949'. MD /7171' TVD (+/- 39.85 .deg inc.). Cement Plug 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2734' MD / 2400' TVD cemented to surface .' RECEIVED' DE,C 2 8 2000 Alaska Oil & Gas ConS. Commission Anchorage Plu,q #2: 250'~:17 ode to cover the HRZ when in place (top at +/-81997 Top of cement plug' dressed. off to 8461' MD / 6796' TVD (+/- 39.85' deg inc.) Top of cement Plug #i at +/- 8449' 8OO ff CD1-21 Colville River Field Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812" ID) at 1700' TVD = 1822' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2734' MD / 2400' TVD cemented to surface A1 Injection Valve (2.125"1D) - to be installed later RECEIVED DEC ?~ 8 Z000 Alaska Oil & Gas Cons. Commission Anchorage 4-1/2" 12.6 ppf L-80 IBT Mod. R_~3 tubing run with Jet lube pipe dope . Packer Fluid mix: 9.6 ppg KCl Brine with 2000' TVD diesel cap Tubing Supended with diesel Completion MD TVD. Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 1822" 1700' '4-1/2", 12.6#/ft, IBT-Mod Tubing $3 Packer (c/w handling pups) 8670' 6935' 4-1/2" tubing joint (1) R2 HE$ "XN" (3.725" ID) - 61 deg. 871'6' 6959'. 4-1/2" 10' pup joint. WEG - 62 deg' 8728' 6965' TOC @ +/- 8370' MI: (+500' MD above top Alpine) Top Alpine at 8870' MD t 7019' TVD 'Baker S3 Packer at +/- 8670' (<200' MD above to top Alpine) Well TD at 12340' MD I ,7021' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9039' MD / 7046' TVD'@ 88 deg (" Colville River Field CD1-21 Injection Well Completion Plan Formation Isolation Contingency Options 16" Conductor ,o 114' (Ii 1700 TVD = 1822 MD l,,iii!!iill o-s/o'' ~6 ppf ~-ss BTC ~ Surface Casing @ 2734' MD / 2400' TVD cemented to surface .4-1/2" 12.6 ppf L-80 IBT Mod. tubing run with Jet Lube Run'n'Seal pipe dope Updated 12/20/00 RECEIVED DEC ~ 8 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID). - Baker HMC Liner Hanger -.XO to IBT-Mod - blank 4-1/2" joints (TBD) -.Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1-.2) blank - Guide Shoe (B) 'oPen Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-IO ECP (anchor) - Muleshoe / Entry Guide (C) Open .Hole Bridae Plua Assembly - Baker Payzone ECP (cement inflated) -XO . -Float Collar - 4-1/2" Float Shoe . Well TD at Baker $3 Packer set at +/- 8670' 12340.'. MD I i, ' ' ,, . ' 7021' 'FVD (+500' MD above top ..... A~) '..ill ............. u .. 7" 26 ppf L-80 BTo Mod Production Oaring @ 9089' MD / 7046' TVD @ 88 deg ( CD1-21 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 · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2734 / 2400 14.2 1086 1532 7" 9039 / 7046 16.0 3188 2483 N/A 12340 / 7021 16.0 3177 N/A · NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. 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 surface 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 lb./gal 0.052 = Conversion from lb./gal to psi/ft. 0.1 = Gas gradient in psi/ft 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 RECEIVED DEC 8 000 Alaska Oil & Gas Cons. Commission Anchorage ASP CALCULATIONS Drilling below conductor casing (16") .. . ASP = [(FG x 0.052) -0.1] D = [(10.9 x 0.052)- 0.1] x 114 = 53 psi OR ASP = FPP ' (0.1 x D) = 1086 - (0.1 x 2401') = 846 psi Drilling below surface casing (9 5/8") ' ASP: ASP = [(FG x 0.052)- 0.1] D [(14.2 x 0.052) -'0.1] x 2400 =' 1532 psi OR .' FPP - (0.1 x D) 3188 - (0.1 x 7046') = 2483 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3188 - (0.1 x 7046') = 2483 psi AlPine, CD1-21PH Cementinq Requirements CD1-21PH Cement Plug #1: 8949' MD to 8449' MD -- 500'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500'X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 fte => 196 Sx @ 1.16 fte/sk CD1-21PH Cement Plug ~2: 8199' MD to 8449' MD = 250'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 250'X 0.3941 ft3/ft X 1.15 (15% excess) = 113.3 fte => 114 sx @ 1.00 fte/sk Alpine, CD1-21 Well Cementing Requirements 9 5/8" Surface Casing run to 2734 MD 12400' TVD. Cement from 2734'. MD to 2234' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2234' to surface with Arctic Set Lite 3. Assume 30(P/o excess annular volume in permafrost and 5(P/o excess below the permafrost. Lead slurry: System' (2234'-1638') X 0.3132 fts/ft X 1.5 (50% excess) = 280.0 ft= below permafrost 1638' X 0.3132 fts/ft X 4 (300% excess) = 2052.1 fte above permafrost Total volume -- 280.0 + 2052.1 = 2332.1 ft~ => 526 $x @ 4.44 ft3/sk 526 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fte/sk, class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079.extender, 1.5%' S001 accelerator, 50% D124 extender and 9% BWOW! D044 freeze suppressant .. Tail slurry: , 3 o 500 X 0.3132 ,ft/ft X 1.5 (50 '/o excess) = 234.9 fte annular volume , 3 3 80, X 0.4341 ft/ft = 34.7 ft shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fte => 230 $x @ 1.1 7 ft~/sk ,. System: 230 $x Class G +.0.2%'D046 antifoamer, 0.3% D065 dispersant and 1% $001 accelerator @ 15.8 PPG yielding 1.17 fte/sk . '. 7" Intermediate Casing run to 9039 MD 17046' TVD Cementfrom 9039' MD t° +/- 8370' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. ' Slurry: (9039' - 8370') X 0.1268 fts/ft X1 .'4 (40% excess) = 118.8 fte annular volume ' 80' X 0.2148 fie/ft'= 17.2 ft~ shoe joint volume ' Total volume = 11'8.8 + 17.2 = 136fts => 119 $x @ 1.1'5 ft3/sk'. .. System: 119 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 1.15 fts/sk ' ~ By Weight Of mix Water, all other additives are BWOCement RECEIVED DEC 8 ZOOO Alaska Oil & Gas Cons. Commission . Anchorage .. r,.. ~.,~ ..,,~..~.. ,.. (..~ ,.~[ Sfructure: CD#I Well : 2 ~ ~ itl I - """~ I Field: Alpine Field Location : Norfh Slope, Alaska Point KOP - Sidetrack PROFILE COMMENT DATA MD Inc - Dir 'rVD North East V. Sect .8460.59 39.85 308.48 6796.23 2978~04 -3711.42 4373.82 K-1 8500.28 42.97 LCU Miluveoch A Alpine D Alpine TO'rget - Casing Pt 8644.73 3-11.'12 6'826.00 2994.85 -3731.57 8754.57 '8811'.46 4398.14 8870.20 54.69 518.63 6921.00 3071.79 -3807.94 4501.95 9039,47 322.96 6977.00 3144.82 -3867.29 4594.32 9292.59 324.95 7000.00 3187.06 .-3898.01 4646.04 12340.09 63.85 68.64 12540.11 73.61 326.86 7019.00 3235.08 -3929.14 4701.30 EOC TD - Casing Pt. Base Alpine 88.00 331.94 7046.00 5376.55 -4013.82 4867.74 90.53 90.53 331.94 7049.24 3599.88 -4152.88 5120.82 90.5'3 '331.94 7021.00 6289.00 . -5566.42 81 68.19 331.94 7021.00 6289.02 -5566.44 8168.21 Deg/1 O0 0.00 9.00 9.00 9.00 9.00 9.00 9.00 1.00 0.00 0.00 : ~ ~ For: S Iteynolda I Date p~lecl: 21-Deo-2OOO I . -Phillips.-Alaska, Inc. Field : Alpine Field Location : North Slope, Alaska Point KOP Begin Turn/Build West Sak- Base Permafrost EOC C-40 C-30 9 5/8 Casing Pt C-20 K-2 . Albion-97 AlbiOn-96 HRZ K-1 - Lcu Miluveach A Alpine. D Pilot 'Hole TOrget Alpine AIpine//OdO TD PROFILE COMMENT DATA MD 250.00 .. 750.00 1058..78 _ 1637.51. 1750.92 2448.88 2728.94 '2734.15 3204.38 4585.11 4862.56 7036'.57 7652.69 8317.01 8499.37 8623.-11 '8696.06 8726.02 8752.07 8753.-37 0817.20 '8948.76 Inc Dir TVD North East V. Sect -0.00 318.00 250.00 0.00 0.00 0.00 10~00 318.00 747.47 32.34 -29.12 42.96 19.15 312.04 .1046.00 86.30 -84.80 120.15 36.46 308~81 ' 1 556.00 258.95 -290.88 388.93 39.85 308.48 1 645.17 302.69 -345.60 458.98 39.85 308.48 2181.00 580.99 -695.72 906.24 39.85 308.48 2396.00 692.66 -836.21 1085.69 39.85 308.48 2400.00 694.73 -838.82 1089.03 39.85 308.48 2761.00 882.23 - 1074.71 1 390.35 39.85 308.48 ' 3821.00 1432.77 -1767.:54 2275.12 39.85 308.48 4034.00 1543.40 -1906.52 2452.91 39.85 308.48 5703.00 2410.24 -2997.08 5846.00 39.85 308.48 6176.00 2655.91 -3306.15 4240.81 . 39.85 308.48 6686.00 2920.79 -3639.39 4666.50 39.85 308.48 6826.00' 2993.50 -,3730.87 4783.35 39.85 308.48 6921.00 3042.84 -3792.95 4862.65 39.85 308.48' 6977.00 3071.93 -3829.54 4909.39 39.85 308.48- 7000.00 3083.87 -3844.57 4928.59 . 39.85 308.48 7020.00 3094.26 -3857.64 4945.28 39.85 308.48 7021.00 '3094.78 -3858.29 4946.12 .,,39.85 ,308.48 7070.00 5120.25 -,..'3890.51 49§7.02 .39.85 '308.48 7171~00 3172.69 -3956.30 5071.32 Deg/lO0 0.00 2.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~ ~: a. ~ For: S Reynolds Oat. plott~l: 21-~ P~ ~ b ~1-21 PH1 V~.~. Phillips Alaska, Inc. Structure: CD#I Well: 21PH1 Field: Alpine Field Location: North Slope, Alaska <- West (feet) 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 1200 800 400 0 400 i i i i i i i i i i i i i i i I I I I I I I I I I f f I ! ! t i TD - Casing Pt. ITI3 LOCATION: 644' FSL 1747' FWL SEC. 30;' T12N, R5E PILOT HOLE TD LOCATION: 2472' FNL, 1512' FEL SEC. 31, T12N, RSE PILOT HOLE TOT LOCATION: 2525' FNL, 1447' FEL SEC. 31, T12N, RSE TD Alpine/Udl -- Pilot Hole '".', ", EOC ., TARGET LOCATION; 2268' FNI., 1569' FEL SEC. 31, T12N. R5E ;t - Casing Pt D A - Sidetrack Pt Albion-g6 HRZ AlbiOn-g7 308.74 AZIMUTH 5071' 'TO TD) TRUE K-2 K-3 .RECEIVED OEO 2 8 ZOO0 Alaska Oil &'Gas ConS. Commission Anchora~ C-20 g 5/8 Casin . ~,~.EOC . Base Permafroet~ SURFACE LOCATION: Begin Turn/Bul 365' FNL, 2435' FWL OP SEC. 5, T11N, 68O0 56O0 5200 48OO 40OO A ~00 I Z O 3200 28O0 2400 20O0 1000 1200 800 400 400 Phillips Alaska, Inc. Structure: CDr1 field: Alpine Iqeld Well: 21PH1 LoQa'llon: North Slope, Alaska 400 800 1200 24OO 3200 4000 I v '4~oo 5200 5000 6B00 7200 i I i i i 400 0 400 RECEIVED RKB Elevet$on: 56' KOP 2.00 4.1:)0 6.00 DIS: 2.00 des per 100 ft 8.00 Begin Turn/Build 14.43 17.40 20.38 West Sak DIS: 3.00 oleg per 100 ft 23.37 26.,.t6 29.35 32.34 35.33 ElQse Permafrost EOC 308.74 AZIMUTH 4945' (TO PH TARGET) **~Plone of Proposol~, g 5/8 CQslng Pt C-40 C-30 C -20 AVERAGE ANGLE 39.85 DEG K-3 K-2 Albion-97 AlbiQn--g6 ~\b~oq- ,Oq/ ' Go~b . / Pilot 800 1200 1600 2000 2400 2800 3 3600 4000 4 ' 4800 Vertical Section. (feet) -> Azimuth 508.74 with reference 0.00 S, 0.00 E from slot #21 DEC 2 8 ZOO0 Alaska Oil & Gas Cons'. CommisSion Anchorage I i i I 5200 5600 IC,utad b~: u. TaM For:. B Re~noldsI ' Dots p~ted: 2!-0e~-2000 I Plot tbfemflce b CD1-21 Ve~bfl]~4. ' I True Vertical Deptlm orol~nCe RKO (IkJtyofl-lS).I ~ I Phillips Alaska, Inc-. Sfrucfure: CD#1 Well: 21 Field : Alpine Field Locofion : Nor'th Slope, Alaska 54OO 5600 58OO 84OO 6600 68OO 7000 7200 7400 7600 7800 8OOO - Sidetrack Pt K-1 %42.95 Mi!uveoch A DIS: 9.00 des per 100 ft .... '~.._ 51.01 Npine D - ~ Torget - Cos;fig Pt 331.94 AZIMUTH 8161.21' TO TD ***Plane of Proposal*** TANGENT ANGLE 90.53 DEG . i i i i i i i i i i 4200 4400 4600 4800 5000: '- 5200 5600 5800 8000 6 5400 6600 6800 7000 7 Vertical Section (feel) -> Azlmufh 551.94 wlfh reference 0.00 S, 0.00 r from sial #21 ! t '7.~o TD - Casing Pt. Base Alpine ! 8200 Phillips Alaska, Inc. S~ru=fure: CDjJ[1 Well: 21PH1 Field: Alpine field Looafion: North Slope, Alaska 130 120 110 lO0 9O 8O 7O 4O ~0 2O 10 10 100 90 BO 70 60 i i i i i i i i i I~? 100 % · % · % I i 100 BO 70 60 ,RECEIVED ~,900 · % \ <- West (feet) 50 40 30 20 10 0 10 20 30 i i i i i i i i i I I I I I I I I ~'~%~ ' \\ '~",',~].,, .,~oo % \ ~mo ,' '~o , , -- , <- West (feet) . . 130 120 110 100 2O 0 · 500 jgoo ?oo ',o 300 ' ' O0 5OO ' 20 ,.,', 30 20 10 0 10 20 30 DEC :~ $ 2000 Alaska Oil & Gas Cons. Commission Phillips Alaska, Inc. Structure: CDt1 Well: 21PHI Field: Alpine Field Location: North Slope, Alaska <- West (feet) 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 1iX) 0 1700 1600 1500 1400 1300 1200 1100 A 1000 0 Z 700 600 5OO 400 20O 3100 · · · · ",%2900 · · · 2700 2500 ~700 2300 · . ~300 · · % 500;%,~100 ~ ~J 900 · · · 6700 · 2100 %. 1700 · 68OO 8300 t00 ,0 1400 1300 1200 . 111343 1000 900 000 700 600 500 400 300 <- Wesf(feel) RECEIVED 17fl0 16OO 1500 1400 1300 oo 2 1 O0 i 1 O0 900 00 1000 .A I 25O0 000 0z ' . ?00 ~ i 2700 ~ 250O 5O0 ~ 2300 4OO ~ 2100 ~,o~ ~o' 1~0 ' , . 200 ~ ~ ~ ~00 ~ ~ 11~ 100 % . 0 loft ~ 0 Surfoce 0~0 S O~OE DEC 2 8 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Structure: CD#I Well: 21PH1 Field: Alpine Field Location: North Slope, Alaska 7200 6BO0 56OO 48OO A' I 44oo 4000 1:: 301313 O Z 32oo 28oo 241313 2oeO 181313 121313 80o <- West (feet) 6400 8OOO 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 1200 I I I ! i ! ! i ! i I I I I I I I I I I I I I I i ! i 6900 61~9~;100 6300 6100 5900 5700 5500 6500 6300 6100 ~ 5900 '~ 5700 ~5500 ' `%5~00 %,4900 ,%4700 `%4500 `%4300 3900~, 3700~. 3500~ 430~100 3300~ 3900 3700 3500 7200 6BOO 56OO 48OO 40oo ::L 3600 ~ ,-I- 2800 2400 20OO i600 1200 8OO 6400 6000 5600 5200 4800 4400 4000 . 3600 3200 2800 2400 2000 1600 1200 <- West. (feet) RE.CE.IVED DEC 8 2000 Alaska Oil & Gas Cons. Commission Anchorage 320 310 .330 Phillips Alaska, Inc. Slrueture: CO~l Reid: Alpine Field Well: 21 Location: North Slope, Alaska 340 TRUE NORTH 350 0 10 20 30 off,, 500 300 ~oo ~ 290 280 80 270 90 260 100 250 110 240 2'0 3'0 500 70O . 9[ 170 900 Normal Plane Travelling Cylinder ,- Feet All depths shown are Measured depths on Reference Well ,RECEIVED DEC 2. 8 2000 Alaska Oil & Gas Cons. Commission Anchorage r 330 320 310 Field: Alpine Field Location: North Slape, ~daskaI TRUE NORTH 350 0 10 340 20 3O 300 290 6O 800 7O 280 8O 27O '.4- 260 100 25O 110 240 230 140 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well RECEIVED DE C szO00. Alaska Oil & Gas Cons. Commission, 'Anchorage Phillips Alaska, Inc. CD#1 21 slot #21 Alpine Field North Slope, Alaska PROPOSAL L I.S T I NG Baker Hughes INTEQ Your tee : CD1~21 Version#4 Our ref : prop4349 License : Date printed : 27-Dec-2000 Date. created : 14-Dec-2000 bast revised : 18-Dec-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 '33.5120w150 55 3~.938 Slot Grid.coordinates are N 5975763.718, E 385858.505 Slot local ~oordlnates are 364.43 S 2433.89 E . . Pro~ecti0n type: alaska - Zone 4, Spheroid: Clarke - 1866 ReEerence North ks True North RECEIVED. Alaska Oil & Gas Cons. Commission Phillips Alaska, Inc. CD#1021 Alpine Field0North Slope, Alaska Measured Inclin. Azimuth True Vert R B C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 100.00 0.00 318.00 100.00 0.00 200.00 0.00 318.00 200.00 0.00 250.00 0.00 318.00 250.00 0.00 350.00 2.00 318.00 349.98 1.30 450.00 4.00 318.00 449.84 5.19 550.00 6.00 318.00 549.45 11.66 650.00 8.00 318.00 648.70 20.72 750.00 10.00 318.00 747.47 32.34 800.00 11.47 316.40 796.59 39.17 900.00 14.43 314.18 894.04 55.06 1000.00 17.40 312.70 990.19 73.88 1100.00 20.38 311.64 1084.79 95.60 1200.00 23.37 310.84 1177.58 120.14 1300.00 26.36 310.21 1268.31 147.45 1400.00 29.35 309.71 1356.71 177.44 1500.00 32.34 309.29 1442.56 210.04 1600.00 35.33 308.93 1525.62 245.15 1700.00 38.33 308.62 1605.65 282.68 1750.92 39.85 308.48 1645.17 302.69 2000.00 39.85 308.48 1836.39 402.01 2500.00 39.85 308.48 2220.24 601.37 3000.00 39.85 308.48 2604.10 800.74 3500.00 39.85 308.48 2987.95 1000.10 4000.00 39.85 308.48 3371.81 1199.47 4500.00 39.85 308.48 3755.66 1398.83 5000.00 39.85 308.48 4139.51 1598.20 5500.00 39.85 308.48 4523.37 1797.56 6000.00 39.85 308.48 4907.22 1996.93 6500.00 39.85 308.48 5291.07 2196.29 7000.00 39.85 308.48 5674.93 2395.66 7500.00 39.85 308.48 6058.78 2595.02 8000.00 39.85 308.48 6442.63 2794.39 8460.59 39.85 308.48 6796.23 2978.04 8500.00 '42.95 311.10 6825.79 2994.73 8500.28 42.97 311.12' 6826.00 2994.85 8600.00 51.01 316.58 6893.99 3045.45 8644.73 54.69 318.63 6921.00 3071.79 8700.00 59.28 320.92 6951.11 3107.18 .8754.37 63.83 322.96 6977.00 3144.82 8800.00 8811.46 8870.20 8900.00 9000.00 9039.47 9039.49 9139.49 9239.49 9292.59 PROPOSAL LISTING Page 1 Your re~ : CD1-21 Version#4 Last revised : 18-Dec-2000 Dogleg Vert Deg/100ft Sect S 0.00 E 0.00 0.00 S 0.00 E 0.00 0.00 S 0.00 E 0.00 0.00 S 0.00 E 0.00 0.00 N 1.17 W 2.00 1.69 N 4.67 W 2.00 6.77 N 10.50 W 2.00 15.23 N 18.66 W 2.00 27.06 N 29.12 W 2.00 42.24 N 35.46 W 3.00 51.24 N 51.25 W 3.00 72.69 N 71.18 W 3.00 98.68 N 95.19 W 3.00 129.14 N 123.22 W 3.00 163.98 N 155.18 W 3.00 203.11 N 190.99 W 3.00 246.43 N 230.55 W 3.00 293.80 N 273.76 W 3.00 345.11 N 320.49 W 3.00 400.21 N 345.60 W 3.00 429.68 N 470.55 W' 0.00 576.10 N 721.37 W 0.00 870.01 N 972.18 W 0.00 1163.93 N 1223.00 W 0.00 1457.84 N 1473.82 W 0.00 1751.76 N 1724.64 W 0.00 2045.67 N 1975.46 N 0.00 2339.59 N 2226.28 W 0.00 2633.50 N 2477.10 W 0.00 2927.42 N 2727.91 W 0.00 3221.33 N 2978.73 W 0.00 .3515.24 N 3229.55 W 0.00 3809.16 N 3480.37 W 0.00' 4103.07 N 3711.42 W 0.00. 4373.82 KOP - Sidetrack Pt N 3731.43 W 9.00 4397.96 N 3731.57 W . 9.00 4398.14 K-1 N 3783.92 W .9.00 4467.42 N 3807..94 W 9.00 4501.95 LCU N 3837.84 W . 9.'00 4547.25 N 3867.29 W 9.00 4594.32 Miluveach A 67.67 324.56 6995.74 3178.37 N 3891.87 W 9.00 4635.49 68.64 324.95 7000.00 3187.06 N · 3898.01 W 9.00 4646.04 Alpine D 73.~1 326.86 7019.00 3233.08 N 3929.14 W 9.00 4701.30 Alpine 76.14 327.79 7026.78 3257.29 N 3944.67 W 9.00 4729.97 84.64 330.78 7043.46 3341.98 N 3994.95 W 9.00 4828.36 88.00 331.94. 7046.00 3376.55 N 4013.82 W 9.00 4867~74 Target - Casing Pt 88.00 331.94 7046.00 3376.56 N 4013.83 W 9.00 4867..76 CD1-21 Tgt Rvsd 14-Dec-00 89.00 331.94 7048.62 3464.78 N 4060.86 W 1.00 4967.72 90.00 331.94 7049.49 3553.02 N 4107.90 W 1.00 5067.72 90.53 331.94 7049.24 3599.88 N 4132.88 N 1.00 5120.82 EOC All data is in feet unless otherwise stated. Coordinates from slot #21 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 8398.63 on azimuth 318.49 degrees from wellhead. Total Dogleg for wellpath is 94.66 degrees. Vertlcal section is ~rom S 0.00 E 0.00 on azimuth 331.94 degrees. Calculatlon uses the minimum curvature method. Presented by Baker Hughes'INTEQ RECEIVED Alas~ Oi! & Gas Oons. Commission Phillips Alaska, Inc. CD#1,21 Alpine Field,North Slope, Alaska Neasured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : CD1-21 Version#4 Last revised : 18-Dec-2000 Dogleg Vert Deg/lOOf~ Sect 9500.00 90.53 331.94 7047.32 3782.89N 4230.44W 0.00 5328.22 10000.00 90.53 331.94 7042.69 4224.10N 4465.64W 0.00 5828.20 10500.00 90.53 331.94 7038.05 4665.30N 4700.84W 0.00 6328.17 11000.00 90.53 331.94 7033.42 5106.50N 4936.04W 0.00 6828.15 11500.00 90.53 331.94 7028.79 5547.70N 5171.24W 0.00 7328.13 12000.00 90.53 331.94 7024.15 5988.90 N 5406.45 W 0.00 7828.11 12340.09 90.53 331.94 7021.00 6289.00 N 5566.42 W 0.00 8168.19 TD - Casing 12340.11 90.53 331.94 7021.00 6289.02 N 5566.44 W 0.00 8168.21 CD1-21 TD Rvsd 14-De¢-00 All data is in feet unless otherwise, stated. Coordinates from slot #21 and TVD' from RKB .(Deyon 19) (56.00 Ft above mean sea level).. Bottom hole distance is 8398.63 on azimuth 318.49 degrees from wellhead. Total Degleg for wellpath is 94.'66 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 331.94 degrees. Calculatlon uses the minimum curvature method. Presented by Baker Hughes INTEQ 'RECEIVED DEC 2 8 2'000 Naska Oil & Gas Cons;, Commission Anchorage, Phillips Alaska, Inc. CD#1,21 Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD1-21 Version#4 Last revised : 18-Dec-2000 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 8460.59 6796 23 2978.04 N 3711.42 W KOP - Sidetrack Pt 8500.28 6826 00 8644.73 692100 8754.37 697700 8811.46 700000 8870.20 701900 9039.47 7046.00 9039.49 7046.00 9292.59 7049.24 12340.09 7021.00 12340.11 7021.00 2994.85 N 3731.57 W K-1 3071.79 N 3807.94 W LCU 3144.82 N 3867.29 W Miluveach A 3187.06 N 3898.01 W Alpine D 3233.08 N 3929.14 W Alpine 3376.55 N 4013.82 W Target - Casing Pt 3376.56 N 4013.83 W CD1-21 Tgi Rvsd 14-Dec-00 3599.88 N 4132.88 W EOC 6289.00 N 5566.42 W TD - Casing Pt. 6289.02 N 5566.44 W CD1-21 TD Rvsd 14-Dec-00 Casing positions in string 'A' ============================== TopMD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 9039.49 7046.00 3376.56N 4013.83W 7" Casing 0.00 0.00 0.00S 0.00E 2734.15 2400.00 694.73N 838.82W 9 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates. Revised CD1-21 Tgt Rvsd 14-D 381898.000 5979202.000,0.0000 7046.00 3376.56N 4013.83W 14-Dec-2000 CD1-21 TD Rvsd 14-De 380391.000.5982158.000,0.0000 7021.00 6289.02N 5566.44W 14-Dec-2000 RECEIVED .,DEC 8 ?000 Alaska Oil & Gas Cons. commission. Anchorage Phi11iDs Alaska, Inc. CD#1 21 slot #21 Alpine Field North Slope, Alaska PROPOSAL LISTING Baker Hughes INTEQ Your ref : CD1-21 Verslon#4 Our ref : prop4349 License : Date printed : 27-Dec-2000 Date created : 14-Dec-2000 hast revised : 18-Dec-2000 Field is centred on n70 20 37.100,w~50 51 37.53 Structure'is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20'33.512,w150 55 34.938 Slot. Grid coordinates are N 5975763.718, g 385858.505 Slot local'coordinates are 364.43 S 2433.89 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED Alaska Oil & Gas Cons. Commission' Anchorage Phillips Alaska, Inc. CD#1021 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : CD1-21 Version#4 Last revised : 18-Dec-2000 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C O O R D S G E 0 G R A P H Z C Depth Degrees Degrees Depth C O O R D I N A T E S Basting Northing C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.005 0.00E 385858.50 5975763.72 n70 20 33.51 w150 55 34.94 100.00 0.00 318.00 100.00 0.00S 0.00E 385858.50 5975763.72 n70 20 33.51 w150 55 34.94 200.00 0.00 318.00 200.00 0.00S 0.00E 385858.50 5975763.72 n70 20 33.51 w150 55 34.94 250.00 0.00 318.00 250.00 0.00S 0.00E 385858.50 5975763.72 n70 20 33.51 w150 55 34.94 350.00 2.00 318.00 349.98 1.30N 1.17W 385857.36 5975765.03 n70 20 33.52 w150 55 34.97 450.00 4.00 318.00 449.84 5.19N 4.67W 385853.92 5975768.98 n70 20 33.56 w150 55 35.07 550.00 6.00 318.00 549.45 11.66N 10.50W 385848.19 5975775.54 nT0 20 33.63 w150 55 35.24 650.00 8.00 318.00 648.70 20.72N 18.66W 385840.18 5975784.72 n70 20 33.72 w150 55 35.48 750.00 10.00 318.00 747.47 32.34N 29.12W 385829.89 5975796.51 nT0 20 33.83 w150 55 35.79 800.00 11.47 316.40 796.59 39.17N 35.46W 385823.67 5975803.43 n70 20 33.90 w150 55 35.97 900.00 14.43 314.18 894.04 55.06N 51.25W 385808.12 5975819.56 nT0 20 34.05 w150 55 36.43 1000.00 17.40 312.70 990.19 73.88N 71.18W 385788.49 5975838.69 nT0 20 34.24 w150 55 37.02 1100.00 20.38 311.64 1084.79 95.60N 95.19W 385764.82 5975860.78 n70 20 34.45 w150 55 37.72 1200.00 23.37 310.84 1177.58 120.14N 123.22W 385737.18 5975885.75 nT0 20 34.69 w150 55 38.54 1300.00 26.36 310.21 1268.31 147.45N 155.18W 385705.65 5975913.55 n70 20 34.96 w150 55 39.47 1400.00 29.35 309.71 1356.71 177.44N 190.99W 385670.31 5975944.09 n70 20 35.26 w150 55 40.52 1500.00 32.34 309.29 1442.56 210.04N 230.55W 385631.26 5975977.30 n70 20 35.58 w150 55 41.67 1600.00 35.33 308.93 1525.62 245.15N 273.76W 385588.61 5976013.08 nT0 20 35.92 w150 55 42.93 1700.00 38.33 308.62 1605.65 282.68N 320.49W 385542.48 5976051.33 nT0 20 36.29 w150 55 44.30 1750.92 39.85 308.48 1645.17 302.69N 345.60W 385517.68 5976071.72 nT0 20 36.49 w150 55 45.03 2000.00 39.85 308.48 1836.39 402.01N 470.55W 385394.31 5976172.96 n70 20 37.47 w150 55 48.68 2500.00 39.85 308.48 2220.24 601.37N 721.37W 385146.64 5976376.18 nT0 20 39.43 w150 55 56.01 3000.00 39.85 308.48 2604.10 800.74N 972.18W 384898.97 5976579.41 nT0 20 41.39 w150 56 03.33 3500.00 39.85 308.48 2987.95 1000.10N 1223.00W 384651.30 5976782.63 nT0 20 43.35 w150 56 10.66 4000.00 39.85 308.48 3371.81 1199.47N 1473.82W 384403.64 5976985.86 nT0 20 45.31 w150 56 17.99 4500.00 39.85 308.48 3755.66 1398.83N 1724.64W .384155.975977189.08 nT0 20 47.27 w150 56 25.32 5000.00 39.85 308.48 4139.51 1598.20N 1975.46W 383908.30 5977392.30 'nT0 20 49.23 w150 56 32.65 5500.00 39.85 308.48 4523.37 1797.56N 2226.28W 383660.64 5977595.53 n70 20 51.19 w150 56 39.97 6000.00 39.85 308.48 4907.22 1996.93N 2477.10W 383412.97 .5977798.75 nT0 20 53.16 w150 56 47.30 6500.00 39.85 308.48 5291.07 2196.29N 2727.91W 383165.30 5978001.98 nT0 20 55.12 w150 56 54.63 7000.00 39.85 308.48 5674.93 2395.66N 2978.73W .382917.63.5978205.20 nT0 20 57.08 w150 57 01.96 7500.00 39.85 308.48 6058.78 2595.02N 3229.55W 382669.97 5978408.42 nT0 20 59.04 w150 57 09.29' 8000.00 39.85 308.48 6442.63 2794.39N 3480.37W 382422.30 5978611.65 n70 21 01.00 w150 57 16.62 8460.59 39.85 308.48 6796.23 2978.04N 3711.42W 382194.15 5978798.85 nT0 21 02.80 w150 57 23.38 8500.00 42.95 311.10 6825.79 2994.73N 3731.43W 382174.41 5978815.85 n70 21 02.97 w150 57 23.96 8500.28 42.97 311.12 6826.00 2994.85N 3731.57W .382174.27 5978815.98 nT0 21 02.97 w150 57 23.97 8600.00 51.01 .316.58 6893.99 3045.45N 3783.92W 382122.72' 5978867.38 nT0 21 03.47 w150 57 25.50 8644.73 54.69 318.63 6921.00 3071.79N 3807.94W 382099.11 5978894.09 n70 21 03.73 w150 57 26.20 8700.00 59.28 320.92 6951.11 3107.18N 3837.84W · 3'82069.77 5978929.93 nT0 21 04.07 w150 57 27.07 8754.37 63.83 322.96 6977.00 3144.82N 3867.29W 382040.91 5978968.02 nT0 21 04.44 w150 57 27.93 8800.00 67.67 324.56 .6995.74 3178.37N 3891.87N 382016.86 5979001.95 nT0 21 04.77 w150 57 28.65 8811.46 68.64 324.95 7000.00 3187.06N ' 3898.01W 382010.86 5979010.73 n70 21 04.86 w150 57 28.83 8870.20 73.61 326.86 7019.00 3233.08N 3929.14W 381980.44 5979057.23 nT0 21 05.31 w150 57 29.74 8900.00 76.14 327.79 7026.78 3257.29N 3944.67W 381965.29 5979081.67 nT0 21 05.55 w150 57 30.20 90'00.00. 84.64 330.78 7043.46 3341.98N 3994.95W 381916.34 5979167.13 n70 21 06.38 w150 57 31.67 9039.47 88.00 331.94. 7046.00 3376.55N 4013.82W 381898.01 5'979201.98 n70 21 06.72 w150 57 32.22 9039.49 88.00 331.94 7046.00 3376.56N 4013.83W 381898.00"' 5979202.00 nT0 21 06.72 w150 57 32.22 9139.49 89.00 331.94 7048.62. 3464.78N 4060.86W 381852.36 5979290.93 nT0 21 07.59 w150 57 33.59 9239.49 90.00 331.94 7049.49 3553.02N 4107.90W 381806.70 '5979379.88 n?0 21 08.46 w150 57 34.97 9292.59 90.53 331.94 7049.24 3599.88N 4132.88W 381782.45 5979427.12 nT0 21 08.'92w150 57 35.70 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #21 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 8398.63 on azimuth 318.49 degrees from wellhead. .. Total Dogleg for wellpath is 94.66 degrees. Vertlcal section is from S 0.00 B 0.00 on azimuth 331.94 degrees. Grid is alaska - Zone 4. Grid coordinates An FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ RECE~vEo DEC 8 2000 Alaska Oil & Gas Cons. Commission Anchorage. Phillips Alaska, Inc. CD#1,21 Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 9500.00 90.53 331.94 7047.32 3782.89N 4230.44W 10000.00 90.53 331.94 7042.69 4224.10N 4465.64W 10500.00 90.53 331.94 7038.05 4665.30N 4700.84W 11000.00 90.53 331.94 7033.42 5106.50N 4936.04W 11500.00 90.53 331.94 7028.79 5547.70N 5171.24W 12000.00 90.53 331.94 7024.15 5988.90N 5406.45W 12340.09 90.53 331.94 7021.00 6289.00N 5566.42W 12340.11 90.53 331.94 7021.00 6289.02N 5566.44W PROPOSAL LISTING Page 2 Your ref : CD1-21 Version#4 Last revised : 18-Dec-2000 GRID COORDS GEOGRAPHIC Easting Northing C 0 0 R D I N A T E S 381687.75 5979611.61 n70 21 10.72 w150 57 38.55 381459.46 5980056.38 nT0 21 15.06 w150 57 45.43 381231.17 5980501.15 n70 21 19.40 w150 57 52.31 381002.88 5980945.92 nT0 21 23.73 w150 57 59.19 380774.58 5981390.69 nT0 21 28.07 w150 58 06.07 380546.29 5981835.46 nT0 21 32.41 w150 58 12.95 380391.01 5982137.98 nT0 21 35.36 w150 58 17.63 380391.00 5982138.00 n70 21 35.36 w150 58 17.63 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #21 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 8398.63 on azimuth 318.49 degrees from wellhead. Total Dogleg for wellpath is 94.66 degrees. .. Vertical section is from S 0.00 E 0.00 on azimuth 331.94 degrees. Grid is alaska - Zone 4. . Grid coordinates in FEET and compute~ using the Clarke - 1866 spheroid 'REL;EIVED Presented by Baker Hughes INTEQ A DEC 3 8 Z000 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. CD#1,21 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD1-21 Version#4 Last revised : 18-Dec-2000 Con~ents in wellpath ==================== MD TVD Rectangular Coords. Con~ent 8460.59 6796.23 2978.04N 8500.28 6826.00 2994.85N 8644.73 6921.00 3071.79N 8754.37 6977.00 3144.82N 8811.46 7000.00 3187.06N 8870.20 7019.00 3233.08N 9039.47 7046.00 3376.55N 9039.49 7046.00 3376.56N 9292.59 7049.24 3599.88N 12340.09 7021.00 6289.00N 12340.11 7021.00 6289.02N 3711.42W KOP - Sidetrack Pt 3731.57W K-1 3807.94W LCU 3867.29W Miluveach A 3898.01W Alpine D 3929.14W Alpine 4013.82W Target - Casing Pt 4013.83W CD1-21 Tgt Rvsd 14-Dec-00 4132.88W EOC 5566.42W TD - Casing 5566.44W CD1-21 TD Rvsd 14-Dec-00 Casing positions in string °A' ============================== TopMD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 9039.49 7046.00 3376.56N 4013.83W 7' Casing 0.00 0.00 0.00S 0.00E 2734.15 2400.00 694.73N 838.82W 9 5/8' Casing Targets associated with this wellpath ===================================== . Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD1-21 Tgt Rvsd 14-D 381898.000,5979202.000,0.0000 7046.00 3376.56N 4013.83W 14-Dec-2000 CD1-21 TD Rvsd 14-De 380391.000,5982138.000,0.0000 7021.00 6289.02N 5566.44W 14-Dec-2000 RECEIVED DEC 8 7nflO Alaska Oil & Gas Cons. Commission Phillips Alaska, Inc. CD#1 21PH1 slot #21 Alpine Field North Slope, Alaska PROPOSAL LI. STING Baker Hughes !NTEQ Your ref : CD1-21 PH1 Verslon#4 Our ref : prop3031 License : Date printed : 27-Dec~2000 Date created : 1-Ju1-1998 Last' revised = 21-Dec-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot locatlon is n70 20 '33.512,w150 55 34.938 Slot Grid coordinates are N 5975763.718, E 385858.505 Slo~ local coordinates are 364.43 S 2433.89 S Pr0~ectlon type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED · . DE O 8 200,0 Alaska Oil & Gas Cons. Commission Anchorage .. Phillips Alaska, Inc. CD#1,21PH1 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 318.00 100.00 200.00 0.00 318.00 200.00 250.00 0.00 318.00 250.00 350.00 2.00 318.00 349.98 450.00 4.00 318.00 449.84 550.00 6.00 318.00 549.45 650.00 8.00 318.00 648.70 750.00 10.00 318.00 747.47 800.00 11.47 316.40 796.59 900.00 14.43 314.18 894.04 1000.00 17.40 312.70 990.19 1058.78 19.15 312.04 1046.00 1100.00 20.38 311.64 1084.79 1200.00 23.37 310.84 1177.58 1300.00 26.36 310.21 1268.31 1400.00 29.35 309.71 1356.71 1500.00 32.34 309.29 1442.56 1600.00 35.33 308.93 1525.62 1637.51 36.46 308.81 1556.00 1700.00 38.33 '308.62 1605.65 1750.92 39.85 308.48 1645.17 2000.00 39.85 308.48 1836.39 2448.88 39.85 308.48 2181.00 2500.00 39.85 308.48 2220.24 2728.94 39.85 308.48 2396.00 2734.15 39.85 308.48 2400.00 3000.00 39.85 308.48 2604.10 3204.38 39.85 308.48, 2761.00 3500.00 39.85 308.48 2987.95 4000.00 39.85 308.48 3371.80 4500.00 3'9.85308.48 3755.66 4585.11 39.85 308.48 3821.00 4862.56 39.85 308.48 4034.00 5000.00 39.85 308.48 '4139.51 5500.00 39.85 308.48. 4523.37 6000.00 39.85 308.48 4907.22 6500.00 39.85 308.48 5291.07 7000.00 39.85 308.48 5674.93 7036.57 39.85 308.48 5703.00 7500.00 39.85 308.48 6058.78 7652.69 39.85 308.48 6176.00 8000.00 39.85 308.48 6442.63 8317.01' 39.85 308.48 6686.00 8460.59 39.85 308.48 6796.23 8499.37 39.85 308.48 6826.00 8500.00 39.85 308.48 6826.49 8623.11 39.85 308.48 6921.00 8696.06 39.85 308.48 6977.00 8726.02 39.85 308.48 7000.00 RECTANGULAR COORDINATES 0.00 S 0.00 0.00 S 0.00 0.00 S 0.00 0.00 S 0.00 1.30 N 1.17 5.19 N 4.67 11 . 66 N 10 . 50 20.72N 18.66 32.34N 29.12 39.17N 35.46 55.06 N 51.25 73.88 N 71.18 86.30 N 84.80 95.60 N 95.19 120.14N 123.22 147.45N 155.18 177.44N 190.99 210.04N 230.55 245.15N 273.76 258.95N 290.88 282.68N 320.49 302.69N 345.60 402.01N 470.55 580.99N 695.72 601.37N 721.37 692.66 N 836.21 694.73 N 838.82 800.74 N 972.18 882.23 N 1074.71 1000.10N 1223.00 1199.47N 1473.82 1398.83N 1724.64 1432.77N '1767.34 1543.40N 1906.52 1598.20N 1975.46 1797.56N 2226 1996.93N 2477 2196.29N 2727 2395.66N 2978 2410.24N 2997 2595.02N 3229.55' 2655.91N 3306.15 2794.39N, 3480.37 2920.79N 3639.39 2978.04N 3711.42 2993.50N 3730.87 2993.75N 3731.19 3042.84N 3792.95 3071.93N 3829.54 3083.87N 3844.57 Dogleg Deg/100ft 0.00 0.00 0.00 0.00 2.00 2.00 2.00 2.00 2.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 0.00 0.00 0,00 .0,00 0,00 0,00 0,00 0,00 0,00 0,00 0',00' 0,00 0,00 .28 W 0,00 .10 W ,0.00 .92 W 0.00 .73 W . 0;00 .08 W 0.00 PROPOSAL LISTING Page 1 Your ref : CD1-21 PH1 Version#4 Last revised : 21-Dec-2000 Vert Sect 0.00 0.00 0.00 0.00 KOP 1.72 6.89 15.49 27.52 42.96 Begin Turn/Build 52.17 74.43 101.76 · 120.15 West Sak 134.08 171.29 213.31 260.01 311.27 366.94 388.93 Base Permafrost 426.88 458.98 EOC 618.60 906.24 938.99 1085.69 C-30 1089.03 9 5/8',Casing Pt 1259.39 1390.35 C-20 1579.79 1900.18 2220.58 2275.12 K-3 2452.91 K-2 2540.98 2861.38 3.181.77 3502.17 3822.57 3846.00 Albian-97 0.00 4142.96 0.00 4240.81 Alblan-96 0.00 4463.36 0.00 4666.50 HRZ 0.00 4758.50 0.00 4783.35 K-1 0.00 47,83.76 0.00 4862.65 LCU 0.00. 4909.39 Miluveach A 0.00 4928.59 Alpine D .' All data is in feet unless otherwise stated. Coordinates from slot #21 and TVD fro~RKB (Doyon 19) (56.00 Pt above mean sea level). Bottom hole distance is 5071.32 on azimuth 308.73 degrees from wellhead. Total Dogleg for wellpath is 40.03 degrees. Vertlcal section is from wellhead on azimuth 308.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTBQ RECEIVED DEC 2 8 Z000 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. CD#1021PH1 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : CD1-21 PH1 Version#4 Last revised : 21-Dec-2000 Dogleg Vert Deg/100ft Sect 8752.07 39.85 308.48 7020.00 3094.26 N 3857.64 W 0.00 4945.28 Pilot Hole Target 8753.37 39.85 308.48 7021.00 3094.78 N 3858.29 W 0.00 4946.12 Alpine 8817.20 39.85 308.48 7070.00 3120.23 N 3890.31 W 0.00 4987.02 Alpine/UJU 8948.76 39.85 308.48 7171.00 3172.69 N 3956.30 W 0.00 5071.32 TD All data is in feet unless otherwise stated. Coordinates from slot %21 and TVD' from RKB (Doyon 19) (56.00 Ft above mean sea level).. Bottom hole distance is 5071.32 on azimuth 308.73 degrees from wellhead. Total Dogleg for wellpath is 40.03 degrees. . Vertical section 'is from wellhead on azimuth 308.74 degrees. Calcu!ation uses the minimum curvature method. Presented by Baker Hughes INTEQ '~~'1~~ . . DEC 2 8 2000 Alaska Oil & Gas cons. commission Anchorage Phillips Alaska0 Inc. CD#l,21PH1 Alplne Field,North Slope0 Alaska PROPOSAL LISTING Page 3 Your ref : CD1-21 PH1 Version#4 Last revised : 21-Dec-2000 Comments in wellpath ==================== MD TVD Rectangular Coords. Co~uent 250.00 250.00 0 00 S 0.00 E KOP 750.00 747.47 32 34 N 29.12 W Begin Turn/Build 1058.78 1046.00 1637.51 1556.00 1750.92 1645.17 2448.88 2181.00 2728.94 2396.00 2734.15 2400.00 3204.38 2761.00 4585.11 3821.00 4862.56 4034.00 7036.57 5703.00 7652.69 6176.00 8317.01 6686.00 8499.37 6826.00 8623.11 6921.00 8696.06 6977.00 8726.02 7000.00 8752.07 7020.00 8753.37 7021.00 8817.20 7070.00 8948.76 7171.00 86 258 302 580 692 694 882 1432 77 1543 40 2410 24 2655 91 2920 79 2993 50 3042 84 3071.93 3083.87 3094.26 3094.78 3120.23 3172.69 30 N 84.80 W West Sak 95 N 290.88 W Base Permafrost 69 N 345.60 W EOC 99 N 695.72 W C-40 66 N 836.21 W C-30 73 N 838.82 W 9 5/8' Casing 23 N 1074.71 W C-20 N 1767.34 N N 1906.52 W K-2 N 2997.08 W A1bian-97 N 3306.15 W A1blan-96 N 3639.39 W HRZ N 3730.87 W K-1 N 3792.95 W ~CU N 3829.54 W Miluveach A N 3844.57 W Alpine D N 3857.64 W Pilot Hole Target N 3858.29 W Alpine N 3890.31 W Alpine/UJU N 3956.30 W TD Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 9039.49 7171~00 3172.69N 3956.30W 7' Casing 0.00 0.00 0.00S 0.00E 2734.15 2400.00 694.73N 838.82W 9 5/8' Casing Targets associated with this wellpath ===================================== . Targe~ name Geographic Location T.V.D. Rectangular Coordinates Revised CD1-33PH Targ Rvsd I 7020.00 3094.26N 3857.64W 19-Dec-2000 RECEIVED' DEC 8 000 Alaska Oil & Gas,cons. Commission Anchorage, .. Phillips Alaska, Inc. CD#1 21PH1 slot #21 Alpine Field North Slope, Alaska PROPOSAL L I. ST I NG by Baker Hughes INTEQ Your ref : CD1-21 PH1 Version#4 Our ref : prop3031 License : Date printed : 27-Dec-2000 Date created : 1-Ju1-1998 Last'revised : 21-Dec-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on n70 20'37.100,w150 56 46.041 Slot location is nTO 20 33.512,w150 55 34.938 Slot Grid coordinates are N 5975763.718, E 385858.505 Slot loc~1 coordinates are 364.43 S 2433.89 S Projection type= alaska - Zone 4, Spheroid: Clarke - 1866 Re~erence North is True North RECEIVED DEC 8'20OO Alaska Oil & Gas Cons. Commission Phillips Alaska, Inc. CD#1,21PH1 Alpine Pield,North Slope, Alaska Measured Inclin Azimuth True Vert Depth 0.00 100.00 200.00 250.00 350.00 450.00 4.00 550.00 6.00 650.00 8.00 750.00 10.00 800.00 11.47 900.00 14.43 1000.00 17.40 1058.78 19.15 1100.00 20.38 1200.00 23.37 1300.00 26.36 1400.00 29.35 1500.00 32.34 1600.00 35.33 1637.51 36.46 1700.00 38.33 1750.92 39.85 2000.00 39.85 2448.88 39.85 2500.00 39.85 2728.94 39.85 2734.15 39.85 3000.00 39.85 3204.38 39.85 3500.00 39.85 4000.00 39.85 4500.00 39.85 4585.11 39.85 4862.56 39.85 5000.00 39.85 5500.00 39.85 6000.00 39.85 6500.00 39.85 7000.00 39.85 7036.57 39.85 ., 7500.00 39.85 7652.69 39.85 8000.00 39.85 8317.01 39.85 8460.59 39.85 8499.37 39.85 8500.00 39.85 8623.11 39.85 8696.06 39.85 8726.02 39.85 Degrees Degrees 0.00 0.00 0.00 0.00 2.00 Depth 0.00 0.00 318.00 100.00 318.00 200.00 318.00 250.00 318.00 349.98 318.00 449.84 318.00 549.45 318.00 648.70 318.00 747.47 316.40 796.59 314.18 894.04 312.70 990.19 312.04 1046.00 311.64 1084.79 310.84 1177.58 310.21 1268.31 309.71 1356.71 309.29 1442.56 308.93 1525.62 308.81 1556.00 308.62 1605.65 308.48 1645.17 308.48 1836.39 308.48 2181.00 308.48 2220.24 308.48 2396.00 308.48 2400.00 308.48 2604.10 308.48 2761.00 308.48 2987.95 308.48 3371.80 308.48 3755.66 308.48 3821.00 308.48 4034.00 308.48 4139.51 308.48, 4523,37 308.48 4907.22 308.48 5291.07 308.48 5674.93 308.48 5703.00 308.48 6058.78 308.18 6176.00 308.48 6442.63 308.48 6686.00 308.48 6796.23 308.48 6826.00 308.48' 6826.49 308.48 6921.00 308.48 6977.00 308.48 7000.00 RECTANGULAR COORDINATES 0.00S 0.00E 0.00S 0.00E 0.00S 0.00E 0.00S 0.00E 1.3 ON 1.17W PROPOSAL LISTING Page 1 Your ref : CD1-21 PH1 Version#4 Last revised : 21-Dec-2000 GRID C Easting 385858.50 385858.50 385858.50 385858.50 385857.36 5.19N 4.67W 385853.92 11.66N 10.SOW 385848.19 20.72N 18.66W 385840.18 32.34N 29.12W 385829.89 39.17N 35.46W 385823.67 55.06N 51.25W 385808.12 73.88N 71.18W 385788.49 86.30N 84.80W 385775.06 95.60N 95.19W 385764.82 120.14N 123.22W 385737.18 147.45N 155.18W 385705.65 177.44N 190.99W 385670.31 210.04N 230.55N 385631.26 245.15N 273.76W 385588.61 258.95N 290.88W 385571.71 282.68N 320.49W 385542.48 302.69N 345.60W 385517.68 402.01N 470.55W 385394.31 580.99N 695.72W 385171.96 601.37N 721.37W 385146.64 692.66N 836.21W 694.73N 838.82W 800.74N 972.18W 882.23N 1074.71W 1000.10N 1223.00W 385033.24 385030.66 384898.97 384797.74 384651.30 1199.47N 1473.82W .384403.64 1398.83N 1724.64W 384155.97 1432.77N 1767.34W 384113.81 1543.40N 1906.52W 383976.38 1598.20N 1975.46W 383908.30 1797.56N 2226.28N 1996.93N 2477.10W 2196.29N 2727.92W 2395.66N 2978.73W 2410.24N 2997.08W 383660.63 383412.97 383165.30 382917.63 382899.52 2595.02N 3229.55W 382669.97 2655.91N · 3306.15W '382594.33 2794.39N 3480.37W 382422.30 2920.79N 3639.39W 382265.27 2978.04N 3711.42W 382194.15 2993.50N 3730.87W 382174.94 2993.75N 3731.19W 382174.63 3042.84N 3792.95W 382113.65 3071.93N 3829.54W 382077.52 3083.87N 3844.57W 382062.68 OORDS GEOGRAPHIC Northing C O 0 R D I N A T E S 5975763.72 nT0 20 33.51 w150 55 34.94 5975763.72 nT0 20 33.51 w150 55 34.94 5975763.72 nT0 20 33.51 w150 55 34.94 5975763.72 nT0 20 33.51 w150 55 34.94 5975765.03 nT0 20 33.52 w150 55 34.97 5975768.98 n70 20 33.56 w150 55 35.07 5975775.54 n70 20 33.63 w150 55 35.24 5975784.72 n70 20 33.72 w150 55 35.48 5975796.51 nT0 20 33.83 w150 55 35.79 5975803.43 n70 20 33.90 w150 55 35.97 5975819.56 nT0 20 34.05 w150 55 36.43 5975838.69 nT0 20 34.24 w150 55 37.02 5975851.32 n70 20 34.36 w150 55 37.41 5975860.78 nT0 20 34.45 w150 55 37.72 5975885.75 n70 20 34.69 w150 55 38.54 5975913.55 n70 20 34.96 w150 55 39.47 5975944.09 nT0 20 35.26 w150 55 40.52 5975977.30 nT0 20 35.58 w150 55 41.67 5976013.08 nT0 20 35.92 w150 55 42.93 5976027.14 nT0 20 36.06 w150 55 43.43 5976051.33 n70 20 36.29 w150 55 44.30 5976071.72 nT0 20 36.49 w150 55 45.03 5976172.96 nT0 20 37.47 w150 55 48.68 5976355.41 nT0 20 39.23 w150 55 55.26 5976376.18 nT0 20 39.43 w150 55 56.01 5976469.23 nT0 20 40.33 w150 55 59.36 5976471.35 .nT0 20 40.35 w150 55 59.44 5976579.41 nT0 20 41.39 w150 56 03.33 5976662.48 nT0 20 42.19 w150 56 06.33 5976782.63 nT0 20 43.35 w150 56 10.66 5976985.86 nT0 20 45.31 w150 5.6 17.99 5977189.08 nT0 20 47.27 w150 56 25.32 5977223.67 n70 20 47.61 w150 56 26.56 5977336.44 nT0 20 48.69 w150 56 30.63 5977392.30 nT0 20 49.23 w150 56 32.65 5977595.53 nT0 20 51.19 w150 56 39.97 5977798.75 n70 20 53.16 w150 56 47.30 5978001.98 nT0 20 55.12 w150 56 54.63 5978205.20 nT0 20 57.08 w150 57 01.96 5978220.06 nT0 20 57.22 w150 57 02.50 5978408.43 n70 20 59.04 w150 57 09.29 5978470.49 n70 20 59.64 w150 57 11.53 5978611.65 nT0 21 0'1.00w150 57 16.62 5978740.50 nT0 21 '02.24w150 57 21.27 5978798.86 n?0 21 02.80 w150 57 23.38 5978814.62 nT0 21 02.96 w150 57 23.95 5978814.87 n70 21 02.96 w150 57 23.95 5978864.91 nT0 21 03.44 w150 57 25.76 5'978894.56nT0 21 03.73 w150 57 26.83 5978906.74 nT0 21 03.84 w150 57 27.27 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #21 and TVD from RKB (Doyon 19) (56.00 Pt above mean sea level). Bottom hole distance is 5071.32 on azimuth 308.73 degrees irom wellhead. Total Dogleg for we11Dath is 40.03 degrees. Vertical section is £rom wellhead on azimuth 308.74 degrees. Grid is alaska - Zone 4. GrAd coordinates in PEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Co~s. Commission 'Ancho~ Phillips Alaska, Inc. CD#1,21PH1 Alpine Field0North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 8752.07 39.85 308.48 7020.00 3094.26N 3857.64W 8753.37 39.85 308.48 7021.00 $094.78N 3858.29W 8817.20 39.85 308.48 7070.00 3120.23N 3890.31W 8948.76 39.85 308.48 7171.00 3172.69N 3956.30W PROPOSAL LISTING Page 2 Your ref : CD1-21 PH1 Version#4 Last revised : 21-Dec-2000 GRID COORDS GEOGRAPHIC Easting Northing C O O R D I N A T E S 382049.77 5978917.33 n70 21 03.95 w150 57 27.65 382049.13 5970917.86 nT0 21 03.95 w150 57 27.67 382017.51 5978943.80 n70 21 04.20 w150 57 28.61 381952.35 5978997.27 nT0 21 04.72 w150 57 30.54 All data in feet unless otherwise, stated. Calculation uses minimum curvature method. Coordinates from slot %21 and TVD from RKB'(Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance .is 5071.32 on azimuth 308.73 degrees from wellhead. Total Dogleg for wellpath is 40.03 degrees. .- Vertical section is from wellhead on azimuth 308.74 degrees. Grid is alaska - Zone 4. . Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ RECEIVED DEC gl~ Oil' & Gas Cims. Com~s~on Anchorage .. Phillips Alaska, Inc. CD#l,21PH1 Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD1-21 PH1 Version#4 Lest revised : 21-Dec-2000 Comments in wellpath ==================== MD TVD Rectangular Coords. Co=~ent 250.00 250.00 0.00S 0.00E KOP 750.00 747.47 1058.78 1046.00 1637.51 1556.00 1750.92 1645.17 2448.88 2181.00 2728.94 2396.00 2734.15 2400.00 3204.38 2761.00 4585.11 3821.00 4862.56 4034.00 7036.57 5703.00 7652.69 6176.00 8317.01 6686.00 8499.37 6826.00 8623.11 6921.00 8696.06 6977.00 8726.02 7000.00 8752.07 7020.00 8753.37 7021.00 8817.20 7070.00 8948.76 7171.00 32.34N 86.30N 258.95N 302.69N 580.99N 692 66N 694 73N 882 23N 1432 77N 1543 40N 2410 24N 2655.91N 2920.79N 2993.50N 3042.84N 3071.93N 3083.87N 3094.26N 3094.78N 3120.23N 3172.69N 29.12W Begin Turn/Build 84.80N West Sak 290.88W Base Permafrost 345.60W EOC 695.72W 836.21W C-30 838.82W 9 5/8' Casing Pt 1074.71W 1767.34W K-3 1906.52W K-2 2997.08N A1bian-97 3306.15W Albian-96 3639.39W HRZ 3730.87W K-1 3792.95W LCU 3829.54W Miluveach A 3844.57W Alplne D 3857.64W Pilot Hole Target 3858.29W Alpine 3890.31W Alplne/UJU 3956.30W TD Casing positions in string ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 9039.49 7171~00 3172.69N 3956.30W 7' Casing 0.00 0.00 0.00S 0.00R 2734.15 2400.00 694.73N 838.82W 9 5/8" Casing . Targets associated with this wellpath ===================================== . Target name Geographic Location T.V.D. Rectengular Coordinates Revised CD1-33PH Targ Rvsd i 7020.00 ' 3094.26N 3857.64W 19-Dec-2000 .RECEIVED DEC 2 8 000 Alaska Oil & Gas Cons. Commission Anchorage ,, Phillips Alaska, Inc. CD# 1 21 slot #21 Alpine Field North Slope, Alaska MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : CD1-21 Version#4 Our ref = prop4349 License : Date printed : 27-Dec-2000 Date created : 14-Dec-2000 Last revised : 18-Dec-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 33.512,w150 55 34.938 Slot Grid coordinates are N 5975763.718, E 385858.505 Slot local coordinates are 364.43 S 2433.89 E Projection type= alaska - Zone 4, Spheroid= Clarke - 1866 Reference.North is True North Report is'limited to clearances less than 500 feet Proximities w~ll incorporate ellipses - when Survey tools are defined for both. wells. El'llpse separa=ion in ~everse brackets, e.g. )10.2(, where available. DECREASING CLeaRANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS ~10879 - 11934'>,09PH,CD#l PMSS IFR <0 - 15350°>,,9,CD#1 PMSS ~7182 - 11170'~,,41,CD#1 PMSS <475 - 8166'>°,41PHi,CD#1 CD1-15 Version #2,,15,CD#1 PMSS <0-9357°~,,16PH1,CD#1 PMSS <8393 - 12600'~,,16,CD#1 PMSS <0-10224'>,,39PH1,CD#1 PMSS.<9146- 13289'~,,39,CD#1 PMSS <9081 - 12811',,,44,CD#1 PMSS <297 - 9882'),,44PHi,CD#1 PMSS <476 - 11190'),,34,CD#1 PMSS ~0-10897'>,,3,CD#1 PMSS ~0-8350°,,,26PH1,CD#1 PMSS <7755-11134'~,,26°CD#1 PMSS <0-8844'>,,45PHI,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-11608'>,,42,CD#1 'PMSS <12550 - 16023'>,,6,CD#1 PMSS <0-13308'>,,6PH, CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <10803-13706'>,,24,CD#1 PMSS <0-12921'>,,43,CD#1 PMSS <0-13450'>,,35,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS IFR <564-18590'>,,17,CD#1 PMSS <0-11300'>,,13,CD91 PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>,,19A,CD#1 PGMS <0 - 8050'>,,22,CD#1 PMSS <8091 - 8372'>,,22,CD#1 PMSS <8464 - 11500'>,,22A,CD#1 PMSS <832 - 12147'>,,25,CD#1 ' PMSS <384 - 14477'>,,23,CD#1 Closest approach with 3-D Last revised Distance MinlmumDistance method M.D. Diverging from M.D. 18-0ct-2000 .)117.0( 437.5 18-Oct-2000 )117.0( 437.5 3-Apr-200'0 )198.2( 200.0 26-Mar-2000 )198.2( 200.0 5-Apr-2000 )57.5( 475.0 4-Jan-2000 )49.2( 200.0 25-Oct~1999 )49.2( 200.0 4-Jan-2000 )178.7( 387.5 22-Sep-1999 )178.7( 387.5 23-May-2000 )229.4( 200.0 23-May-2000 )229.4( 200.0 11-May-2000 )127.9( 262.5. 4-Jan-2000 )178.1( 337.5 6-Mar-2000 )49.3( 200.0 1-Nov-1999 )49.3( 200.0 4-Jan-2000 )238.8( 250.0 16-Novh1999 )238.8( 250.0 23-Dec-1999 )209.1( 200.0 21'-Aug-2000)147.2( 537.5 21-Aug-2000 )147.2{ 537.5 23-Jan-2000 )157.1( 337.5. 23-Jan-2000 )157.1( 337.5 7-Aug-2000 )28.5( 375.0 27-0ct-2000 )219.8( ' 100.0 24-Jul-2000 )138.9( 200.0 5-Sep-2000 )189.3( 200.0 20-0ct-2000 )38.5( 325.0 27-Sep-2000 )78.4( 412.5 6-Apr-2000 )14.6( 662.5 30-Apr-2000 )14.6( 662.5 13-Nov-2000 )8.6( 350.0 13-Nov-2000 )8.6( 350.0 13hNov-2000 )8.6( 350.0 1S-Mar-2000 )37.1( 337.5 29-Aug-2000 )17.3( 350.0 437.5 437.5 8742.3 200.0 475.0 9005.6 9005.6 11620.0 11620.0' 8966.7 200.0 262.5 337.5 200.0 200.0 250.0 250.0 8818.0 11520.0 '11520.0 8540.2 8540.2 375.0 8600 0 11180 0 200 0 325 0 412 5 .662 5 662 5 9680 0' 8466.2 '9239.5 337.5 350.0 RECEIVED DEC 8,ZOO0 Alaska Oil & Gas Cons. Commission Anchorage .. PMSS <654 - 10956'>,,38PB1oCD#1 PMSS <9876 - 12240'>.,38,CD~1 PQMS <0-10255°>,.WD20CD#1 PMSS <0-7331'~,,1PH1,CD#1 PMSS <5946 - 10289°>,,10CD#1 PMSS <562 - 12134'>.,370CD#1 CD1-2 Version#12,020CD#1 PMSS PMSS <563-13977'~,,4,CD#1 PMSS <0-11492'~,°27,CD#1 PMSS <565 - 9505'>,,30PH1,CD#1 PMSS ,8965 - 12850'~,,30.CD#1 PMSS ,473 - 14364'~°,31,CD#1 PMSS ,0-11067°>,,32PHi,CD#1 PMSS -10013° - 14353'~0,32,CD#1 NQ1 PH1 Vers#5,,NQIPH,CD#1 CD1-28 Version #80,28,CD#1 PMSS ,656 - 7210'>,028PHi,CD#1 PMSS <6549 - 10468'>0028,CD#1 CD1-33 Version#5,,33,CD#1 PMSS ,507 - ???°>,,330CD#1 PMSS ,472 - 1545'~,,36PH10CD#1 PMSS <763 - 7440'>,,36PH2,CD~1 PMSS <6600 - 10654°~,,36,CD#1 PMSS ,0-11693'>,,100CD#1 CD1-21 PH1 Verslon#4,,21PH1,CD#1 13-Feb-2000 14-Feb-2000 28-Jun-1999 29-Feb-2000 27-Jun-1999 26-Aug-1999 30-0ct-2000 21-Nov-2000 15-Nov-2000 16-Mar-2000 25-Sep-2000 1-0c~-2000 27-0ct-2000 4-Jan-2000 14-De¢-2000 4-Dec-2000 15-De¢-2000 17-Dec-2000 22-Dec-2000 19-Dec-2000 27-De¢-2000 4-Jan-2000 4-Jan-2000 22-Dec-1999 8-Dec-2000 21-Dec-2000 )168 )168 )1120 198 198 158 188 188 169 )58 )89 )89 )96 )107 )107 )78 )68 )63 )63 118 117 149 149 149 102 )0 200.0 200.0 855.6 250.0 250.0 287.5 325.0 250.0 200.0 200.0 100.0 100.0 537.5 387.5 387.S 275.0 275.0 525.0 525.0 400.0 425.0 100.0 100.0 100.0 662.5 8876.2 200 0 200 0 855 6 5800 0 7760 0 287 5 10280 0 9540 0 200 0 200 0 100.0 12340.1 12340.1 387.5 12340.1 9011.3 725.0 525.0 525.0 400.0 425.0 100.0 100.0 8513.6 662.5 8876.2 RECEIVED 'DEC 2 8' 2000, Alaska Oil & Gas Cons. Commission Anchorage '. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 28, 2000 Alaska Oil and Gas Consewation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska, 99501 Re: Application for Permit to Drill CD 1-21 (& CD 1-21 PH) Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Water Alternating Gas (WAG) injection well from the Alpine CD1 drilling pad. The intended spud date for this well is January 22, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD1-21 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 39.85°. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizOntal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and ' the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting the completion of well work'that will allow it to begin injection, · 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, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. . ~, 5.. Proposed pilot hole schematic. 6..Proposed completion diagram. 7. Proposed completion diagram with open hole. isolation.options. ' 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9, CD1-21 and CD1-21PH Cementing Requirements. 10. Directional drilling / collision avoidance information as required by 20 ACC 25.050 ,(b). Information pertinent to this .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, i-,~-.- CE I VE D DEC 2 8 ?nno Alaska Oil & Gas Cons. Commission 'Anchorage If you have any quesl~ions or require further information, pleast~ contact Scoff Reynolds at 265-6253 or Chip Alvord at 265-6120. ~Scott D. Reynolds' Drilling Engineer Attachments CC: CD1-21 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 8680 ATO 868 ATO 810 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED' DE'C :~ 8 ZOO0 Alaska Oil & Gas.Cons', Commission Anchorage. Text for inclusion in permit approval cover letter: In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD1-21 PH) and API number (50-103-20362-70) from records, data and logs acquired for well CD 1-21. 108 · Cash Advance Draft American Express DATE ~ e2-4o/to2t Issu~l ~ I.t.~'"~.-P'~'~. T~ Inc. NOI %AUD ~K A~NT OVER SI ~ ,. ~: ~O ~ IoOhOO~l '~ S ',,,O ~ ? SOOD S ~6~'0 ID& . . WELL PERMIT CHECKLIST COMPANY ,*///,~ WELL NAME ~__.Z::>/-' E./ PROGRAM: exp FIELD & POOL / Z..(~) / ~ INIT CLASS ~t//C_~' U.J~?,/,4.~ GEOL AREA ADMINISTRATION DATE 1. Permit fee attached. ~., · 2. Lease number approPriate.,) 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs.... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... ;~ :~,,,~, ..... 26. BOPE press rating appropriate; test to ~'~L.~ psig. 27. Choke manifold complies w/APl RP~53 (May 84) ........ 28. Work will occur without operation shutdown.... ........ ' 29. Is presence of H2S gas probable .................. GEOLOGY . 30. Permit can be issued w/o hydrogen sulfide measures ..... Y '~ 31. Data presented on potential overpressure zones ...... '.' Y~ " 32. Seismic analysis of shallow gas zones .... · .......... ~Z)~/Y ..N IIApI~R DATE , 33. Seabed condition survey (if off-shore) ......... ~ ./~J"' Y N Contact name/phone for weekly progress reports/....~ratory..., only] Y N II'ANNULAR DISPOSAL35. With proper cementing records,, this plan ' (A). will contain waste in a suitable receiving zone; ........ Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disPosal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N dev reddl serv v/' wellbore seg .ann. disposal para req UNIT# ~)~--0 ~'~~ ON/OFFSHORE APPR., DATE GEOLOGY: ENGINEERING: .. UlCIAnnulaf COMMISSION: ' 'comments/Instructions: Z (' O .. c:~nsoffice\wordian~iana~checklist (rev. 111011100)
