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Home My WebLink About202-092Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2024 InspectNo:susKPS240208092337 Well Pressures (psi): Date Inspected:2/9/2024 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:3/26/2023 #322-509 Tubing:10 IA:0 OA:110 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Bruce Richwine Date AOGCC Notified:2/8/2024 Type of Inspection:Initial Well Name:COLVILLE RIV UNIT CD2-22 Permit Number:2020920 Wellhead Condition All Valves appeared in good working order with working gauges on the tubing, IA,and OA.Ther are no VR or BPV installed. SSV is closed, Surrounding Surface Condition everything looked good no debris around well area. Condition of Cellar Cellar is cover with plywood to keep the snow out. Removed plywood and celler was dry with no trash or sheen visable. Comments Location was verified by pad map and well signage. Supervisor Comments Photos (4) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Thursday, April 4, 2024          jbr 2024-0209_Suspend_CRU_CD2-22_photos_ksj Page 1 of 2 Suspended – CRU CD2-22 (PTD 2020920) Photos by AOGCC Inspector K. StJohn 2/9/2024 2024-0209_Suspend_CRU_CD2-22_photos_ksj Page 2 of 2 SSV stem posi�on showing the valve is closed 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11134'feet 7206', 7292', 7321'feet true vertical 7135'feet None feet Effective Depth measured 7178'feet 7201' feet true vertical 6983'feet 6997'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 7322' MD 7065' TVD Packers and SSSV (type, measured and true vertical depth) 7201' MD N/A 6997' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Alpine Oil Pool - Suspended 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker S-3 Packer SSSV: None Kate Dodson kate.dodson@conocophillips.com (907) 265-6181Senior Well Interventions Engineer Open Hole: 7845-11134' Open Hole: 7183-7135' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 114' ~~~ ~~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-092 50-103-20421-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL380075, ADL0022530 Colville River Field/ Alpine Oil Pool -Suspended CRU CD2-22 Plugs Junk measured Length Production Liner 7810' Casing 7182'7845' 2345' 114'Conductor Surface Intermediate 16" 9-5/8" 77' 2382' 2380' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:04 am, Feb 23, 2024 Digitally signed by Kate Dodson DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E= kate.dodson@conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.22 14:25:58-09'00' Foxit PDF Editor Version: 13.0.0 Kate Dodson VTL 8/15/2024 DSR-2/24/26 RBDMS JSB 022924 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Suspension Date: Sundry No.: Well Pressures (psi): Tubing 10 IA 0 OA 110 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm 2020920 Condition of Surrounding Surface Location: 03/26/23 322-509 REVIEWED BY: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date AOGCC Notified: Kam StJohn 02/09/24 Yes Other (specify in comments) CPAI CD2-22 Yes Well is inside wellhouse, wellhead was clean with no debris around. No VR plugs or BPVs, working casing valves with gauges on all annuli. Yes Clean inside wellhouse and clear snowpack outside with no debris present Follow Up Actions Needed: Photos Taken? Bruce Richwine 907-265-6181 Type of Inspection: Onshore None verified location on pad map and wellhouse signage. 02/08/24 Initial wnsintegrity@conocophillips.com Wellbore Diagram Avail.? PLB 12/2015 CD2-22 initial suspended well inspection 2-9-24.xls Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 7178' SLM (7206' RKB) CD2-22 3/26/2023 oberr Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: State witnessed Tag / CMIT-IA CD2-22 3/26/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: Surface Casing Repair, Sleeve installed at the bottom of the starter head. 26" 9 5/8" X65.500 12/28/2013 lehallf NOTE: Tubing leak identified at 1,101' ELMD, located with Eline LDL 4/2/2012 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 14.69 37.0 114.0 114.0 109.00 H-40 WELDED SURFACE 9 5/8 8.92 36.8 2,381.7 2,380.5 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 7,845.2 7,182.5 26.00 L-80 MBTC OPEN HOLE 6 1/8 6.13 7,845.0 11,134.0 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.9 Set Depth … 7,321.9 Set Depth … 7,065.2 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.9 32.9 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 1,993.4 1,992.8 5.04 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 7,042.6 6,887.0 40.25 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 7,201.0 6,997.5 51.39 PACKER 5.970 BAKER S-3 PACKER BAKER S-3 3.875 7,204.8 6,999.9 51.67 MILLOUT 5.562 PACKER MILLOUT EXTENSION 3.958 7,309.4 7,059.0 59.69 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 7,320.7 7,064.6 60.70 WLEG 5.000 BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,101.0 1,100.9 0.72 LEAK - TUBING Spinner LDL found leak mid joint. 0.1 blm LLR 4/2/2012 0.000 3,125.0 3,123.7 0.59 LEAK - TUBING Spinner LDL found tubing leak 3/14/2018 0.000 7,206.0 7,000.6 51.75 PLUG Dump Bail 42 gallons of cement 2/28/2023 0.000 7,290.0 7,049.0 58.07 CEMENT RETAINER 12/23/2022 0.000 7,292.0 7,050.0 58.23 PLUG Pumped 172 bbls of 15.8 ppg cement for reservoir abandonment 12/23/2022 0.000 7,320.7 7,064.6 60.70 PLUG Pumped 172 bbls of 15.8 ppg cement for reservoir abandonment 12/23/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,042.6 6,887.0 40.25 1 GAS LIFT DMY BK 1 0.0 12/18/2016 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,845.0 7,182.5 87.89 OPEN HOLE 6.125 6.125 CD2-22, 6/10/2023 9:26:47 AM Vertical schematic (actual) OPEN HOLE; 7,845.0-11,134.0 PLUG; 7,320.7 PRODUCTION; 35.0-7,845.2 WLEG; 7,320.7 NIPPLE; 7,309.4 PLUG; 7,292.0 CEMENT RETAINER; 7,290.0 PLUG; 7,206.0 MILLOUT; 7,204.8 PACKER; 7,201.0 GAS LIFT; 7,042.6 LEAK - TUBING; 3,125.0 SURFACE; 36.8-2,381.7 NIPPLE; 1,993.4 LEAK - TUBING; 1,101.0 CONDUCTOR; 37.0-114.0 HANGER; 32.9 WNS INJ KB-Grd (ft) 43.71 RR Date 5/28/2002 Other Elev… CD2-22 ... TD Act Btm (ftKB) 11,134.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032042100 Wellbore Status INJ Max Angle & MD Incl (°) 92.95 MD (ftKB) 10,605.64 WELLNAME WELLBORECD2-22 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 1a. Well Status:Other Abandoned SuspendedSPLUGOil 1b. Well Class: 20AAC 25.105 20AAC 25.110 ExploratoryDevelopment WDSPLGINJ WINJ No. of Completions: ___________________Stratigraphic TestService 14. Permit to Drill Number / Sundry:6. Date Comp., Susp., or2. Operator Name: Aband.: 15. API Number:7. Date Spudded:3. Address: 16. Well Name and Number:8. Date TD Reached:4a. Location of Well (Governmental Section): Surface: 17. Field / Pool(s):9. Ref Elevations: KB:Top of Productive Interval: GL: BF: 18. Property Designation:10. Plug Back Depth MD/TVD:Total Depth: 19. DNR Approval Number:11. Total Depth MD/TVD:4b. Location of Well (State Base Plane Coordinates, NAD 27): Zone- 4Surface: 20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4TPI: Zone- 4Total Depth: 5. Directional or Inclination Survey: Yes (attached) No 21. Re-drill/Lateral Top Window MD/TVD:13. Water Depth, if Offshore: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 114'H-4016" 2380'J-559-5/8" 7182'L-807" 25.24. Open to production or injection? Yes No 26. NoWas hydraulic fracturing used during completion? Yes AMOUNT AND KIND OF MATERIAL USEDDEPTH INTERVAL (MD) 27. Method of Operation (Flowing, gas lift, etc.):Date First Production: Gas-MCF:Production forHours Tested: Test Period Oil Gravity - API (corr):Gas-MCF:CalculatedCasing Press: Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Colville River Field/ Alpine Oil Pool N/A Water-Bbl:Oil-Bbl: 42 gal. 15.8 ppg Class G Cement w/additives, dump bailed 172 bbls 15.8 ppg cement below retainer, 1 bbl7274'-11134' MD above retainer Water-Bbl: PRODUCTION TEST N/A Oil-Bbl:Date of Test: Flow Tubing 7178'- 7274' MD SUSPENDED Open Hole: 7845-11134' MD and 7183-7135' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 35'26# 62.5# 36# 114' 7845'35' DEPTH SET (MD)SIZE 7201' MD/ 6997' TVD PACKER SET (MD/TVD) 42" 12-1/4"37'350 sx AS III Lite, 230 sx Class G 37' 2382'37' 37' CASING WT. PER FT.GRADE 5/27/2002 CEMENTING RECORD 1652' MD/ 1652' TVD SETTING DEPTH TVD TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM 50-103-20421-00-00 CRU CD2-22 ADL380075, ADL0022530 1785' FNL, 1536' FEL, Sec. 2, T11N, R4E, UM 1598' FSL, 1034' FWL, Sec. 35, T12N, R4E, UM N/A 5/15/2002 11134' MD/ 7135' MD 7178' MD/ 6983' TVD P.O. Box 100360, Anchorage, AK 99510-0360 1531' FNL, 2525' FEL, Sec. 2, T11N, R4E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 202-092/ 322-5093/26/2023 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 165 sx Class G8-1/2" 7322' MD4-1/2" Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022 x- 371704 x- 370720 x- 369051 y-5974572 y- 5974843 y- 5978002 52.4' 22 yds Portland Type III By Grace Christianson at 9:12 am, Jun 21, 2023 Suspended 3/26/2023 JSB RBDMS JSB 062723 xGDSR-6/29/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface Top of Productive Interval 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Kate Dodson Digital Signature with Date:Contact Email: kate.dodson@conocophillips.com Contact Phone:(907) 265-6181 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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. TPI (Top of Producing Interval). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Formation Name at TD: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A Suspended Authorized Name and INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A Suspended Authorized Title: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 1652'1652' Digitally signed by Kate Dodson DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E=kate.dodson@conocophillips.com Reason: signing for Steve Drake Location: Date: 2023.06.20 15:49:57-08'00' Foxit PDF Editor Version: 12.1.2Kate Dodson Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 7178' SLM (7206' RKB) CD2-22 3/26/2023 oberr Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: State witnessed Tag / CMIT-IA CD2-22 3/26/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: Surface Casing Repair, Sleeve installed at the bottom of the starter head. 26" 9 5/8" X65.500 12/28/2013 lehallf NOTE: Tubing leak identified at 1,101' ELMD, located with Eline LDL 4/2/2012 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 14.69 37.0 114.0 114.0 109.00 H-40 WELDED SURFACE 9 5/8 8.92 36.8 2,381.7 2,380.5 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 7,845.2 7,182.5 26.00 L-80 MBTC OPEN HOLE 6 1/8 6.13 7,845.0 11,134.0 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.9 Set Depth … 7,321.9 Set Depth … 7,065.2 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.9 32.9 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 1,993.4 1,992.8 5.04 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 7,042.6 6,887.0 40.25 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 7,201.0 6,997.5 51.39 PACKER 5.970 BAKER S-3 PACKER BAKER S-3 3.875 7,204.8 6,999.9 51.67 MILLOUT 5.562 PACKER MILLOUT EXTENSION 3.958 7,309.4 7,059.0 59.69 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 7,320.7 7,064.6 60.70 WLEG 5.000 BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,101.0 1,100.9 0.72 LEAK - TUBING Spinner LDL found leak mid joint. 0.1 blm LLR 4/2/2012 0.000 3,125.0 3,123.7 0.59 LEAK - TUBING Spinner LDL found tubing leak 3/14/2018 0.000 7,206.0 7,000.6 51.75 PLUG Dump Bail 42 gallons of cement 2/28/2023 0.000 7,290.0 7,049.0 58.07 CEMENT RETAINER 12/23/2022 0.000 7,292.0 7,050.0 58.23 PLUG Pumped 172 bbls of 15.8 ppg cement for reservoir abandonment 12/23/2022 0.000 7,320.7 7,064.6 60.70 PLUG Pumped 172 bbls of 15.8 ppg cement for reservoir abandonment 12/23/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,042.6 6,887.0 40.25 1 GAS LIFT DMY BK 1 0.0 12/18/2016 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,845.0 7,182.5 87.89 OPEN HOLE 6.125 6.125 CD2-22, 6/20/2023 10:07:50 AM Vertical schematic (actual) OPEN HOLE; 7,845.0-11,134.0 PLUG; 7,320.7 PRODUCTION; 35.0-7,845.2 PLUG; 7,292.0 CEMENT RETAINER; 7,290.0 PLUG; 7,206.0 GAS LIFT; 7,042.6 LEAK - TUBING; 3,125.0 SURFACE; 36.8-2,381.7 NIPPLE; 1,993.4 LEAK - TUBING; 1,101.0 CONDUCTOR; 37.0-114.0 WNS INJ KB-Grd (ft) 43.71 RR Date 5/28/2002 Other Elev… CD2-22 ... TD Act Btm (ftKB) 11,134.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032042100 Wellbore Status INJ Max Angle & MD Incl (°) 92.95 MD (ftKB) 10,605.64 WELLNAME WELLBORECD2-22 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 1/17/2022 CHANGE WELL TYPE EQUALIZED & PULLED 3.81" XXN PLUG @ 7309' RKB. READY FOR COIL. 12/19/2022 CHANGE WELL TYPE TRAVEL FROM MT7 TO CD2-22 MIRU RIH W / 3.70" NZ FOR A DRIFT FOR CEMENT RETAINER CLEAN DRIFT **** JOB IN PROGRESS **** 12/20/2022 CHANGE WELL TYPE RAN IN HOLE W / CEMENT RETAINER TAGGED DB NIPPLE @ 1974 CTMD POOH AND RETAINER WAS GONE RIH HOLE W / A NOZZLE AND CONFIRMED RETAINER SET AT 1974' CTMD STBY FOR MILLS FROM QUADCO **** JOB IN PROGRESS**** 12/21/2022 CHANGE WELL TYPE RIH W / MOTOR & 3.70 MILL TAGGED RETAINER @ DB NIPPLE CAME ONLINE W / PUMP AND DID NOT SEE ANYTHING DRIFTED TO 7400' PAST XN @ 7309' POOH RBIH W / 3.80 MILL TAGGED XN @ 7284' CTMD PAINT A EOP FLAG 7282.7' POOH STBY FOR RETAINER INSTALL NIGHT CAP & PT **** JOB IN PROGRESS **** 12/22/2022 CHANGE WELL TYPE STBY FOR TOOLS FROM DEADHORSE 12/23/2022 CHANGE WELL TYPE RAN IN W / CEMENT RETAINER SET @ 7290' TOP OF RETAINER PERFORMED INJECTIVITY TEST 1 BPM 1664 % 1.5 BPM 2300 & 2 BPM 3000 PUMP 172 BBLS OF 15.8 PPG OF CEMENT BELOW RETAINER LAID 1 BBL ON TOP OF RETAINER C/O & FREEZE PROTECT W /38 BBLS OF DIESEL POOH RDMO ***READY FOR SLICKLINE*** 12/30/2022 CHANGE WELL TYPE PERFORM STATE WITNESSED TAG OF CEMENT @ 7274' SLM - RECOVER SAMPLE OF CEMENT. LRS PERFROM WITNESSES CMIT-TxIA TO 2500 PSI - ****PASSED**** 1/22/2023 OPTIMIZE WELL START STATIC BHP GAUGE RUN 1/23/2023 OPTIMIZE WELL PERFORM SBHPS AT 7272' SLM. MAX PRESSURE 3900 PSI, MAX TEMP 151 DEGF. JOB COMPLETE 2/25/2023 CHANGE WELL TYPE MADE 4- 10' DUMP BAILER RUNS. APPROX. 8 GALLONS DUMPED STARTING @ 7257' SLM, LAST MD TAGGED 7255' SLM. JOB IN PROGRESS. 2/26/2023 CHANGE WELL TYPE MADE 6- 10' DUMP BAILER RUN APPROX 12 GALLONS DUMPED, ESTIMATED TOP @ 7237'. JOB IN PROGRESS 2/27/2023 CHANGE WELL TYPE MADE 5 DUMP BAILER RUNS APPROX 10 GALLONS DUMPED. ESTIMATED TOP @ 7218'. JOB IN PROGRESS. 2/28/2023 CHANGE WELL TYPE MADE 6 DUMP BAILER RUNS APPROX 12 GALLONS DUMPED. ESTIMATED TOP @ 7191' SLM. READY FOR SW TAG & CMIT-IA IN 72 HOURS. JOB IN PROGRESS. 3/26/2023 CHANGE WELL TYPE TAG HARD CEMENT (STATE WITNESSED BY ADAM EARL) W/ 3" DRIVE DOWN BAILER @ 7178' SLM. LRS PERFORM STATE WITNESSED CMIT-TxIA TO 2500 PSI ***PASSED****. IN PROGRESS. CD2-22 Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:2 Township:11N Range:4E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:11134 ft MD Lease No.:ADL 0380075 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 114 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 2382 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 7845 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:4 1/2"O.D. Tail@ 7322 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 7289 ft 7178 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 2620 2580 2580 IA 2580 2560 2545 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Perry Kline Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to CRU CD2-22 to witness a CMIT-TxIA along with a wireline tag of top of cement (TOC). The plug tag was completed first with the tool string made up of 10 feet of 2 1/8" w-bar, spangs, and 5 feet of 3-inch bailer (335lbs of hanging weight). Tagged TOC @7,178 ft MD - good solid tag. Bailer had just an inch of hard cement from tag. Most of the bailer was empty which tells me the cement was nice and hard. March 26, 2023 Adam Earl Well Bore Plug & Abandonment CRU CD2-22 ConocoPhillips Alaska PTD 2020920; Sundry 332-509 none Test Data: P Casing Removal: rev. 3-24-2022 2023-0326_Plug_Verification_CRU_CD2-22_ae               MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 2 Township: 11N Range: 4E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 11134 ft MD Lease No.: ADL 380075 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 114 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2382 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 7845 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 7322 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 11134 ft 7274 ft 6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2720 2640 2621 IA 2723 2642 2618 OA 67 66 66 Remarks: Attachments: Brendan Weimer Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Reservoir suspension plug. Traveled to location to witness the tag of a cement plug that was founded on bottom and brought up into the well's 4.5 inch tubing. Combo mechanical integrity test of the tubing and inner annulus (CMIT TxIA) was to follow. Common 2.5 inch bailer assembly was used for the tag. Top of cement (TOC) was found at 7,274 ft (inclination 59°) with multiple set downs. This put the cement only 16 feet above the retainer set at 7,290 ft. Cement interface/washup was observed in the bailer once out of the hole. A passing CMIT TxIA was then done to a target of 2500 psi. AOGCC granted a variance to the retainer set depth allowing it to be placed in the tubing ~ 556 ft above the open hole section. I did not find where any approval was given to not have a 50 ft cap of cement on the retainer. Operator' field procedure was oddly worded on their cementing schedule: "With one barrel of cement remaining in coil, un-sting from the retainer and lay the last 3 barrels on the retainer". Sundry approval says lay 1 barrel cement on retainer which would give 65 ft cap. December 30, 2022 Austin McLeod Well Bore Plug & Abandonment Colville River Unit CD2-22 ConocoPhillips Alaska, Inc. PTD 2020920; Sundry 322-509 Excerpt from Operator Field Procedure Test Data: P Casing Removal: rev. 11-28-18 2022-1230_Plug_Verification_CRU_CD2-22_am Common 2.5 inch bailer assembly was used for the tag. Top of cement (TOC) was found at 7,274 ft (inclination 59°) with multiple 16 feet above the retainer set at 7,290 ft. bailer once out of the hole. A passing CMIT TxIA was then done to a target of 2500 psi. AOGCC granted a variance to the I did not find where any approval retainer set depth allowing it to be placed in the tubing ~ 556 ft above the open hole section. was given to not have a 50 ft cap of cement on the retainer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y Anne Prysunka at 3:46 pm, Aug 25, 2022 Travis Smith Digitally signed by Travis Smith Date: 2022.08.25 13:46:22 -08'00' ; '65'/% $$& F' K ; $YDULDQFH LV JUDQWHG WR DOORZ WKH SODFHPHQW RI WKH FHPHQW UHWDLQHU DW DSSUR[LPDWHO\ 0' DERYH WKH RSHQ KROH 97/ ; GWV Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.09.06 14:38:54 -08'00' RBDMS JSB 090722 ϮͲϮϮ^ƵƐƉĞŶƐŝŽŶ WĂŐĞϭ ĂƚĞ͗ ƵŐƵƐƚϮϰ͕ϮϬϮϮ ^ƵďũĞĐƚ͗ ϮͲϮϮ^ƵƐƉĞŶƐŝŽŶ^ƵŶĚƌǇKǀĞƌǀŝĞǁ WƌĞƉĂƌĞĚǇ͗dƌĂǀŝƐ^ŵŝƚŚ͕ϲϳϬͲϰϬϭϰ KďũĞĐƚŝǀĞ ϮͲϮϮŝƐĂŶůƉŝŶĞŝŶũĞĐƚŽƌŽƌŝŐŝŶĂůůǇĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝ ŶϮϬϬϮ͘dŚĞǁĞůůǁĂƐƐŚƵƚͲŝŶĚƵĞ ƚŽƚƵďŝŶŐůĞĂŬƐŝŶϮϬϭϮĂŶĚŚĂƐƌĞŵĂŝŶĞĚŽĨĨůŝŶĞƐŝŶĐĞ͘dŚĞůƉŝŶĞƌĞƐĞƌǀŽŝƌŚĂƐŶŽĞĐŽŶŽŵŝĐ ǀĂůƵĞƐƵĨĨŝĐŝĞŶƚƚŽũƵƐƚŝĨǇƌĞƉĂŝƌ͘dŚĞĨŽůůŽǁŝŶŐŽǀĞƌǀŝĞǁĚĞƐĐƌŝďĞƐĂƉƌŽƉŽƐĞĚƐƵƐƉĞŶƐŝŽŶŽĨ ƚŚĞǁĞůů͘ /ŶƚŚŝƐƉƌŽĐĞĚƵƌĞ͕ƚŚĞƌĞƐĞƌǀŽŝƌĐĞŵĞŶƚƉůƵŐŝƐƉůĂĐĞĚǁŝƚŚĂĐĞŵĞŶƚƌĞƚĂŝŶĞƌƐĞƚϱϱϲ͛ĂďŽǀĞ ƚŚĞƚŽƉŽĨƚŚĞŽƉĞŶŚŽůĞƐĞĐƚŝŽŶŽĨƚŚĞǁĞůů͕ŝŶĞǆĐĞƐƐŽĨƚŚĞƐƉĂĐŝŶŐƐƚŝƉƵůĂƚĞĚďǇϮϬ Ϯϱ͘ϭϭϮ͘ŶĞǆĐĞƉƚŝŽŶŝƐƌĞƋƵĞƐƚĞĚŝŶƚŚŝƐĐĂƐĞŝŶŽƌĚĞƌƚŽƉůĂĐĞƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌǁŝƚŚŝŶƚŚĞ ϰͲϭͬϮ͟ƚƵďŝŶŐ͕ƌĂƚŚĞƌƚŚĂŶƵƐŝŶŐĂŶŝŶĨůĂƚĂďůĞƌĞƚĂŝŶĞƌƐĞƚďĞů ŽǁƚŚĞƚƵďŝŶŐƚĂŝůŝŶƚŚĞϳ͟ĐĂƐŝŶŐ͘ WƌŽĐĞĚƵƌĞ ^ůŝĐŬůŝŶĞ ϭ͘ƋƵĂůŝǌĞĂŶĚƉƵůůyyEƉůƵŐĨƌŽŵϳ͕ϯϬϵ͛Z<͘ Ϯ͘ƌŝĨƚƚƵďŝŶŐĨŽƌĐĞŵĞŶƚƌĞƚĂŝŶĞƌƚŽƚŚĞyEEŝƉƉůĞĂƚϳ͕ϯϬϵ͛Z<͘ ŽŝůĞĚdƵďŝŶŐ ϭ͘^ĞƚϰͲϭͬϮ͟ĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂƚϳ͕Ϯϴϵ͛Z<͗ŝŶƚŚĞŵŝĚĚůĞŽĨƚŚĞĨŝƌƐƚĨƵůůũŽŝŶƚŽĨƚƵďŝŶŐ ĂďŽǀĞƚŚĞyEͲŶŝƉƉůĞ͘ Ϯ͘WĞƌĨŽƌŵD/dͲdǆ/ƚŽǀĞƌŝĨǇĐĞŵĞŶƚƌĞƚĂŝŶĞƌŝŶƚĞŐƌŝƚǇ;ŵƵůƚŝƉůĞƚƵďŝŶŐŚŽůĞƐǁŝůůƉƌĞǀĞŶƚ ĂŶD/dͲdĨƌŽŵƉĂƐƐŝŶŐͿ͘ ϯ͘WƵŵƉŝŶŐĚŽǁŶĐŽŝůƚŚƌŽƵŐŚƚŚĞƌĞƚĂŝŶĞƌ͕ƉĞƌĨŽƌŵŝŶũĞĐƚŝǀŝƚǇƚĞƐƚƚŽǀĞƌŝĨǇĂĚĞƋƵĂƚĞ ŝŶũĞĐƚŝǀŝƚǇĨŽƌĐĞŵĞŶƚŝŶŐ͘ ϰ͘WƵŵƉŝŶŐĚŽǁŶĐŽŝůƚŽĨŽƌŵĂƚŝŽŶ͕ƉƵŵƉƚŚĞĨŽůůŽǁŝŶŐƐĐŚĞĚƵůĞƚŚƌŽƵŐŚƚŚĞƌĞƚĂŝŶĞƌ͘ tŝƚŚŽŶĞďĂƌƌĞůŽĨĐĞŵĞŶƚƌĞŵĂŝŶŝŶŐŝŶĐŽŝů͕ƵŶͲƐƚŝŶŐĨƌŽŵƚŚĞƌĞƚĂŝŶĞƌĂŶĚůĂǇƚŚĞůĂƐƚ ďĂƌƌĞůŽŶƚŚĞƌĞƚĂŝŶĞƌ͘ Ă͘ϱďďůƐĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌ ď͘ϭϳϬďďůƐϭϱ͘ϴηůĂƐƐ'ĐĞŵĞŶƚ Đ͘ϱďďůƐĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌ Ě͘ŽŝůĚŝƐƉůĂĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ ^ůŝĐŬůŝŶĞͬ&ƵůůďŽƌĞ ϭ͘dĂŐƚŚĞĐĞŵĞŶƚƚŽƉĂďŽǀĞƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘WƌŽǀŝĚĞϮϰͲŚŽƵƌŶŽƚŝĨŝĐĂƚŝŽŶĨŽƌK' ǁŝƚŶĞƐƐ͘ Ϯ͘WĞƌĨŽƌŵK'ͲǁŝƚŶĞƐƐĞĚD/dͲdǆ/ƚŽϮ͕ϱϬϬƉƐŝĂďŽǀĞƚŚĞĐĞŵĞŶƚ͘ ϮͲϮϮ^ƵƐƉĞŶƐŝŽŶ WĂŐĞϮ ϮͲϮϮ^ƵƐƉĞŶƐŝŽŶ WĂŐĞϯ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRW FOLFNOLQNVRURSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQW LVVDIH )URP6PLWK7UDYLV7 7R/RHSS9LFWRULD72*& 6XEMHFW5(>(;7(51$/@&58&'37'6XQGU\$EDQGRQPHQW 'DWH7KXUVGD\$XJXVW30 $WWDFKPHQWVLPDJHSQJ ,ĞůůŽsŝĐƚŽƌŝĂͶ WĞƌŽƵƌĐŽŶǀĞƌƐĂƚŝŽŶ͕ǁĞŚĂǀĞƌĞͲƐƵďŵŝƚƚĞĚĂϭϬͲϰϬϯĨŽƌƚŚŝƐǁĞůůĚĞƐŝŐŶĞĚŶŽǁĂƐĂƐƵƐƉĞŶƐŝŽŶ ƌĂƚŚĞƌƚŚĂŶĂĨƵůůWΘ͘dŚŝƐĂƉƉůŝĐĂƚŝŽŶǁĂƐƐƵďŵŝƚƚĞĚƚŽƚŚĞK'ĞĂƌůŝĞƌƚŽĚĂǇ͘ ^ĞĞĂůƐŽŵǇĂŶƐǁĞƌƐďĞůŽǁ͘ dŚĂŶŬƐ͕ dƌĂǀŝƐ &ƌŽŵ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭϱ͕ϮϬϮϮϭϭ͗ϱϵD dŽ͗^ŵŝƚŚ͕dƌĂǀŝƐdфdƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁ZhϮͲϮϮ;WdϮϬϮͲϬϵϮ͕^ƵŶĚƌǇϯϮϮͲϰϭϰͿďĂŶĚŽŶŵĞŶƚ CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. dƌĂǀŝƐ͕ WůĞĂƐĞƉƌŽǀŝĚĞĐĞŵĞŶƚŝŶĨŽŽŶƚŚĞϳ͟ĐĂƐŝŶŐ͘ dŚĞϳ͟ǁĂƐĐĞŵĞŶƚĞĚǁŝƚŚϭϲϬƐĂĐŬƐŽĨůĂƐƐ'ĐĞŵĞŶƚ͘/ŶŝƚŝĂůĐĂůĐƵůĂƚŝŽŶƐǁĞƌĞŵĂĚĞĂƐƐƵŵŝŶŐ ϰϬйĞǆĐĞƐƐ͘/ĨƚŚĂƚŝƐĂŐŽŽĚĂƐƐƵŵƉƚŝŽŶĨŽƌŚŽůĞǀŽůƵŵĞǁĂƐŚŽƵƚ͕ƚŚĞĐĞŵĞŶƚũŽďǁŽƵůĚŚĂǀĞ ƌĞĂĐŚĞĚϲ͕ϵϬϱ͛DĨŽƌƚŚĞϳ͘͟dŚĞ>ŽŶƚŚŝƐǁĞůůǁĂƐƉĞƌĨŽƌŵĞĚĂĨƚĞƌƚŚĞǁĞůůǁĂƐĐŽŵƉůĞƚĞĚ ǁŝƚŚƚƵďŝŶŐ͕ƐŽƚŚĞĐĞŵĞŶƚǁĂƐŽŶůǇŝŶƐƉĞĐƚĞĚďĞŶĞĂƚŚƚŚĞƚƵďŝŶŐƚĂŝů͘dŚĞ>͞ĨŽƵŶĚĞǆĐĞůůĞŶƚ ĐĞŵĞŶƚĨƌŽŵĨŝƌƐƚƌĞĂĚŝŶŐĂƚϳ͕ϰϴϴ͛ƚŽϳ͕ϯϯϰ͕͛ƚŚĞŶĨƌŽŵϳ͕ϯϮϰ͛ƚŽƚƵďŝŶŐƚĂŝůĂƚϳ͕ϯϭϴ͛͘͟ WůĞĂƐĞƉƌŽǀŝĚĞĚĞƉƚŚƐŽĨĂůůŚǇĚƌŽĐĂƌďŽŶďĞĂƌŝŶŐǌŽŶĞƐ͘ hƉĚĂƚĞƐĐŚĞŵĂƚŝĐǁŝƚŚƚŚŝƐŝŶĨŽƌŵĂƚŝŽŶ͘ ^ĞĞƐĐŚĞŵĂƚŝĐŝŶƌĞǀŝƐĞĚ^ƵƐƉĞŶƐŝŽŶϭϬͲϰϬϯĂƉƉůŝĐĂƚŝŽŶ͘ tŚĂƚŝƐƚŚĞƉƌŽďůĞŵǁŝƚŚƐĞƚƚŝŶŐĂŶŝŶĨůĂƚĂďůĞƉĂĐŬĞƌŝŶƚŚĞϳ͟ĐĂƐŝŶŐ͍ dŚĞŝŶĨůĂƚĂďůĞƌĞƚĂŝŶĞƌŝƐĂŵŽƌĞƉƌŽďůĞŵͲƉƌŽŶĞƉŝĞĐĞŽĨĞƋƵŝƉŵĞŶƚ͘hƐŝŶŐŽŶĞŝŶĐƌĞĂƐĞƐƚŚĞ ĐŚĂŶĐĞƐŽĨĂůĞĂŬŝŶŐƌĞƚĂŝŶĞƌŽƌŽƚŚĞƌŽƉĞƌĂƚŝŽŶĂůŝƐƐƵĞƐ͘tŚŝůĞƚŚĞŝŶĐƌĞŵĞŶƚĂůƌŝƐŬŝƐƉƌŽďĂďůǇŶŽƚ ǀĞƌǇůĂƌŐĞ͕/ĚŽŶ͛ƚďĞůŝĞǀĞŝƚ͛ƐǁŽƌƚŚƚŚĞŝŶĐƌĞŵĞŶƚĂůƌŝƐŬƚŽŐĂŝŶĂĨĂŝƌůǇƐŵĂůůŵĞĂƐƵƌĞĚĚĞƉƚŚ ĂĚǀĂŶƚĂŐĞǀĞƌƐƵƐĂϰͲϭͬϮ͟ƌĞƚĂŝŶĞƌ͘ sŝĐƚŽƌŝĂ Victoria Loepp 6HQLRU3HWUROHXP(QJLQHHU 6WDWHRI$ODVND 2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ :WK$YH $QFKRUDJH$. :RUN 9LFWRULD/RHSS#DODVNDJRY CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov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y Samantha Carlisle at 4:33 pm, Apr 05, 2021 321-163 Travis T. Smith Digitally signed by Travis T. Smith Date: 2021.04.05 15:17:13 -08'00' X -00 X DSR-4/5/21 10-407 SFD 4/5/2021 SFD 4/5/2021 X AOGCC inspection is required after cutoff and before any remedial cementing. A variance to 20 AAC 25.112 is granted to allow the cement retainer for the reservoir plug to be placed ~556' above the open hole section in the 4-1/2" tubing instead of an inflatable retainer set below the tubing tail in the 7" casing. VTL 5/3/21" 5/3/21 dts 5/3/2021 JLC 5/3/2021 RBDMS HEW 5/3/2021 CD2-22 P&A Page 1 Date: March 19, 2021 Subject: CD2-22 P&A Sundry Overview Prepared By: Travis Smith, 670-4014 Objective CD2-22 is an Alpine injector originally drilled and completed in 2002. The well was shut-in due to tubing leaks in 2012 and has remained offline since. The well has no economic value sufficient to justify repair. The following overview describes a proposed full P&A of the well. In this procedure, the reservoir cement plug is placed with a cement retainer set 556’ above the top of the open hole section of the well, in excess of the 500’ stipulated by 20 AAC 25.112. An exception is requested in this case in order to place the cement retainer within the 4-1/2” tubing, rather than using an inflatable retainer set below the tubing tail in the 7” casing. Procedure Slickline 1. Equalize and pull XXN plug from 7,309’ RKB. 2. Drift tubing for cement retainer to the XN Nipple at 7,309’ RKB. E-line 1. Set 4-1/2” cement retainer at 7,289’ RKB: in the middle of the first full joint of tubing above the XN-nipple. Coiled Tubing 1. Make up stinger for 4-1/2” cement retainer. Run in hole and latch retainer. Perform CMIT-TxIA to verify cement retainer integrity (multiple tubing holes will prevent an MIT- T from passing). 2. Pumping down coil through the retainer, perform injectivity test to verify adequate injectivity for cementing. 3. Pumping down coil to formation, pump the following schedule through the retainer. With one barrel of cement remaining in coil, un-sting from the retainer and lay the last barrel on the retainer. a. 5 bbls freshwater spacer b. 170 bbls 15.8# Class G cement c. 5 bbls freshwater spacer d. Coil displacement to surface Slickline / Fullbore the reservoir cement plug is placed with a cement retainer set 556’ above the top of the open hole section of the well, in excess of the 500’ stipulated by 20 AAC 25.112. An exception is requested in this case well has no economic value sufficient to justify repair. in order to place the cement retainer within the 4-1/2” . tubing, rather than using an inflatable retainer set below the tubing tail in the 7” casing. CD2-22 P&A Page 2 1. Tag the cement top above the cement retainer. Provide 24-hour notification for AOGCC witness. 2. Perform AOGCC-witnessed CMIT-TxIA to 2,500 psi above the cement. E-line 1. Make up toolstring for 5’ tubing punch. Run in hole and punch tubing from approximately 7,170’ – 7,175’ MD: in the middle of the first full joint of tubing above the S-3 packer. Refer to the slickline tag above, this depth may need to be adjusted based on the cement top. Coiled Tubing 1. Make up nozzle BHA for cementing. Condition hole while running in, fluid packing both the tubing and IA and confirming good returns to surface from both. Park nozzle at 7,165’, just above the tubing punch. 2. Pump the following surfactant wash to clean up the IA. Pump down coil, holding the CT x tubing annulus shut-in and taking returns up the IA. a. 50 bbls surfactant wash: freshwater + surfactant b. 135 bbls seawater to flush the IA c. Coil volume of seawater for displacement 3. Rig up cementers to pump down coil, mixing cement on the fly. Pump the following cement to place an intermediate cement plug from the production packer to 1,000’ MD in both the tubing and IA. a. Pump down coil with both the tubing and IA open at surface. Allow the cement to lay in both the IA and tubing, u-tubing through the tubing punches and tubing leaks. When cement first reaches the nozzle in coil begin pulling up hole with coil, matching the speed of coil to the fill-up rate of the TxIA. i. 5 bbl freshwater spacer ii. 210 bbl Class G cement iii. 5 bbl freshwater spacer iv. Coil displacement volume b. Rig down, shut in the IA and tubing with equalized pressure—do not trap pressure on tubing or IA if possible. Slickline 1. Tag the cement top in the tubing (designed top at approximately 1,000’). E-line 1. Make up toolstring for perforating 4-1/2” tubing and 7” casing. Run in hole and perforate at approximately 950’ – 960’ (refer to the slickline tag of the cement plug, depths may need to be adjusted up or down). Tag the cement top above the cement retainer. Provide 24-hour notification for AOGCC witness. 2.Perform AOGCC-witnessed CMIT-TxIA to 2,500 psi above the cement. at ~7289' MD CD2-22 P&A Page 3 Fullbore 1. Rig up to pump down the tubing, taking returns from both the IA and OA. a. Holding the OA shut-in, confirm circulation through the perforations to the IA by pumping down tubing taking returns from the IA. b. Holding the IA shut-in, confirm circulation through the perforations to the OA by pumping down tubing taking returns from the OA. 2. Once circulation paths are confirmed, pump the following surfactant wash. a. Holding the IA shut-in, pump surface to surface out the OA: i. 30 bbls hot diesel ii. 17 bbls seawater iii. Shut down for one hour to let diesel soak in OA iv. 25 bbls surfactant wash: freshwater + surfactant v. 45 bbls seawater or brine displacement b. Open the IA and shut-in the OA. Pump the following to clean up the IA: i. 15 bbls surfactant wash: freshwater + surfactant ii. 35 bbls seawater or brine displacement 3. Rig up cementers to pump down the tubing and take returns from the IA and OA. Start pumping with the OA open and the IA shut-in. Once clean cement is seen returning from the OA (should be at surface with 43 bbls cement away), open the IA and shut-in the OA. When clean cement is seen at the IA, shut down and close in the IA and tubing. a. 5 bbls MeOH b. 5 bbls freshwater spacer c. 75 bbls Class G cement Well Integrity 1. Excavate and cut-off all casings and wellhead 3’ below original tundra level. Top job all annuli and tubing with cement as needed. 2. Notify the AOGCC to witness cement tops in all annuli. Photo document the cut-off wellhead prior to the cap. 3. Bead weld marker cap on outermost casing string (16” Conductor) to read as follows— photo document the marker cap after installation: ConocoPhillips Alaska, Inc. CD2-22 PTD # 202-092 API # 50-103-20421-00 AOGCC inspection is required after cutoff and before any remedialcementing. CD2-22 P&A Page 4 CD2-22 P&A Page 5 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD2-22 haggea Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: T/S AnnComm 3/14/2018 CD2-22 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 14.69 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 109.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.8 Set Depth (ftKB) 2,381.7 Set Depth (TVD) … 2,380.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 7,845.2 Set Depth (TVD) … 7,182.5 Wt/Len (l… 26.00 Grade L-80 Top Thread MBTC Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) 6.13 Top (ftKB) 7,845.0 Set Depth (ftKB) 11,134.0 Set Depth (TVD) … Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.9 Set Depth (ft… 7,321.9 Set Depth (TVD) (… 7,065.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.9 32.9 0.00 HANGER FMC TUBING HANGER 4.500 1,993.4 1,992.8 5.04 NIPPLE CAMCO DB NIPPLE 3.812 7,201.0 6,997.5 51.39 PACKER BAKER S-3 PACKER 3.875 7,204.8 6,999.9 51.67 MILLOUT PACKER MILLOUT EXTENSION 3.958 7,309.4 7,059.0 59.69 NIPPLE HES XN NIPPLE 3.725 7,320.7 7,064.6 60.70 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,309.4 7,059.0 59.69 PLUG 3.813" XXN Plug OAL=55" 3/11/2018 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,042.6 6,887.0 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 12/18/2016 Notes: General & Safety End Date Annotation 12/28/2013 NOTE: Surface Casing Repair, Sleeve installed at the bottom of the starter head. 26" 9 5/8" X65.500 4/2/2012 NOTE: Tubing leak identified at 1,101' ELMD, located with Eline LDL 8/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 CD2-22, 3/24/2021 3:48:00 PM Vertical schematic (actual) OPEN HOLE; 7,845.0-11,134.0 PRODUCTION; 35.0-7,845.2 WLEG; 7,320.7 PLUG; 7,309.4 NIPPLE; 7,309.4 MILLOUT; 7,204.8 PACKER; 7,201.0 GAS LIFT; 7,042.6 SURFACE; 36.8-2,381.7 NIPPLE; 1,993.4 CONDUCTOR; 37.0-114.0 HANGER; 32.9 WNS INJ KB-Grd (ft) 43.71 Rig Release Date 5/28/2002 CD2-22 ... TD Act Btm (ftKB) 11,134.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032042100 Wellbore Status INJ Max Angle & MD Incl (°) 92.95 MD (ftKB) 10,605.64 WELLNAME WELLBORECD2-22 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CNi o) s a) 0 _ M If) c ~ > ,^ ,a P P P P P P T T T Y e , Q O N2 `v CA 4" > CO h H. CO 4- 75 r0 a) c > +' It 0 0 0 o > co c LA.) / a c > Q J w CO CO CO CO CO co CO co co a'' a) '- Oa 6 c0 C.0 P 4 4 4. E - L a O 0a O R m` `a ca R rO <O ra ro G F- 4 f` N M a t0 1.-- 0 4U'' - C N O O z Z CZ U a) \ U CU > C ' a) O c i Hr,-. - N C u +-' rO o 0 0 0 0 0 0 0 0 0 c v v 0 w J J J J J J J J J CA O } W W W W W W W W W �C U 4- F- LL LL LL LL LL LL LL LL LL a-+ aJ a) CU 'O fi a J J J J J J J J J > +L+ F" Q a a a a Q a Q a O azzzzzzzzz o 0 45 c: LL LL LL LL LL LL LL LL LL _c Q > C 0 Y > 4-1 a) } a LC 111 O _0 C v U o Z Q a) u a) _ 7, o c o „ w c>o • C E P. E Ti) Y U L C f9o I__ CCO a O O Co ,r V J J < a) a en c a C U N LL L LL ` L C w 3 O d F-- illJ J d O O LL G a LL N Q- 0 0 Q m U U U J J U g- vi 8 Q a� � a a 044 U IV o c °1 O > � , a N rn m o +� lC . a > Y (�� 0 0+, F) 172 N — L W _ �� VV a '+. 15 M E.' CO 0 1 LAI ea O U ea y U z m p w 'O 0 z � u . C J J J J J J J J J z O 3 y Q < 1.9 a M Q w 0 3 3 aL. ) CVtlyN w ha CU -0 VIII W W W W W W W W W M► 3 00 in CD z W W W W W W W W 11.1 • - 00 0 J J J J J J J J J • Q W w > > > > > > > > > a o _ ry J J J J J J J J Ju 0 0 0 0 0 0 0 0 0 0 0 0 O 00000000 c u c o r o 'won ra 0 W tV v x n — (dj m O w N M N Co ti Q V N O O N M co O O O OL cc 0 0 0 0 0 0 •T O O O O O O O O O v r ts Q O O O O O O O O O .1C W +� 5 aaaaaa n) t th L. • v m m m m m m O O p > F- F- F - F- F- N rn V) @ fie w 0 0 0 0 0 0 0 0 0 C O x `^ - F CD u E win _ h 0 :. 0 0 T 0 0 0 0 0 n0 O 0 0 0 O O O O ao a' O CON O) O) P h 'y)g. E W co 0) 0) CO N N 0) N 01 1.0 ` O N 0 0 0 O O 'Cr 0 0 0 O 0 N N N N N N N N N N L Q 1� r M M M M M M M M a) U) b O O O O O O O O ' � CJl . . . . . T O O O O o O O O O 4-1 C ,., to N N )n N N to In N a uu C cc Z a, E •a) •5 +U-. an � � Qg w C C .� v� F- N N N a a sn N N tO N CD -I a) 7 a z Q O co p0/ e11 irjH c +. a 0 C/� a Q �J� It a E. G Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 20.2:- °9:l.'well History File Identifier Organizing (done) RE~N V~ Color items: ( Grayscale items: 0 Poor Quality Originals: ~scan Needed OVERSIZED (Scannable) 0 Two~Sided DI~AL DATA V Diskettes, No. Other, Norrype 1 0 Maps: Other items scannable by large scanner 0 0 0 Other: OVERSIZED (Non-Scannable) 0 Logs of various kinds NOTES: BY: BEVERLY ROBIN VINCENT SHERYLAWINDY 0, Other J f DATE: 1 :J: rtf!SI \1\1-2 Project Proofing BEVERLY ROBIN VINCENT SHERYL MARIA WINDY ! . DATE: 1 !). DlI'!S! BY: mP 07 vwP ~.vu p~ ~ ./ YES PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:~ . NOI1 SEVERL y ROBIN VINCENT SHERYL~ WINDY DATE: ~,;;J3, ötf Isl ~ í IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO Scanning Preparation :~ . 7 = TOTAL PAGES , . þ-"". .. DATE:, ~tIflSI C¡tJ x 30 = + BY: BEVERLY ROBIN VINCENT SHERYL .9vINDY Production Scanning 0'6 Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY Is/ DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (iH(JÍI'idcwf fn~r: [:;par.ial ,1ft()l)li(¡fI} ,scðlming ¡;pmplnlod) RESCANNED Bt: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ General Notes or Comments about this file: Quality Checked (dOI(;'\ 12/1 O/02Rev3NOTScanned, wpd ~ -..!1 !i J'l~~ 1;;- ~¡ '\ rÈ ~V w w��\ s THE STATE Alaska Oil and Gas °fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFALAS�� Anchorage Main:907 279.1433 SCANNED HC P: 13 2013 Fax: 907.276.7542 S Martin Walters U Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-22 Sundry Number: 313-531 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster ��A Chair, Commissioner DATED this J4 dray of October, 2013. Encl. STATE OF ALASKA t AIL OIL AND GAS CONSERVATION COM ION V*.4) APPLICATION FOR SUNDRY APPROVALS tk OCT Q 9 20133 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair well r Change Appr. -#nw Suspend r Rug Perforations r Perforate \\Fka5Tubing r e swl� Operational Shutdown r Re-enter Susp.Well r Stimulate �Selter casing r Other: SC Repair r i 2.Operator Name: 4.Current Well Class: \Q\ 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 202-092 3.Address: Stratigraphic r Service F,, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20421-00• 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p-' CD2-22 " 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380075 ‘ Colville River Field/Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11134 • 7135 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' 1640 630 SURFACE 2345 9.625 2382' 2381' 3520 2020 PRODUCTION 7810 7 7845' 7183' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): NA NA 4.5 L-80 7321 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER S-3 PACKER MD=7201 TVD=6998• SSSV-CAMCO"DB"NIPPLE MD= 1993 ND= 1993• 12.Attachments: Description Summary of Proposal • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r: • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Octover 15, 2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG p• Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers/Kelly Lyons Email: n1878(a)_cop.com Printed Name /7,416(4t Martin Walters Title: Problem Wells Supervisor Signature Mtli'� Phone:659-7224 Date: 10/04/13 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ' kZJ' 5 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes 0 No Subsequent Form Required: /0 — 4.04 APPROVED BY Approved by: 2(te441 - COMMISSIONER THE COMMISSION Date: ID -/ 4 -1 Approved application is valid for 12 months from the date of approval. Form 10-403(Revi ed 10/2012) ORIGINAL / '01, /6 ttachrpe�r]t�jgQyp ateuCT 1 1 v� /a/6)/13 / /91/ J�[CSP�M Ul • • RECEIVED ✓ OCT 0 9 2013 ConocoPhillips Alaska A G C P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 4, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD2-22, PTD 202-092 surface casing inspection and repair. Please contact MJ Loveland or me at 659-7043 if you have any questions. Sincerely, `fi(kea!�t i — Martin Walters ConocoPhillips Well Integrity Projects Supervisor ' • • ConocoPhillips Alaska,Inc. Alpine Well CD2-22 (PTD 202-092) SUNDRY NOTICE 10-403 APPROVAL REQUEST October 4, 2013 This application for Sundry approval for Alpine well CD2-22 is for the inspection and repair of surface casing. This well was determined to have 59%wall loss in the surface casing after cutting conductor windows during an inspection. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s)and/or BPV. 2. Remove the floor grate,well house,flow lines,or other equipment from around the wellhead as needed. 3. Excavate around the wellhead as necessary to achieve an adequate depth. 4. Install nitrogen purge equipment for the conductor(and OA if needed)so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection(already completed). Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill with gravel and reinstall cellar as needed around the wellhead. 12. Remove plug(s)and/or BPV and return the well to injection. 13. File 10-404 with the AOGCC post repair. Well Integrity Project Supervisor 10/4/2013 WNS • CD2-22 COnOcOPhillipS Well Attributes Max Angle&MD TD Inc Wellborn API/UWI Field Name Well Status Inc!C) MD(ft(B) Act Btm(ftKB) Alaska. «><,«,»n,ll,p, 501032042100 ALPINE INJ 92.95 10,605.64 11,134.0 Comment H2S(ppm) Dab Annotation End Date KB-Ord(ft) Rig Release Date SSSV:NIPPLE Last WO: 43.71 5/27/2002 Well Cont g:-CD2-22,3/5/2012 7:51:17 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SET PLUG ninam 3/5/2012 Casing Strings .,;. Casing Description String 0... String ID...'Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd k%' CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 WELDED HANGER,33 ; , CasIng Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)--.String Wt...String-..String Top Thrd SURFACE 95/8 8.921 36.8 2,381.7 2,380.5 36.00 J-55 BTC Casing Description String 0--. String ID...Top(ttKB) Set Depth(f...Set Depth(TVD).-.String Wt...String...String Top Thrd ,# p PRODUCTION 7 6.276 35.0 7,845.2 7,182.6 26.00 L-80 MBTC Casing Description String 0... String ID...Top(tIKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd OPEN HOLE 61/8 6.125 7,845.0 11,134.0 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 41/2 3.958 32.9 7,321.9 7,065.0 12.60 L-80 IBTM Completion Details Top Depth (ND) Top Ind Monti... Top(fU(B) (MB) CI Item Description Comment ID(In) 32.9 32.9 -0.11 HANGER FMC TUBING HANGER 4.500 1,993.4 1,993.0 6.72 NIPPLE CAMCO DB NIPPLE 3.812 CONDUCTOR, 7,201.0 6,997.5 51.39 PACKER BAKER S-3 PACKER 3.875 37-114 7,204.8 6,999.9 51.67 MILLOUT PACKER MILLOUT EXTENSION 3.958 IIII1: 7,309.4 7,059.0 59.69 NIPPLE HES XN NIPPLE 3.725 VALVE,1,993 , 7,320.7 7,064.4 60.70 WLEG BAKER WIRELINE GUIDE 3.875 ii NIPPLE.1.993� j Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Inc! Top(ftKB) (KKB) (°) Description Comment Run Date ID(in) 1,993 1,993.0 6.72 VALVE 4.5"A-1 INJECTION VALVE set 10/10/2004 10/10/2004 1.375 7,309 7,059.0 59.69 PLUG 3.81"PXN PLUG 3/4/2012 0.000 Notes:General&Safety End Date Annotation 8/30/2010 NOTE View Schematic w/Alaska Schematic9.0 SURFACE, ' 37-2,382 GAS LIFT. 7,043 PACKER,7,201 MILLOUT, or 4, 7,205 I ii PLUG,7,309 NIPPLE,7,309 �i WLEG,7,321 'e... """iii�� Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ttKB) HtKB) P) Make Model (in) Sery Type Type PP) (Psi) Run Oct. Con... 1 7,042.6 6,887.0 40.24 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/28/2002 PRODUCTION, 35-7,845 OPEN HOLE, 7,845-11334N TD,11,134 • • Bettis, Patricia K (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Wednesday, October 09, 2013 10:25 AM To: Bettis, Patricia K(DOA) Subject: RE: CD2-22: Sundry Application Attachments: CD2-22 Wellbore Schematic.pdf Sorry for the exclusion. Please contact me at your convenience if you have questions or comments. Martin Martin Walters/MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office: 907-659-7043 Cell: 907-943-1720 Pager: 907-659-7000#937 Home: 907-854-9949 From: Bettis, Patricia K (DOA) [mailta:patricia.bettisPalaska.gov] Sent: Wednesday, October 09, 2013 10:05 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]CD2-22: Sundry Application Good morning Brent, Please provide a current wellbore schematic for CD2-22. A pdf copy can be emailed to me. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis(aalaska.Bov. 1 a 2202:092. 273 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log: CD2 -22 Run Date: 4/2/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2 -22 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20421 -00 SLANNEDmAy . z01Z PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: gip/ � � Signed: F -z >7 26 Oq Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] c 2 '• 7 / Sent: Monday, February 06, 2012 1:08 PM �C To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD2 -22 (PTD 202 -092) Report of suspect TxIA communication 1 -30 -12 Jim, Guy, Initial diagnostics were conducted on Sunday February 5th. CD2 -22 failed both an MITIA and an IA DDT. The desired IA test pressure could not be achieved to even begin the MIT test. The tubing packoff testing passed, indicating the leak path is downhole. The well was shut in and freeze protected yesterday. Further diagnostics with slickline and eline well be sche�ede�as needed. Brent Rogers / KeIIy Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 "z oblem Well Supv , January 30, 2012 3:49 PM Thomas E (DOA) ; 'jim.regg @alaska.gov'; 'guy.schwartz @alaska.gov' lem Well Supv D2 -22 (PTD 202 -092) Report of suspect TxIA communication 1 -30 -12 Tom, Jim, Guy Alpine injection wel CD2 -2 TD 202 -092) s being reported to have suspect TxIA communication due to frequent bleeds on the IA. Initial dia nostics will include u Ing packoff testing, an MITIA and potential IA drawdown test. Due to the weather, we may not be able to get to do these diagnostics for a few days, but will do them as soon as possible. If the MITIA fails, the well will be shut in and freeze protected and further diagnostics with slickline and /or eline will be pursued. The well will be added to the monthly report. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted to continue injection or repair as needed. Attached is the schematic and 90 day TIO plot. « File: CD2 -22 schematic.pdf» « File: CD2 -22 90 day TIO.ppt» Brent Rogers / KeIIy Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 • • C,Pck PTh 0-6z.097.0 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, January 30, 2012 3:49 PM %ki To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: CD2 -22 (PTD 202 -092) Report of suspect TxIA communication 1 -30 -12 Attachments: CD2 -22 schematic.pdf; CD2 -22 90 day TIO.ppt f Tom, Jim, Guy Alpine injection well CD2 -22 (PTD 202 -092) is being reported to have suspect TxIA communication due to frequent bleeds on the IA. Initial diagnostics will include tubing packoff testing, an MITIA and potential IA drawdown test. Due to the weatner, we may not be able to get to do these diagnostics for a few days, but will do them as soon as possible. If the MITIA fails, the well will be shut in and freeze protected and further diagnostics with slickline and /or eline will be pursued. The well will be added to the monthly report. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted to continue injection or repair as needed. Attached is the schematic and 90 day TIO plot. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 StANNEP FEE C 2L2 1 Well Name CD2-22 Notes: Start Date 111/2011 1 0q2-0 Days 90 End Date 1130 /2012 Annular Communication Surveillance 1400 — 90 WHP - 80 1200 — 70 1000 — so • 800 — I — sow .� Cr) Cm Tr — 40 600 / _.--, — A - _ — 30 400 r rJ - 20 200 — 10 0 0 Oct -11 Nov -11 Dec -11 Jan -12 • 2000 _... _ ................. __.__ _____ - -. 1000 1600 1400 d 61 1200 - DGI c 1000 — *00 - MGI ■ v pW1 L 600 - 400 - SWI 200 - iBLPD 0 0 Oct -11 Nov -11 Dec -11 Jan -12 D ate WNS CD2 -22 Conoco Phillips 64 - £rte Attributes Pd N�ii;P % ', l i to 8. MD TD? =, Wellbore API /UWI Field Name Well Status Incl ( °) MD (fKB) Act Btm (99(8) = 9 501032042100 ALPINE INJ 92.95 10,605.64 11,134.0 Comment H2S (ppm) Date Annotation End Date KB -Ord (ft) Rig Release Date SSSV: NIPPLE Last WO: 43.71 5/27/2002 Annotation Depth (ftK8) End Data Annotation Last Mod ... End Date Last Tag: Rev Reason: FORMAT UPDATE Imosbor 2/3/2011 , i " - - - Casin Dn Strin 0... S Top (ftKB) Set Depth (L-. Set Depth (TVD) .,- String Wt... String . 8tring Top 7hrtl ul �) _ ` CONDUCTOR eseriptio 16 14 88 37.0 114.0 114.0 109.00 H-40 WELDED HANGER, 33 ' I �€ NQ/ Casing Description String 0... String ID -.. Top (6K8) Sat Depth (f... Set Depth (ND) ... String Wt... String .,. String Top Thrd SURFACE 95/8 8.921 36.8 2,381.7 2,380.5 36.00 J -55 BTC � o ( Casing Description String 0... String ID ... Top (968) Set Depth (9... Set Depth (ND) ... String Wt... String ... String Top Thrd ' r r , " PRODUCTION 7 6.151 35.0 7, 845.2 7,182.6 26.00 L 80 MBTC s Casing Deaodptlon String O.. String 10 Top (968) Set Depth (f... Set Depth (TVD) -.. String Wt... String Top Thrd II OPEN HOLE 61/8 6.125 7,845.0 11 134,0 Tub . _ _ r �; y „ Tubing Description String 0..- String ID .. Top MO) Set Depth (f... Set Depth (ND) .,. String Wt... String ... String Top Thrd . r TUBING 41/2 3.958 32.9 7,321.9 7,065 12 L - 80 IBTM Top Depth Fp (ttK (TVD) Top Inol Nom). 8) ( °) Item Description Comment ID (In) • e,. - x,:a» ,ii ■= s»a A 32.9 32.9 -0.11 HANGER FMC TUBING HANGER 4.500 ' 1,993.4 1,993.0 RN NIPPLE CAMCO DB NIPPLE UM CONDUCTOR. 7,201.0 6,997.5 ling PACKER BAKER S-3 PACKER LW 37 414 7,204.8 6,999.9 misig MILLOUT PACKER MILLOUT EXTENSION glij _ y - 7,309.4 7,059.0 59.69 NIPPLE HES XN NIPPLE IM VALVE. 1 3 NIP 7,320.7 7,064 4 60 70 WLEG BAKER WIRELIKE GUIDE Iiiiii PLE 1,9 -, 1171M. '�A i [dine , Top Depth (TVD) Top Intl Top (9168 ( ( °) Desctl •tlon Comment Run Date ID (in) 1,993.4 1,993 . VALVE 4.5" A-1 INJECTION VALVE set 10 /10/2004 10/10/2004 Bea �t.Jl�. i ius. ra , a .. , ld I� 1 .I I' t:, , 8/30/2010 NOTE: VIEW SCHEMATIC w /Kaska Schematic9.0 I, SURFACE, t 37- 2382`;. 4 , I•`.. A II GAS LIFT, 7,043 F PACKER, 7,201 irairliii k j NIPPLE, 7,309 WLEG, 7,321 £ Wil figAPP e'9,1' - ti r ' ? II *:Pli 11 °I,"_ nl T° Depth Top Port (ND) Incl OD Valve Latch Size TRO Run ill ® To • (ttKB) ( 68 ) (°) tohe Model On) Sery Type Type (in) (P 0 Run Date il 7,042.6 6,887.0 40.24 CAMCO KBG -2 NU GAS LIFT DMY lail 0.000 0.0 5/28/2002 - PRODUCTION, 35-7,845 i�p OPEN HOLE, %i 9 ,L 7,845 - 11,134 TD,11,134 • • MEMORANDUM TO: Jim Regg P.I. Supervisor ~jc~ 7 (27 f t~=' FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-22 COLVILLE RIV UNIT CD2-22 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: COLVILLE RIV UNIT CD2-22 Insp Num: mitJJ100719122532 Rel Insp Num: API Well Number: 50-103-20421-00-00 Permit Number: 202-092-0 Inspector Name: Jeff Jones Inspection Date: 6/11/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ cDZ-zz ~ Type Inj. ; G ~ TVD 6997 - IA tazo zzzo - ~ zllo zllo P.T.D 2020920 ' TypeTest SPT ' Test psi 1749 ~ OA 600 650 650 650 Interval 4YRTST per, P ,Tubing 3460 3460 3440 3440 Notes: 0.7 BBLS diesel pumped. 1 well inspected; no exceptions noted. ' } 1+~1'; Monday, July 26, 2010 Page 1 of 1 ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Torn Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 2 7 Z007 Q,OJ..- 0 ~d- Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~:Z::::~~ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 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 Qal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 318/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 318/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 00'2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 318/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 318/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 318/2007 . . ~ ConocoPhillips Alaska 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 ~J O~a- ~()" þ..~R l) ~ 75$)1 S~~f.O Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom 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 ITom 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 PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 MEMORANDUM . State of Alaska _ Alaska Oil and Gas Conservation Commis. TO: Jim Regg P.I. Supervisor Îf11 6f¡~)1 DÇ, DATE: Wednesday, August 30,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-22 COLVILLE RIV UNIT CD2-22 dPd:' O(rcr FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,]BiZ- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-22 API Well Number 50-103-20421-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828141457 Permit Number: 202-092-0 Inspection Date: 8/27/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-22 Type Inj. w TVD 6997 IA 700 2550 2510 2510 P.T. 2020920 TypeTest SPT Test psi 1749.25 OA 350 550 550 550 "" / Tubing 1920 1920 1920 1920 Interval 4YRTST P/F P Notes Pretest pressure observed and found stable SCANNED SEP 0 8 2008 Wednesday, August 30,2006 Page I of I . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc "Î v'} /", u tJ I<J'N""'~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 MD 11134r' TVD 7135 ~ Completion Date 5/28/2002 - Completion Status 1WINJ Current Status 1WINJ 'sf ~<-dr- i (- n, ~ <h:1 ^ API No. 50-103-20421-00-00 ~ Permit to Drill 2020920 Well Name/No. COLVILLE RIV UNIT CD2-22 Operator CONOCOPHILLlPS ALASKA INC REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes--- DATA INFORMATION Types Electric or Other Logs Run: GRlRes/NeuUDens Well Log Information: (data taken from Logs Portion of Master Well Data Maint) -~ Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ÈD D Directional Survey 1 0 11134 Open 6/13/2002 : Rpt Directional Survey 0 11134 Open 6/13/2002 -Log Cement Evaluation 5 Col 0 7488 Case 7/12/2002 Vi Log Temperature 5 Col 0 7488 Case 7/12/2002 ¡~og - Pressure 5 Col 0 7488 Case 7/12/2002 ~~- D w..r"81 LIS Verification 2359 11 089 Case 10/15/2002 (ßøt LIS Verification 2359 11089 Case 10/15/2002 ~ C ~ See Notes 2360 11134 Open 11/6/2002 Digital Well Log data ! Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM*ON Well Cored? Y ;W Daily History Received? ~/N (}yN Chips Received? .~ Formation Tops Analysis Received? ""h'-N- Comments: ~~ ~ - DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020920 Well Name/No. eOl VlllE RIV UNIT CD2-22 API No. 50-103-20421-00-00 Operator eONOeOPHllLlPS ALASKA INe MD 11134 TVD 7135 Current Status 1WINJ J UIC Y / /1 ~ Date: . J~) ~à.ið C(-- ~tion Date 5/28/2002 Completion Status 1WINJ Compliance Reviewed By: Annular Disposal during the third quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-41 19560 100 0 19660 377 4000 24037 June 2003 July 2003 CD2-20, CD2-55 3S-17A 2133 100 0 2233 361 4659 7253 June 2003 July 2003 35-19 Hansen 1 2498 100 0 2598 0 115278 117876 January July 2003 Hansen 1, Hansen 1 A 2002 CD2-38 29522 100 0 29622 389 0 30011 July 2003 Sept 2003 CD2-40, CD2-30, CD2-55 IB-20 36655 100 0 36755 0 0 36755 July 2003 Sept 2003 1B-102, 1B-101 (, CD2-23 22140 100 0 22240 377 0 22617 Sept 2003 Sept 2003 CD2-18, CD2-55 Total Volumes into Annulifor which Disposal Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 371 380 375 Total h(l) Total h(2) Total h(3) Well Name Volume Volume Volume X'y CD2-46 31393 100 0 0 q;;L CD2-22 30773 100 0 CD2-48 31525 100 0 Start Date End Date 31864 31253 32000 Status of Annulus Open, Freeze Protected Open, Freeze Protected April 2003 May 2003 February March 2003 2003 December February 2002 2003 Open, Freeze Protected Source Wells CD2-51, CD2~ I 2 CD2-08, CD2-36, CD2- 51 CD2-45, CD2-35, CD2- 08, CD2-28 ( RE(:;E~\/E OCT 2 3 2003 A\aska Oil & Gas Cons. Commissio¡' ,Pin.chorage ) ,PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CD2-22 NIP (1993-1994, 00:4.500) TU BING (0-7322, 00:4-500, 10:3.958) ~OOUCTION (0-7845, 00:7,000, Wt26.00) PACKER (7201-7202, 00:5.970) NIP (7309-7310, 00:5.000) OPEN HOLE (7845-11134, 00:7,000) d.. 0 J.. - 0 "¡ALPINE Angle @ TS: deg @ Angle @ TO: 92 deg @ 11134 API: 501032042100 SSSV Type: NIPPLE Well Type: INJ Orig Completion: Last W/O: Ref Log Date: TO: 11134ftKB 93 10701 Rev Reason: New Well Last Update: 8/4/2002 Annular Fluid: Reference Log: Last Tag: Last Date: Max m:i; J II ¡q; Description CONDUCTOR SURFACE PRODUCTION Size 16.000 9.625 7.000 Wt Grade Thread 109.00 H-40 WELDED 36.00 J-55 BTC 26.00 L-80 MBTC Bottom 114 2382 7845 11 TVD 114 2381 7182 1 Size 4.500 .,. 11 ,.:, ",:,,:.:, ,-- " ~; f I J i r~: !:-: . . ~ ~;;: . ~: St MD TVD Man Man Mfr Type 7043 6887 CAMCO KBG-2 V Mfr V Type V OD Latch Port TRO Date Run BK 0.000 0 5/28/2002 Vlv Cmnt DMY 1.0 TVD Type Description 1993 1992 NIP CAMCO 'DB' LANDING NIPPLE 7201 6997 PACKER BAKER S-3 PACKER W/MILLOUT EXTENSION 4.5" 10 7309 7059 NIP HES 'XN' NO GO NIPPLE W/RHC ROD/BALL 7322 7065 WLEG BAKER ID 3.958 3.875 3.725 3.875 II ~ I I I :','1 '". ' . .'l:t' , .,'1<'.,', , " :"',~, . ,to ,,:,,:1 ...,"'" ~ ) ConocJPhillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih 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 casing 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 of2002, CDI-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 Attachment Alpine Cement Top Fill ) Subject: Alpine Cement Top Fill' 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 <tom_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 individual404'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 cement. 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 Fill " ",' ,~,._-_.._,-'" ..) , '" .,m. " mC, ".., ,)"u ".. "..' , .. Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) , , Encoding: base64 '''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' .....,....."................ "0'"'''' ''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''""""""""'''''''''''''''''''''''''''''' .,. .... .... ,0"""""""""""",,,,,,,,,,, -,..........., ..................~................................,.............. ,............................. ""'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''......,............................................ , \< ..~.,."",.....""", """'-'\"'\',""'~\W,':\\I'.Ùh"'" t\ ';hl' ",\\\1" 'II""W" _V,."'\-Y", 'AM'_'II,' . .... """,' "I Name: Cement Top Fill AOGCC Letter 04-23-03.doc D Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 ~"III," L'A v '1-'''' --, ''''''/MN. V. n ^ .\ mv W.' M_~ h_\'^ x,- M--W.wn /t, v - ,..- .\1. '~\r" '''''''' .. 'v II!. \WW\",A M. ",v.,--v,_w N^ AV -w-rw.l,M ^.'''^vw..,-,'-WW\v.lMNIA #",..'" -,-- '1\1/"'..,,, .. ,-A,- M- \ ,,- -\\ W A'M -¡v,,,"'-w,- . 'f, \ "', n^.'^'- w,w,wI." f._\ _\V W ,It'_,. Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission NW( 'A' -'-V\'\Wir.M""\.... , 2 of2 4/24/20037:55 AM ) ) ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 \~S- \ð~ \ ~C;-ùC;L\ d 0\- aaG \~ "\- ),s~- . \~~-{)\'o-3>. JOO- \ \ Ù \ ~\.-(:)ã <:.. d Cj:)--f$:) ~, rt . dOf:r-~~ d C)C)- \'-t ~ DEPTH VOLUME TYPE SACKS \1 _._------~--_..'_. BBLS --Cement-- \ \<; c;"()-"1(g-_._~ CD1-1 2.25' 0.3 WI 1.8 >;)'CO-- ,,", ) -'CD1-2 ---------4;-" -O: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.~ --- - --- CD1-6 10.42' 1.4 GI 8.5 CD1-16 14.33' 2 WI 12.1 ;)()O"\4Ç 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 .--.---.--..______0____."-.""'--"-".'''-'---- -.- -------. ---.--...,,-.-- \ '" ~- \ ol.{_~D 1_~~__, ----~_:.?,~.~---,-----_..J_~~------ - P 7.2 JOQ':.Ç>'-1") _~9J_:.?4 41.:-~~,~_- 5.7 P _._~j.4 ., -, - \~S-\\) CD1-36 16.75' 2.3 WI 13.9 __'.0- --------..-.-.-----.- .----.---. -._- ,Ç)CC:~DD~3>- CD1-3~- 3~~-' 0.5._------_-.!:' ----~:.Q---, . \~ ~- \ \ <; ___~g1.::1_L..___~:_~~:._-----_._----Q_:~- M I___.._-_._-~~-- d-()d__ì"-'-\: (X>-()\'6 -g~~:~;_!t~,~~-- ;:~ :~ 195~~ øè)-\ \. d d -'CD2-19 --1f66-;----'''----------{6-----------þ'----'-----g'::¡-- . ;}{) . J~-~"O--g:>-~~-_.-!~.J'~== Di=--==:r~~==JQ}J- dód~~'-\: ,~~?-~L-._--_?Z:~?-'----______3.7 ~---------_. 22.3 c- )D\ "':ð~'). CD2-26 10.~.~~ 1.4 I_~_~__n_.____--~:~- JQ -\J d , _~~?~~2 _..,-~~§~--,---- _._-_J.~ !~_-L__._--_..__-.J.:?- \ J-O \ - \ J \:) -_Çq.?-3,~_-= -______1~._._._-,_._----_!__._-------~_._---~~ dó. . ~\: JO:H'd:lo ~~~:~}- =-_Ü:~L_==ß~ : -=--~;C JO~ ~() ð<)d-\D 'D-{~~~t- ___-1~1l~,-- m-1-\I-~---~f~------- --~:~--- ':)0 \ - d ''\C1=~~Ö2~9--'- =~~9-"-~~~~= ~-~=---n~1~~=--=-~.===j~~===~. -~~~~_'~=_f~,~~=== ; ) D d-tl~ CO2-50 1.66' 0.25 P 1.5 WELLS \<;~... \~O !dOO~-~\ ~ I ;j::/)-Ofrs?:> ~ d-O\.... \"d-\-\ Jb\-\:ð 5 Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 38-18 31501 100 0 31601 306 0 31907 January March 38-15,38-16,38-22,38-08 2003 2003 38-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 38-10, 38-15, 38-09, 38-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CD2-36, CD2-51 ( 2003 38-10 21104 100 0 21204 388 0 21592 March March 38-21,38-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March 1C-190, 1C-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 2002 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October 2002 2002 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 Source Wells 2P-427, Heavenly CD2-l3, CD2-37, CD2- 35 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-38, CD2-44, CD2- 29, CD2-l3 CD2-50, CD2-46, CD2- 22 ~ECEIVED APR 1 6 2003 ( lli ~ I 0 Alaska Oil & Gas Cons. Commission -0 Anchorage 9J ~ t ~ () Annular Disposal during the first quarter of 2003: ~ 'ð b(l) b(2) h(3) Total for Freeze Previous New Start End Source Wells 0 Well Name V ohune Volume Volume Quarter. Protect Total Total Date Date l~ Volumes 38..18 31501 100 0 31601 306 0 31907 I anuary March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Ian 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dee 2002 Feb 2003 ' CD2-45, CD2-35, CD2-08, CD2-28 ) CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 , Feb 2003 March CD2~08, CD2-36, CD2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21,3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name V olume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 ) 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-I3 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 " , ) ) ¿;(()}-o9~ II3Lf3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tlt Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 11, 2002 RE: MWD Formation Evaluation Logs - CD2-22, AK-MW-22077 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20421-00. ~~~v~~ ~~~ ~~rl, RECE\V\:.o . . r,. " r\ f\ NOV 0 6 i.~J\.;L 0.\ 8 G'''''.:! '\or'~; Ccmm\~\oo þJa~a I' l d... \.I ~. Anchorege LJ ) ) a oa--oc¡~ IJ~) , " Ã,las,ka ()!! and (ras ConSCf\latIon j:"'':; ~ ,:,'~ ~ ,,- r ~~ :) ;~~ ~..;, ,t~, .!~ '~~~:" C)~;,,~ -~ R " . <"'''Ï'íì4ìi -00 4.PI#: 50- ,! ~},~,--~- "," "'-' '- f). ~ ~ RECEIVED OCT 7 5 2002 AI.a Oii & Gas Cons. Coillnli88iDn Anchorage 'J \ ; ') , ) G. C. Alvord Alpine Drilling Team Leader . Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 September 12,2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-22 (202-092) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-22. If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265-6081. Sincerely, k <- Ot~ G. C. Alvord Alpine Drilling Team Leader Conoco Phillips Alaska Drilling GCA/skad ~~ f ~~~ ~ \l ç \\. ';1 :~':' I::\~.\., S~~T) "!~' 2002 0' '. r) \("ì;\Î\\,,~ /\ ~ ~~w¡' \1) I ti \~ fA ~ ,'\ \.~,' a J~ .I!.,,.,.,,. 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 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended 0 Abandoned 0 Service 0 WAG Injector 7. Permit Number 202-092 I 8. API Number 50-103-20421-00 1785' FNL, 1536' FEL, Sec. 2, T11N, R4E, UM (ASP: 371704, 5974572)f CGi!;¡'¡;¡:i~7îÒi,C:1 At Top Producing Interval j ,!1\11:i ~ 1531' FNL, 2525' FEL, Sec. 2, T11 N, R4E, UM (ASP: 369355, 5977387) i ~'-,z,~~f,Z,'i,.,,",'Ji:, At Total Depth 1 ~;.¡: 1598' FSL, 1034' FWL, Sec. 35, T12N, R4E, UM (ASP: 369051, 597800~L..,~:~,;:::1f. " 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. .' '''" RKS 33' feet ADL 380075 & 22530 12. Date Spudded" 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. May 15, 2002 May 27,2002 May 28,2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11134' MD I 7135' TVD 11134' MD 17135' TVD YES 0 No 0 22. Type Electric or Other Logs Run G R/Res/Neut/Dens 23. 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-22 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set Landing Nipple @ 1993' MD 16. No. of Completions 1 21. Thickness of Permafrost 1652' MD 16" WT. PER FT. 62.5# 36# 26# GRADE H~40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2382' Surface 7845' HOLE SIZE CASING SIZE 42" CEMENTING RECORD 22 yds Portland type III 350 sx AS III Lite, 230 sx Class G 165 sx Class G AMOUNT PULLED 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 7322' PACKER SET (MD) 7201' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production N/A Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector GAS-MCF Production for OIL-BBL WATER-BBL CHOKE SIZE GAS-OIL RATIO N/A Flow Tubing Casing Pressure Test Period> Calculated 24-Hour Rate> OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. 28. psi CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ~~~ !'w t~:k ff r~' ì, ìf' N/A RBDMS 8Fl ,~ :. . ,:...; " Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ll~) [! ~ '"" ~ \ f¡ ~ 1\ '-:' II !\ , [, SEP 2 3 2002 Submit in duplicate ~ ,,... l:;"'" 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-22 Top Alpine D Top Alpine C 7490' 7556' 7129' 7145' 31. LIST OF ATTACHMENTS 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 Vern Johnson 265-6081 Signed ~~.t: &Z Chip Alvord Title Alpine Drilling Team Leader Date J( lJ I~J..... Prepared by Sharon Allsup-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 pertinent 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: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 'I ,,~ ~ J \ ~ 'I ;'\ ~ ) ~H I;LI pS' , A ~,'t1l ~~~, ~, ,', PHILHJiF:)SALASi{AINy. " .' qþ~t~t'øn~Slitn¡rl1C1rYFr~þöt~ , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 ,'Date '" ' " , . Sub From..JTo Hours Code Code Phase' 5/15/2002 07:30 - 12:00 4.50 MOVE MOVE MOVE 12:00 - 12:30 0.50 WELCTL NUND RIGUP 12:30 - 15:30 3.00 MOVE POSN MOVE 15:30 - 18:30 3.00 MOVE RURD RIGUP 18:30 - 20:00 1.50 MOVE RURD RIGUP 20:00 - 20:30 0.50 MOVE SFTY RIGUP 20:30 - 21 :00 0.50 WELCTL BOPE RIGUP 21 :00 - 21 :30 0.50 MOVE RURD RIGUP 21 :30 - 00:00 2.50 DRILL DRLG SURFAC 5/16/2002 00:00 - 16:15 16.25 DRILL DRLG SURFAC 16:15 - 17:00 0.75 DRILL CIRC SURFAC 17:00 - 18:15 1.25 DRILL WIPR SURFAC 18:15 - 19:00 0.75 DRILL CIRC SURFAC 19:00 - 20:30 1.50 DRILL TRIP SURFAC 20:30 - 23:00 2.50 DRILL PULD SURFAC 23:00 - 00:00 1.00 CASE RURD SURFAC 5/17/2002 00:00 - 00:45 0.75 CASE RURD SURFAC 00:45 - 01 :00 0.25 CASE SFTY SURFAC 01 :00 ~ 01 :45 0.75 CASE RUNC SURFAC 01 :45 ~ 03:15 1.50 CASE RURD SURFAC 03:15 - 06:00 2.75 CASE RUNC SURFAC .) Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 Spud Date: 5/15/2002 End: 5/28/2002 Group: . . .. . . . . De$þriptiQnof.Opørélti()n$ , Prepare for move, move out pipe shed and p itslmotor complex, skid rig floor and derrick . Move rig to CD2-22. Set surface stack on conductor with rig, tes t seals to 400 psi. Center rig over hole, skid rig floor and derri ck over hole, move in pit/motor complex and pipe shed. Rig up water, air, steam and ele ctrical lines. Accepted rig @ 1500 hours - 3 0 min. credit for setting surface stack. NU riser, Divertor line and flowline, finish c leaning mud tanks, rig up - high line power 0 n at 1630 hrs. Begin taking on mud at 1730 hrs. PU bit-motor~nmlc-nmstab-nmlc-mwd-ubho, s cribe tools, mu 1 stand of 8" DC's. Held Prespud meeting with rig crew and sup port personel!. Performed Divertor and Accumulator tests, J ohn Crisp (AOGCC) waived witnessing test. Fill Conductor and check for leaks, pressure test mud lines to 3500 psi. Spud well at 2130 hrs, drill from 114' to 368 '. ART=1.2 AST=O Drill from 368' to 2390' (2389' tvd) casing p oint. ART=9.6 AST=2.3 Circ hole clean, 650 gpm, 120 rpm, 2200 psi Flow check well, static. Wipe hole to 1377' 10~35k over, flow check well, static. RIH, no problems. Circulate and condition mud, 650 gpm - 80 r pm - 2200 psi. Heavy cuttings through first bottoms up, circ until I clean. Monitor well, static. POH, 5-10k over - flow check @ hwdp, static, stand back hwdp and 1 stand 8" DC's. LD UBHO, MWD collar, nmlc, nmstab, nmlc a nd motor. Clear tools from rig floor. RU to run 9 5/8" casing, MU fill up tool, cha nge out to long bails, RU slips and elevator s. RU to run 9 5/8" casing Held safety and operations meeting with rig and support crews. Ran 5 joints of casing and attempted to circ ulate to check floats, unable to circ through fill up tool. LD fill up tool, change out hose and check v alve assembly. MU fill up tool to Top Drive and circulate to check floats. Run casing (total 56 jts) MU hanger and Ian ding joint and land casing with shoe @ 2382 Printed: 6/6/2002 9:55:22 AM ~S... .~... ) , " , ., PHILL.I~S,ÄLAS~A:liNq. '. ..QpËJra~ign~",.'$l.Il11m~~Y..'.Rl!pØrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date' From ':Tö 5/17/2002 03: 15 - 06:00 06:00 - 06:45 06:45 - 08:30 08:30 - 10:00 10:00 - 10:30 CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 "'...... ..'...',,' ,',.«.SUb H,.,' ,,0, U,r,s" ,"'., Co, d, "',,e, ,>" .,',C'.""'d: ,,'" ",.'" " Q e . ... Phase, ') Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 Spud Date: 5/15/2002 End: 5/28/2002 Group: . . . . . .. . . . , DØscriþtiöhQf()per~~i()ns.', 2.75 CASE RUNC SURFAC " F C @ 2300'. 0.75 CEMENT RURD SURFAC Lay do w n fill u P too I and M U c e men the ad. 1.75 CEMENTCIRC SURFAC Circulate and condition mud for cementing 8 .0 bpm /330 psi, had full returns througho ut. PUW 152k SOW 148k. 1.50 CEMENT PUMP SURFAC T est e d c e men t I i n est 0 25 0 0 psi - P u m P e d 4 0 bbls of Biozan spacer with nut plug for ma rker, 50 bbls of 10.5 ppg spacer, 275 bbls 0 f 10.7 ppg lead and 48 bbls of 15.8 ppg tail slurry. 0.50 CEMENT DISP SURFAC D i s P I ace d wit h 2 0 b b I s F W fro m c e men t e r s a nd 178 bbls of mud with rig pumps @ 8-9 bp m, plugs bumped, floats held. Reciprocated pipe untill last 30 bbls of displacement, had 80 bbls of 10.7 ppg cement returns to surf ace, fu II r e t urn s t h r 0 ugh t, C I P @ 1 030 h r s . Flush Conductor and flowline, RD cement he ad and LD landing joint. NO Divertor system, install and test Unibody wellhead to 5000 psi. NU BOPE. Install test plug and test BOPE. Test pipe a nd blind rams, choke, kill, manifold and surf ace safety valves 250/5000 psi. Test annula r preventor 250/3500 psi. Pulled test plug a nd installed wear bushing. John Crisp (AOG CC) waived witnessing test. Hang short bails and 5" elevators. PU motor, bit, stab, LWD and MWD collars, scribe and initialize tools. RIH to 2200' and shallow test tools. Wash down, tagged cement @ 2255', cleaned out to 2280' and CBU. RU and test casing to 2500 psi for 30 minut e s. Drill out cement, float equipment and 20' of new hole to 2410'. Circulate and condition mud for LOT. RU and perform LOT, established EMW of 15 .1 P P g. Displaced 9.4 ppg LSND mud to bit and drill ahead while changing over mud. Drilled fro m 2410 to 4218'. ART=9.9 AST=0.2 Drill f/4219' t/4601'; 4600' TVD. ART=2.0 h rs; AST=O.O hrs. 15 minutes per stand aver age to obtain survey and pumps off PU, SO, & ROT weight. Pumps off PU, SO & ROT wei ght is taking an additional 5-7 minutes per s tan d. 0.50 DRILL CIRC INTRM1 C ire u I ate a r 0 u n d H i Vis Nut P lug s wee pin pre paration for a short trip. 1.5 to 2 times nor mal cuttings return. Monitor well~-static. 1.50 DRILL WIPR INTRM1 W i P e h 0 I e f I 460' 1 t I 23 1 l' wit h n 0 pro b I ems. 10:30 - 12:00 1.50 CEMENT RURD SURFAC 12:00 - 15:00 3.00 WELCTL NUND SURFAC 15:00 - 18:30 3.50 WELCTL NUND SURFAC 18:30 - 00:00 5.50 WELCTL BOPE SURFAC 5/18/2002 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 02:00 1.50 DRILL PULD SURFAC 02:00 - 03:15 1.25 DRILL TRIP SURFAC 03: 15 - 04:00 0.75 CEMENTCOUT SURFAC 04:00 - 05:00 1.00 CASE DEQT SURFAC 05:00 - 06:15 1.25 CEMENT DSHO SURFAC 06:15 - 06:45 0.50 CEMENT LOT SURFAC 06:45 - 07:45 1.00 CEMENT LOT SURFAC 07:45 - 00:00 16.25 DRILL DRLG INTRM1 5/19/2002 00:00 - 03:00 3.00 DRILL DRLG INTRM1 03:00 - 03:30 03:30 - 05:00 Printed: 6/6/2002 9:55:22 AM ) ~HI~LlPS" / ~:Q ~ ~ ) , , PHILL.IPSALÆ\SKAINC. , ()Pl!rét~i()l1s..~lUl1l11~ry.. R~.ppr~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 Spud Date: 5/15/2002 End: 5/28/2002 Group: Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 Desçriptipn . of Opëra,tiqns , ' , ,Sub ,Date Fröm..To'. Hours' Gode Code 5/19/2002 03:30 - 05:00 05:00 - 06:00 06:00 - 07:00 1.50 DRILL WIPR INTRM1 1.00 DRILL WIPR INTRM1 1.00 DRILL WIPR INTRM1 07:00 - 12:00 5.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 5/20/2002 00:00 - 00:00 24.00 DRILL DRLG INTRM1 5/21 12002 00:00 - 00:30 0.50 DRILL CIRC INTRM1 00:30 - 03:00 2.50 DRILL WIPR INTRM1 03:00 - 04:00 1.00 DRILL TRIP INTRM1 04:00 - 04:30 0.50 DRILL REAM INTRM1 04:30 - 12:00 7.50 DRILL DRLG INTRM1 12:00 - 16:00 4.00 DRILL DRLG INTRM1 16:00 - 17:00 1.00 DRILL CIRC INTRM1 17:00 - 20:30 3.50 DRILL TRIP INTRM1 20:30 - 21 :00 21 :00 ~ 22:30 0.50 DRILL PULD INTRM1 1.50 DRILL PULD INTRM1 5/22/2002 22:30 - 00:00 00:00 - 02:30 1.50 DRILL PULD INTRM1 2.50 DRILL TRIP INTRM1 02:30 - 03:00 0.50 DRILL REAM INTRM1 Monitor wellustatic. RIH to 4505' with no problems. Wash f/4505' t/4601' (1 stand) while circulat ing around HiVis sweep. 1.5 to 2 times nor mal cuttings return with flat 3" diam clay pa ncakes. Drill f/4601' t/5100' MD; 5098 TVD. ART=2. 3 hrs; A5T=0.90 hrs. 33 minutes per stand average to obtain survey and pumps off PU, 50, & ROT weight. One shaker is down due to a crack in the belly pan. Drill f/5100' MD t/6223' MD; 6163 TVD. ART =5.0 hrs; A5T=2.6 hrs. 22 minutes per stand average to obtain survey and pumps off PU , 50, & ROT weight. Drill from 6223' to 6875'. ART=2.3 A5T=12. 2 Obtaining required dogleg for plan 6/100 with 22' slide and 9' rotation per joint. ROP' s of 25-40 fph while sliding consistent with offset CD2-46 in the Albian-96 formation. A nticipate increased ROP @ 6962' (Top of HR Z). Discontinued collecting pump off parame ters. Circulate hole clean for wiper trip - R&R pip e Monitor well (static) Wiper trip f/ 6875' to 4410' - no problems Monitor well (static) RIH f/ 4410' to 6795' - no problems Establish circ - pump hi vis pill & safety wa sh & ream f/ 6795' to 6875' Dril18 1/2" hole fl 6875' to 6984' ~ 6842' T VD ADT- 5.10 A5T- 4.80 ART- .30 Dril18 1/2" hole f/ 6984' to 7075' - 6912' TV D ADT- 2.7 A5T- 2.6 ART-.1 - Unable to build high enough dogleg in reach target Pump hi-vis sweep & circ hole clean to trip for BHA - 110 RPM @ 600 GPM - monitor wel I ( static) Observe wellustatic. POOH f/7075' t/6127' with good hole fill. Obsever wellustatic. P ump dry job and continue to POOH t/1074'. Observed well @ shoe and BHAustatic. Stand back 5" HWDP, Jars & Drill Collars. LID motor, bit, and stab. MU Mach 1X motor and download MWD. Bit came out with one broken cutter, some ringing on nose; howev er, still in gauge. M/U bit and RIH with HWDP, Jars, & DC's. RIH f/ 1542' to 6981' fill pipe every 2000' (s hallow test MWD @ 2000') Establish circ - safety wash & ream f/ 6981' to 7075' Printed: 6/6/2002 9:55:22 AM ) ) , . ",PHILLIPS ALASKA INC." Qpèra~i()IÎ$$Î.I.-gm~ryiR~pørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 Spud Date: 5/15/2002 End: 5/28/2002 Group: ",Date ""SUb Frbm'-Tb Hours Code Code, , , . ... Description' ofOþeratiQt1s 5/22/2002 03:00 - 12:00 9.00 DRILL DRLG INTRM1 12:00 - 23:00 11.00 DRILL DRLG INTRM1 23:00 - 00:00 1.00 DRILL CIRC INTRM1 5/23/2002 00:00 - 00:30 0.50 DRILL CIRC INTRM1 00:30 - 02:00 1.50 DRILL WIPR INTRM1 02:00 - 03:30 1.50 DRILL CIRC INTRM1 03:30 - 08:00 4.50 DRILL TRIP INTRM1 08:00 - 09:00 1.00 DRILL PULD INTRM1 09:00 - 09:30 0.50 DRILL OTHR INTRM1 09:30 - 12:00 2.50 CASE OTHR INTRM1 12:00 - 13:00 1.00 CASE RURD INTRM1 13:00 ~ 15:30 2.50 CASE RUNC INTRM1 15:30 - 16:00 0.50 CASE CIRC INTRM1 16:00 - 18:00 2.00 CASE RUNC INTRM1 18:00 - 19:00 1.00 CASE CIRC INTRM1 19:00 - 21 :30 2.50 CASE RUNC INTRM1 5/24/2002 21 :30 - 00:00 00:00 - 01 :30 2.50 CEMENTCIRC INTRM1 1.50 CEMENT PUMP INTRM1 01 :30 - 02:00 0.50 CEMENT RURD INTRM1 Drill 8 1/2" hole f/ 7075' to 7399' MD, 7099' TVD. ART=1.2 hrs; AST=4.9 hrs; ADT=6.1 hrs. Drill 8 1/2" hole f/ 7399' to 7856' MD, 7183' TVD. ART=3.4 hrs; AST=4.6 hrs; ADT=8.0 hrs. Drill site picks top Alpine C @ 7554' M D 7144' TVD Circulate and condition hole for 10 stand sh ort trip. Pump HiVis/nutplug sweep. Circulate hole clean for short trip - recip & rotate pipe - 600 GPM - monitor well - static Wiper trip f/ 7856' to 6950' - hole in good c ondition - Monitor well - static - RIH to 777 5' Establish circ - wash to 7856' ~ pump sweep & circulate hole clean 2X btms up POOH to run 7" casing F 7856' to 1070' Handle BHA - std back HWDP & flex collars - LD bit, motor, MWD PU stack wash tool & flush stack - LD wash e r Pull wear bushing - set test plug wI 7" test j oint - change top pipe rams to 7" & test to 3 500 psi - pull test joint & test plug - set thi n wall wear bushing Rig up to run 7" casing - PJSM Ran 7" casing - MU & Bakerloc shoe track - ran 57 jts. 7" 26# L-80 MBTC to 2341' Circulate pipe volume + @ 2341' Continue running 7" casing - ran 120 jts (tot al). 7" 26# L-80 MBTC to 4955' Circ & condition mud @ 4955' Continue running 7" casing - Run grand tota I of 190 jts. 7" 26# L-80 MBTC casing - land ed on mandrel hanger wI shoe @ 7845' & flo at collar @ 7759' RD casing equip - RU cem ent head Circ & condition mud & hole for cement job PJSM - Cement 7" casing: Pumped 5 bbls AR CO wash @ 8.3 ppg - Test lines to 3500 psi - pumped 15 bbls ARCO wash - Pumped 50 b bls Mud Push @ 12.5 ppg - Drop bottom plug - Mixed & pumped 33.8 bbls (165 sks) Clas s G wI 0.2% D046, 0.25% D065, 0.25% D800 & 0.18% D167 @ 15.8 ppg - Kick out top pi ug wI 20 bbls water f/ Dowell - Switch to rig pumps & displace wI 277bbls 9.6 ppg LSND mud ~ pumped plug wI 1150 psi - floats held - CIP @ 0125 hrs - Full circulation through job RD cement head, casing elevators ~ LD landi ng joint Printed: 6/6/2002 9:55:22 AM ) ~HI;LlPS'~ ~Z~~ ;~ ) , , , PHILLIPSALA$KAINC., , ' ,qp~rÇ!~lotls. ~IJ rnn1~ryRf!PQrt. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 Spud Date: 5/15/2002 End: 5/28/2002 Group: ,Sub HöursCÖde ' Code 0.50 DRILL OTHR INTRM1 6.00 WELCTL BOPE INTRM1 . . . .. .. , " D~scriptiQrlofOp$ratiof1$ , 5/24/2002 02:00 - 02:30 02:30 - 08:30 08:30 - 11 :30 3.00 DRILL PULD INTRM1 11 :30 - 12:00 0.50 DRILL TRIP INTRM1 12:00 - 16:30 4.50 DRILL TRIP INTRM1 16:30 - 17:30 1.00 DRILL CIRC INTRM1 17:30 - 21 :30 4.00 RIGMNT RSRV INTRM1 21 :30 - 22:00 0.50 CEMENT COUT INTRM1 22:00 - 23:00 1.00 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL OTHR INTRM1 5/25/2002 00:00 - 03:00 3.00 CEMENT DSHO INTRM1 03:00 - 03:30 0.50 DRILL CIRC INTRM1 03:30 - 04:00 0.50 DRILL FIT INTRM1 04:00 - 05:30 1.50 DRILL CIRC PROD 05:30 - 00:00 18.50 DRILL DRLH PROD 5/26/2002 00:00 - 00:00 24.00 DRILL DRLH PROD 5/27/2002 00:00 - 00:30 0.50 DRILL DRLH PROD 00:30 - 03:30 3.00 DRILL CIRC PROD 03:30 - 06:00 2.50 CMPLTN CIRC CMPL TN 06:00 ~ 07:00 1.00 CMPL TN OBSV CMPL TN 07:00 - 07:30 0.50 CMPL TN CI RC CMPL TN 07:30 - 08:00 0.50 CMPL TN OBSV CMPL TN 08:00 - 10:00 2.00 CMPL TN TRI P CMPL TN Set & test 7" packoff to 5000 psi Set test plug - change top pipe rams f/ 7" b ack to 3 1/2" X 6" variable rams - Test BOP E as per Phillips policy - AOGCC waived wit nessing of test - RD test equipment & blow down choke line RU & MU BHA # 4 - bit (6.125") motor, stab , MWD - Down load MWD - PU NM flex colla rs & OX RIH w/ HWDP & Jars to 362' - test MWD RIH picking up 90 jts. 4" DP f/ pipe shed to 3221' - continue RIH w/ DP f/ derrick to 760 9' (fill pipe every 2000') circulate bottoms up fl 7609' PJSM - Slip on new drill line 1800' - servi ce top drive ~ adjust brakes RIH to 7694' - Tag up - CIO cmt f/ 7694' to 77 OS' Circulate hole clean for casing test RU - test 7" casing to 3500 psi for 30 mins. - R D C/O hard cmt in shoe track - drill FC@ 7759 , - hard cmt to FS drill FS @ 7845' C/O rat hole to 7856' - Drill 20' new hole fl 7856' to 7876' C ire h '0 lee I e a n for FIT Perform FIT to 12.5 ppg EMW / 9.6 ppg mud wI 1100 psi - rig down test equip - blow dow n kill Ii n e PJSM - Change well over to 9.1 ppg Flow-P ro fluid ~ monitor well - static Dril16 1/8" hole f/ 7876' to 9327' MD 7186' TVD ADT- 12.5 ART- 11.5 AST~ 1.0 Note: Hole taking fluid while drilling - lost 160 bbls - Avg. - 12.8 bbls/hr. Dril16 1/8" hole fl 9327' to 11044' MD 7138 'TVD ADT - 16.4 AST- 2.7 ART- 13.7 To tal losses past 24 hrs. - 55 bbls Total loss es while drilling - 210 bbls Dril16 1/8" hole f/ 11044' to 11134' MD 713 4' TVD ADT -.5 ART - .5 Pump hi vis sweep & circulae hole clean - 5 B/M @ 2300 psi - R&R pipe 110 RPM Change well over to 9.1 ppg brine - hole tak ing fluid Monitor well - hole taking fluid @ 130 B?H - build LCM pill Spot 40 bbls LCM pill wI brine, Flovis, & 10 #/bbl MI seal Monitor well ~ losses slowed to 6 B/H Blow down top drive- zero trip tank - POOH f/ 11134' to 9700' Hole took 11 bbls over c a Ie. fill Printed: 6/6/2002 9:55:22 AM ~~; ~~~~ ~ ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Date 5/27/2002 5/28/2002 10:00 - 10:30 10:30 - 13:00 13:00 - 16:00 16:00 - 18:00 CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 'Sub . HoUrs G()de. COde Phase', 0.50 CMPLTN CIRC CMPLTN 2.50 CMPL TN TRIP CMPL TN 3.00 CMPL TN TRIP CMPL TN 2.00 CMPL TN TRIP CMPL TN 18:00 - 20:00 2.00 CMPL TN PULD CMPL TN 20:00 - 20:30 0.50 CMPL TN OTHR CMPL TN 20:30 - 21 :00 0.50 CMPL TN OTHR CMPL TN 21 :00 - 00:00 3.00 CMPLTN RUNT CMPL TN 00:00 - 04:30 04:30 - 08:30 08:30 - 09:00 09:00 - 12:00 12:00 ~ 14:30 4.50 CMPL TN RUNT CMPL TN 4.00 CMPL TN NUND CMPL TN 0.50 CMPL TN OTHR CMPL TN 3.00 CMPL TN FRZP CMPL TN 2.50 CMPL TN PCKR CMPL TN Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 Spud Date: 5/15/2002 End: 5/28/2002 Group: Spot 15 bbls LCM pill wI brine, flovis, & 5 # I bbl MI seal Monitor well - Blow down TD zero trip tank - POOH f/ 9700' to 7800' - monitor well @ 7" shoe - static losses 9 bbl/hr - RU to LD dri II pipe POOH laying down 93 joints 4" DP to pipe s hed Continue POOH f/ 4842' to 268' - Flush BHA wI 40 bbls 9.1 ppg brine wI 10gals. Conquo r 404 - Handle BHA - Std back HWDP, jars, & flex collars Handle BHA - Down load MWD ~ LD MWD, st ab, motor, & bit clear floor Pull wear bushing RU to run 4 1/2" completion - PJSM Run 4 1/2" completion - MU WLEG, pup, XN nipple w/RHC plug, 2 jts. 4 1/2" 12.6# L-80 IBTM, Baker S-3 packer wI mill out ext- Bak erLoc all connections below packer - 3 jts. 4 1/2" 12.6# L-80 IBTM tbg, Camco GLM wI dummy valve, 55 jts. 4 1/2" 12.6# L-80 IBTM to 2176' * Note: total brine losses 4 52 bbls Continue running 4 1/2" completion - ran 61 jts.4 1/2" 12.6# L-80 IBTM tbg - Camco DB nipple - 45 jts.- 12.6# L-80 IBTM tbg - FMC 4 1/2" tbg hanger - Land tbg in wellhead wI tail @ 7321.89' - DB nipple @ 1993.43 - Ca mco GLM wI dummy valve @ 7042.63 - Baker S-3 packerwl mill out exten. @ 7201.02' - XN nipple @ 7309.40 - Run lock down screw s - test hanger seals to 5000 psi - LD landin 9 jt. - Total of 166 jts. 4 1/2" tbg PJSM - ND BOPE - NU tree & test to 5000 p si - RU FMC lubricator and pull TWC RD lubr icator Rig up squeeze manifold and hard lines to t bg & annulus PJSM - Pumped 90 bbls 9.4 ppg inhib. brine - pumped tbg volume plus 2000' annulur vol ume diesel for freeze protect - Shut in well - RU lubricator & drop ball/rod to set packer PJSM - Test lines to 3600 psi - Pressure up on tbg to 3500 psi to set packer - test tbg t 0 3500 psi for 30 mins. ~ bleed down tbg to 900 psi - Pressure up on 7 x 4 1/2" annulus and test to 3500 psi for 30 mins. ~ bleed an nulus to 0 psi and tbg to 900 psi - shut in w ell - Vac out line wI hydrocarbon truck ~ flu sh line wI water and blow down wI air - Rig odown lines and manifold Printed: 6/6/2002 9:55:22 AM i;H¡.. ~.. ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,"Ðatè Frorn,-To 5/28/2002 14:30 - 16:00 , , PHILLIPS ;ALASt(;AINC." ,()Þøra~i()nSSllÎ1101é1rY>Røport '. CD2-22 CD2-22 ROT - SIDETRACK doyon1 @ppco.com Doyon 19 , Hours Gode:Suþ , ,. ,Phase' . .' ",',."', ' Gode Spud Date: 5/15/2002 End: 5/28/2002 Group: Start: 5/15/2002 Rig Release: 5/28/2002 Rig Number: 19 , D~scriþtion ()fOperatiöns 1.50 CMPL TN OTHR CMPL TN R U F M C I u b r i cat 0 r & set B P V - R Diu b r i cat 0 r - secure well and cellar Release Rig @ 1600 hrs. - Move to CD2-48 Printed: 6/6/2002 9:55:22 AM BAKER HUGHES INTEQ ======> ALPINE CD2-22 Alaska State Plane VSect. Plane = 331.86 Coordinates Measured Angle Azimuth TVD-RKB TVD X Y N / -S E/-W DLS Vert.Sec SVY# Depth deg deg ft Subsea ft ft ft ft deg/100 ft ft 1 0.00 0.00 0.00 0.00 -52.00 371703.70 5974572.20 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 62.00 371703.70 5974572.20 0.00 0.00 0.00 0.00 3 305.51 0.26 158.83 305.51 253.51 371703.85 5974571.79 -0.41 0.16 0.14 -0.43 4 397.15 0.52 163.90 397.15 345.15 371704.03 5974571.20 -1.00 0.35 0.29' -1.04 5 487.74 1.09 159.10 487.73 435.73 371704.43 5974569.99 -2.20 0.77 0.63 -2.30 6 575.74 1.31 158.31 575.71 523.71 371705.07 5974568.26 -3.92 1.44 0.25 -4.13 '~ 7 664.21 0.88 157.65 664.16 612.16 371705.68 5974566.68 -5.48 2.07 0.49 -5.81 8 754.58 1.14 170.24 754.52 702.52 371706.07 5974565.15 -7.01 2.49 0.38 -7.36 9 845.17 0.82 166.34 845.09 793.09 371706.35 5974563.63 -8.53 2.79 0.36 -8.84 10 934.73 0.06 39.98 934.65 882.65 371706.52 5974563.04 -9.12 2.97 0.96 -9.44 11 1029.83 0.70 340.78 1029.75 977.75 371706.37 5974563.63 -8.53 2.82 0.71 -8.85 12 1126.21 0.73 343.86 1126.12 1074.12 371706.02 5974564.78 -7.38 2.45 0.05 -7.67 13 1221.02 0.76 345.93 1220.92 1168.92 371705.72 5974565.97 -6.19 2.13 0.04 -6.47 14 1315.91 0.81 347.78 1315.80 1263.80 371705.45 5974567.24 -4.93 1.84 0.06 -5.21 15 1411.07 0.79 348.97 1410.96 1358.96 371705.20 5974568.55 -3.63 1.57 0.03 -3.94 16 1505.93 0.63 359.18 1505.81 1453.81 371705.09 5974569.71 -2.46 1.43 0.21 -2.85 17 1601.12 0.55 16.21 1600.99 1548.99 371705.23 5974570.67 -1.50 1.55 0.20 -2.06 18 1695.70 0.51 20.93 1695.57 1643.57 371705.52 5974571.50 -0.67 1.83 0.06 -1 .46 19 1790.78 1.79 266.16 1790.63 1738.63 371704.19 5974571.82 -0.38 0.50 2.16 -0.57 20 1885.95 4.40 252.47 1885.66 1833.66 371699.21 5974570.70 -1.58 -4.46 2.83 0.72 21 1980.74 5.09 248.54 1980.12 1928.12 371691.79 5974568.19 -4.21 -11.84 0.80 1.87 22 2076.02 4.72 247.36 2075.05 2023.05 371684.18 5974565.27 -7.26 -19.40 0.40 2.74 23 2171.15 2.42 247.87 2169.99 2117.99 371678.67 5974563.10 -9.53 -24.87 2.42 3.33 24 2266.40 0.34 126.72 2265.22 2213.22 371677.02 5974562.20 -10.45 -26.51 2.74 3.28 ''-'" 25 2327.18 1.02 80.93 2325.99 2273.99 371677.70 5974562.16 -10.48 -25.83 1.35 2.94 26 2440.20 0.86 77.97 2439.00 2387.00 371679.53 5974562.47 -10.14 -24.00 0.15 2.38 27 2534.95 1.00 79.76 2533.73 2481.73 371681.04 5974562.74 -9.85 -22.50 0.15 1.93 28 2631.00 0.99 79.03 2629.77 2577.77 371682.69 5974563.02 -9.54 -20.86 0.02 1.42 29 2727.30 0.26 289.63 2726.07 2674.07 371683.30 5974563.24 -9.31 -20.25 1.27 1.34 30 2823.04 0.54 303.85 2821.80 2769.80 371682.73 5974563.57 -8.98 -20.82 0.31 1.90 31 2917.79 0.57 299.72 2916.55 2864.55 371681.96 5974564.07 -8.50 -21.60 0.05 2.69 32 3013.38 0.55 303.14 3012.13 2960.13 371681.17 5974564.57 -8.01 -22.40 0.04 3.50 33 3108.88 0.57 296.54 3107.63 3055.63 371680.37 5974565.04 -7.55 -23.21 0.07 4.29 34 3203.17 0.71 293.58 3201.91 3149.91 371679.42 5974565.50 -7.11 -24.17 0.15 5.13 35 3299.75 0.36 237.25 3298.49 3246.49 371678.62 5974565.59 -7.03 -24.97 0.61 5.57 36 3395.28 0.38 229.24 3394.02 3342.02 371678.12 5974565.23 -7.40 -25.46 0.06 5.48 37 3490.93 0.36 240.84 3489.67 3437.67 371677.61 5974564.89 -7.76 -25.96 0.08 5.41 38 3586.27 0.41 232.37 3585.00 3533.00 371677.07 5974564.54 -8.11 -26.50 0.08 5.34 39 3681.67 0.29 232.71 3680.40 3628.40 371676.60 5974564.19 -8.46 -26.96 0.13 5.25 40 3777.08 0.38 238.51 3775.81 3723.81 371676.14 5974563.89 -8.78 -27.42 0.10 5.19 41 3872.45 0.38 236.90 3871 .18 3819.18 371675.60 5974563.56 -9.11 -27.95 0.01 5.15 42 3968.07 0.39 234.00 3966.80 3914.80 371675.06 5974563.21 -9.48 -28.48 0.02 5.08 43 4063.23 0.46 239.93 4061.95 4009.95 371674.46 5974562.83 -9.86 -29.08 0.09 5.02 44 4158.85 0.31 233.22 4157.57 4105.57 371673.92 5974562.50 -10.21 -29.62 0.16 4.97 45 4253.07 0.26 234.73 4251.79 4199.79 371673.53 5974562.23 -10.48 -29.99 0.05 4.90 46 4347.72 0.25 229.89 4346.44 4294.44 371673.20 5974561.97 -10.74 -30.33 0.03 4.83 47 4442.93 0.18 229.30 4441.65 4389.65 371672.92 5974561.75 -10.97 -30.60 0.07 4.76 ,"-I 48 4538.28 0.34 222.39 4537.00 4485.00 371672.61 5974561.45 -11 .28 -30.90 0.17 4.63 49 4634.28 0.34 237.76 4633.00 4581.00 371672.17 5974561.09 -11.64 -31 .34 0.09 4.51 50 4730.82 0.49 232.73 4729.53 4677.53 371671.60 5974560.70 -12.04 -31.91 0.16 4.43 51 4825.48 0.55 243.48 4824.19 4772.19 371670.86 5974560.26 -12.49 -32.64 0.12 4.38 52 4921 .28 3.07 247.42 4919.93 4867.93 371668.06 5974559.12 -13.68 -35.42 2.63 4.64 53 5015.13 6.30 253.86 5013.46 4961.46 371660.75 5974556.85 -16.08 -42.69 3.48 5.95 54 5111.25 9.73 253.73 5108.63 5056.63 371647.82 5974553.32 -19.82 -55.55 3.57 8.72 55 5208.01 12.02 253.53 5203.64 5151.64 371630.23 5974548.47 -24.97 -73.07 2.37 12.44 56 5303.49 12.96 256.24 5296.86 5244.86 371610.21 5974543.44 -30.34 -93.00 1.16 17.11 57 5399.20 14.01 253.57 5389.93 5337.93 371588.58 5974537.98 -36.17 -114.54 1.28 22.13 58 5494.44 15.69 252.74 5481.99 5429.99 371565.10 5974531.29 -43.25 -137.89 1.78 26.90 59 5589.93 18.07 250.42 5573.36 5521.36 371538.67 5974522.94 -52.04 -164.18 2.59 31.54 60 5685.09 20.74 248.42 5663.11 5611.11 371508.91 5974512.30 -63.19 -193.76 2.89 35.66 61 5780.52 21.83 249.42 5752.03 5700.03 371476.39 5974500.40 -75.64 -226.09 1.20 39.93 62 5875.76 20.64 248.47 5840.80 5788.80 371443.99 5974488.56 -88.03 -258.28 1.30 44.19 63 5970.94 22.28 248.24 5929.38 5877.38 371411.42 5974476.26 -100.87 -290.64 1.73 48.13 64 6066.08 22.52 248.19 6017.34 5965.34 371377.53 5974463.38 -114.33 -324.31 0.25 52.14 65 6161.45 20.70 247.40 6106.00 6054.00 371344.79 5974450.67 -127.59 -356.83 1.93 55.78 --/ / 66 6256.59 22.32 248.55 6194.51 6142.51 371312.24 5974438.15 -140.66 -389.17 1.76 59.51 67 6351.57 23.28 248.77 6282.07 6230.07 371277.74 5974425.34 -154.05 -423.45 1.01 63.87 68 6415.74 22.92 250.80 6341.09 6289.09 371253.97 5974417.04 -162.75 -447.07 1.36 67.34 69 6447.64 22.93 253.49 6370.48 6318.48 371242.09 5974413.43 -166.56 -458.90 3.28 69.55 70 6479.88 22.96 258.29 6400.17 6348.17 371229.86 5974410.58 -169.62 -471.08 5.80 72.60 71 6510.71 23.04 261.73 6428.55 6376.55 371217.97 5974408.69 -171.71 -482.94 4.37 76.35 72 6541.26 23.72 266.07 6456.59 6404.59 371205.90 5974407.61 -172.99 -494.98 6.06 80.90 73 6575.39 24.49 271.81 6487.75 6435.75 371191.98 5974407.60 -173.24 -508.91 7.23 87.25 74 6608.35 25.45 274.82 6517.63 6465.63 371178.11 5974408.65 -172.43 -522.79 4.83 94.51 75 6638.08 26.47 277.50 6544.36 6492.36 371165.20 5974410.27 -171.03 -535.73 5.23 101.85 76 6672.02 27.11 279.57 6574.66 6522.66 371150.12 5974412.79 -168.76 -550.85 3.33 110.99 77 6703.97 27.71 282.03 6603.02 6551.02 371135.72 5974415.80 -166.00 -565.30 4.01 120.23 78 6733.80 28.32 285.4 7 6629.36 6577.36 371122.18 5974419.36 -162.66 -578.90 5.79 129.59 79 6767.91 29.22 288.21 6659.26 6607.26 371106.56 5974424.38 -157.90 -594.61 4.68 141.19 80 6799.35 30.12 290.31 6686.58 6634.58 371091.96 5974429.77 -152.77 -609.30 4.37 152.65 81 6829.00 31.17 292.49 6712.09 6660.09 371077.99 5974435.52 -147.25 -623.36 5.16 164.15 82 6861.41 32.34 293.90 6739.65 6687.65 371062.43 5974442.51 -140.53 -639.04 4.27 177.47 83 6893.59 33.11 296.41 6766.72 6714.72 371046.82 5974450.17 -133.13 -654.78 4.85 191 .42 84 6924.26 34.05 297.57 6792.27 6740.27 371031.83 5974458.12 -125.43 -669.89 3.71 205.34 85 6959.42 35.58 300.30 6821 .14 6769.14 371014.44 5974468.13 -115.71 -687.45 6.21 222.19 86 6990.97 36.88 302.61 6846.59 6794.59 370998.71 5974478.13 -105.98 -703.35 5.97 238.27 87 7013.06 38.23 303.82 6864.10 6812.10 370987.58 5974485.70 -98.60 -714.62 6.96 250.09 88 7053.02 40.96 307.26 6894.89 6842.89 370967.13 5974500.86 -83.79 -735.32 8.76 272.91 89 7084.32 43.13 309.11 6918.14 6866.14 370950.88 5974514.10 -70.82 -751.79 7.98 292.11 ~ 90 7116.04 45.03 311 .72 6940.92 6888.92 370934.34 5974528.69 -56.52 -768.58 8.28 312.65 91 7147.89 47.32 314.51 6962.98 6910.98 370917.84 5974544.68 -40.81 -785.34 9.57 334.41 92 7180.03 49.88 316.35 6984.23 6932.23 370901.23 5974562.14 -23.63 -802.25 9.05 357.53 93 7210.70 52.09 318. 00 7003.54 6951.54 370885.33 5974579.89 -6.15 -818.45 8.33 380.58 94 7243.04 54.51 320.51 7022.87 6970.87 370868.75 5974599.82 13.50 -835.36 9.73 405.88 95 7274.01 56.75 322.83 7040.35 6988.35 370853.25 5974620.13 33.55 -851.21 9.51 431.04 96 7306.00 59.39 324.54 7057.27 7005.27 370837.55 5974642.28 55.43 -867.28 9.42 457.91 97 7338.06 62.25 326.52 7072.90 7020.90 370822.11 5974665.61 78.50 -883.11 10.42 485.72 98 7371.62 65.00 326.80 7087.81 7035.81 370806.02 5974691.00 103.62 -899.63 8.23 515.66 99 7401.46 67.37 328.28 7099.86 7047.86 370791.76 5974714.28 126.65 -914.28 9.15 542.88 100 7435.08 69.98 329.54 7112.08 7060.08 370776.05 5974741.37 153.47 -930.45 8.51 574.16 101 7468.14 72.55 329.72 7122.70 7070.70 370760.69 5974768.64 180.48 -946.28 7.79 605.44 102 7497.43 75.03 329.67 7130.88 7078.88 370746.91 5974793.15 204.76 -960.47 8.47 633.54 103 7531.11 75.87 331 .1 7 7139.34 7087.34 370731 .30 5974821.77 233.11 -976.56 4.98 666.13 104 7563.35 76.15 330.76 7147.13 7095.13 370716.58 5974849.37 260.46 -991.74 1.51 697.41 105 7593.12 77.88 330.13 7153.82 7101.82 370702.70 5974874.84 285.70 -1006.05 6.17 726.41 106 7626.55 78.51 329.05 7160.66 7108.66 370686.62 5974903.33 313.92 -1022.61 3.68 759.10 107 7658.70 79.96 329.17 7166.67 7114.67 370670.87 5974930.70 341 .02 -1038.83 4.52 790.65 ~ 108 7689.14 81.95 328.63 7171.45 7119.45 370655.78 5974956.70 366.76 -1054.36 6.77 820.67 109 7721.94 84.28 327.08 7175.38 7123.38 370638.92 5974984.56 394.33 -1071.68 8.51 853.15 110 7753.91 86.25 327.01 7178.02 7126.02 370622.05 5975011.58 421.06 -1089.01 6.17 884.90 111 7784.33 87.00 327.16 7179.81 7127.81 370605.98 5975037.34 446.55 -1105.51 2.51 915.16 112 7797.31 87.27 327.46 7180.46 7128.46 370599.17 5975048.37 457.46 -1112.52 3.11 928.08 113 7937.03 89.08 329.98 7184.91 7132.91 370528.70 5975168.90 576.80 -1185.01 2.22 1067.51 114 8029.40 89.63 330.49 7185.95 7133.95 370484.21 5975249.84 656.98 -1230.87 0.81 1159.83 115 8124.65 89.32 329.91 7186.82 7134.82 370438.29 5975333.27 739.63 -1278.20 0.69 1255.04 116 8220.34 89.14 329.97 7188.05 7136.05 370391.84 5975416.91 822.48 -1326.06 0.20 1350.67 117 8313.58 89.51 329.23 7189.15 7137.15 370346.03 5975498.11 902.90 -1373.24 0.89 1443.83 118 8409.27 89.75 330.13 7189.76 7137.76 370299.13 5975581.50 985.50 -1421.55 0.97 1539.45 119 8507.63 89.45 329.92 7190.45 7138.45 370251.44 5975667.52 1070.70 -1470.69 0.37 1637.75 120 8603.12 90.37 329.94 7190.60 7138.60 370205.00 5975750.95 1153.33 -1518.53 0.96 1733.19 121 8698.60 90.37 329.99 7189.98 7137.98 370158.62 5975834.39 1235.99 -1566.32 0.05 1828.62 122 8794.24 90.12 330.05 7189.58 7137.58 370112.24 5975918.02 1318.83 -1614.11 0.27 1924.20 123 8888.53 89.94 330.82 7189.53 7137.53 370067.12 5976000.80 1400.85 -1660.64 0.84 2018.47 124 8983.83 90.86 330.92 7188.86 7136.86 370022.14 5976084.81 1484.09 -1707.03 0.97 2113.75 125 9079.58 90.68 331 .15 7187.57 7135.57 369977.21 5976169.34 1567.86 -1753.39 0.31 2209.48 126 9174.79 90.49 331.34 7186.60 7134.60 369932.83 5976253.56 1651.32 -1799.19 0.28 2304.68 127 9271.29 90.18 331.61 7186.04 7134.04 369888.19 5976339.11 1736.10 -1845.27 0.43 2401.17 128 9366.90 90.12 332.13 7185.79 7133.79 369844.55 5976424.17 1820.42 -1890.35 0.55 2496.78 129 9462.53 91.17 332.20 7184.71 7132.71 369801.34 5976509.46 1904.98 -1935.00 1.10 2592.40 130 9557.31 90.80 332.52 7183.08 7131.08 369758.80 5976594.14 1988.93 -1978.96 0.52 2687.17 131 9652.58 90.00 332.55 7182.42 7130.42 369716.30 5976679.39 2073.46 -2022.90 0.84 2782.43 ~ 132 9748.09 89.82 333.17 7182.57 7130.57 369674.18 5976765.10 2158.45 -2066.47 0.68 2877.92 133 9843.55 91.35 332.16 7181.59 7129.59 369631.80 5976850.62 2243.25 -2110.30 1.92 2973.36 134 9938.24 91.48 332.33 7179.25 7127.25 369589.14 5976935.11 2327.02 -2154.38 0.23 3068.02 135 1 0033.54 91.54 332.39 7176.74 7124.74 369546.38 5977020.23 2411 .41 -2198.58 0.09 3163.29 136 10128.30 90.92 331.51 7174.71 7122.71 369503.25 5977104.58 2495.02 -2243.13 1.14 3258.02 137 10223.93 91.05 331 .38 7173.06 7121.06 369458.98 5977189.32 2579.00 -2288.83 0.19 3353.64 138 10263.82 92.71 330.49 7171.76 7119.76 369440.21 5977224.48 2613.85 -2308.20 4.72 3393.50 139 10319.11 92.65 331.50 7169.17 7117.17 369414.25 5977273.23 2662.15 -2334.98 1.83 3448.72 140 10414.53 92.03 331 .17 7165.27 7113.27 369369.94 5977357.64 2745.81 -2380.71 0.74 3544.06 141 10510.13 91.79 329.93 7162.09 7110.09 369324.38 5977441.61 2829.01 -2427.69 1.32 3639.58 142 10605.65 92.95 331 .74 7158.14 7106.14 369279.29 5977525.71 2912.34 -2474.19 2.25 3734.99 143 10701.10 92.95 332.60 7153.23 7101.23 369236.23 5977610.74 2996.64 -2518.70 0.90 3830.31 144 10796.57 92.65 332.47 7148.56 7096.56 369193.69 5977696.07 3081.25 -2562.67 0.34 3925.66 145 10892.17 92.46 332.62 7144.30 7092.30 369151.10 5977781.55 3165.99 -2606.71 0.25 4021 .16 146 10985.62 92.22 334.62 7140.48 7088.48 369111.03 5977865.88 3249.64 -2648.19 2.15 4114.48 147 11074.36 92.28 334.53 7137.00 7085.00 369074.33 5977946.58 3329.72 -2686.26 0.12 4203.06 148 11134.00 92.28 334.53 7134.63 7082.63 369049.62 5978000.81 3383.52 -2711.89 0.00 4262.58 ~ ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 11-Jun-02 Definative Surveys Re: Distribution of Survey Data for Well CD2-22 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 11,134.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED " '!\! 1 Ï' "001') 0VI'J .0L!. Alaska Oil & Gas Cons. Commissfon Anchorage aQ;)~oc¡~ ~ () , ~ 1) DEFINITIVE -- Kuparuk Rwer Unit North Slope, Alaska Alpine CD-2, Slot CD2-22 CD2..22 Job No. AKMW22077, Surveyed: 27 May, 2002 SURVEY IfEPORT 6 June, 2002 Your Ref: API 501632042100 Surface Coordinates: 5974572.39 N, 371704.15 E (70° 20-19.5451" N, 151002' 27.8173" W) Kelly Bushing: 52.4Oft above Mean Sea Level /- Sï ....-..- '.¡ ~Y"" JI1 tU~'LLIr..aG seAvtces A Halliburton Company Survey Ref: svy9892 Sperry-Sun Dri' ~~~~t'~'<Services . Survey Report.CD2-22 DEF\N'1''é Your Réf: AP1'5ð1ØSI0421lJO Job No. AKMW22077, SlIniéyed: 27 May, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -52.40 0.00 O.OON O.DOE 5974572.39 N 371704.15 E 0.00 MWD Magnetic 114.00 0.000 0.000 61.60 114.00 O.OON O.OOE 5974572.39 N 371704.15 E 0.000 0.00 305.51 0.260 158.830 253.11 305.51 0.418 0.16E 5974571.98 N 371704.30 E 0.136 -0.41 397.15 0.520 163.900 344.75 397.15 1.008 0.35E 5974571.39 N 371704.48 E 0.286 ~1.00 487.74 1.090 159.100 435.33 487.73 2.208 0.77E 5974570.18 N 371704.88 E 0.633 ~2.20 575.74 1.310 158.310 523.31 575.71 3.928 1.44 E 5974568.45 N 371705.52 E 0.251 -3.96 664.21 0.880 157.650 611.76 664.16 5.48 8 2.07E 5974566.87 N 371706.13 E 0.486 -5.57 754.58 1,140 170.240 702.12 754.52 7.018 2.49E 5974565.34 N 371706.52 E 0.377 -7.03 845.17 0.820 166.340 792.69 845.09 8.538 2.79E 5974563.81 N 371706.80 E 0.361 -8.40 934.73 0.060 39.980 882.25 934.65 9.128 2.97E 5974563.22 N 371706.97 E 0.957 -8.97 1029.83 0.700 340.780 977.35 1029.75 8.538 2.82E 5974563.81 N 371706.82 E 0.706 -8.42 1126.21 0.730 343.860 1073.72 1126.12 7.388 2.45 J: 5974564.97 N 371706.47 E 0.051 -7.29 1221.02 0.760 345.930 1168.52 1220.92 6.198 2.13E 5974566.16 N 371706.17 E 0.043 -6.16 1315.91 0.810 347.780 1263.40 1315.80 4.938 1.84 E 5974567.43 N 371705.90 E 0.059 -4.99 1411.07 0.790 348.970 1358.56 1410.96 3.638 1.57 E 5974568.74 N 371705.66 E 0.027 -3.81 1505.93 0.630 359.180 1453.41 1505.81 2.46 8 1.43 E 5974569.90 N 371705.54 E 0.214 -2.82 1601.12 0.550 16.210 1548.59 1600.99 1.50 8 1.55E 5974570.86 N 371705.68 E 0.201 ~2.14 - 1695.70 0.510 20.930 1643.17 1695.57 0.678 1.83 E 5974571.69 N 371705.97 E 0.063 -1.67 1790.78 1.790 266.160 1738.23 1790.63 0.388 0.50E 5974572.01 N 371704.64 E 2.163 -0.61 1885.95 4.400 252.470 1833.26 1885.66 1.588 4.46 W 5974570.89 N 371699.66 E 2.831 1.56 1980.74 5.090 248.540 1927.72 1980.12 4.218 11.84 W 5974568.38 N 371692.24 E 0.804 4.12 2076.02 4.720 247.360 2022.65 2075.05 7.268 19.40 W 5974565.46 N 371684.63 E 0.402 6.46 2171.15 2.420 247.870 2117.59 2169.99 9.538 24.87 W 5974563.29 N 371679.12 E 2.418 8.12 2266.40 0.340 126.720 2212.82 2265.22 10.458 26.51 W 5974562.39 N 371677.47 E 2.742 8.42 2327.18 1.020 80.930 2273.59 2325.99 10.488 25.83 W 5974562.36 N 371678.15 E 1.349 7.98 2440.20 0.860 77.970 2386.60 2439.00 10.148 24.00 W 5974562.66 N 371679.98 E 0.148 7.10 2534.95 1,000 79.760 2481.33 2533.73 9.858 22.50 W 5974562.93 N 371681.49 E 0.151 6.39 2631.00 0.990 79.030 2577.37 2629.77 9.548 20.86 W 5974563.21 N 371683.13 E 0.017 5.60 2727.30 0.260 289.630 2673.67 2726.07 9.318 20.25 W 5974563.43 N 371683.75 E 1.268 5.40 2823.04 0,540 303.850 2769.40 2821.80 8.988 20.82 W 5974563.76 N 371683.18 E 0.308 6.01 - ------- 6 June, 2002 - 13:06 Page 20f7 DrillQuest 2.00.08.005 ¿.~.:~~_.,. . ,:>!...,~:, '; , Sperry-Sun Drilling Services Survey Report~":~CD2...22 Your Ref: APISOffIIf042100 Job No. AKMW22077, -Su,y.eyed: 27 May, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaetlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) -~.... 2917.79 0.570 299.720 2864.15 2916.55 8.505 21.60 W 5974564.26 N 371682.40 E 0.053 6.88 3013.38 0.550 303.140 2959.73 3012.13 8.015 22.40 W 5974564.76 N 371681.61 E 0.041 7.76 3108.88 0.570 296.540 3055.23 3107.63 7.555 23.21 W 5974565.24 N 371680.81 E 0.071 8.62 3203.17 0.710 293.580 3149.51 3201.91 7.11 5 24.17 W 5974565.70 N 371679.87 E 0.153 9.57 3299.75 0.360 237.250 3246.09 3298.49 7.035 24.97 W 5974565.78 N 371679.06 E 0.613 10.13 3395.28 0.380 229.240 3341.62 3394.02 7.40 S 25.46 W 5974565.42 N 371678.57 E 0.058 10.15 3490.93 0.360 240.840 3437.27 3489.67 7.765 25.96 W 5974565.08 N 371678.06 E 0.081 10.19 3586.27 0.410 232.370 3532.60 3585.00 8.11 S 26.50 W 5974564.73 N 371677.52 E 0.079 10.24 3681.67 0.290 232.710 3628.00 3680.40 8.46 S 26.96 W 5974564.39 N 371677.05 E 0.126 10.25 3777.08 0.380 238.510 3723.41 3775.81 8.785 27.42 W 5974564.08 N 371676.58 E 0.101 10.30 3872.45 0.380 236.900 3818.78 3871.18 9.11 S 27.95 W 5974563.76 N 371676.04 E 0.011 10.37 3968.07 0.390 234.000 3914.40 3966.80 9.48 S 28.48 W 5974563.40 N 371675.51 E 0.023 10.42 4063.23 0.460 239.930 4009.55 4061.95 9.865 29.08 W 5974563.03 N 371674.91 E 0.087 10.49 4158.85 0.310 233.220 4105.17 4157.57 10.21 5 29.62 W 5974562.69 N 371674.36 E 0.164 10.56 4253.07 0.260 234.730 4199.39 4251.79 10.485 29.99 W 5974562.42 N 371673.98 E 0.054 10.58 4347.72 0.250 229.890 4294.04 4346.44 10.745 30.33 W 5974562.17 N 371673.64 E 0.025 10.59 4442.93 0,180 229.300 4389.25 4441.65 10.975 30.60 W 5974561.94 N 371673.37 E 0.074 10.58 4538.28 0.340 222.390 4484.60 4537.00 11.28 5 30.90 W 5974561.64 N 371673.06 E 0.171 1053 .- 11.64 5 31.34 W 5974561.29 N 371672.62 E 0.095 10.51 4634.28 0.340 237.760 4580.60 4633.00 4730.82 0.490 232.730 4677.13 4729.53 12.04 5 31.91 W 5974560.89 N 371672.04 E 0.160 10.56 4825.48 0.550 243.480 4771.79 4824.19 12.49 5 32.64 W 5974560.46 N 371671.30 E 0.121 10.66 4921.28 3.070 247.420 4867.53 4919.93 13.685 35.42 W 5974559.32 N 371668.50 E 2.632 11.47 5015.13 6.300 253.860 4961.06 5013.46 16.085 42.69 W 5974557.04 N 371661.20 E 3.482 14.15 5111.25 9.730 253.730 5056.23 5108.63 19.82 S 55.55 W 5974553.52 N 371648.27 E 3.569 19.28 5208.01 12.020 253.530 5151.24 5203.64 24.97 S 73.07 W 5974548.67 N 371630.67 E 2.367 26.21 5303.49 12.960 256.240 5244.46 5296.86 30.34 S 93.00 W 5974543.65 N 371610.64 E 1.160 34.49 5399.20 14.010 253.570 5337.53 5389.93 36.17 5 114.54 W 5974538.19 N 371589.01 E 1.275 43.41 5494.44 15.690 252.740 5429.59 5481.99 43.25 S 137.89 W 5974531.51 N 371565.54 E 1.778 52.49 5589.93 18.070 250.420 5520.96 5573.36 52.04 S 164.18W 5974523.16 N 371539.10 E 2.590 62.07 5685.09 20.740 248.420 5610.71 5663.11 63.19 S 193.76 W 5974512.53 N 371509.34 E 2.891 71.87 ------- --- --- 6 June, 2002 - 13:06 Page 30f7 DrílfQuest 2.00.08.005 .,,:"- . Sperry-Sun Dri/lit'lg Services Survey Reportfð1:CD2...22 Your Ref: API'5D1032042100 Job No. AKMW22077, SUnfeyed: 27 May, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlng. Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) - 5780.52 21.830 249.420 5699.63 5752.03 75.64 S 226.09 W 5974500.63 N 371476.80 E 1.204 82.37 5875.76 20.640 248.470 5788.40 5840.80 88.03 S 258.28 W 5974488.80 N 371444.40 E 1.301 92.84 5970.94 22.280 248.240 5876.98 5929.38 100.87 S 290.64 W 5974476.51 N 371411.82 E 1.725 103.06 6066.08 22.520 248.190 5964.94 6017.34 114.33 S 324.31 W 5974463.63 N 371377.93 E 0.253 113.62 6161.45 20.700 247.400 6053.60 6106.00 127.59 S 356.83 W 5974450.92 N 371345.19 E 1.933 123.60 6256.59 22.320 248.550 6142.11 6194.51 140.66 S 389.17W 5974438.41 N 371312.63 E 1.759 133.63 6351.57 23.280 248.770 6229.67 6282.07 154.05 S 423.45 W 5974425.61 N 371278.12 E 1.015 144.62 6415.74 22.920 250.800 6288.69 6341.09 162.75 S 447.07 W 5974417.31 N 371254.36 E 1.362 152.61 6447.64 22.930 253.490 6318.08 6370.48 166.56 S 458.90 W 5974413.70 N 371242.47 E 3.285 157.03 6479.88 22.960 258.290 6347.77 6400.17 169.62 S 471.08 W 5974410.85 N 371230.24 E 5.803 162.26 6510.71 23.040 261.730 6376.15 6428.55 171.71 S 482.94 W 5974408.97 N 371218.35 E 4.367 168.05 6541.26 23.720 266.070 6404.19 6456.59 172.99 S 494.98 W 5974407.89 N 371206.28 E 6.059 174.58 6575.39 24.490 271.810 6435.35 6487.75 173.24 S 508.91 W 5974407.88 N 371192.35 E 7.227 183.09 6608.35 25.450 274.820 6465.23 6517.63 172.43 S 522.79 W 5974408.93 N 371178.48 E 4.831 192.41 6638.08 26.470 277.500 6491.96 6544.36 171.03 S 535.73 W 5974410.55 N 371165.58 E 5.228 201.59 6672.02 27.110 279.570 6522.26 6574.66 168.76 S 550.85 W 5974413.08 N 371150.49 E 3.333 212.83 6703.97 27.710 282.030 6550.62 6603.02 166.00 S 565.30 W 5974416.09 N 371136.10 E 4.011 224.01 6733.80 28.320 285.470 6576.96 6629.36 162.66 S 578.90 W 5974419.66 N 371122.55 E 5.789 235.12 .- 6767.91 29.220 288.210 6606.86 157.90 S 594.61 W 5974424.68 N 371106.93 E 4.680 248.66 6659.26 6799.35 30.120 290.310 6634.18 6686.58 152.77 S 609.30 W 5974430.07 N 371092.33 E 4.373 261.85 6829.00 31.170 292.490 6659.69 6712.09 147.25 S 623.36 W 5974435.83 N 371078.36 E 5.156 274,96 6861.41 32.340 293.900 6687.25 6739.65 140.53 S 639.04 W 5974442.82 N 371062.80 E 4.275 290.00 6893.59 33.110 296.410 6714.32 6766.72 133.13 S 654.78 W 5974450.48 N 371047.19 E 4.848 305.62 6924.26 34.050 297.570 6739.87 6792.27 125.43 S 669.89 W 5974458.44 N 371032.21 E 3.711 321.08 6959.42 35.580 300.300 6768.74 6821.14 115.71 S 687.45 W 5974468.46 N 371014.82 E 6.211 339.65 6990.97 36.880 302.610 6794.19 6846.59 105.98 S 703.35 W 5974478.46 N 370999.08 E 5.975 357.19 7013.06 38.230 303.820 6811.70 6864.10 98.60 S 714.62 W 5974486.03 N 370987.95 E 6.964 369.99 7053.02 40.960 307.260 6842.49 6894.89 83.79 S 735.32 W 5974501.20 N 370967.50 E 8.760 394.50 7084.32 43,130 309.110 6865.74 6918.14 70.82 S 751.79 W 5974514.44 N 370951.26 E 7.983 414.91 7116,04 45.030 311 .720 6888.52 6940.92 56.52 S 768.58 W 5974529.03 N 370934.71 E 8.284 436.58 ------------.---- 6 June, 2002 - 13:06 Page 4 of7 DrillQlIest 2.00.08.005 Sperry-Sun DtilllØg Services . Survey ReportfprCD2-22 Your Ref: API 501032042100 Job No. AKMW22077, SUt1tèyed: 27 May, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ,- 7147.89 47.320 314.510 6910.58 6962.98 40.81 S 785.34 W 5974545.03 N 370918.22 E 9.571 459.32 7180.03 49.880 316.350 6931.83 6984.23 23.63 S 802.25 W 5974562.49 N 370901.61 E 9.048 483.30 7210.70 52.090 318.010 6951.14 7003.54 6.15 S 818.45 W 5974580.25 N 370885.72 E 8.343 507.06 7243.04 54.510 320.510 6970.47 7022.87 13.50 N 835.36 W 5974600.18 N 370869.15 E 9.716 532.97 7274.01 56.750 322.830 6987.95 7040.35 33.55 N 851.20 W 5974620.50 N 370853.65 E 9.515 558.53 7306.00 59.390 324.540 7004.87 7057.27 55.43 N 867.27 W 5974642.65 N 370837.95 E 9.417 585.65 7338.06 62.250 326.520 7020.50 7072.90 78.51 N 883.11 W 5974665.99 N 370822.51 E 10.423 613.56 7371.62 65.000 326.800 7035.41 7087.81 103.62 N 899.63 W 5974691.39 N 370806.42 E 8.228 643.49 7401.46 67.370 328.280 7047.46 7099.86 126.66 N 914.28 W 5974714.67 N 370792.17 E 9.147 670.63 7435.08 69.980 329.540 7059.68 7112.08 153.47 N 930.45 W 5974741.76 N 370776.47 E 8.512 701.66 7468.14 72.550 329.720 7070.30 7122.70 180.48 N 946.27 W 5974769.04 N 370761.10 E 7.791 732.64 7497.43 75.030 329.670 7078.48 7130.88 204.76 N 960.46 W 5974793.56 N 370747.33 E 8.469 760.46 7531.11 75.870 331.170 7086.94 7139.34 233.11 N 976.56 W 5974822.18 N 370731.73 E 4.980 792.64 7563.35 76.150 330.760 7094.73 7147.13 260.47 N 991.74 W 5974849.79 N 370717.01 E 1.509 823.48 7593.12 77.880 330.130 7101.42 7153.82 285.70 N 1006.05 W 5974875.26 N 370703.14 E 6.166 852.12 7626.55 78.510 329.050 7108.26 7160.66 313.92 N 1022.61 W 5974903.76 N 370687.06 E 3.681 884.50 7658.70 79.960 329.170 7114.27 7166.67 341.02 N 1038.83 W 5974931.14 N 370671.31 E 4.525 915.79 7689.14 81.950 328.630 7119.05 7171.45 366.76 N 1054.35 W 5974957.14 N 370656.23 E 6.768 945.58 .~ 7721.94 84.280 327.080 7122.98 7175.38 394.33 N 1071.68 W 5974985.00 N 370639.38 E 8.513 977.93 7753.91 86.250 327.010 7125.62 7178.02 421.06 N 1089.01 W 5975012.02 N 370622.50 E 6.166 1009.63 7784.33 87.000 327.160 7127.41 7179.81 446.56 N 1105.51 W 5975037.80 N 370606.44 E 2.514 1039.84 7797.31 87.270 327.460 7128.06 7180.46 457.47 N 1112.51 W 5975048.82 N 370599.63 E 3.107 1052.73 7934.03 89.080 329.980 7132.42 7184.82 574.24 N 1183.45 W 5975166.79 N 370530.69 E 2.269 1188.22 8029.40 89.630 330.490 7133.49 7185.89 657.02 N 1230.80 W 5975250.37 N 370484.78 E 0.786 1282.42 8124.65 89.320 329.910 7134.36 7186.76 739.67 N 1278.13 W 5975333.82 N 370438.86 E 0.690 1376.52 8220.34 89.140 329.970 7135.65 7188.05 822.48 N 1326.06 W 5975417.44 N 370392.36 E 0,198 1471.11 8313.58 89.510 329.230 7136.75 7189.15 902.90 N 1373.24 W 5975498.65 N 370346.56 E 0.887 1563.36 8409.27 89.750 330.130 7137.36 7189.76 985.50 N 1421.54 W 5975582.07 N 370299.68 E 0,973 1658.03 8507.63 89.450 329.920 7138.05 7190.45 1070.70 N 1470.68 W 5975668.10 N 370252.00 E 0.372 1755.24 8603.12 90.370 329.940 7138.20 7190.60 1153.34 N 1518.53 W 5975751.54 N 370205.58 E 0.964 1849.65 --- ---------- --------- ---- - 6 June, 2002 - 13:06 Page 50f7 DrillQuest 2.00.08.005 Sperry-Sun,fJrilllng Services . Survey Report lorCD2-22 Your ReI: AP"5tJ1t132042100 Job No. AKMW22077, SutVeyed: 27 May, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) - 8698.60 90.370 329.990 7137.58 7189.98 1235.99 N 1566.32 W 5975835.00 N 370159.21 E 0.052 1944.03 8794.24 90.120 330.050 7137.18 7189.58 1318.84 N 1614.11W 5975918.65 N 370112.84 E 0.269 2038.56 8888.53 89.940 330.820 7137.13 7189.53 1400.85 N 1660.63 W 5976001.45 N 370067.73 E 0.839 2131.65 8983.83 90.860 330.920 7136.46 7188.86 1484.09 N 1707.02 W 5976085.4 7 N 370022.77 E 0.971 2225.62 9079.58 90.680 331.150 7135.17 7187.57 1567.86 N 1753.39 W 5976170.02 N 369977.84 E 0.305 2319.98 9174.79 90.490 331.340 7134.20 7186.60 1651.32 N 1799.19 W 5976254.26 N 369933.48 E 0.282 2413.75 9271.29 90.180 331.610 7133.64 7186.04 1736.11 N 1845.27 W 5976339.82 N 369888.85 E 0.426 2508.73 9366.90 90.120 332.130 7133.39 7185.79 1820.42 N 1890.35 W 5976424.89 N 369845.23 E 0.547 2602.71 9462.53 91.170 332.200 7132.31 7184.71 1904.98 N 1935.00 W 5976510.20 N 369802.03 E 1.100 2696.61 9557.31 90.800 332.520 7130.68 7183.08 1988.93 N 1978.96 W 5976594.89 N 369759.51 E 0.516 2789,62 9652.58 90.000 332.550 7130.02 7182.42 2073.46 N 2022.90 W 5976680.16 N 369717.03 E 0.840 2883.05 9748.09 89.820 333.170 7130.17 7182.57 2158.46 N 2066.47 W 5976765.89 N 369674.92 E 0.676 2976.62 9843.55 91.350 332.160 7129.19 7181.59 2243.25 N 2110.30 W 5976851.42 N 369632.55 E 1.920 3070.20 9938.24 91.480 332.330 7126.85 7179.25 2327.02 N 2154.38 W 5976935.93 N 369589.90 E 0.226 3163.13 10033.54 91.540 332.390 7124.34 7176.74 2411.41 N 2198.57 W 5977021.07 N 369547.16 E 0.089 3256.63 10128.30 90.920 331.510 7122.31 7174.71 2495.02 N 2243.12 W 5977105.43 N 369504.04 E 1.136 3349.73 10223.93 91.050 331.380 7120.66 7173.06 2579.01 N 2288.83 W 5977190.18 N 369459.78 E 0.192 3443.84 10263.82 92.710 330.490 7119.36 7171.76 2613.85 N 2308.19W 5977225.35 N 369441.02 E 4.721 3483.15 10319.11 92.650 331.500 7116.77 7169.17 2662.16 N 2334.97 W 5977274.11 N 369415.07 E 1.828 3537.59 10414.53 92.030 331.170 7112.87 7165.27 2745.81 N 2380.71 W 5977358.53 N 369370.77 E 0.736 3631.46 10510.13 91.790 329.930 7109.69 7162.09 2829.01 N 2427.68 W 5977442.52 N 369325.23 E 1.320 3725.76 10605.65 92.950 331.740 7105.74 7158.14 2912.34 N 2474.19W 5977526.64 N 369280.15 E 2.249 3819.87 10701.10 92.950 332.600 7100.83 7153.23 2996.64 N 2518.69 W 5977611.69 N 369237.10 E 0.900 3913.48 10796.57 92.650 332.4 70 7096.16 7148.56 3081.25 N 2562.67 W 5977697.03 N 369194.57 E 0.342 4007.01 10892.17 92.460 332.620 7091.90 7144.30 3166.00 N 2606.70 W 5977782.52 N 369152.00 E 0.253 4100.67 10985.62 92.220 334.620 7088.08 7140.48 3249.64 N 2648.19W 5977866.87 N 369111.95 E 2.154 4191.89 11074.36 92.280 334.530 7084.60 7137.00 3329.73 N 2686.26 W 5977947.59 N 369075.26 E 0.122 4278.19 11134.00 92.280 334.530 7082.23 7134.63 3383.53 N 2711.89 W 5978001.82 N 369050.55 E 0.000 4336.19 Projected Survey - -~---~-~~--- ~-_._~ 6 June, 2002 - 13:06 Page 60f7 DrillQuest 2.00.08.005 Sperry-Sun.. Drilling Services Survey Report forCD2-22 Your Ref: API501032042100 Job No. AKMW22077, Surveyed: 27 May, 2002 . Kuparuk River Unit North Slope, Alaska Alpine CD-2 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. -- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 321.288° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11134.000., The Bottom Hole Displacement is 4336.19ft., in the Direction of 321.288° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11134.00 7134.63 3383.53 N 2711.89W Projected Survey Survey tool program for CD2-22 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 11134.00 7134.63 MWD Magnetic -------~-- ---- -- ------- ------------- 6 June, 2002 - 13:06 Page 70f7 Dr;JtQuest 2.00.08.005 ) ) Note to File Well CD2-22 PTD 202-092 Sundry 302-274 Phillips Alaska, Inc. (PAl) requests approval for annular disposal in the subject well. This note analyzes information submitted by PAl, affirms mechanical integ- rity of all wells within CD2-22's area of review (AOR), and recommends approv- ing PAl's request for annular disposal. CD2-22 9-5/8" surface casing was cemented with 276 bbls lead cement followed by 48 bbls tail cement, totaling about 1400/0 excess cement relative to gauge wellbore. 80 bbls of lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that CD2-22's sur- face casing is adequately cemented. The formation below the 9-5/8" shoe supported a 16.2 ppg EMW leak off test. Applied pressure dropped 65 psi (from 860 psi) during a 10 minute observation. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 9.7 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pressure reached a maximum of 845 psi. The pressure then stabilized and shut in pressure varied between 533 psi and 455 psi over 10 minutes. Cementing records indicate mechanical integrity of all wells within CD2- 22's AOR. Refer to well CD2-46 (PTD 202-082) for additional information on wells within this AOR. Based upon information submitted, AOGCC recommends approval of Phillips' request for annular disposal in Well CD2-22 (PTD 202-092). ì J /6 .A CC/Ic¿J tJ L Winton Aubert \IN' rr Petroleum Engineer ) ') Phillips Alaska, Inc. Post Office Box. 100360 Ancho,rage, Alaska 99510-0360 Telephone 907-276-1215 .11.'.,."".' '" t'l,'l,"',,'.,:. " , , , '. August 21, 2002 Alaska Oil and Gas Conservation Commission 333 West 71Ì1 Avenue, Suite 100 Anchorage, Alaska 99501-3539 .Re: Application for Sundrv Approval for Annular Di.sposal of Drillinp: Waste on well CD2-22 Dear Sir or M:adam: Phillips Alaska, Inc. hereby requests that CD2-22 be penllitted 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 CD2-22 approximately September 30, 2002. Please find attached form 10-403 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 CD2 pad and the lateral distance from the surface casing shoe. Details regarding wells on CD2 pad within 1¡4 mile radius should be on file at the AOGCC. If you have any questions or require further information, please contact Vem. Johnson at 265-6081, or Chip Alvord at 265-6120. dIY, ~Tohnso¡ Drilling Engineer cc: CD2-22 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 ~"II ii :,:,:..,. ;'~ " ¡~ uc; '2, '7' ?OG? ,d¡.laS~(a lj;.~ ~:;\, ']...,:'.~ . .' ORfG' ~t,>"g l~ N ,C-' , , ,~" II " " ". ! " ; 1);1' \I:l,.J¡ l ,.. ~,~~,,! \L' \ '-. ì\ } ') WCiI\- ~' 075 Cì!IQ IO'L 9( 1'1/~ '7/2.0/0 <- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well- Change approved program- 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1786' FNL, 1537' FEL, Sec, 2, T11 N, R4E, UM At top of productive interval 1497' FNL, 2613' FEL, Sec. 2, T11 N, R4E, UM At effective depth At total depth 1589' FSL, 1019' FWL, Sec. 35, T12N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 11034 7134 11034 7134 measured true vertical Length 78' 2345' Size 16" 9-5/8" Casing Conductor Surface Production 7808' 7" Perforation depth: measured None true vertical None Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented Pre installed 350 Sx AS III L & 230 Sx 15.8 class G 165 Sx 15.8 class G Tubing (size, grade, and measured depth 4.5" 12.6#, L-80 ibtm @7322' MD Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6, Datum elevation (DF or KB feet) F\KB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-22 9. Permit number I approval number 202-092 10. API number 50-1 03-20421-00 11. Field I Pool Colville River Field / Alpine Oil Pool Measu red Depth 114' 2382' True vertical Depth 114' 2381' 7845' 7182' 13. Attachments Packers & SSSV (type & measured depth) 7" Baker S3 Permanent Packer @ 7201' MD, Cameo DB nipple @ 1993' MD Description summary of proposal- Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation 15. Status of well classification as: September 30,2002 16. If proposal was verbally approved 011- Name of approver Date approved Service _x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.{ {}tÂ.... Ch Ip Alvord Title: Alpine Drilling Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- 0n91Oal Signed By Cammy Oechsli Taylor Approved by order of the Commission Form 10-403 Rev 06/15/88. (J Gas- Suspended - Questions? Call Vern Johnson 265-6081 Date 8IL~(OL I Approval no. 7ll ..30'--2 7 i!efloÆ o~ /w&.hW.{Q;v Dv's po ~CL (; Date 9ß~2 Commissioner 1 L~ SUBMIT IN TRIPLICATE ) ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-22 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. 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 1S000 mg/I. (Ref. AOGeC Conservation Order No. 443, March 15, 1999) d. 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 There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types offluids can be n1ud, diesel, cement, and waste to be disposed of and the estim.ated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1905 psi. See operation and calculations showing ho"v this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT/FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i, Any additional data required by the Commission NA to confirm containment of drilling wastes. ,) ) CD2-22 Pressure Calculations for Annular Disposal DETAILS: ~ ..... ..... Q) "C Q) <U "C Q) <U .s::. Q) .s::. lñ Ii) Co Co o 0 0> 8 0 c: N 0 ëñ N <U + + () ~ ~ Co Iii ïñ Lõ Co Co I ,¡- ..- L 0 0 ~ ~ II) <U C> C> <=:9-5/8" 36Ib/ft, J-55 BTC casing (c.g 2382 ft MD (2381 ft TVD) Pburst = 3520 psi, (@ 85%: Pburst85% = 2992 psi .......... .... .... .... ..tö'ë Z Z Estimated Top of Cement @ 6903 ft MD (6774 ft TVD) (7" csg x 8-112" Open hole annulus) 0> c: :is ::J I- 0> ~ c: "7 "jii "I;" <U 0 <=:4-1/2" 12.6 lb/ft L-80 tubing to 7322 ft MD (planned) L ~ <=:7" 261b/ft, L-80, BTC casing C?ß 7845 ft MD (7182 ft TVD) Pcollapse = 5410 psi, C?!) 85%: P coUapse85% = 4598 psi ¡:... ~ ASSUM.PTIONS: . M:aximum injection pressure, P Applied = 1500 psi . Maximum. density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULA TIONS: Maximum pressure at 9-5/8" shoe: P max = PHydrostatic + P Applied - PF'onnation Pmax = 12.0 (0.052) (2381)+1500 - 0.4525 (2381) P ma.x = 1908 psi M.aximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFonnation 2992 = MWmax (0.052) (2381) + 1500 - 0.4525 (2381) MWmax = 20.8 ppg Ma.ximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0.052) (6774) + 1500 - (0.1) (6774) - 2000 MWmax = 16.4 ppg ) ) Casing Detail 9 SI8",$urface Casing ~PHILLIPS Alaska, Inc. .' A Subsidiary of PHILLIPS PETROLEUM COMPA~~Y Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 56 Doyon 19 RKB to LDS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 54 Jts Jts 1 to 2 2Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 33 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18.20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54 60 joints total in shed - 56 joints total to run Last 4 joints stay out # 57 thru # 60. Use Best-O-Life 2000 pipe dope Remarks: Up Wt - 152k On Wt - 148k Block Wt - 75 Well: CD2-22 Date: 5/17/2002 LENGTH 36.82 2.22 2260.53 1.60 78.79 1.70 2390.00 Supervisor: David Burley DEPTH TOPS 36,82 39.04 2299.57 2301.17 2379.96 2381.66 ;~ ,~ ) ) Legal Well Name: CD2-22 Common Well Name: CD2-22 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/15/2002 1 Report Date: 5/18/2002 5/15/2002 End: 5/28/2002 +=:7D~?~!S~-=Z,~7~ii~~~~l;;~Ë;~~'~è-:i"=?"=~=:==; Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,382 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/17/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cm~.C~: ~~.C~: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Cmtd. Csg: Cementer: Jim Thompson Pipe Movement: Reciprocati ng : ::"P~Þè::"'9ve""l1t Rot Time Start:: Time End:: RPM: RecTime Start:06:45 Time End: 10:25 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 152 (Ibs) I ,p,.".-~'--r7i'"'~~~'::~'-i'~r"~~::,~:~."'''';o.,.~-r-::';~-;"'Tr-~"..''','~:~~~':'~':'~'.T~~\~-":I~~""-7'Tr-~':':'~~"-rrr"~'p~'~""-rry,:,~:.~.~~-r:'~1'"~::rT" Max Torque: (ft-Ibf) Drag Down: 148 (Ibs) " 'Stagè'Nø:1tJf1 ' , I ~-~.~---~~~.~~.~_1._~"-~~-"""~.~_'L'_""~.~--_._'-~--''''''~_.~~.._~...~~~~___._~L._---~~___.__l.....-:;~..~~;~~~..:~'~~~~~~~._...,"_....:.'~~~~.._~...-:.~:~-~.__..._...'.......,.~~~.__....._--.~-~~..~...__.......~~-~-;-_i__.--:~-~J..'_..._-:.......~..~__;._l_...--..~~_.:-~.~~ Type: Cement Casing Volume Excess %: 50.00 Meas. From: 80 Time Circ Prior To Cementing: 1.75 Mud Circ Rate: 336 (gpm) Mud Circ Press: 330 (psi) Start Mix Cmt: 09:06 Start Slurry Displ: 09:07 Start Displ: 10:01 End Pumping: 10:29 End Pump Date: 5/17/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8,50 (bbl/min) 9.00 (bbl/min) y 470 (psi) 900 (psi) 2 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 80.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer M,u~Daw'. ' ~.J_:¿-~"~'.¥.,. ~.~ .......J -' ~4';'~...:, '~~';-':'-"~:;"~"~'''- ; _.:_._~.~.~: ~p~~-;~...~~...::.:"'~~,_¥. _:_-~ ~._:'.:"'~., ~- ,L .......~':,~~ - ,-~_:.~'-'~ ..~:...:.. ~'-'-"'~.- ..: ..:...:..~ -. ...~.~.-:. --~~-;--~~ ,_:,~,.....~ .:- ,-~..._.,.~.,~ . _._._~~~...;:~-...~ ...-.."- ......:,--';"'.;.::_..~,~'.~......~'......~,; ..~-,-~'.~ ~_.......,~ Type: Spud Mud Density: 9.5 (ppg) Vise: 48 (s/qt) Bottom Hole Circulating Temperature: 78 eF) Displacement Fluid Type: Mud PV/yP: 16 (cp)/18 (lb/100ft2) Gels 10 see: 15 (lb/1ooft2) Gels 10 min: 21 (lb/1oofF) Bottom Hole Static Temperature: 58 (OF) Density: 9.5 (ppg) Volume: 178.00 (bbl) . I .' , , ,. . .. , Stáge,No~f,SlurrY' ,No:'1Qf. 4 " " , . , ..-.:.._-_.~ ..._.¡JL-_......~~..:""'.~-_...._..... -~:..L-_......._~.. ._.,,"-_._;-~' ...~.~I..---~_.¡ ...'_.Iol.-.._.~.... _..."---~._.-!. .. '_...,--_.~_..... ~.'..I..---~"""";""".- '-:..--....-..... '-........_~..._..... '-.__.~~,... '.."'_--"¡"--~''':''''''''__4.o.-~...~.''--''.o.-.....- '-.1.1. Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: eF) To: (ft) Description: Biozan water wI nut plug Class: Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: eF) Temperature: (oF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (oF) eF) Pressure (psi) (psi) Printed: 8/19/2002 4:16:44 PM ~~", ,(Ø ) ) Legal Well Name: CD2-22 Common Well Name: CD2-22 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/15/2002 1 Report Date: 5/18/2002 5/15/2002 End: 5/28/2002 ......~~~, I ";",~~~-'~-~~'-~'~--:-"""~-:r~-"':~~"'-:"-'~r-rr~~I"'" 'I IM.~"7~:-;-:'''''''~~-~~~-~~~~''''~''~-'''''''':f---r-...:~~__~r~_'''-'-~-""7--.r-::"--~-~:,-'Of--""-'--""""T-~:'~~ >',.'< "",'< ,,'" " , ',$tå~~l\1øi"','1,'~IUrry~O:2bf4 ," " ,', ,," ,"" ~~"~~~~~~..L:l~,~,~~'~_~~~I'~_'. ,.-J._~-~~~:~.- ..J_~---'~' .. ~~,'~.I'~.~_"~-~'.:..J"-~~~'-~~'~~.~ ~--~~.....~:;:~._."":~~,.~_..~.;.:~.~.~.--~,:"""~~l~.I.~......_~,_...~~"~-'---- ."._-'.,J.~~_~~' '~:""~'-'~~-~~:~.I.~.----_...J..~ ~~~.~..i.._.."~~~.J._~.:...:~,~--:~ Slurry Data Fluid Type: FLUSH Slurry Interval: (It) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) Description: Mud Push XL Spacer Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: eF) Temp eF) eF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) I '. 'I ',' . I, ,', , ',' " ' , ", ' ':'$tag,~No=,l,ShA.rry,Nq:.3 ot4 " ' " ' , , " ' :~;.... ~ _~':l ~1,~~.~~~..'~nL..'.~~'/, -,..._~~~~'~' -I. LL "';~.:~~~:...~I.' ~-~~.. ''''::~_~~_al.'~_'~~' '_____"M .l~__~LL ~ .~~.~ "M"'~~_~LI:-: ~:"..' '~.:.''':~~ ~~:.. ~--'~.~'.'.:~':u '~, ~~'~._L~.~LI'~ ~~~ ~;_.~ ~":oL .-:~~~~._-:.~~ -_..-:.~~-'--_.. ~ ....____~-:'~LL - _~..:"_L~....I.-'¡ J~'~"'-:'~:"'.~-~~'';'''-'~..... Slurry Data Fluid Type: LEAD Description: ASLite Class: Slurry Interval: 1,882.00 (ft)To: 37.00 (ft) Cmt Vol: 276.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Source: Slurry Vol:350 (sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: eF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) .. '~~.~,::'~~:~~~ :~-~I'~~~~ ,~wor""'-:-~I':'''--~~-~"":''~~,':'~' ..~~~,'_M~'~~~~""'"'--:""-~I:...,~---,_.-r'~'-~"~-(!~'~~'~~-'~I"T.~.-ì'~-'~~~-r'~'-~:~-:-~':-~~~,':'''-~'7"'~:~:'"""7-:'~~~-~-~'~~~' ~-:,~¡,-......-r '~~if'-~-(~-'-~','ì'~-~-;-""" " , ' , ','" ,Štag,ø 'N9:1~turry'~~: 40f4, ,'" ' , --l.b.I..:~;_L':.""~"":'-hl.........1.J"',~----~~'.~,. 1~_...:~..L.~':~,"~__l..~~',.....~._.'~--,-',~~~.._L....""~',:'~ ~......'~,.~._-_:..:...'~~.:,....._:'_...--o..~,.....,-~.-..:....._,.--"....."':~.....~-',-i...~~--~"'.J.._~ ~....._..J..~"~~~":"'~''''''_-':'._.!.._.,.- :~..:- eF) Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,382.00 (ltyro: 1,882.00 (ft) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol:230 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: -..----.. Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: eF) Time Compressive Strength 1: Compressive Strength 2: eF) u_---_.._~ Temp eF) (OF) Purpose: TAIL Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 8/19/2002 4:16:44 PM ) ) ~~, 'R;¡ , I~ I, , , "PHf~LJ~$ALÄSKA I'NC. , ',: '" " """", " ," "C,è~enti:ngR.eport Legal Well Name: CD2-22 Spud Date: 5/15/2002 Common Well Name: CD2-22 Report #: 1 Report Date: 5/18/2002 Event Name: ROT - DRILLING Start: 5/15/2002 End: 5/28/2002 ~.~~~~'~:'~'~~:'~-;t'"T~~~'~:~-"~~',~7~:':~:,~-~"""-~"7 .,-.~~-,T""w"~'.~~-~-----~-~ '~'~~~""7:'.-'-~-;r~"7"--~""T"f-;'~--~'~~77'-----~-;"'~--~,~"~::~~~;-'----'-:r""-7~'~~'-,~-'~'-:r~~~'L<'-' ',:':ija:~'ngl';J~~t: , '" ' " ,,', ,.Li~erT~p,'Test"'", , ~...IJ'~~'''''''':.I:'''''''_'~'''''_-'-'''''':~-oJI''-~':'''''~~ ~_.-....._'~....J". ''''''"---'~-''''-~''''''''-'-'''''-''~.J...'-'!''_..I._._.~.:.-.,:.....~_.:J....J'-'''----':-L..'''':~._.~.",:~,~-~~,,~,.-.I...o~.~ ~....I.~........_~,-,-J':"""_~"_~I_~":"..J.~~~,-i...-': .I...J....-"--'.~,:""_,,,,,,--,--,:~~.... ':"-~..J.~~--~-_.u"...""",-,""",- .~.._~ Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 15.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N -:-'~-"~~~"7ï~:"~'~"~""~'~'~~~':',~'7"'''''~'"7~~~':~~:''';'~~~:'"'~~':'r'"~"-";7""""7":-~17::.1: ':1. . '. . ',' "',',,':',~~/~u,ry~v,,~va~U#idn,:, ,'" .'. , '.' ". ,":' ,:I"t!'~Pretati~PSU~ðiaifY":,:" ',.,,':.' '.', _...._~-- ,..L.----...'-.........--..-.""""'-,-..-- ---.........J_'_.........--...__...J..'_... ...:.--..,........--.---. --_.IoIJ...'-"', .........'--_.o-J...'-"'.'-~_.~''''''''''_...._-_..,¡,J.._..--'-- .w..,-...-- --....J-._..,..- '-_......J...,---~_......L-o...:......_-'-_. oU....o...-....--'-- ....J.........._~.....,--_.~ CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N ._._-_.....__._._-_..,..~._.__.~.._-_..._-.._._.._....~,,_.""'--'-.----"'--'- ---..-..--.-.-..-....-.-.---...--.-.---..-.-.---. _._'-_.~'---'-._---'._-'- Printed: 8/19/2002 4:16:44 PM ) /. ~ ~, ~'~,~ ~', PhIUip_Alasl«i¡h1ç,' ~'I I, ,'" ';",: :'-",' ': :,'." ,I , ",', '",' ,",pa,ily'QrlUin'Q,f(8Þ9tt:':"",,', ",,' , :~LL NAME' CD2-22' " I JOB NUM~ËR ¡ ËVE~T;~DÊ I ~'H~S PRÒa' T~~390.0 r rv;389.0 r DFS2.1 Q.,_J.R~::_;:~_.I~~;l~~?- ,SUPERV;:~~~!~~,_.,-,-,-_.t:,::~-;;;~~~:@~~~~~m 19 .,.J.::ELD NAME ~~~~;~~'-_"---_.__._~~~J~~1.0 I DAIL ~..~~~:qQ_.. fU_:_~~~;QQ-_.._,,-_._.,.- CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG WI MUD ,,~,--,_...._...__...._..,_._.,._.,,--,__.,.QtiJJ!n..9 out cemen!''@_?~§'Q~......",_..,-_.._._-,.._...._....._._-,_._...._..-_._,-,_.._..._-,--,_.~,_._.,._....._..__.....~.,.,._..,.__.--,-, O. 00 ._..._....__.__..._._......,._._._~".._...Q.:,QQ....,_.__.._-.,,----- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAIL V TOTAL CUM COST WI MUD .-...,--..-..-- CI~!!:LQ!:IJ£~.!TI.~!:!!J.._ElL ck!!L~J.[?~.~,_b~~..:..,__. -_.__.~..._-_._- 5/1.?gJ2Q~____,----,------~- 309,041_.___--,--_._.._...~__.?lQJ...~Q__---~--_... ::;;VEŸ:õArETM)--t~~:;:tr~;;:~:T-=-lNEXr~N"-~~--~~~T-- 5/16/200~_~,_..,..,--,..~.~1.?.: 18 , 1.020 ..___,..?Q~;30 16.QQQ,1!!!) @ 118.0 (~L, _~~§,'<in) @ 2,3?0.0 (ft) 5/1712002 --..--. ::~,~-~-~1!(.~.e~LL- r-2~-~ ;'-'-r.l!~~L..,__.._..~ .'ë..,,-~.P.t r--J.~!lQJ}~ltJ.~~~~!~~!l-~..-- .,~:~-._- :,~......L~~~_~r"~tJ,~.. ,-~:-,g:?9_-:,__~ .... '"I~¥",<'~"0',~"~t:L~,WLtJi,ntP,,F~J1:$~L,, ,QI~M'~r< ,,"/"~I1~~~~ ,P~,pM,;,:"""Pt(~. "',:';<::1",, C~:.' "',I;f::!S, 'L,~t:".S.. 46 11/9 3/10 10.81 31 193 /12.5 7.11 I -_._~--..__._--_..._-_.._--~~- -.--.-- _.._--.._--~--~.._-------. --~".._---_._-----_.__... ~~~~~Ei~i~1E~~jf~~~~~~\1.~=~~§t~:2'f~~~~= . 1,074.39 --cc"-~~~:-~-'~' -:---:.--:;-'Tf~~¡~~ïp~ø~~-~'7--~ -~-~~'---~.~"~-- ~- -~RjT$~". .~.~iijGi~~~ ~ ._--'-~Ö:~:.~._,..~-~ ~:TD:r-~~-'~C~N~:s,ie'r'éi?-~'-~;tlPi- BIT DP-0912 PDC 1 1.00 8,500 ..,-_.__..~---_.....,_..._._-_......._-_.._._--_..._-_.__.---"'--'--'-'__"_'M"'_"_--'-'---.'-"'-"- .--.---.---. ----'--'-'-----"--'-'--'---'--'-'----~"---'--'--"'--..- .-----.---.-.-.---..... NAVIDRILL M1XP 1 23.04 8.375 NMSTAB 1 4,45 8,125 2.875 '-'---"""---'-""---""---'-'---"'---'-'- ---....-- _._- -"",,----,'...---.-.-.--.ø_-.' ,-.,----..-.-.----.-.--.-.---....- GAMMA SUB 1 27.72 6.750 1,920 MWDW/FLOAT 1 22.35 6.750 1.920 ."-'---""-""_'M____.'-""'~'._...'---"_.'_."~~'~._-'"..._~...__...~..._--_._..__...._~._._-- -""--~~-.'- '-'--"-"~_._---'-'-~-'-'---"-" ..._._--_.._..~-_._-- DPCSNM 3 88.87 4,500 2.875 CROSSOVER 1 1.67 6,250 2.875 "~-"-"'_~"_~M"'.'~_'-"-""--'~'-'--'--'-""'--~'-'--_. .-...-...--....-.-...-...-.-----.-.-,-....-..--.--...,,-...----.-..,,--.----.-...-...- .-. ..-...-,--,-.-...-..-----.-.--...-,..-.-...-..--.-....-...--...- HWDP 3 90.47 5,000 3.000 JARS 1 32.37 6.250 2.250 ..---- --'------M"____'M"_'._"--.'.----".-'-"--.-.----".._--_._-.__....__._.__.__....._..__._._~_... ._~-_._._- ..~._,..__.- --'."-"--'-'~'--"-'----'-'--'..._"---'-'---"..'-------_..~. HWDP 23 689.09 5.000 3.000 CROSSOVER 1 1.37 6.500 2.500 -'---'-'--"-'''-'---''''---''--''-'"''''-''-----'--''''--'----'--""--"'-_'_"__M"____,"--""-'-"".'''--''--''- ~.._'"_.. __'___M' ---,,~-- ---.._-- HWDP 3 91.99 4.000 2,562 ~~jt~1:E~~-::=;i~~EE~îE~~~z!if~~~;:~3-3~~~i~rii~:~~~:r 2 I 1 8.500 HC DP0912 7000565 12/12/12/12/12/ 2,390.0 5/17/2002 0-1-GT -5-D-I-NO-BHA -"~-~'-r:-:"~~':-~"':-'--:~~"~~'~"-:~-''-~~-'-T~~-:-~-:~.':---~'~"~'::~~'-".~'.'~~':BffòPERATïo~-~:-'--r: -~-c~.,~r~'-~--"-'"7'-~-":-'~~:---:---:~-~'--~~-~:~-'._,~,-~~,.-:--'_. ~~"=~~!!~~ii~=r"~:-wge~-1~:,RÞ~=1~~.~~fI~~~}~l!=:r-~~$: I' 1-~4W~ë)~$T"-Tt4Hf~o~~.r¿-~M '¡Rslçüiii)~~~rt~~t\Oi: ~~~~J~~~~~~~~-;;~~I== 00:00 00:45 0.75 CASE P RURD SURFAC RUt 0 run 9 5 I 8" cas i n 9 00:45 01 :00 0.25 CASE P SFTY SURFAC H e Ids a f e t y and 0 per a t ion s me e tin 9 wit h rig and support crews. RUNC SURFAC Ran 5 j 0 i n t s 0 f cas i n 9 and at t e m p t e d to c i r cui ate to check floats, unable to circ through fill up to 0 I. -- --. -- RURD SURFAC L D fill u P too I, c h a n 9 e 0 u tho sea n d c h e c k val v e assembly. MU fill up tool to Top Drive and circul ate to check floats. RUNC SURFAC Run cas i n 9 (t 0 t a I 56 j t s) M U h a n 9 era n d I and i n 9 j oint and land casing with shoe @ 2382', FC @ 23 00' . ._._-_.~.._-_.- '-""-"-~._--'--'.~~ ---.--....------. 01:00 01 :45 0.75 CASE P 01:45 03:15 1.50 CASE Np EQIP 03:15 06:00 2,75 CASE P --------'------___'__M_._--__-----------'--'---- ------'--"--- ._---- Printed: 8/19/2002 4:26:40 PM ) ) /¡m~' .. .", . I ~I' . I . , I P~lilli,P~'Alaskaflnc~: I ,'~~i'I)'t;)ri~n~Q,~éPotf , , , ' JOBNUMBER[EVENTCODE I24HRSPROG ITMO '[,vD' lDFS IREP_T_N30.DA,TE' CD2-22 ODR 2,390,0 2,389.0 2.10 5/17/2002 ~~~~jti~~~E~:@~~?~~~~~ff~~E1E~~f~!2 ,.~:9.<l_~:~.?_---Q:.?~_.._-~,,~~§~!J.:_~--_.._~_.,,-_.!3_~~ D ---.- .~~. R ~~.9..~._~,I._~.~~ n.,._!J_!_~.~.,.~--~.~~.,._~-~-~-~~__~~...!.m e n t ~_.~ ad. 06:45 08:30 1.75 CEMENTP CIRC SURFACCirculate and condition mud for cementing 8.0 bp m I 330 psi, had full returns throughout. PUW 15 2k SOW 148k, PUMP SURFAC T est e d c e men t Ii n est 0 2500 psi - P u m P e d 40 b b I s of Biozan spacer with nut plug for marker, 50 b bls of 10,5 ppg spacer, 275 bbls of 10.7 ppg lead and 48 bbls of 15.8 ppg tail slurry. SURFAC D is p I ace d wit h 20 b b I s F W fro m c e men t e r san d 1 78 bbls of mud with rig pumps @ 8-9 bpm, plugs bumped, floats held. Reciprocated pipe until I las t 30 bbls of displacement, had 80 bbls of 10.7 pp 9 cement returns to surface, full returns throught , CIP @ 1030 hrs. RURD SURFAC Flu s h Con d u c tor and f low I i n e, R D c e men the a d a nd LD landing joint. NUND SURFAC N D D ¡v e r tor s y s t em, ins t a II and t est U nib 0 d Y well --,---.----_..,.~._-,_.._.._".- ,-~---_._--,-,!:!.~~-,_!....~.~ 0 0 0 p ,~_!~-_.._.._,-_....._--- NUND SURFAC N U BO P E. -_... ~-,._-- ..-----..--..---.....---. ..-.----..---..-..-- BOPE SURFAC Ins t a II t est p lug and t est BOP E. T est pip e and b I ind rams, choke, kill, manifold and surface safet y valves 250/5000 psi. Test annular preventor 25 0/3500 psi. Pulled test plug and installed wear b ushing. John Crisp (AOGCC) waived witnessing t est. WELL NAME 08:30 10:00 1.50 CEMENT P 10:00 10:30 0.50 CEMENT P DISP 10:30 12:00 1.50 CEMENT P 12:00 15:00 3.00 WELCTL P -.-, ..-......-..---,...-- . ''''---'------''''--'. 15:00 18:30 3.50 WELCTL P -"-'."-".'''--.'-''-----''-...'.-''--.''-.'.---'--'' 18:30 00:00 5.50 WELCTL P ---""'-"_."._-'-""-"""_"'R'"___'.''''-'~''''''M___''._~R'''...._-_...._.w._-,--_..._,,~..._.~- -_"._~R'____W""'-~~'-----"._~W'-----". ----"--~_._----"._~-'-----"._'R'''____''._~~.''---''''._.~...- -~~._'i~~.~Y..~~~~~.Y.:,.._~~!:)..~-~.~._C?~'!1~~~-~':!.Œ:~~!_~.~~J~l shoe @ .?~~?'.:.~,!stall wellhead!~,~.~~~.~~_!f?_~~9~.~.:.._....._~,_._..- ---~..__._._._--_..__._.~.._-----_.. t2t~~£=Ì:S~~:S:-~~~~]l~~!~~~iE3~==~2~~~~;~~~ .~~!~!P~--_._.__..,_._-_....._,._._._---~..._...- _._.._---_.__..,-,--,_.__._..._._!.__....__._,-,--_.~X~'!_---.._...-'-'-----"-"-'-'-- ---"---'-"-----'----'-'-'-- ~---.._..~?J__...._....,-,--_... AC 5 DSR 4 ..--.-.----... -..--.--...-...---.-.--...-...--.-. --'--'--.-'--".-.'---'--'''--'--'-'--'--.'-'-'--'- _~~~~_I.~~..9..~,- .---.--.-----.--.- --~---_._- 1 MI ,?!!~ling..£~~i~~__. --.---...--. ---~-- Dowell 3 Sperry Sun 2 .-.---...---.-.----.--.-.---...-- -..--.-.---.. --'-'-.--'.-'- =-~'.-;=-~~',-:==--='-~-~"-'~~-"-~~:-""'~"'-'-~'.'~===--=:~~mg'R1~,:j'-~f{s~fiQ~j'~.-:~=~~~'~'-;~~~~~~'.-;=~"-'~'.-~==--=.-;.=.=-~'::== ~--"J..~~ -~--_:,-~~,,!~:...;~___~~USA~,__~~~ HA~_',_~~-_.....; ITE~~__L.-.-~:~N'T$' -~- USAGE, --~~<>~-~~~~._L... Fuel gal!.-...___- 918 -3,394 ~~ter, Potable bbls 115 --_::~~Q......-- Wa~er, Drilling bbls ._.._-2~~-_.___..:2,~~- .--..----.-..-- --~--'7----- --:---"~-:-----~~---~'---'--"'~-----'S~PPORTÇRAFT-----'~ ~._~~!_-~---~~O~-~___,,-~RKS -~~ .. 'TYPE CD2-49 1,626 CD2-22 -.------",----",---,-'....------.---"---......-. NO. " ' REMARKS -----..__--J._-~._- Printed: 8/19/2002 4:26:40 PM CASING AND FORMATION INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 5/1812002 Pump used: I ~1 Mud Pump, I... Strokes .., 'Pumping down I' annulus and DP. I.., , I I Hole Depth 2,410 Ft-MD 2,409 Ft-TV.D I. L.- Formation IntearitvTes1 Mud Weight: 9.3 ppg Mud 10 min Gel: 14.0 Lb/100 Fr Rotating Weight (Pumps off): 140,000 Lbs BlocksITop Drive Weight: 75,000 Lbs Desired FIT EMW: 16.0 ppg Estimates for Test: 830 psi 0.5 bbls ,... FIT 15 Second Shut-in Pressure, psi 855 Well Name: CD2-22 I Rig: Drilling Supervisor: David Burley Type of Test: I Casing Shoe Leak Off Test Hole Size: IS-1/2" I. Casing Shoe Depth RKB-CHF: 37.0 Ft 2,382 Ft-MD 2,381 Ft-TVD Casina Size and Description: 19-5/s" 36#/R J-55 BTC Casina Test Mud Weight: 9.4 ppg Mud 10 min Gel: 18.0 Lb/100 Ft2 Test Pressure 2500.0 psi Rotating Weight (Pumps off 140,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Estimates for Test: 1.5 bbls EMW = Leak-off Pressure + Mud Weight = 860 9 3 0.052 x TVD 0.052 x 2381 + . EMW at 2382 Ft-MD (2381 Ft- TVD) = 16.2 ppg / ./ 3000 . 2500 2000 . w c:: :J ~ 1500- W c:: a. 1000 " 500 . 0 0 Barrels Lost 70 psi during test, 97.2% of test pressure. ~ti4.,~~_~~J_1 I i I .--'.-_o_--~~~~~~4~-i,~~~- I i-- I I I ! 2 I ¡ i i i i , 3 0 5 10 15 20 25 Shut-In time, Minutes 0 FIT Point ~LEAK~FFTEST ~CASING TEST Comments: I Volume Input Volume/Stroke Pump Rate: ; ! - ì i .. ~ 0.10001 Bbls/Strk! .. 6.01 Strk/min I .. ¡ ! ' ! ! CasinQ Test Formation Integrity Tes1 Pumping Shut-in Pumping Shut-in Strks psi Min psi Strks psi Min psi 0 0 0 2510 0 50 0 855 6 620 1 2490 1 140. 0.25 855 8 835 2 2490 2 270 0.5 852 10 1040 3 2490 3 400 1 825 12 1250 4 2480 4 550 1.5 800 14 1430 5 2480 5 680' 2 765 '~~ 16 1650 6 2470 6 770 2.5 745' 18 1900 7 2470 7 860 3 728 20 2130 8 2470 3.5 700 22 2380 9 2470 4 680 23 2510 10 2470 4.5 670 15 2460 5 650 20 2450 5.5 635 25 2440 6 625 30 2440 6.5 622 7 615 7.5 612 8 605 8.5 600 9 597 9.5 595 10 595 I ~, 30 Volume Volume Pumped Bled Back 2.3 tsbls ~ ~. Volume Bled Back -,HbIS Phillips Alaska, Inc. ) ) Casing Detail 7" Inter",ediate Casinq Jt Number Num of Jts Jts 3 to 190 Jts1to2 Remarks: 188 Jts 2 Jts Up VVt = 255 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to LDS FMC 11" X. 7" Hanger 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg T' Davis Lynch Float Shoe 8-112" TD 1 straight blade centralizer per jt # 1 thru # 22 # 131, 132,133, then every other joint fl # 135 to # 187 Total Centralizers: 53 198 joints in pipe shed - last 8 joints stay out Use Best-o-life 2000 pipe dope On VVt = 200 Block VVt= 75K Supervisor: Don Mickey Well: CD2-22 Date: 5/21/2002 LENGTH 35.05 1.58 7722,19 1.42 83.25 1.70 DEPTH TOPS 35.05 36.63 7758.82 7760.24 7843.49 7845.19 7856.00 /Pit~, ,cø ) ) , , Legal Well Name: CD2-22 Common Well Name: CD2-22 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/15/2002 2 Report Date: 5/24/2002 5/15/2002 End: 5/28/2002 , , " " , " "o",rn~n. J,c)bTyp,Ø~:,Þrifl1~ry ':,'" "', ' , ' ,::~~Z~E:-~~=;.:::~~fu~~~~i:.~I~~i~2_~:~~~::§i~~;S;i~~t~~!~':~~=,:~>"~:~:~~~~~~~:¿ç~¡¡;i~:~:~_~~~:~~==~::::'=:L~:=~:~~g_:TI~~.~~'-~~~:~:~.=~ Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 7,846 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/23/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/li sa Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) sa TMD: Plug Type: sa Date: Drilled Out: ~~.C~: C~.C~: Cement Co: Dowell Schlumberger -. 'I.",' Cmtd. Csg: Intermediate Casing/lin Cmtd. Csg: Cementer: Jim Thompson Pipe Movement: Reciprocating . I, r~':~-:~~~~-~'~~"'~~P-~'~~~:'-~r-:-7r-~~'~~"~-~~"~~~'~;'~~~-,~~"""':-'~~I~"'~"~--~'~-~,'.T~"~--"~~'--I':"':~'":'--.,-:~~"-.~.-.:~. ,PJp,è,'IVIÓv~rri,nt ' I '" '.. Rot Time Start:: Time End:: RPM: Rec Time Start: 21 :30 Time End: 00:30 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 260 (Ibs) Max Torque: (ft-Ibf) Drag Down: 190 (Ibs) .".....,..... ¡~'-:""-r':;,'~ ~' .,-~¡-~~.;,,~ ,~".,~ 1"'í'-~~~-:;':-r:"T-~'11'""",~';~'''~-....,r-'''''''''',-r :~' -'-.,.~r--7'"'": '~"-ï,~...,r-"""-~:"""""""~T'"'TI7"~:,.,-r-':,~ ~"'7'T'-~:;,"'I'""~"'~'~""""I"""1"'" r'1' ......~ rl""',"-rr--::,~ ,-""~ r-rl~-'->r"'": ''''''-''-''""T''''-''-n-'.,~'~'';'''v~:''''''¡-':,'~ "ï:~""~~:.1"1' '-T"''''''"''l'~'''''.~.'I' ~ -~..~-~:_-,--;._.:._-:L~~,.~:._-,_._:~~.c:_~L,__~:~~.,.~c:.'~~-_-:.~--~:._::_-~-~~--_.._.~-_,~;:_i.:.:..!~~~.~~.:.~~-~._;~:_-~-~~.;..-,.~:.___L__;__~".:-:.._~_.. ----_._~c..:""_~-_-:~~--"'_-':'__'_'~-'~_'_~:'_-'-':~--'_:~- Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 2.50 Mud Circ Rate: 210 (gpm) Mud Circ Press: 470 (psi) Start Mix Cmt: 00:30 Start Slurry Displ: 00:30 Start Displ: 00:45 End Pumping: 01:25 End Pump Date: 5/24/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7,00 (bbl/min) 7.00 (bbl/min) Y 640 (psi) 1 ,180 (psi) 5 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densometer Type: Non-Disp. LS Density: 9.7 (ppg) Vise: 39 (slqt) Bottom Hole Circulating Temperature: 96 eF) Displacement Fluid Type: Mud ----~c_: "~~_:~_i__: :':~-'-"~~_:":~~"~-~~~'~:.L_'~~c':_: '~'~~_,~_i~_:~~.._~~c~:~~--~~U~~~~~!~-~-~ ~~.._L-'~~~L~~_~L_,___~_.~,--,-~~,~~~c:_-~~-' ~~--~-'-'--~~ PVNP: 8 (cp)/19 (lb/10Qft2) Gels 10 see: 6 (lb/1ooft2) Gels 10 min: 8 (lb/10Qft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 297.00 (bbl) ,',. I. " , ' ,'StagfNo:fSlurry,No: 10f3 , " , " ~~"'",--.-!.~o"'_o"_..._~lo..._o"L._..._I..~'_...__......._~o..._o....._--~,_I.....:""0"____'__"0"':""0"__.""_1.0"'_'"'':'-_--'-1.'.:'''''''__-'-1..0...:'''',''__-,"-1.0''':""..._--~I.:",-,"--_.i.o--J.o...~..Io_.~.~...:""."~l.o_:"".",L.-_-..._.,..:""...._......_".,~'-o'" S lu rry Data . Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: eF) To: (ft) Description: ARCO WASH Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: CF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: PRE FLUSH Mix Water: (gal) Foam Job: N Temp eF) (oF) Pressure (psi) (psi) Printed: 8119/2002 4:17:22 PM ) \) /PH'I'~~PS'~ 1!7;1 ~ Legal Well Name: CD2-22 Common Well Name: CD2-22 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/15/2002 2 Report Date: 5/24/2002 5/15/2002 End: 5/28/2002 ~:'~-'~~'77~"-:"'~-~.r~.~"';"7"~:~~~77"~'~-~'-~-:r""T-~~"~'~"~--'-''':~:'-'''-~.-"~':M-"7~'-;,'-.'~~7~~~~',~ ~ ~~'~;~~-:r-'f~~'~~~~~~~~~'~"7~7~"'7~-;"""',~~"7:'~---'-""T"[~~:~~.'~'~-rr-~"'~~~~~-~~'-;""-~7""7'~'~' , ' ' ""'" " " ' , $tåg' ',~,.N.' o,~,1, 8' lurrd,,:,NO, :2,' of:t " '," " ' I II II" ,.' I ' I . " .,' ':1:, ,I , , ' .' I " , . ~...J."'. ;"~'.--'-'---~~.~'~I-o..w.:~_I__~U..J"_.'~ _......:.I----~ ~.J'~'_:"""'_-'n '.- - ~.,' '."':"~..._~-~-,. _~I.J.'......"....,._- ,.~'-_.~. ----""'-. --.."':_..1.':" -'- - .":-i-.L.I.._..J.J.. '-'-"'-- - - '_--'..10":""-'-- ---.... - .l..l.... "::"...._~,~,:,-,;,.J'~"""¡"'¡"-- .'~":,_:",,,._~""':.~ ~ '.J,_-......... _..~ .:-:,.,..~'.....:...:._~, _1..._;...1.'., ~.........:........._- Slurry Data Fluid Type: SPACER Slurry IntelVal: (ft) Water Source: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Auid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp eF) (OF) Temperature: ('>F) Temperature: (OF) Temperature: (OF) (OF) , ' ,~~-, ,~-~~~~~~~:_~,~~:~!,~~~._~~~~i!_~_:.~,~,~~----,~~-, ~~~_~_L~ ~'~____~_L- ~,. .'~.~"--'~~-'~;~'~- ~_:_-,~.~~ Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Description: Slurry IntelVal: 7,845.00 (ft)To: 6,903.00 (ft) Cmt Vol: 33.8 (bbl) Water Source: Slurry Vol:165 (sk) Class: G NEAT Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) eF) Temperature: (OF) Temperature: (OF) Temperature: (OF) eF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) '--::~~'~-'-~'-"-7---""--~~-;;~;;-1~;~;~~;'i:;~Á~-;~~:'~C'-7ë--~--7---:c----c--- ~_::~Z"7:=_=~2~j~~~:Ñ;~~='~.~:=-~~.:~-I~:?~:=.:=1~P;~=~~~=.;£~~~ii.'=-,*7"=,Jj~t;,'=_:-;=?~iji~~~~~=~~~.=-;~~~~:-:::-= 0-46 DEFOAMER 0.02 % D-65 DISPERSANT 0.25 % D-800 RETARDR MID-T 0.25 % D-167 Fluid loss 0.18 % -_.~._---_..~~._._~.."._----,.~~-"-_.,,.__.._-,.~--,-_.._._~...__..~--_._-_._---~.._-_._.~."._--_.._-_._."._.-__.0___'__,------..---",--,-"-,---,,,,--,---,----,,---.--,,,.-----..-----.------..---.--.,,.-----,...--.---...___"_M_"__"w'----"_._'--'~'--___".M_'_. Printed: 8/19/2002 4:17:22 PM ) :; ~, cg... Legal Well Name: CD2-22 Common Well Name: CD2-22 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/15/2002 2 Report Date: 5/24/2002 5/15/2002 End: 5/28/2002 . '.,,; .~"'¡;-~'~("~~-:-~-~~'''''~~~~-'''''''''~-7''''~'''''''''''''''''~T"''1''-''';"-'''-~~-~-~..,_.- """".~.."';"~~"""''''''~-~r'""T-'':-:":-:'''''''''''"'~-";"7:'''''''-''''-"~-7~.'-~""7.'.'''''~~'";"7"~""7~-'~~~--.~""''''''''''~-"';"~"}'''''~~'':;'-''''' , , å~~i~g"T~$t'", ',', "'Šh'~~'Tèst'.,:',, ,:U~~rTd'p,Tést, ,: ;, " ~.~.:- .&!~"",--~~~.:J~._~..,-,.,~~~~:~.~ ~;":"".~ -~~._~..~,.~"'.- ~~ ,.~ .......~-~:~L¡.~_':"..¡......w--,-~,~_~l:~. :.'.........._~,~.... ~ '~~" ~ -'- ..~-_.... _.'J. I. -.. -,.....,.~~~~.'- ~.~',~~~~' ~..¡. .._~--. h......~l.J. __'~,,'- r~ --~:~. ,-----..:~ -.L. ~~: ',..~~, ._~....,~ '...J. -~ .~~~..L._~'~' ~'. ..'~..- ..'. ...~- Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12,50 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N I ,"",'",t~~Sù~EtY:~~~~~~~iO~",' ,':"", ,':", """lht~rpret~tignt1U~mary"", ", " _.....-----':".....J..,.,........... -... .-....-......1...-...---- '.._._1. IJ..I...'_... ...... -_.. ....I...":"".._---'__.oIJ..'.'._.... -..-- ~---_.......~.__.....J....:....._.._-_....L.,- -.. -... _.,_...,J.J..._- ---.--..,.I.0I-l.':"'--- _:..'U-'---- --.oJ..-'--"'- -'~_..............:...._- ~-...J..'..;.J.-, .- ... --,....J....,-- --- '_...'.¡J,.I....:.... CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N '_._---'''''-'-'~'._--'''.._-'-'--_..'---'''_._--''.._-' ._._~-_._.._-,-. ,--,-.,..-,--,,-,----,., ...---....---.....-.-.-...--....--.-.--- Printed: 8/19/2002 4:17:22 PM ) ) , F»~Unp,'~låaf<..:'~nc~' ',' " '" I ,'Q~I'ly' Qtl~lirJg~ep'9rf" I' " ' W~L~NAME "",, ' JOBNUMBER[EVENTCODE [24 HRSPROG" 'TM~ IrVD' 'rDFS' I REPTNO, DATE CD2-22 ODR 7,856.0 7,183.0 9.10 9 5/23/2002 ,:.~~,:~I~;~L~~Y-rlOldS I RIG ~~;;;~ @P;CO'COnJ_1g._-_.___J~I_:~_:~:~ ~~~~:O._-~U;~ ,;~1 .9.__J::.~ Y TA~~oo I C~~~-~~~Q9._._---,~...~.. CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM IN TANG WI MUD _._,----_._~...__.....~...._..__....,-_....._",-~-,--",-,~__,__I~~JtlJ9_-~QP'-';---,.._--,--,--_..,---,-_.~,-_...._-",---~_._-~,--"--'--'''-'-'''-~'----'-'-'---''---'---'-'--'''---'-~'----_._-",-~..__."---_._-",Q.:Q9.---_.._,,,--_._~,-_._-,--_..__.._-~,_.._-,Q.:,~_.._---,-_._--",,-- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD ._--_...l~l!t~..Q-~ê.:_-~~~~jf~:~?l:I.~:'~I,!tL:.I.~st~-~!fJT - Drill 5~....?/2oo2 ---.--- 210,187 -- _J..I~~1,~q~--_._-_.._~- ;;wv,DArË 1MD ---,;~~;î;~:;';:~~~11NëXT~ÑG~Q!I- ::.B-t.:~~~---- -__!?!..??l~Q~__- 7,797 :,~1_-,~_._,.J~7 .2?Q-,.._-__~_£!..:.4_EJ.9__1.]&QQJj!11.,@L__.J..J.~~5.0 (ft) 4.500 .{!~@...--" 7,413.0 (ft) 5/1712..Q91._,__..--. -~!!i~J!c.~t~~.J'r-""r-~.?~,-,'r--,_Lf.t.Il'è-"'_-""-'~"'""'-r-J,~9J,-,-~-J~,.MJ;!ItgA1.M_~~:~!!~~!J-.,-_.__. - .,E:'~-'-"-':'~'-'r .L£~~_~~~I~'J. ...-,._-,._._"P-~9.~-_.- -. -'é" ""~~'" \~VN,P 'f3t=L~, ,',~I1'n:fP,::""F~rt.$~L,I .",'()I~IW.,r':,' 1I~~~~/IJa,T.', "" ,PWþNl., ' " ,~f(~ " ",': ,ÇI,I',', ".t~1. ,.'~:'l$, ' MlVlfE,,:~~, 41 8/20 6/8 4.4/10.0 11 / 118.7 8.8/ I ~---.._--.--~-- -----------.--- -----.._____M_- iff~~~~T~::Zk'~~~~?f~=~~~:~:i1i~~~E:I~~~~~::2- 1,069.84 '-"'T~~~~¡~~~iri1()~?~-""~-"""-";~~---.'~'7--"")"-'-"~RJr$,"'--:~-~EÑ(i~:'~~ --'-";~-.Q:~-':;'''-~-'~ "-',-i:D:--- -'~-,-':'-ëCfÑ~i~1iïi~:-ÇÓ~N:f(~~.:- BIT MX09DX 1 0.85 8.500 .._-_._.-.~._.~~.__.._.__....-..._._.._... -,.....-.-..-.--...-...-,,---.-.---.-..--..-.--,--...-.-.-.-----'--.-'--'--.'---".-'- 'M'_'___'--'-_.'---'--'-"-'-_..__.._.__._-~.__.._.._._-,--'.'---'- ._~-,..~...._--.-.-_..._.... NAVIDRILL M1X 1 23.09 8.375 GAMMA SUB 1 27.72 6,750 1.920 .-.-.--.....-.---""""--'" "-'-'~"----"'.._---'_._--""-~-'~"'''--'~'-'--'_.'"--"'-'-'_._--"'._--'_._--~~'._-'."-'-_._'--'-' "--'-'---'~'---'---"._'--'-"--'-""._-'-'-'--'~'.--.- MWDIW FLOAT 1 22.35 6,750 1,920 NMCSDP 3 88.87 4,500 2.875 ~_._--_.._.._..."._.._--_..__..~.._._---_..._...,,_.._..~.--_..-._......_"----_..~_......._.~-_..-.._.._.".._-"-~--_.._...~_.~---_...._."~~.~~--_.._......_"---_..- "~~-~----""-'"---"-- .--.-- XO 1 1.67 6.250 2.875 HWDP 3 90.47 5.000 3.000 _._.."_..~..._-,.__._..._..... .'"--~'-----'-'..'--'---'-' ._."._~._.._. - '-"-'-''''-~'-'._-'- "_.'-~'-"-"'-~ JARS 1 32.37 6.250 2.250 HWDP 23 689.09 5.000 3.000 _._~--,_...._._-_._._--".".......__._._-_..."_._~_. _.__n.._"._------."'-----..-,---"..--"--,,,,,--.,,,----..--"...-...----.---.-..-.-- .-.-- XO 1 1.37 6.500 2,500 HWDP 3 91.99 4.000 2.562 ._--_.._."------_...._."~_._---_._.__.... ----_.~-_...._---_..._..__._~._-------_._-----,-_..._-----.----.-------.,'.-------. -.-----.--....--.-- ----.-- ---.---.--- ------.--..-----.----- ,.",-~:"~,~:":,,.~"._~:,,~,,.:,:~~=,=~~-~=~==~~~::~:~~~~=-~~~=:'~-==~=~~=:~:ijj!$=~:;-'~:=~I'~~~~~=-~':7"~;_-",c'L:,=:=~:~~~,=~~=~-'~:'"' ~,'~~:'-:~-'~~,~:':- ~~l~_~.L~B~:~"~':._,~J!t~"~'~~~,:'LL~,.~~t.:._.,,~,"..:.~"~~~:~..::..~~~~.t~_~'~~L',:'~.:'_~~,!!:~.'O~-~~~~.I~~~~~~:J>æ~!~1~,.P~!!J~_:~~,l~~D~~~.:!~~~"::CI~"'~ ._----,~._r._,-_._--,-_!_._-,"._"--~,~~-C?Q-_.t!g------,---_._-----~-~Q~Q~__!31~9...~_._--_._---,---_.__..._._1~_!~{~_~j!L_,_- 7,075.0 .~{~_~!~~3__!:!:~:~,:,~:!:!:J2:!.!?___-- -'-~'~~7~:'-':~'-"1-~'-:-'-'::"~'-"1-~-'~¡:':-':-"1-ë-:-¡-";'~'''-~~:-':-:~:~.I-''77¡:'::---'I-~7¡--si,fõ~pgBATIÕÑ''i~:-¡-':-"~-:'~-:-':'::':---ë,-'C-7'::-'-'"1-ë-:-¡-"',.''-~-~-:-"'::","T"~-~~:'.I--'-":-"-;-~'-"','~ ~~~~~~"Œ~~~_:L'=~~ø::~~]==~~~=E~E~=TIIt~~;I~i~~~.j~~=~=[~~~~3~~~~~QE~1~}f~~]§~Ã~]I~~~~Q]~: ':" ,,' II' '. ,",:' "',' I ,IOPERATlONUUMMARY " ,', "I ", ,'", .''" '~ÓM'~~:'T~~HQUR&, . -~'CQD~-- TftÓU~L~~S~'--PHA$¡-:-:-~'~' .' ~~c'-~~~-"ë~-c~'D¡-sct4ìpTt9N~..~,~~~,.~-7-~'~~'r-ë"~r:-- 00:00 00:30 0.50 DRILL P CIRC INTRM1 C i r cui ate h 0 I e c I e a n for s h 0 r t t rip - r e c i p & rot a t e pipe - 600 GPM - monitor well - static WIPR INTRM1 Wi per t rip f I 7856' to 6950' - h 0 lei n goo d con d i t i on - Monitor well - static - RIH to 7775' INTRM1 Est a b lis h c ire - was h to 7 856' - P u m P s wee p & c i rculate hole clean 2X btms up TRIP INTRM1 ~_O H tor u n 7" ca s i n~~!5 6' to 1070' PULD INTRM1 H and I e B H A - s t d b a c k H W D P & fie x coil a r s - L D b i!.~~~t 0 r, M W D ------ ------- OTHR INTRM1 PUs t a c k was h too I & flu s h s t a c k - L D was her OTHR INTRM1 Pull we arb u S h in g - set t est pi u g wi 7" t est j 0 i n t - change top pipe rams to 7" & test to 3500 psi - pull test joint & test plug - set thin wall wear bu 00:30 02:00 1.50 DRILL P 02:00 03:30 1.50 DRILL P CIRC 03:30 08:00 4.50 DRILL P 08:00 09:00 1.00 DRILL P -.---.--.------ ----------- 09:00 09:30 0.50 DRILL P 09:30 12:00 2.50 CASE P Printed: 8/19/2002 4:27:21 PM ) ') ~m..~,I~, ..~ " ,I '."1 , I I ~.:'. ,r, I. I . " " , P~~~I¡:p'~I~s~~f~nç~.' .Q~ily Øtl'~UI1.Q,~epC)tt" ' ." , " . JOBNU.M._.._B.E_R I EVE- ONTDCRODE 24.HRSPROG TMD [rvD rDFS REP_TN90' DATE CD2~22 -. 1- 7,856.0 7,183.0 ~ 9.10 512?/2oo2- ~tt~~~~Ef~2Ii~~~~'~~~~~~~E~¡~2BE?=E~~t?~ .,~.:~_._~.~~9P__._?~.Q.__.~~~~...~_.".._"._-_..~---",.-<?I.~~...._..J~TRM1 ~,~~,.!:IjL.___..._.,,-~.~-_.,,-~-_._- ._--""._---"---_...._.~_.~..._-,,,---~.-._.,_..... 12:00 13:00 1.00 CASEP RURD INTRM1 Rig up to run 7" casing - PJSM 13:00 15:30 2.50 CASEP RUNC INTRM1 Ran 7" casing ~ MU & Bakerloc shoe track - ran 5 7 jts. 7" 26# L~80 MBTC to 2341' ...1?.:!3___!~P.9- ._....._~~.2_.~.9.~~§-~--_.,,_.._.___._2.!.~.2._.__l,~!,~_N.I1 C i r c_~"".!. ate pip ~_.~!?..!..l:'_.~.!..._.:..._~.._?._.~~..~:_._.._._-_.._._---_.__.-'---"-.'-.' 16:00 18:00 2.00 CASE P RUNC INTRM1 Con tin u e run n i n g 7" cas in 9 ~ ran 1 20 j t s (t 0 t a I) . 7" 26# L-80 MBTC to 4955' M_~M""'_'__'M_".__.""'-'-'_._-"_.-".._--_..._--".._-..-..---.-.,......---.-----......--.-----......---...--..."'.--'-'''---...'''---'''--...'''--' CIRC INTRM1 C ire & con d it ion mud @ 4955' RUNC INTRM1 Con tin u e run n i n 9 7" cas i n 9 ~ Run 9 ran d tot a I 0 f 1 90 jts. 7" 26# L-80 MBTC casing ~ landed on man drel hanger wI shoe @ 7845' & float collar @ 775 9' RD casing equip ~ RU cement head 21:30 00:00 -_.,~:~Q.._-~.9.~M.~~!_~,-_.._,---_.._._Ç!.~~_.._-.J!:i!~~.1 C ire ~._-~~._r:!.~~.~!~!J,_r:!._~-~-~-,-~_._b.~..!,e for c e "!~..~.L..L!?.~.._._~----_...~ WELL NAME 18:00 19:00 1.00 CASE P 19:00 21 :30 2.50 CASE P -_."-"'-'----""'''-'''''-'-'--'--~'''-~''-''''-'-'''-'''-'-~"-'-"-"--"--~"-'-'-'~--"--~"-"'-'-'--"~'~"-~"~"--._._--_.._....~.._,-_._.._- -~-_..._,-~._--_.._-~..~_..,~...._.._-..--~.._,_._--_...._-,.- '----"--~"--'-----"--"-'-"----"- 24 HR SUMMARY: Circ hole clean ~ wiper trip to 6950' - RIH ~ cire hole clean - POOH to run 7" casing ~ LD BHA ~ RU & run 7" casing - circ & . condition for cmt _._..-..,_._~_.._. j2~::~~~~2Et~~~i=sq~i:~~:~~~~=t:~~Þiai~2~t5@i? f~~l.!œ..~_.~.__...__._-,._.- .__.._-~~...._~. '"-_._~..__..~..__._!?~~_._-_..__._-_...__._-~_.._.._-_.--~~..__._-_.._-. 4 --..-...---.-- ~ç------_._- ....--.---...-,.--------.-. "-'-----'.-'. 5 MI}2!.11IinQ_.f!uid~__._.._----_.,_..__.._---",_..__..--.- -~-_._.._--_._- Baker In~~~__.__... 2 Sperry Sun .-'.--"'---.-'.--.""'-"-'-'..' 2 Dowell 2 FMC 1 ''''-''''-''-'--''~'-'.'-''''-'-'-'''--'----''''''--'-''''''--'''-"-'--'-'---~'-'---'-'---"-'--'-'-~--"-"-'_._'----..-.--.. ._,-~-_......_-_._.._--_._.__._.__._.._._,,--,----~._._-..-'-'-'--~'-'-"----'~'-'-'-'-""'-'-"'-'-_._'---~'-'-"-' _~1.?.~......_---_.._.._.._._...__._.._,"--_...,-_._.._.....-----..-.-..-...---.....-.....---.- 27 -..------.-.-..-.----."'.-..----....- ~,~,"~~"~....~,,"~.:.~~'~".2.;~_~J:~~."~2J~"~I.~:Ä.~.;-'.1Ml.g~§J~~Q~'jJjP:rJg~--~.~';."~:~.~~'L~~~._~Ä~~~."~'¡~:~._~_.--,,:.~.~',~:~.,~ "'.'.,'.I!~'.', ',:~NI)'~,:'.. ',U.~Ei:'.',"".,:.~NHAfIIØ:;':.",'.lt~~" "'.U~t'ts"'. ',",.'U$A\c)fæi' ,',: 'QN~.ANQ, ." ..~~.~!.__._--,_._._-_....~....._.~.._--~.._~._~als --,_!~~g~..._-,,- _....__._:~!.~~~-~.._- ~~.~~~!_f.~!!~~_..__._._.._---_._~,_._~.Þ-!~~..__._._.._--_..__.._._.._~Q._-,--_.._--_.__..,_.~I!Q~.._.... Water, Drilling bbls 200 -5,477 ;=r~~=:~~I2E~~~~~~52j5i::;:=;~~2~f~j CD2-49 20 CD2~22 '.--'-''''''---'''----'--'--''.--'-'--'--''.----''''-'--''.--'-"----~.._-_._._---~._--_.__._......__._.__....-. --'-' ---~'--_'____N'__'__'--'--".__._._-,---.-_._.__.__..._-..-.--.- Printed: 8/19/2002 4:27:21 PM ) ) l'-œ','~,I~~ , I , , I:' " ,~j , PhiIÎip.'Ala8k~,'lrt~~, , " DaiIY'[)t'~linQ:~øp()~:." ' " ' " 'IJOBNUMBER [EVENT CODE 24HRSPROG 'TMD '[,vD IDFS' REPTNO. DATE CD2-22 ODR 7,856.0 7,183.0 10.10 10 5/24/2002 ,:UPERV~_~~~:~'-~" I RI~~~~;~O~~~:~.CO.~_.1g..___._.J:I,:LD -~~~..:~:,~~.,.., AU~~ ,;~.1:.9 I DAILY ~~~:~~L._..__,_..t~_:~~~~~~~Q9.__......_._,_.._. CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD ..._..._~...._.J2r!m!1JLI?.._y'?.:.:,_b.~.~.fgt?..~.~~..__..,._...._._-,..__...._........~-_.........._........._~...._..__.._._._-,_._..__....._.--_.--_... ..Q.~QQ.._...__.~_.._~,...._....._...._,--,_.._,Jl.:,QQ......._--_.._....,-... 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Drill 6 1/8 " hole 5/22/2002 175 309 1 666 661 ~~~=-~~:~EI~~::l~12m-I~Ñ~~~---~;~£sr--- --_9.L?2:!2002 ~.,.L 797.31 ..~-,..,~?.11.Q~_.._- 327.460__1J.:..000 (in) (a>.-_._~~.§.O ,{!fl.. --,!§QQ.{!!:!L@L_....ld13.0 (ft) 5/24/2002 L~!~~~!!,!~,p'j~!;I:"'-r"~'~' r,...."..L!!~L.- ':'''~'':'''-'''r-..,..J:~~RL.1-_, ,jNl~QJiÆI~1~1,~'.'-~~!!J""T'-, ,9.:..~.,.. -T" ...t~~~-§.~tj".._._-~._.-:p:~g --, ~"- I~Y:'~'!rf:~:q~L~" '~J-,"""P"~c:J:r:~ÇL,, Ø'JJW~T'""%~,,,~'Ma,~ ,P~/PM, '~tIIW, "'~, ". tÞ,f4::!~"LI\I1E,' es" 43 9/19 6/8 4.8/10.0 11 I 117.5 9.21 I ------~--- ~._--_._._-- ::I'¡~~~~I~I~~~:~~E2:~~~~~1K~~¿~~~~~S:~E~~~~==- 362.06 --~'--''''~''''~~:'''~'_.~~.-''''-'~'-''~'W~?~~if'Tì()~~~-''',""-::"'-~-"'''--'~''':'-''''''---':~~~Jr~''::''~~'~~~j~ÕTH'." --"-:"";':o.ïi"~'-_..~--'-,'~,~i:D::--"'-~--,~ë~>NÑ-¡iiii.~-'éQÑ~;TYP~'.~ BIT STR386 PDC 1 0.85 6.125 ~._~_.__.__.__w.__._.-.-~-,--..._.._._..~.- --...--.-.-...."...-- ""----'--"'-"'--'-'---_."--'-""'--'--"'._-~'_-'"N_--...--..-.-.-.--..--.-.--...--...---.-..--.,..-...--.-.--..-_...- TURBOBACK STB 1 0.83 6.092 1.500 NAVIDRILL M1X 1 20.81 6.000 '-'--'.-""--"--'-'---'.'--'-'---"""-'--"""-"--"-.---.-.----.---....-.- ..---.-.---.....--.-.-.- --...-._.,- NM STAB 1 4.53 6.125 2.375 GAMMA SUB 1 25.00 5.375 1,250 ".-....-.-----.-..-.-----..-...--.-.---.-..---- ,----.---,.-.-----"- -.--.-----.------ .-....-..--. ---.-.....-..--.-.-. MWD 1 19.42 4,750 1.250 HANG OFF SUB 1 11.27 4.750 2.815 ,,-.-...-....-.....-- ._,...__..._..._,_.._.."..._,.._---,-,.._.~._~*.__._...__.-,_._._.....__.__.__._...',.._~-_._-_. ._.~-~.__.._~..._*._._-_. .._*.__._._,-~..._~._.-... -~-'--*-'-"'--'--- NMCSDP 3 92.23 3.500 2.375 XO 1 1,20 5.000 2.500 ...._--_._..~--_...........__._*--_.... .*._-~.-_.._-_._...*..--*._.-._.__....._._-~.._,._,_.._._--_._--_...._.~...__.._.__.."._~-_._,,-~-'...._--_._.__.-..---. ._._-~.._. HWDP 3 92.05 4.000 2.562 JARS 1 32.40 4.750 2.250 ---~..-._-----_......_-,....._...,----._..__._...,----_._,_...-----~.._,----_._-_._...._---_._._,,-_.._..._---_...._.._,-~-----,-_."...__.*------~.,-----.._._-,-----_._.~--.,.----...--,---.--- HWDP 2 61.47 4,000 2.562 3E~:i~~~~:~G~t~~~~~=~Bt~~ig~31i~tE 4 I 1 6.125 HUGHES-CHR STR386 7000558 15/15/15/15// 7,856.0 5/24/2002 0-1-CT -G-D-I-NO- TD =i~~~r=-~:2~=E~j=i~riiT:~~=~l;Ji~f~-}~~§R~~~~~~ "---_'~c-'_""_""~~-~_'_"'''_'--~-'''~':''_''-~~-''':-~-c-~"...,--- ,'PUMP I HYDAAULIO'-ÓÃTA ' , '''-r--~-~'~"'' , , " ': "-~~-,~'- ~_.~~.~~-----_..~~..._...~~KS~~_!~~.__._-,~~~."~_._-~~~~~~!~L_~~,~~~ ,(!!!L._.~~~~~-'.~,~~~_:_~!~~~~!!~Jt~~!~~~"-_:_~~~~s!~)i!!~!~~~~L_~ 1 Continental Emsco 12.000 6.000 47 196.75 1,150 196.75 WELL NAME ---... __'_'M'_'___'."-"--,,,, .-..,-*-.-----_..-...-*---_.__..._..~.. '-~--'-'-~--*'-*--'----"-'----'---'-'_.- --~~-,--,-_.~~-~~---~~--=-~~=~_._----~--=-~Q~~iY'.!lO~~'§YMM.«\~y----~~-=-~~-==~,~._-~~_.. _.._..~~--~~ FROM TO 'HOURS' CODE TROUBLE SUB' PHASe . ' . ' ,DESCRIPTION . --_-.t._--------.---,-------------':"""--""'-.-------.-------- . ----'-.- --"-----.----. 00:00 01:30 1.50 CEMENTP PUMP INTRM1 PJSM - Cement 7" casing: Pumped 5 bbls ARCO w ash @ 8.3 ppg - Test lines to 3500 psi - pumped 15 bbls ARCO wash - Pumped 50 bbls Mud Push @ 12.5 ppg - Drop bottom plug - Mixed & pumped 33.8 bbls (165 sks) Class G wI 0.2% D046, 0.25 % D065, 0.25% D800 & 0.18% D167 @ 15.8 ppg - Kick out top plug wI 20 bbls water f/ Dowell - S witch to rig pumps & displace wI 277bbls 9.6 ppg LSND mud - pumped plug wI 1150 psi - floats he Printed: 811912002 4:27:49 PM ) ) 7utã"d:I~~","~, .,Þ I 'I " , ~-" , I .' . .'. ",' .",' :'~"', : .',,' 'I,: ,I',' """',,1 ,I',' .. :' " Jt'hl~bP.:~I~~l<a_'lnc~' I , ,~"iIY,9~~li,n{;J',f(~þ~~', , " " , " ' IJOB NUMBER"rEVE~TCODE I24HRS PROG TMD' ITVD 'DFS" REPT NO. . [DATE . CD2-22 -- ODR 7,856,0 7,183.0 10.10 10 5/24/2002_. ~~~L~~EZ¡~~~~~~~T=~~~~~~~~~t:2StS;Ï~~g= 00:00 01:30 1.50 CEMENTP PUMP INTRM1 Id - CIP @ 0125 hrs ~ Full circulation through job WELL NAME 01:30 02:00 0.50 CEMENT P RURD INTRM1 R Dee men the ad, cas i n gel e vat 0 rs ~ L D I and i n g j oint ,--~:.~._~~.~.~...._-~~P_.~.Q~~~~.._-"..~..._.__._..._Q!',:!~---- .~.~!.~-~...! Set &_,_!.~-~.!_....?~~_..e..~~..~,~..!..!_~~?-._~-~..2.g_.- psi 02:30 08:30 6.00 WELCTL P BOPE INTRM1 Set t est p lug ~ c h a n get 0 p pip era m s f I 7" b a c k t 0 3 1/2" X 6" variable rams - Test BOPE as per P hill ips policy - AOGCC waived witnessing of test ~ RD test e9._~~pment & _blow down c~~ke line PULD INTRM1 R U & M U B H A # 4 ~ bit (6. 1 2 5") mot 0 r, s tab, M W D - Down load MWD - PU NM flex collars & OX .._._~-,_...__......-.-*.-.__.__..............-.._._..._. ..,.-....-,.---.......--,........-.-..-.......-.-"......-. -"-'''''''--'''-'''''''- -.......--.......-.-..-.......--..-....-.---.-...--.-....-.-..-.......- _..._._.._......_-,.._..._._.._-.-...__..-._--~_._~.__......._..-.-.-...--........-.---.-...-.-......-- 11 :30 12:00 0.50 DRILL P TRIP INTRM1 R I H wI H W 0 P & Jar s to 362' - t est M W D 12:00 16:30 4.50 DRILL P TRIP INTRM1 R I H pic kin g up 90 j t s. 4" D P f I pip e she d to 3221 , - continue RIH wi DP fl derrick to 7609' (fill pi _.._----_.~-----~----------_._.~.__._-----~------_._~--._--_.._P_!_-~..y._~-~Y-_-~9._Q 0 ' ) .----.---.------.--.- 16:30 17:30 1.00 DRILLP CIRC INTRM1 circulate bottoms up fl 7609' 17:30 21 :30 4.00 RIGMNT P RSRV INTRM1 P J S M - S lip 0 n new d rill I i n e 1 800 ' .. s e r v ice t 0 ..~_._-~,,_._,,------ ._-_.~_.._- _.._--_._~_.._-,,~_.._...~..__.~- .~-_._-,~_._p""....~..!_~~,~."..":",,.!,~J~_!L.~_~.~~ e s ~-,---"-,-_.__.,,.,,_.~_._~...,-_.__._~_..__.._.. ,_?_~.:!>_,~,~~g-~--_9.~?Q._-~~-~~!:I,:!~-_.._,------~QY} INTRM1 R I t!_~!._o 76 9 ~~_:_"!:.~_JL,~p"~..:~-'-,,,9..._c m.!_,_!L.2.~_~_~_:_!_~-_?..?_~~_:~ _~?~29_.~.~~90 1.0Q---Q~!~~-----,,~_.__,__._91 RC I NTRM_!,,_~_!!..~ u I ate h -~~!....?J.,,~_L~.!:....£,,~_~_.!.:!_~J.~ s t ,-------_..",----- .~~:QQ.._QQ:~-,,-,,~ .O~_.__DRILL P OTHR INTRM1 R U .. t e s_!...i._:"~ a sin g to 35 O.Q..- psi for 3"Q....!!1J.:!..~-_:""":_~.!?." 24 HR SUMMARY: Cmt. 7" casing wI 160 sxs G, set Be test packoff.. test BOPE ~ MU & RIH wI 61/8" BHA to 7600' Slip drill line .. C/O cmt fl 7694' to 7705' - Test casing to 3500 psi t~~22fritlt~~=-~£fi~=~~~~~&c?i~g23~E~~i - Ph!!~p.s ._-"....__._..___m__.__~...__.__._,-_.. DS R -.---.--,-.....-_.._.__m__._. -~~"..__._-,,_..._- ~C ,--,-~-_.._-_..,-- _.._._~-_.._.._..._~-_..__..__.._~-~-_.,_._~.._-_._~.Q!!!!.~~.,£~~i<!~.___",_.._-_.._".,_.._--_.._-_._--_.._.._.._--_._-,--""--~_.. -"---~--'---- -~-~.~.!~..I.!:1!~.9"._--,-_.."_.,,...._-_..~~_.._..._--,--_.._...---,----_..._..__._-_.._._?_,--_._..._-_..._._~l?~-'!Y..,,~~~...-_.......__.~-"".- --_._...._---'''~~_._.._.- -~."_..._?_,,._.._._..._,,-,-~- .~~~.~--~.._.._._.__._....._.._.._._..,,_.._.__._.._,---~.._.._._.--_....._.._._,---_._.._._~--_.._.._._,-_._,~P~~---_.._.._,-,---,,,,,-..-,,-.---,,..-..-.-,---,,...-----,--.-.-.-,....-,----..-..-,.?_-_...._--,-,_._-~ ..~~~-~_.,--,-,-_..~.,__m_.'__,.._.. ___,1,?'~,_.,-_._,~_...., '--'-'----"---'-'--"~"--'-'----"--'-'--"--- -.--.-,----... ._....-.~-,.._-..._---._-~._.__.... 08:30 11:30 3.00 DRILL P ~~~~~~~~~==~:~;~t¿=~~~~~~~¥é~~~~~::~:!ïE§=.=~~r~=:"i~~_~: Fuel -"-_._J!.CIJ~,,._---_._._._~~,~_____~2,3E!~._. W~~!:!...~otaÉ!~___-- bb~~_.__-_._---~Q...-_._".__.~!~_.- Water, Drilling bbls 550 -6,027 "'".~--- ~~...- ---'-- ",,--' --'-'''---- -:-',,"'"--"--"'- "-'--"'--"'-'--~-ÜPPORT CRAFT' .--..-.:._..__'_m_.__"';- ..~ _....,-: "------."-' ---.--,,-..,,-...,,-. . TYPE ."°. " ' REMARKS,' '. ' " TYPE 'NO; , , . . RE;MARKS, . ' ---'--'----~--- -"---.........._-~-~...._--~--~_-I.....-.-J..._-- --------- _:.-~-, -- ~_'__- -,-----"-._--_-i.-..........._-~--------_-----......._--~._-~_....... -'---......"'---~._-- CD2-49 1,206 CD2-22 Printed: 8/19/2002 4:27:49 PM CASING AND PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 'Date: 5/2412002 I Volume Input i Pump used: i Cement Unit ¡ . ! I , ¡ Barrels I ~ 'Pumping down I annulus. ! ~ I Well Name: CD2-22 I Rig: Drilling Supervisor: Don Mickey Type of Test: I Annulus Leak Off Test for Disposal Adequacy Hole Size: i USE PICK UST I. Casing Shoe Depth RKB-CHF: 35.2 Ft 2,381 Ft-MD 2,381 Ft-TVD Casina Size and Description: I USE PICK UST Çhanaes for Annular Adeauacv Tes Enter outer casing shoe test results in comments Casing Description references oute casing string Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. !. Leak-off Pressure + Mud Weight = 0 0.052 x TVD 0.052 x EMW at 2381 Ft-MD (2381 Ft-lVD) = I I I ! i I I EMW = 1000 . w 0::: ::J en 500- en w 0::: a.. 0 2 ~CASING TEST Comments: Hole Depth 6,903 Ft-MD 6,774 Ft-TVD !. I Pressure IntearitvTes1 Mud Weight: 9.7 ppg Inner casing 00 7.0 In. Desired PIT EMW: Estimates for Test: 2381 + 9.7 9.7 4 5 Barrels ! i I ! ! I i I i . 7 6 -4Þ-LEAK~FFTEST 8 i f i 1 9 16.0 ppg 780 psi -1 bbls I. i PIT 15 Second Shut-in Pressure, psi 576 Xt 10 0 I I ! i ! I I ! ~ ¡ I l 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point ... 30 i i ¡ BbIs/Strk ... Pump Rate: 0.5 Bbl/min ! 1..- i I Pressure Integrity Tes1 Pumping Shut-in Bbls psi Min psi 0 35 0 525 0.5 38 0.25 576 1.5 44 0.5 572 2 60 1 500 2.5 81 1.5 497 '. , 3 160 2 487- 3.5 288 2.5 487 4 370 3 480 4.5 423 3.5 480 5 630 4 480 5.5 670 4.5 471 6 749 5 470 6.25 845 5.5 472 6.5 553 6 471 7 570 6.5 466 7.5 545 7 465 8 540 7.5 464 8.5 560 8 463 9 539 8.5 458 9.5 525 9 455 9.5 455 10 455 '~ Volume Volume Volume Volume Pumped Bled Back Pumped Bled Back 0.0 Hbls ~ 9.5 tibls _tibls ) ) '_'__."_"'."_"-_."_-''''"'_'~'_'...._~....,,,._,..,....,.,~....._--,."".."._."...~".~.....~".._.._._,_._.~-'-'-'_"_'_~M"'__'_--"'_.__.._._....._-_._.~".~ Structure: CD#2 FIeld: AlpIne Field Well: 22 Location: North Slope, Alaska -_.._'-_.'..-'ë;;;tÕ~.bÿ.¡;;;;i¡;¡;¡;;'¡---......__... ... O<M plOItOd : 2""Ju"~2002 Plat RG'llrort(I 111 MWD <0-'1134'), C..rdl.oI., oro In loot rof,...... ,lot '~2. True Vcwt10al t)ettt~. are I'4IrI'fM'IIMr:t1l e:atlmatftd RKB. .£ ,._,._....._--_...._.._~¡¡.:::,~::~.,....._-_._.._._..., -_!.~.Q~.i!_,!.~_P_~-,_. ,.~_.!.~~-~~_.?,.._--_!_~-~?_--~-, <- West (feet) S""I. 1 irlCh m 100 ft leoo 1500 1400 UOO UOO HOO 1000 gOO IlOO -/00 !oo 000 ~oo :100 200 100 I t I I J I I 100 200 300 40Q 500 IlOO 700 HOO gOO '000 1100 1200 '300 1400 I I L I I I I I I I 1.DOD W ~- r I I t I I I t I , J I I I I J I , , J I J , I I I -14<)0 - .'---- -----.~ '0/" ."''' ~ . '/8 n"'r~ / ...' ---------- /'./ /~--- '-----------,~ // // ",....-",,,,,,.:::::>- "-"" ~".". .-?" ØJ "--- ./ 7 --...--------------.-. ...~ // /./".. ~-:::;::: ~-==~£::===:_~~-.~- .,.r''''''''''''- ...--;-1" r.o."" "----- ~ ,~~,""'r--~N& -., ~ ~,~ ~~--~----- ~ 'þ/ r~ ~ -~~ ::: ~ ¿ I ~ ~:: ---~ /- þ7' \ ~------ r;Ø:r'~_/~/// / "" ~ /8 "''' :700 ~ / / I IIC --"':~""'-~:ðM /~ - ~/ L__-- / /'~--~- /' .. 1300 II ~: . ,~oo 8 ;; - 1100 . 800 . 700 - 600 . 100 VI 0 t: .' 0 :r ...... .... ID - 100 ~ I ,.:/.CO V ¡ .. 14QO SURFACE CASING SHOE SEPARATION FROM CD2-22 CD2-22 X Y Surface Casing Shoe ASP 4 Coordinates: 371678.61 5974562.30 Distance Suñace Suñace csg. Cement Casing No. of Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally LOT Source well **** Start Date End Date well'" Coord. Coord. C D2-35** --- x x 1 ----- ----' ---- 836 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 301-140 6/1/2001 x x 2 CD2-15 33992 6/1/2001 10/1012001 813 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/2001 x x 2 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1061 370630.11 5974721.81 CD2-33 B*** --- x x 4 ---- ---- --- 1666 370155.64 5973886.23 CD2-39 301-281 10/9/2001 x x 2 CD2-15, CD2-47 27879 10/10/2001 11/12/2001 1147 372350.61 5973633.17 - CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47, C02-32 31073 11/13/2001 3/512002 658 372202.47 5974960.87 CD2-15 301-308 11/6/2001 x x 2 CO2-50, CD2-25 21093 3/6/2002 4/2212002 946 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 C02-34, C02-26 27349 12/17/2001 1/2012002 1345 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 CD2-49, C02-17 22991 1/20/2002 2/19/2002 1297 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 NA 0 175 371803.06 5974439.79 CD2-26 302-068 3/4/2002 x x 2 NA 0 120 371798.52 5974554.55 C D2-49 302-070 3/4/2002 x x 2 CD2-50, C02-46, CD2-22 27960 4/22/2002 5/28/2002 654 371252.38 5974065.93 CD2-17 302-122 4/1 0/2002 x x 2 CD-48 15434 5/29/2002 6/13/2002 126 371774.00 5974645.00 CD2-32 302-119 4/30/2002 x x 2 CD2-19, C02-41, C02-23 31113 6/14/2002 7/2312002 463 371295.61 5974302.38 CD2-50 302-121 4/30/2002 x x 2 CD2-41, CD2-19, CD2-16 17900 7/24/2002 8/18/2002 335 371665.21 5974227.65 CD2-46 x x 2 NA 0 252 371694.80 5974310.85 CD2-22 x x 2 NA 0 0 371678.61 5974562.30 CD2-48 x x 2 NA 0 827 371631.74 5973736.14 CD2-19 x x 2 NA 0 618 372284.88 5974681.33 CD2-41 x x 2 NA 0 821 371990.58 5973802.52 CD2-23 x x 2 NA 0 857 370996.57 5975081.46 CD2-16 x x 2 NA 0 828 372471.24 5974801.40 CD2-29 x x 2 NA 0 1063 372680.00 5974918.00 C D2-38 x x 2 NA 0 1101 372057.13 5973528.38 -"' CD2-44 x x 2 NA 0 429 372041.40 5974333.45 * Distance in feet, between surface casing shoes, in the X-V plane - CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MO (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. - As of 18-Aug-02 ) MEMORANDUM ') State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor CJj\' Chair WM SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder <"6 PAl P.I. Supervisor ( \ ~ CO2 22,46,48 FROM: John H. Spaulding Colville R. Unit Petroleum Inspector Alpine Field NON- CONFIDENTIAL DATE: August 9,2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-46 Type Inj. S T.V.D. 7017 Tubing pas pas pos pos Interval I P.T.D. 202-082 Type test P Test psi 1754 Casing 550 1950 1900 1890 P/F f Notes: Well CD2-48 Type Inj. S T.V.D. 7063 Tubing 747 747 747 747 Interval I P.T.D. 202-108 Type test P Test psi 1766 Casing 1050 1850 1840 1850 P/F f Notes: Well CD2-22 Type Inj. S T.V.D. 6997 Tubing 1000 1000 1000 1000 Interval I P.T.D. 202-092 Type test P Test psi 1749 Casing 450 1950 1875 1875 P/F f Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYCle s = SALTWATER INJ. R= Internal Radioactive Tracer Survey v= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Deta ils I witnessed the MIT's on the above wells located in PAl's Colville R. Unit. As noted in the above report all wells stabilized in their respective pressure tests. M.I.T.'s performed: ~ Attachments: none Number of Failures: Q Total Time during tests: 3 hrs. cc: none M IT report form 5/12/00 L.G. mit cru cd2 8-9-02 js.xls 8/14/2002 SchlUmbepgBr Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Log Description Job# CD2-22~-O'~ CD2-46 ~~-()cr;t 22309 22252 SCMT SCMT SIGNE~(Å Oo°r-..J Date 06/02/02 OS/21/02 DATE: 07/09/02 NO. 2207 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine BL Color Prints CD ~ Sepia ~ RECEIVED JUL 12 2002 A!a8kaQi) & Gas Cons. CommiSIkm Ancbof8ge Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. } (i~ ,i AI,ASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR ~~l~E :¡ !Æ~!Æ~~~JJ 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Drilling Team Leader Phillips Alaska, Inc. PO Box J 00360 Anchorage AK 99510-0360 Re: Colville River Unit CD2-22 Phillips Alaska, Inc. Permit No: 202-092 Sur. Lac. 1786' FNL, 1537' FEL, Sec. 2, T11N, R4E, UM Btmhole Loc. 1589' FSL, 1019' FWL, Sec. 35, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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 disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements 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, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations' of 20 AAC 25.080. Approval' of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical 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 prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~:~ Chai r BY ORDER OF THE COMMISSION DATED thi~ day of April, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) ) 1 a, Type of Work STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service X DevelDpment Gas 5, Datum Elevation (DF or KB) DF52' 6, Property Designation ADL 380075, 22530 7, Unit or property Name Colville River Unit 8. Well number v~GIt- ~/L?-ID L- Æ-~{c?~-o~ 2, Drill X Re~Entry Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface Stratigraphic Test Development Oil Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool Redrill Deepen 3, 4. 1786' FNL, 1537' FEL, Sec. 2, T11 N, R4E, UM At target (=7" casing point) 1497' FNL, 2613' FEL, Sec. 2, T11 N, R4E, UM At total depth CD2-22 9. Approximate spud date 1589' FSL, 1019' FWL, Sec. 35, T12N, R4E, UM 12. Distance to nearest 13, Distance to nearest well Property line CD2-24 Crosses from feet 20' at 100' MD / 380075 to 22530 16, To be completed for deviated wells Kickoff depth 1750 feet Maximum hole angle 5/10/2002 14, Number of acres in property Feet 2560 feet 11, Type Bond (see 20 AAC 25,025) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 11341' MD 7155' TVD feet /17, Anticipated pressure (see 20 f'AC 25.035(eX2» 90.65' Maximum surface 2532 j psig At total depth (TVD) 3214 at pslg 7103' TVD.SS 18, Casing program Settin.,9 Depth size Specifications Top Bottom Quantity of cement Hole Casing 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 2353' 37' 37' 2390' 2389' 492 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 7803' 37' 37' 7840' 7183' 132 Sx Class G N/A 4.5" 12.6# L-80 IBT mod 7381' 32' 32' 7413' 7075' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Title Drilling Team Leader Commission Use Only . Permit Number 0 I API nUlJlber ¿ J /") J I Approval date / '1,. " ., I See cover letter for 2t'??- ~ 0 7.2.. 50- /O~=? - 20 /"....c.- ~ 11\\.( J I-' Otherrequirements Conditions of approval Samples required Yes ~ Mud log requr-ed " Yes ~ Hydrogen sulfide measures Yes @ ~ectional survey required ~ No Required working pressure for BOPE 10M '7 CoCO' '" ~ r'\. D ì.~ - \ 2M 3M 5M 15M ~ ~ ~\ ""'''-''''-''-<) ~ ~\.J ~ ~""'" Other: \J...\\~ (J(~~~~1~\ \o~ Cammy Oechsli Taylor Effective depth: measured true vertical feet Junk (measured) RECEI)JiD Casing Length Size Structural Conductor Surface Intermediate Production Liner APR 1 6 2002 AlfIk.OH & GIs Cons. Commission AooIIOr8Qß Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch Drilling fluid program X Time vs depth plot Refraction analysis 21 , I hereby certify that the foregoing is true and correct to the best of my knowledge Diverter Sketch Seabed report Signed )l.! ~ Oß( Approved by Form 10-401 Rev. 7-24-89 Commissioner by Drder of the commission C~n~r:~~..' /\ L Jt\tLltt\Jl~¡ Measured depth True Vertical depth Drilling program X 20 AAC 25,050 requirements X Date +( 15f 0 L. Dare ¡,t~~n(~2:: ) ) CD2-22 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Infonnation for further discussion of these risks) ,12..1/4" Hole /9-5/8" Casing Interval Event Risk Level Conductor Broach Low Well Collision low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole / 7" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate - Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low M itiøation Strateay Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries M itiøation Strateøy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers /' ,6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation moderate Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low M itiøation Strateøy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.0 ppg. / Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers / ) ) Alpine: CD2-22 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 16. 17. 18. 19. 20. 21. 22. Procedure Install diverter. Move on Doyon 19. Function test diverter. / Drill 12-%" hole to the surface casing point as per the directional plan. Run and cement 9-5/8" surface casing. Install and test BOPE to 5000 psi. /' Pressure test casing to 2500 psi. / Drill out 20' of new hole. Perform leak off test. Drill 8-%" hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) Run and cement 7" 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. BOPE test to 5000 psi. / I' i 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 (LWD Program: GR/RES/PWD). ~/ ./ 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. Run 4-%, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and 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. "I'" 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. CD2-24 will be the closest well to CD2-22, 20' at 100' MD. Açcounting for survey tool inaccuracies, the ellipse separation between these wells will be 17.3' at 600' MD. / prilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential 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. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD2-22 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-22 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 C02-22 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 USDWs open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 300-400' 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) ... (2390') + 1,500 psi = 2,996 psi = 1,081 psi Pore Pressure Therefore Differential = 2996 - 1081 = 1915 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 00 (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 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi CD2-22 DRilLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH KCL Su rface Hole: ) ') SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 %" Section - 6 1/8" point -12 X" 8.8 - 9.6 ppg / 9.6 - 9.8 ppg / 8.9-9.2 ppg 1 0 - 25 10-15 20 - 60 15 - 25 25 - 30 100 - 200 4-8 10-15 <18 12 - 20 NC - 10 cc 1 30 min 4 -12 cc/30 min (drilling) 12 - 14 cc/30 min 8.5- 9.0 9.0 -10.0 9.0 - 9.5 6% A standard high viscosity fresh water 1 gel spud mud is recommended for the surface interval. Keep flowline viscosity at :I: 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 1 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 aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with 1: 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ) ) Colville River Field CD2-22 Injection Well Completion Plan I ~' : If I ~ 16" Conductor to 114' . 1"1 ! I: 1.1 ;, .'! :"" ;'1'1 ¡II, i ~! ,III " .I! 4-112" Camco DB Nipple (3.812') at 2000' TVD = 2000' MD 9-5/8" 36 ppf J-55 BTC Suñace Casing @ 2390' MD I 2389' TVD cemented to suñace 4-1/2" 12.6ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope TOC @ +/- 7083' MD (>500' MD above top Alpine) / - Camco KBG-2 GLM (3.909" DRIFT 10) wI dummy Updated 04/08/02 Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing suspenQed with diesel, Com.pletion .Mtl ~ Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB6 nipple 2000' 2000' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2- GLM (3.909" 10) 7200' 6962' 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker 83 Packer wi mlllout extension 7300' 7020' 4-1/2", 12,6#/ft, IBT-Mod Tubing (2) HES "XN" (3.725")-630 inc 7400' 7069' 4-112", 12.6#/ft, IBT-Mod 10' pup joint WEG 7413' 7075' Baker 53 Packer at +/- 7300' <200' TVD from top of Alpine Top Alpine at 7583' MD /7172' TVD Well TD at 11341' MD I 7155' TVD I 1/ ! 7" 26 ppf L-80 BTC Mod Production Casing @ 784<1'MD 17183' TVD @+/- 870 ) ) Colville River Field CD2-22 Injection Well Completion Plan F ormation Isolation Contingency Options - . - 16" Conductor to 114' Updated 04/08/02 . 4-112" Camco DB Nipple (3.812') at 2000' TVD = 2000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2390' MD I 2389' TVD cemented to surface Packer Fluid mix: 9.6 ppg KCI Brine with ?OOO' TVD diesel c~ TubinQ suspended with diesel 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope (A) Ron~al FCP 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 TOC @ +/- 7083' MD (>500' MD above top Alpine) (fl) Open Hole Scab Iner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe I Entry Guide (C) Open Hole BrldQe Plug Assembly - Baker Payzone ECP (cement inflated) -xo -Float Collar - 4-1/2" Float Shoe Cameo KBG-2 GLM (3.909" DRIFT ID) wI dummy Baker 53 Packer at +/- 7300' <200' rvD from top of Alpine Well TD at 11341' MD I 7155' TVD , ",..'" II ~'Ð(fll""" I' ~ (\1')': . I. - . - - .. lXI .. . ..., . . - v! : Top Alpine at 7583' MD /7172' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 7840' MD I 7183' TVD @+/-87° ) ) CD2-22 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 : Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs.1 gal) (psi) (psi) 16 114/114 10.9 52 53 9 5/8 2390 I 2389 14.5 1081 1563 7" 7840 I 7183 16.0 3250 2532 / N/A 11341 I 7155 16.0 3237 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 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 Ib/gal 0.052 = Conversion from Ib.lgal 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 1. 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) = 1081 - (0.1 x 2390') = 842 psi. 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D J = [(14.5 x 0.052) - 0.1] x 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3250 - (0.1 x 7183') = 2532 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3259 - (0.1 x 7190') = 2540 psi J ) ) Alpine, CD2-22 Well Cementina Reauirements 95/8" Surface Casin~ run to 2390' MD /2389' TVD. Cement from 2390' MD to 1890' (500' offill) with Class G + Adds (@ 15.8 PPG, and from 1896' to surface with Arctic Set Lite 3. Assume 3000/0 excess annular volume in permafrost and 50% excess below the permafrost (1556' MD). Lead slurry: System: Tail slurry: System: (1890'-1652') X 0.3132 relft X 1.5 (50% excess) = 111.8 fe below pennafrost 1652' X 0.3132 fe/ft X 4 (300% excess) = 2069.6 fe above permafros;.r Total volume = 100.8 + 2069.6 = 2181.4 fe => 492 SX Cê9 4.44 felsk 492 Sx ArcticSet Lite 3 (4), 10.7 PPO yielding 4.44 felsk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 8001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 re/ft X 1.5 (50(Yo excess) = 234.9 re annular volwne 80' X 0.4341 felft = 34.7 fe shoe joint volum,e / Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx (@ 1.17 felsk 230 Sx Class G +0.2% D046 antifoamer, 0.3% D065 dispersant and 1% SOOl accelerator (@ 15.8 PPG yielding 1.17 felsk 7" Intermediate Casinr run to 7840' MD /7183' TVD Cement from 7840' MD to +/- 7083/MD (minimum 651' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 400/0 excess annular volume. Slurry: (7840' -7083') X 0.1268 fe/ft X 1.4 (40% excess) = 134.4 r1? annular vol. 80' X 0.2148 fe/ft = 17.2 reshoejoint volume / Total volume = 134.4 + 17.2 = 151.6 fe => 132 Sx @ 1.15 felsk System: 132 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 ff Isk 1 By Weight Of mix Water, all other additives are BWOCement Phillips Alaska, Inc.1 ~HI~UPS' Created by bmichae! For: V Johnson! Structure: CD#2 Well: 22 ¡ i~~1. Date pioUed: 8-Apr-2002 Ptot Re1erer.c:e is C02-22 Vergjonf5. ¡ Field: Alpine Fie!d Location: North Slope, Alaskal Coordinates ere in f=ct reference slot #22.. I - -' True VerticD! Depths D,e reference Estimated RKB.¡ .. ! ItfIII.s 1N'1'W:4} ---- PROFILE COMMENT DATA ---- '----- Point ----- MD !nc Dir ND North East V. Sect Deg/1 DO! ¡West Sak 1069.00 0.00 250.00 1069.00 0.00 0.00 0.00 n OO! '-' v. ! !Base Permafrost 1652.00 0.00 250.00 1652.00 0.00 0.00 0,00 0.001 ¡Begin Nudge 1750.00 0.00 250.00 1750.00 0.00 0.00 0.00 0.001 I 1950.00 4.00 250.00 1949.84 -2.39 -6.56 5.71 2.00! ¡EOC ¡Begin Drop 2150.00 4.00 250.00 2149.35 -7.16 -19.67 17.14 o.ooi i iC-40 2222.77 2.54 250.00 2222.00 -8.58 -23.57 20.54 2.001 i IEGC 2350.00 0.00 250.00 2349.19 -9.55 -26.23 22.86 2.001 19 5/8 Casing pt 2389.00 i 2389.81 0.00 221.02 -9.55 -26.23 22.86 0.00 iC-30 2399.81 0.00 221.02 2399.00 -9.55 -26.23 22.86 0.00 iC-20 2540.81 0.00 221.02 2540.00 -9.55 -26.23 22.86 O.OO! I ! IK-3 3848.81 0.00 221.02 3848.00 -9.55 -26.23 22.86 O.OO! iK-2 4068.81 0.00 221.02 4068.00 -9.55 -26.23 22.86 i O.OOi ¡Begin Build I 4900.00 0.00 221.02 4899.19 -9.55 -26.23 22.86 O.OO! iAlbian-97 5189.92 8.70 221.02 5188.00 -26.12 -40.64 32.48 3.001 IEGC I 573 Î.42 24.94 22 Î .02 5704.59 -143.95 - 1 43. 1 3 100.93 ï:, OO! i . o..J. ! fAlblan-96 5977.81 24.94 221.02 5928.00 -222.34 -211.32 146.48 0.001 iBegin Final Bld/Trn 6242.51 24.94 221.02 6168.01 -306.57 - 284.58 Î 95.40 o.ooi .~ i j IHRZ 6972.37 40.93 303.37 6806.00 -290.40 -600.78 504.99 6.00! i iK-1 7253.67 55.15 315.70 6994.00 -156.14 -759.49 693.07 6.001 I 6.00! --- ;LCU 7438.18 64.99 321.57 7086.00 -36.08 -864.65 825,76 i 6.001 !Miluvecch A 7480.19 67.27 322.76 7103.00 -5.74 -888.21 856.38 !Alpine D 7526.63 69.79 324.03 7120.00 28.95 -913.98 890.25 6.00! !Alpine 7582.84 72.85 325.52 7138.00 72.44 -944.67 931.17 6.00! iTarget - Casing pt 7840.47 87.00 33 Î .87 7183.00 288.66 -1075.81 1113.87 6.001 ¡ IEGC 8205.33 90.65 331.87 7190.49 610.29 -1247.79 1363.32 1.0°1 j r-' P ¡TO - vaslng t 1 1 341 . 1 8 90.65 331.87 7155.00 3375.45 -2726.36 3508.02 O.OO! . ë;;';ãié'd'-bY'-bmïèï1ãë"'-'~"F'~';: ..-V.~j'~~h~~-;;'~ Date plolted: a-lIpr~ 2002 Plol Rafa...""" I. CD2-22 VaroloniS. Coordinate, ore In feel reI.rone. olot 1/22" Tro" Vorllcol Deptho 0'" r.ro...""" Collenoted RKß, .. ~ '''''.. ,,,,,-,,,,,,-_.,,,._,,~~!~9,,,,,.._,.,,..,..., .. Begin Build - 3.00.. 6.00 .. 5200.. 9.00.. 12..00 .. - 15.00" 18.00. 5600 -. ~~.~~ 0 .. 400 - 800 - 1200,- 1600- 20()() - 2400 -. ,-.... +- () () 2800-- - '-'" .!: +- 32.00 - a.. () 0 0 3600 - () 1: () 4000 .- > () ::J 440()-' L I- I V 4800 - 6000 - 6400 '" 6800 - ) ) '-".._''''''''--''-''._'._''''"'"''-''""-~._-'W_'~-'''-"._,,-_._,,---~._....~...........'._-'._"__'H"''''''''.'--'''''._''--"~_'~'H""""" I:Jllillips Alaska, Ine 0 ."'.""'-"."'-".."""."""-"-'"''._''H'-_'__''..'''.,....-."-,..,,.......-.,.........'....'.'" ,.--. .. ."H".._.-"-'''''''-~'''-'''''-'''''-''..'-.''''-..'' ,. -. .. .-.~.~.._. ~.""~."",,,,,,,~,,,,,-",..,~,.,. Structure: CD#2 Field: Alpine Field Well: 22 Location: North Alaska I RKEì Elevalion: 52' 2B5.02 AZIMUTH 1114' (TO TARGET) ***Plane of F)roposal*** .. West Sak .. Base Permafrost .. Begin Nudge 2.00.. .. mc .. Begin Drap 2.00~ C-40 J;l ~~~{08 Casing M' C-.'20 TANGENT ANGLE "VERTICAL" .. K-3 >c. K-.'2 Albian-97 DLS: 3.00 dog per 100 ft TANGENT ANGLE 24.94 DEG Begin Fimll l~ld/Trn 7200 - 23.9;) 23.31 24.10 26.19 29.32 ç\. 33. 17 .~O; '" 0'1>' 42.26 --' ú'(\'\) C; 52.34 f: \...~\\)..¡~~e.,<,e e\. -- 62.94 v.~'f>~'¡"9Z...o~o; <yOv 79.27 "-.q TO - Casing Pl DLS: 6.00 deg per 100 ft TARGET ANGLE 87 DEG FINAL ANGLE 90.65 DEG L'22l 7600 -- I 400 0 .,---,--r- I .,- I 400 800 1200 1600 2000 2400 2800 3200 3800 4000 4400 4800 5200 5600 6000 Vertical Section (feet) -> Azimuth 285.02 with reference 0.00 N, 0.00 E from slot #22 ) ) .~._,.,--.......,."..,.._.."..~--,~_....".,_......_.....,..,-,-",--",-~""-,-,--"","-,-,-"",~-,-",..~,,._,.__.-"'-""'."--'-"'''.'.'''--'-''--'''.''''''''''..-'''''--..-,..- Cr.ct.d b.V bmlch..1 For: V Johnson Dat. plott<Od: S"lIpr-2002 Pial R.r.r.no. I. CD~,'.22 V.",lonl5, CøordlnatClN ere I" fflet rohmmc:e ~Iot /12.2. Tru.. V.rtlcol Depth. ere r.r.,.,neo E.tlrnclod RKB, ad!: IJllillips Alaska, TI1C. -,.......-.,..,......,..k..,._...........-.-..,-....""'"'''-''''''-'-'--'~'''._''- .--..----,."..-.......,.-....-.-.-.-.,..,...,........---......--"....-.-.-'".-.--.-- <PHiwp~ . 'F!fI,1 ~ Well: 22 Structure: CD#2 Field: Alpine Field Location: North Slope, Alaska INTEQ ..-... ..-.-.--.--"".-,.,.,.""....-..--."..".,.-.-,.-. <- West (feet) 1800 1600 1400 1200 800 1000 600 400 200 0 200 I .-._.l___I___L._,-!--.-..J--.-... 3600 3000 2800 2600 2400 2200 2000 l___,L_..,_,.L..__.L_...,L. I I _..L_....L~_.J._.,_J_...__.L_._...L.._.L~_.J.._.......I I ..._J.._.,-L....__L__,..J___.I_...- I - Casing pt 285.02 AZIMUTH 11.14' (TO TARGET) *"'*Plane of Proposal*** I TD LOCATION: ] 1589' FSL. 101 9' FWL SEC. :35, T12N. R4E --'---'__"__M__'_'- \ f TRUE \~ 'v' '\.,~ \\~ -.--"--..-...-.----.,-.---. ESTIMATED SURFACE LOCATION: 1786' FNl., 1537' FEI. SEC.2, T1 1 N. R4E .--.-.-----.--..------- EOC Target - Casing Pl I TARGET LOCATION: I 1497' FNL. 2613' FEl. SEC. 2. T11 N, R4E - 3400 .. 32.00 .. 3000 ~ 2800 - 2600 .. 24.00 .. 2200 .. 2000 ^ ..1800 I Z - 1600 0 .., -+- ::J" ....-... ~ 14,00 -+. CD CÐ -+- "'-" .. 1200 ~ 1000 - 800 .. 600 .. 400 .. 200 .. 200 .. 400 rcr-;oteð by bmichoe! For: V Johnson ¡ Dote p!oUed: 6-Apr-2oo2 I Plot Refe<ence is CD2-22 VersionfS- i Coordinates are in feet reference siat '22~ ITrue Verticol Depths ere reference Est;mated RKB. ! -- IIfILs I N'I'£Q 5800 - Î "';00-96 --- 6000 - - Q) 2 Begin Final Bld/Tm --- 6200 - 23.9~ ~ - g- 6400 - 24.1 O. 0 - 26.19 2 6600 - =+= I- Q) > 6800 - Q) ::::J .:: 7000 - I V 29_32 33.17 37.54- 42.26 47.22 «'- 52.34 \'- .('~ 57.60 ~c;ù .eoc,'Ç<. Ç) Cp<i>' 62.94 "¡'~-ð" \(\e e'- ,- 68.34 ~ç ~\'è-e ~o~~ OG 79.27 .~ -.ð ~ -..: - 23.31. DLS: 6_00 deg per 100 ft 7200 - 7400 - 200 0 200 600 800 400 Phillips Alaska, Inc. ¡ Structure: CD#2 Field: Alpine Field Well: 22 Location: North Slope, Alaska I 331.87 AZIMUTH 762' (TO TARGET) ***Piane of Proposai*** TARGET ANGLE 87 DEG FINAL ANGLE 90.65 DEG 1000 1400 1600 1800 2000 2200 2400 2600 2800 :5000 1200 Vertical Section (feet) -> Azimuth 331.87 with reference 0.00 N, 0.00 E from slot #22 4~HIWPS' .CtEI ~ '.-- ::::J . 3200 I 3400 3600 3800 ~ ~ TO - Casing pt f22l 4000 4200 4400 ) ) r"'----"-''''-''''-'-'''---''-'-'--'--'''-'-'~'-'''''''--"""-'-"-'--'-""""'-'-""--""-'''-'''''-''-'-----'"'-""""'-'''''-' Phillips Alaska, Irlc. Creatod by bm1ch~.IFor: V Johnson D.I. pl.Und: 4-""r-2002 Plol RoIo",,,,,,, 1. C02..22 Vcndonf5. Coord!".I... .re in ""I .000.,.,n.. .1.1 #22. Trua Vartla.' Depth. oro "".,ono. Esllmoted RI<B, .ra: Structure: CD#2 Well: 22 l...._,......_~!.~~~-_.:,.~.~~~..~~~~_......._....~~:~!I~..~-,:,.~-~:~...:~~~~~,~,~~.~.~~. Il'1'lW <- West (feet) 120 110 100 90 BO 70 60 50 4,0 30 20 10 0 10 20 30 L_,_1._.....1___1._..__I._..__..J,.,.._._I_,_..._l.._~_.l____L__.l-_,_1._._..1_-_.1,- I , I I ,....l_._..l_..._I,.___..L__l.._.,...l___.1__-.-I...-.....J.._,_,_l_-.....1.---.1.----1.-- I Qv, 8300 1100 'i<' 900 '.' , 700 . 8300 -$- Q1]~oo -----.. @300 ------...--- - "". .... ..... --------. ..."'" .,. ,. ------......u..oo ../ ~ 2100 -'- /'1" 2300 ---- ' ~o IIIÍ '""-- '700 / 51 00 -'---"¡'-----_~300 , , , , , , , , , , ,. 5300 , , , , , 1 1 1 1 1 1 1 1 1 , 1 , , 1 , , 1 5500,/ , / .1900 1 , I, 210°.,' 2300", ',/.1300 /@300 "¡,~ , ,', 00 , 100 ~ ' 1500 ~300 ,o- 00 , . 00 3~ ~ --.-- 0 30~00 500 00 --~ . . --.-- -~~ ~3oo 7-------~'3(jcr -:: ---- . ~. 00 t~~,O,~"~~ 1500 J. 500 ~ ~~ .1300 . 8-.- ..5CiO .1500 e 300 .1700 .700 @)JOO 700 .,. 500 '" @300 900 '" ' 8300 1100 111' ' ~~ .~',~"',,\ , , , ~ .. ~ . - 4,0 I D:D-- 30 ~ 20 - 10 .. 0 - 10 _.-.~Ä)G-----(ID - 20 .., 30 ..' 40 $., tn -:>0 0 c: ~~ :r ,III 90~ - 60 ..-.. ..... (J) (J) .... .. '70 ......... I V ~ 80 - 90 -100 500 - - --.--119 -110 @-120 - 1.30 -140 -150 -160 100 - 120 - 140 - 160 - 180 -GD 200 - ,....... -+- 220- OJ OJ '+- '-'" .J:: 240- -+- ::J 0 (f) 260- I V 280- 320 - 340~ 360 ~ 380 ~ Phillips Alaska, Inc.1 ~Hï~ps' tff,~. 110...- ,- ~ ~. r;------- - ! Created by bmìchacl For: V Johnson i Dale platte<!: 4-Apr-2002 ¡ PIOI Reference is C02-22 Versk>nf5. ! Coardirla\ee ore in feet reference eIol 122. ¡True Vertical Depths ere reference Estimated I<KB. , - , ... ! ..... , 1N'1'1!:Q Structure: CD#2 Field: Alpine field Well: 22 i Location: North Slope. Alaska! ~10o& .' .~~œ7""'@ , ./~loo / , ~100 .." / / .. tt '5700 / / 1900 2100 ,.Í'300 ," 5300 2300, --' .0,1 SOD .. / .. .. .. " /5900 .. .. .. .. / / / / / / / / .. .. / / .. / / ../6100 / / / / / / / / / / / / " " , , , ~ 5900 " ,,'" , , , , ....Æ300 ""--------------.6~Q___------------- ""1700 ~ ~ (ß>' ."- BOO c§> --' .1500 I 560 I 480 120 I 100 I 420 I ¡ I I 360 340 320 300 < - West (feet) I 280 I 260 I 540 I 520 I 500 I 240 I 220 I 200 I 180 I 160 I 140 400 380 460 440 ) ) -"~--""-"""'_'"""h__'___"---""---'-'---"""".~_"H'_"_'"'U'-''' ...-.-"....._,..0"",",""-"""."."-,,-,,.--,.,,,,-,--'. .....-.-.._U... .................-..,...--.--,..-....,....,--..--...-...."........,.......-.-,..----.,...-...--....--.-".., Structure: CDH2 Field: Alpine Field Well: 22 Location: North Slope, Alaska ~ ll1i1 '. ".' Created by blrllohanl ¡O'or: V Johnson 00\\1 plottod: +-Apr-2002 Plat R.I.,.nc. i. CD2 -22 V.""anI5. COOrdlnat.. are In - rot.rena. .Iot 122. True Vertical Oepth. 01'0 ...t....""" E.tlmated RKB. - .... Philli s Alaska, Inc. INTIi:Q <- West (feet) 3600 3400 3200 3000 2600 2600 2,400 2,200 2000 1800 1600 1400 1200 1000 800 600 400 L_--L._.--L,_--1-_,L__,-L___...L_,._,J.,_--1__J_""-,_J._~_...L_. I I _-!__-L_._.J.'__L_..l__.J__-L_-""-L'_~__I~ I I _-L,-_J. I --.1----...1,-.----- \ '11\.5600 - 3600 ITIJ ~l , , , , , " '\ , , , , - 3400 ... 3200 \. 6600 \10: \ ~ 5600 - 3000 \ '; ., \ ,- 2800 .. 5100 iI>,6100 .. 2600 Q) , , , , , , , , - 2400 '. 4600 - 2200 , . 3600 \\ '.4100 - 2000 Q7 , \, , , , , , , , 1113100 '\ " \ , , " \, ClÐ------.5"OO " , , ~ ,.3100 . \ ~600 '" , ~\~600 , -"'------, ': ' ", ---------4100, \ ---..~"", ,.2600 "\"", " 26 OO~' .3100 3600" ' - 800 ----------- - . -;. " ..,21 00 '", 41 0 , .2600 ~,.n:.¿',',\",,',','26oÒ2100 ,~: 600 (m-----_---,- 4100 ,,', \ ~ . , --------'--'-----.-. 3600 \'. " '\ \., '" '2~" 100, ,. 1600,R> - 400 ŒJ 3600 -------- ;~100 '. ~" " ~ .. 3100 ---111---- ' , "-<J .' - ~--~ \ 9 Vq200 --~~OO,aiL- 2100 \ --~ '" 7100 0 \ \ " " Œ 2~OÒ' " r:§5 - - 200 "" ...-? - ~~~~- 400 -1800 ^ I ~ 3600 z 0 - 1 600 3: ~"" 0, '", 5100 .......... ..... - 1400 ~ ....... .......... .. 4600 ~ 3100 -1200 -1000 3100 ,. , (ill 3600 . ~ ') i ) ....,~..._.."_.__."...~--".,~--,...._.,.,,_.__....._--H-"__"--""-'---''''''~'----''''-"''-----''-'''---'''--'-----'-'--'.'" -. - '."-"----"-'-'-""'''''~'"'-''-- Structure: CD#2 Field: Alpine Field Well: 22 Location: North Slope, Aloska (PHIWP~. ~ ....,.....,...,...,...............",.....-..,.....-.",....,..,-"""."-"",-""-"""-",,,,-~,,,,.,,,-,,,,, Phillips Alaska, Inc. C,ootiod by bn,lchae' For: V .Johnson Dal. ploU.d: 4-A¡,,-2,Q02 Plat R.hlr.no. 10 CD2..2.2 vonolon#5. Coordinat.. are In f..1 ,.""",nco .101 "22. Tru. V.rtlcal Depths a... feler.nce Estimated RKB, .. .... INTKQ ."..,... '.-. ...............". "--"''''''''''''-~''''''-''-''-''--'''"-'-'''..''-'''''~'".-...,.-.,,,,,-,,,,"..',.""'.'."-..',--''''.....--...'"'.".~"'."...'M.""-...',-.-,._".-,w._,,,...,-,,,,,...,--...,. ...__....,..,.,.._,.."-,-,,....._,.,~.,...,.,..._._,..'_..""~'.__W'-~'~-"...'_.M~,_.'_,'_'"'-~,.._,_..~_..",-",--,._".,..,_.-."_.'.'¥'..~..'._.",,.~,_..,._--_._.,-- Q) <0 \§ TRUE NOI~TH <:> [=:J 0 @9 (j) ~ Q)'" 3'?O 340 .... 1000 . 1000l' 1 0 .. '300.0. ~ LO all/ 3~ 250 (ill 330 .... 320 50 2.90 70 80 270 90 260 100 120 130 210 ~ Normal Plane Travelling Cylinder -- Feet All depths shown are Measured depths on Reference Well ) ) PhilHps Alaska, Inc. CD#2 22 slot. #22 Alpine Field North Slop'), Alaska PP,OPOSAL LIS'rING by Baker HugM1! INTEQ Your ref: CD2'.22 Version#5 Our rE>f : prop4256 LÜ~e!\S.., : Dat.e printed: a...Apr-20 02 Date creilted : 31-0ct~2000 l,ast r(wised: 8-Apr-20 02 Field is cent.red on n70 20 37.100, w150 51 37.53 Structure is ç,entred on n70 20 37.100, wI51 :1. 42.976 Slot le'cat:i.cm is n70 20 I9.543,wl~\1 2 27.830 Slot Grid I~oorclinc¡,tes are N 5974[,72.199, E 371703.700 Slot local coordinates are 1785.00 S 1535.68 W proj ection type: alask¡l .. Zone 4, Spheroid: CL~rke .- 1866 Reference North is True Nortb ) ) Phillips Alas k.a, Inc. PROPOSAL. I,ISTING Page 1 CDj/Z, 2 '2 You,!: ref : CDZ-22 V,.~rsion#!; .hlpine f.'ie.1.d,North Slope I Alask.a lÆ,st revise(;i : 8-.Apr...2002 M'3a:mred Inc1l.n Azimuth TX'IJel Ver1: R F; C T AN G U r, A R G R .1 D C 0 0 R D S G E () G R A I' H I C Depth Degrees D¡:'g.rees Depth C 0 () R D I N A T E: 8 Eas t.inq NOI:thing C 0 0 R D I N A l' B; S 0.00 0.00 0.00 0.00 O.OON 0.0 OF.: 3717C13.70 5974572.20 n70 20 19.54 w151 2 27.83 100.00 0.00 250.00 lOCI. 00 O.OON 0.00£ 371703.70 ~j974572. 20 n70 20 19.54 1~151 2 27.8:) 200. no 0.00 2,50.00 200.00 O. OON O. OOE 371703.70 !)974572.~~0 n70 20 19.54 w151 2 27.8,1 :HJO.OO 0.00 '250.00 300.00 O.OON O. OOE: 371703.70 5974572.20 1170 20 19.54 w151 '2 27.83 400.00 0.00 '2~)0.00 400. no O.OON O. OOE 371703.70 :j974572. 20 n70 20 19.54 w151 2 27.83 500.00 0.00 2~¡0.00 500.00 O. OON O. OOE 371703.70 5974572.20 n71) 20 19.54 w1~\l 2 27.83 600.00 0.00 2~¡0.00 600.00 O.OON O. OOE 371703.70 :)974572.20 n70 20 19.54 w1~,l 2 27.83 700.00 0.00 250.00 700.00 O.OON O. 0 Or.~ 37170:¡. 70 5974572.20 n70 20 19. 5~ wl~ll 2 27.8.3 800.00 0.00 250.00 800.00 O. OON O. OOE 371703.70 5974572.20 n70 20 19.5'J w151 2 27.83 900.00 0.00 250.00 900.00 O. OON O. OOE 371703."/0 5974572.20 n70 20 19. !:.4 wl~j1 2 27.8.3 1000.00 0.00 2e,O.00 1000.00 O.OON O. OOE 37170:¡' ') 0 ~j9745'12.20 n70 20 19.54 wln 2 27.83 1069.00 0.00 '250.00 1069.00 O.OON O. OOE 371703.70 5974572.20 n70 20 19.54 w151 2 27. f;).3 1100.00 0.00 250.00 1100.00 O.OON O. OOE 3'/1703.70 ~j974572.20 n70 20 19.54 wI51 '2 27.83 1200.00 0.00 2!;¡0 .00 1200.00 O.OON O. OOE 371703.70 ~)974.:n.20 n70 20 19.54 1~151 2 27.83 1300.00 0.00 250.00 DOO.OO O. OON O. OOE 371703.70 5974!j72 .20 n70 20 lSi. 54 wl;)l 2 27.83 1400.00 0.00 '250.00 1400.00 I), OON O. OOE :371.703.70 :)974572.20 n70 20 19. ;,4 w151 2 27.83 1.500.00 0.00 '250.00 1.~¡00. 00 O.OON 0.0 OE: 371703.70 5974572.20 1170 20 19. 5'J w151 2 27.83 1600.00 0.00 250.00 1600.00 O.OON O. OOE ,371703.70 ~)974572 .20 n70 20 19.54 w151 2 27.83 1652.00 0.00 250.00 1652.00 O. OON O. DOE 371703.70 5974572.20 n70 20 19.54 w151 2 27.83 1700.00 0.00 2!'¡O. 00 1700.00 O.OON O. OOE: 371703.70 5974572 ø20 n70 20 19.54 wHH 2 27.83 1750.00 0.00 250.00 1750.00 O.OON O. OOE 371703.70 5974572 .20 n70 20 19.54 w151 2 27.83 1850.00 '2.00 2~;O. 0 0 1849.98 0.60S 1. 64\\1 :371702.05 597 4~/) 1. 63 n70 20 19.54 w151 2 27.88 19;)0.00 4.00 2~¡0.00 1.949.84 2.398 6.%1'1 .371697.10 5974569.92 n70 20 19.52 w151 2 28.02 2000.00 4.00 250.00 1.999.72 3.. !:laB 9.84W :n1693.81 5974568.79 n7(1 í;O 19.51. w151 ~¡ 28.12 2150.00 4.00 '250.00 2149.35 7.168 1.9.67W 371683.92 :)974565.37 n70 '20 19.47 w],;) 1 2 28.40 2222.77 2.54 250.00 2222.00 (3.588 23.5 7W 371679.99 5974561]. 02 n70 20 19.46 w1.~n 2 28. ~j2 2250.00 2.00 250.00 2249.:21 8.958 24.59W 371678.97 5974563.67 n70 20 1.9.46 1~1.51 2 28.55 2350.00 0.00 250.00 2349.19 9.558 26.2 3W 371677.32 :)97 4!S 63.10 n70 20 19.4:) w151 2 28.60 2389.81 0.00 221.02 2389.00 9. 5~)S 26.23\\1 371677.32 5974563.10 n70 20 19. 4~\ wH;l 2 28.60 2:J99.(11 0.00 221.02 2399.00 9.553 ;,~ 6 . 2 3\\1 371677.32 597456~1.10 n70 20 19.45 w151 2 28.60 2400.00 0.00 221.02 2399.19 9.558 26.2:31'1 .371677.32 5974563.1.0 n70 20 19.45 w151 2 28.60 2500.00 0.00 221.02 ~~499.19 9.55S 26 . 2 3W 371677.32 5974563.10 n70 20 19.45 w15J. 2 28.60 2540.81 0.00 221.02 :2540.00 9.558 26.2:JW 371677. n 5974563.1.0 n70 20 19. 'J5 w151 I. 28.60 2600.00 0.00 221..02 2:)99.J.9 9.558 26 . 2 3W .371677.32 5974563.10 n70 20 19.45 wl:)l 2 28.60 2700.00 0.00 221.02 2699.19 9. 5~iS :2 6 . 2 3W 371677.32 597456é) .10 n70 20 19.45 1Ü51 2 ;~ 8.60 2800.00 0.00 221..02 2799.19 9.558 26. 2 3W 371677.32 5974563.10 n"/O 20 19.45 w15J. 2 28.60 2900.00 0.00 221.02 2899.19 9. f.J~1S 26.2:,W 371677.32 5974563.10 n70 20 19.45 1~151 :2 ;~8. 60 3000.00 0.00 221.02 2999.19 9.558 26. :2 3W 371677.32 5974563.10 1170 20 19.45 w15J. ~ 28.60 3.100.00 0.00 221.02 3099.19 9.!;~~S 26.Z:¡W 371677.32 5974563.10 :n70 20 19.4:, 111151 2 28.60 3200.00 0.00 221.02 '3199..19 9 ..5 ~)s 26. 2 3W 371677.32 5974563.10 n70 20 1.9.45 IV151 2 28.60 3300.00 0.00 221.02 3299.19 9.553 26.2 3W 371677.32 5974563.10 n70 20 19.45 w151. 2 28.60 3400.00 0.00 221..02 3é199. 19 9.555 26 . 2 3W 371677.32 5974563.10 n70 20 19. 4!'? w151 2 28.60 3500.00 0.00 221.. 02 3499.19 9.558 26 . 2 3W 371677.32 5974563.10 070 20 19.45 w151 2 28.60 3600.00 0.00 221..02 3599.J.9 9..558 26 . 2 3W 37167'7.32 5974563.10 n70 20 19.45 wl~'¡1. 2 28.60 3700.00 0.00 22J..O:2 :3699.19 9.558 26.:2 3W 371677.32 5974563.10 n70 20 1.9.45 w151 2 28.60 3800.00 0.00 221.02 3799.19 9. ;)58 26.2:iW 371677. n 5974563.10 n70 20 19.45 w151 :2 28.60 3848.81 0.00 221.02 3848.00 9.558 26.2 3W 371677.:32 5974563.10 n70 20 19.45 w151 2 28.60 3900.00 0.00 221.02 3899.19 9.558 26.2 3W 371.677.32 597'J563.10 n70 20 H.45 w151 2 28.60 4000.00 0.00 221.02 3999.19 9.558 26 . 2 3W 371677.n ~,974563 .10 n70 20 19.45 w:t:) 1 2 28.60 4068.81 0.00 221. 02 4068.00 9.558 26 . 2 3W 371677. 3~~ 597456:i .10 n70 20 19.45 w151 2 28.60 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot. #'22 and TVD from Estimated RKB (52.00 Ft. above mean sea level) . Bottom hole distance is 4339.00 on azimuth 321. 07 deqrees from wellhead. Total Dogleg for wellpath is 132.47 degrees. ver.tical section is from wellhead on azimuth '285.02 degrees. Grid is ala,~ ka - Zone 4. Grid co(,rdinates in FEET and computed using the Clarke - 1866 sphElroid Presented by Baker Hughes INTEQ ) Phillips Alas ka, Inc. PROPOSAL, 1,1 sn NG page 2 CD#2, 22 Your ref : CD2~22 Vc,rsion#~, Alpine E'ield, N01:th Slope, Alask.a ¡,ast revised : e'-Apr'.2 002 Mea:>tlr.'ed Inclin Admuth T.r:uC'1 Vert H E C T AN G U L A R G H 1 D C () 0 R D S G E 0 G R A P Ii I C Depth D"grees D£.g.t:ees Depth C 0 0 R D I N A T E 8 Eas t.i.ng NOI:thing C 0 0 R D r N A l' .I~; S 4100.00 0.00 221. 02 4099.19 9.5~,S 26 . 2 3W 371677.32 597456:i .10 11711 20 19.45 wl.'Sl 2 28.60 4200.00 0.00 221.02 4199.19 9.558 2 6 . 2 3W :371677.32 5974563.10 n711 20 19.45 wlf¡l 2 28.60 4300.00 0.00 221.02 4:~99.19 9. f)5S 26.2;,W 371677.32 !~97456,J. 10 n70 20 19.IJ5 w151 2 28.60 4400.00 0.00 221.02 4399.19 9. [i58 26.23W 371677.n 5974563.1.0 1170 20 19. 4[) w151 2 28.60 4500.00 0.00 221.02 4499.19 9.558 26 . 2 3W 371677.32 ~j974563 .10 n70 20 19.45 w151 2 28.60 4600.00 0.00 221.02 4[i99.19 9.555 2 (; . 2 3W 371677.32 5974563. J.O n70 20 19.45 w1~)l 2 28.60 4700.00 0.00 221.02 4699.19 9.555 26.23W 371677.32 5974563.10 n70 20 19.45 w151 2 28.60 4800.00 0.00 221. 02 4799.19 9.55S 26 . 2 3W 37H177. 32 597456:1.10 n70 20 19. ~15 w151 2 28.60 4900.00 0.00 221. 02 4899.19 9.55.5 26.23\~ 371677.32 5974563. J.O n70 20 19.45 wHi.1 '2 28.60 5000.00 :3.00 221..02 4999.14 11. 528 27. 94w 371675. E,7 5974561. J.5 n70 20 19.4:3 wH;l 2 28..6,5 5100.00 6.00 221.02 5098.82 17.448 =i~). 09W ,371670.32 5974555.32 n70 20 19.37 N1.5J. 2 28.80 5189.92 8.70 221. 02 ~)1.88.00 26.128 40.64W 371662.6:1 5974546.77 n70 20 19.29 w151 2 29.02 5200.00 9.00 221.02 5197.96 27.298 41. 66W 371661.59 ~)97454S.62 n70 2'0 19.27 w151 2 29.05 5300.00 12.00 221.02 5296 .27 4LO:¡S 53. 62W 371649.40 5974~)32.08 n70 20 19.14 w1.:H 2 29.40 5400.00 15.00 221.02 5:!93.50 58.658 68. 93W 371633.79 5974,514.73 n70 20 18.97 w1n 2 29.84 5500.00 18.00 221.02 ~i489.37 80. 07S 8757W :37161.4.79 fj9744 93.62 n70 20 18.76 w1.fJ1 2 30.39 5600.00 21. 00 221.02 5583.62 105.26S 109.48W 371592. ,n 5974468.82 1170 20 HI.51 w151 2 31. 0:> ~noo.oo 24.00 221.02 ~676.00 134.138 13~1. 59W 371566.87 ~)9744 40. n n70 20 18.22 wI51 2 31. 76 5731.. 42 24. 9,~ 221.02 5704. ~,9 143.958 14 3 . 13W 371558.17 59744,30.70 n70 20 18.13 w151 2 n.Ol 5977.81 24.94 221. 02 5928.00 222.34:;; 211. 32W 371488.67 59743,5:i.48 n70 20 17.36 wH,l ~ 34.00 6000.00 '2 ¡J. 94 221..02 :)948.12 229.418 217.46W 371482.4.1 5974346.52 n70 20 17 .2~) w151 2 3,1.18 6242.51 24.94 221.02 6J.68.01 306.5'18 284.58111 n1414.00 5974270.51 n70 20 Hi .53 w151 2 36.14 6300.00 23.95 229.01 6220.37 323.388 3 0 1. 3 5W 371396. 9.~) 597425').99 n70 20 16 .36 w151 2 36.63 6400.00 23.31 243.93 6312.06 34~j.41S 334. 47w 371363.46 59742:12.5,: n70 20 16.15 wI51 .:,'. :37.60 6500.00 24.10 2~)B. 76 6403.71 358.098 3 n . 3 OW 37.132.:\.4.3 !W74220.48 n70 20 16.02 \~1~)1 2 38.70 6600.00 26.19 272.03 6494.:iO 361.2905 414./J2W 371283.27 597421").99 n70 20 1!5. 99 ,~H)1 2 39.93 6700.00 29.32 283.06 6582.84 3~)4.98S 460.~)6W 3712:n. 44 5974225.08 n70 20 16.05 w1~H 2 41.27 6800.00 33.17 291.94 6668.:37 3:i9.218 509. 63W 371.188.45 5974241. 68 n70 20 16.21 w151 2 112.71 6900.00 37.54 299.06 6749.94 314.168 ~)61.69W 371136.8:3 5974267.60 n70 20 16. 4~; w1~) 1 2 44.23 6972.37 40.93 303.3-' 6806.00 290.408 600. 78W 371098.15 5974292.02 n70 20 16.69 w1lH 2 45.38 7000.00 42.26 304.86 6826.66 280.128 615.96W 371083.J.4 5974302.56 n70 20 16.79 w151 2 4~,.82 7100.00 47.22 .3 09.66 689"/.70 2-37.4410 671. 85W 371027.99 !S974346.17 n70 20 17.21 w151 2 47.45 noo.oo :,2.34 31~1. 74 6962 .í~6 186.6013 72 8 . 7 51'1 370971.96 597097.96 1170 20 1.7.71 w151 2 49..11 7253.67 55.15 315.70 6994.00 156.143 759.49W .370941.7,; 5974428.93 n70 20 18.01 w151 2 50.01 7300.00 57.60 317.29 7019.65 128.168 786.03W 37 0 9J.~,. 68 ~J9744 57.36 n70 20 18.20 w151 2 50.79 7400.00 62.94 320.44 7069.24 62. 7~JS 8 ']3 . 0 7W 3708~)9. 76 5974523.72 n"/O 20 18.92 w1~11 2 52.45 7438.18 64.99 321. 57 7086.00 %.083 864. 6~iW 370838.63 59745f)0. 7 4 n70 20 19.19 ,~151 2 53.08 7480.19 67.27 322.76 7103.00 5.748 888.21W 3'70815.59 59745131. 47 n70 20 19.48 ,~151 2 53.77 7500.00 68.84 32,3.31 7110.48 a.9.1N 899.24W 370804.81 59745%.31 n70 20 19.63 w151 2 54.10 7526.6:3 69.79 324.0:3 7J.20.00 28.95N 913.981'1 370790. 'J2 5974616.59 n70 20 19.83 ,~151 2 54.53 7582.84 72.85 325.52 7138.00 72 . 44N lH4. 671'1 .370760.46 5974660.59 n70 20 20.25 w151 '2 55.42 7600.00 73.79 .325..96 7142.93 86.0 3N 953. 93W 370751. 114 5974674.34 n70 20 20.39 w1n 2 55.69 7700.00 79.27 .328.48 7166.22 167.77N 1006.54W 370700.23 5974756.95 n.70 20 21.19 w151 2 57.23 7800.00 84.77 330.90 7180.09 253.23N 1056.(P3W 370651.74 5974843.23 1170 20 22.03 w1f) 1 2 58.69 7840.47 87.00 331.87 7183.00 288.66N l075.81W 370633.0J. 5974878.98 n70 20 22.38 w151 2 59.26 7840.49 87.00 331.87 7183.00 288.68M 1075. 8;~W 370633.00 5974879.00 n70 20 2í~..30 w151 2 ~)9.26 7940.49 88.00 331.87 7187. % 376.7SN 1122.93W 370587. :39 5974967.88 n70 20 23.25 w151 :3 00.63 13040.49 \39.00 331.87 7189.98 464. 93N 1170. 07W 370541. 76 59750~)6. 81 n70 20 24.11 wJ.51 ~ 02.01 8140.49 90.00 331.87 7190.85 ~,53 .11N 12 17 . 2 2W 370496.1.1 ~97~J14!;,.76 n70 20 24.98 wlfj1 :\ 03.39 8205.33 90.65 :3:31.87 7190.49 610.29N 1247.791'1 370466.51 597520:L 44 n70 20 25.54 w1.51 :3 0<L28 All data in feet Imless otherwise stated. Calculation uses minimUl1l curvature method. Coordinates from slot. #'22 and TVD from Estimated RKB (52.00 Ft above meal1 sea level) . B,)tt,om h,)l0 distance is 4339.00 Qn azimuth 321. 07 deqrees from wellhead. Total Dogleg for wellpath is 132.47 degrees. Vertical section is from wellhead on azimuth 285.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Bak<:>r Hughes INTEQ ) ) Phillips Ala~lk,a. Inc.. CD#2,22 ,1\lpine E'ield,North Slope, Al;~3k.a PROPOSAl.. I,ISTT.NG page:3 Your ref: CD2-22 Vl'Jrsion#5 ¡,a,st revi.sed: 8-Apr--2002 M',¡asured Incli.n AÚmuth Tx:ue Vert Depth Deg.t'eas Dog.rea:;; Depth HF.:CTANGUJJAR COORDINATES GRID COORDS F~as t.ing Northing GEOGRhPHIC COORDIN,A"F.;S 8500.00 90.65 331.87 71.87.1~ 870.J.3N 1386.731'1 370331.99 597546:,.57 n70 20 28.10 wI51 3 08.34 9000.00 90.65 331.87 7181.49 1311.02N 1622.481'1 :3701.03.74 f;975910 .:,6 n70 20 32.43 wl~il " 15.24 9500.00 90.65 331. 87 717~. 8:1 17~\1. 92N 1858.24W 369875.50 !\976355. 14 n70 20 36.77 w151 3 22.13 10000.00 90.65 331.87 7170.18 2192.8lN ,~O 93. 99W 369647.2.71 5976799.92 1170 20 41.10 w151 oj 29.. 02 10500.00 90.65 :,31.87 7164.52 2633. 71N 2329.74W 369419.00 ~)977244. 70 n70 20 45.44 \~151 :3 35.92 nooo.oo 90.65 331.87 7158.86 3074.61N 2565.tiOW 369190.76 5977689.48 n70 20 49.77 wl~\l 3 42.81 11341.18 90.65 ,331.87 nti5.00 3375.4 5N 2726.361'1 369035.01 5977992.98 n70 20 52.73 w1.51 3 47.52 11341..20 90.65 331.87 7155.00 3375.47N 2726.37W 369035.00 597799:1.00 n70 20 52.73 '.,151 3 47.52 All data in feet unless otherwise stated. Calculation tlses minimW11 curvat,ure method. coordinates frc>m slot #'22 and TVD from Estimated RKB (52.00 Ft above mean sea level) . Bottom hole distance is 4339.00 on azimuth 321.07 deqrees from wellhead. Total Dogleg for wellpath is 132.47 degrees. Vertical section is from wellhead on azimuth 285.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) Phillips Al<ISk.." Inc.. CD#2 , 22 Alpine E'i,Üd, North Slope, Alas ka PROPOSAl.. IJISTING Page 4 Your x:ef : CD2~22 v"rsi()n#c' ¡,ast revi.sed: 8-ApJ=..2002 Comments in 1i/ellpat.h r.'::::'~ =:::::::=::::: o::.:::::cr.,::~..::=t::::~-:':':::I=C:=~.':::'::'¡:: MD T'VD Rectangular Coords. Comment -,...-. ~.-. - ~..~.- -.-,-.... ...- -"... -,-'..._. ,,"... _.... n_._'..' ...... ...- ,,,........,- ....., ",... - "'....-,- ......-.... -..,.....-. - ......-. ...-."'....... - ...... .""._'." .-.... - .., ,., -.........,. "..-. - -, ...-..--. ,..h ..,- ...-...... ...,",....- -.......- ...... ".." 1069.00 1069.00 (J.OON (J. OOF; West Sak 16.52. (JO 16.52.00 O. DON O.OOE; Base ]?(:).rmafrost 1750.00 1750.00 (J. OON O.OOF; B.39:Ln Nudge 1950.00 1949.134 2 M39S 6.56W EOC 2150.00 2149.35 "I. J.65 19.67W Begin Dr.'(,p 22:2'2 . 77 2222.00 8.58S 2:3.5iW" C...'IO 2:350.00 2:349.19 9.558 26. 23W EOC 2:J89.81 2,389.00 9.:>58 26.2.3W 9 5/8" Casing pt 2399.81 2399.00 9.55S 26.23\\" C'-:¡O 2540.81 2540.00 9.555 26.2311" C;-20 3848.81 3848.00 9.5~>S ,~6. 23W K",,3 ,~068 .81 4068.00 9. ~i5S 26.23W K...2 490° .00 41399.19 9.55S 26.2 3W Begin Build ~)l89.92 Sl88.00 26.12 S 40. 64W Albian'" 97 :,731.'12 :,704.~'9 143.958 143.13\\" EOC ;)9'".17 . 81 5928.00 222.3QS 211.321'1 Albiau--96 6242.51 6168.01 306.:i78 284.S8W Begin ~"inal fJld/Trn 6972.37 6130(i.OO 290.405 600.78W HHZ 7253.67 6994.00 1!'J6.14~1 759.4911' K".1 74:18.18 7086.00 36.088 864.65W LCU 7480.19 7103.00 !S. 74 S 888.21\>1 Miluvead". A 7526.63 7120.00 2 8 . 95N 913.9811' Alpin~, D 7582" 84 7138.00 72.,HN 94'1.6711' Alpine 7840.47 7183.00 :~08.66N 1075.81W 'rarget .' Casin9 pt 7840.49 7183.00 288. G8N 107:,.8211' CD2..22 Heel Rv,!¡d 11~M.ar-02 8205.33 7190.49 610.;:9N 1;:47.79\\" EOC 11341.1.8 '7l:,fJ.OO 3375.45N 2726. 36W TD .. Casing pt; 11341.20 7155.00 3375.47M 2726.:nW CD2".22 Toe Rvsd ll-M<lr...02 Casing pos:iti<::>ns in .~t:r.ing 'A' ~':'".:'::;= :===:==..::.~=::.:: :.:::n::::=.I =' =;::':':~.::I. :=.u::~:::::::.: :~..====¡:-~~=t::.t:::::I '1'0];' MD Top 'rVD Rectan';rular Coor.'ds. Bot MD B(Jt. TVD Rect.angulal" Coor:ds. casil19 -'''~ ""_M~ -~.~. - .~- ,.,... "~--~. - -..-..,.- .--.. ....- .~- .." ,_.. - --.,-... - ,.".--...., -.."-""'" ,." ,_....oO _....- .~- ....,- .--. --., -,.~ - ,." _.~- - ....-, ...- .... -.-- - ."..,-- ,.,.-...- -.oO-.... -"" -.- -, ......... .--.." - ...-, -... 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE í~389.81 2389.00 O.OOE 7840.49 7l83.00 9 .5~\S 288.68N 26.23W 9 E,/8" Casing 107~,. 82W 7" Casing Targ(-)t¡; associated with thÜ wellpath 1:::C:::: r...::::.:;::r:c~:::r.:~ ==== ~.:::==::.::.:-.-a::I=\:'JI ::.'t~'.I::'-:::':I:::::~t'.r'::::I::.I:: .c:::~t.~:=:n=::::II:m:::: c..::: Target name Geog.raphic J.ocatil'n T.V.D. Rectangular Coordinat.es RE,vised ....--...- -.'" -... ""_"M'"' - -." - .-...-... "M'" -... -........-... ".-- ..,-...-. -.....".-- .".-.-..- -.oO". - -''''-''- .--...". --....- .-...-."' ""__'M' -.-... -... ""__'M' -... ...- ".."..-- ",,- .-- -..."..- - '''.-.- ,.._._n -- ,..- CD2'-22 H0el Rvsd 11... 370633.000,ti9748"19.000,O.0000 7183.00 CD2.-22 'roe Rvsd l1..M 36903~j. 000, :1977993.000, 0 .0000 7155.00 288.68N :J37:J.47N 1075.821v 19-',Jun-1998 27:!6.:J7W 19..,Jun-1998 ) ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 11 , 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-22 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore WAG (water alternating gas) injection we~,from the Alpine CD2 drilling pad. The intended spud date for this well is May 10, 2002. It is intended that Doyon Rig 19 be used to drill the well. CD2-22 will be drilled to penetrate the Alpine reservoir at horizontal. ;;"fter setting 7" intermediate casin~, the horizontal section will be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting completion of well work and facilities work that will allow the well 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: . Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). . Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). . A proposed drilling program, including a request for approval of annular pumping operations. . A drilling fluids program summary. . Proposed pilot hole schematic. . Proposed completion diagram. . Proposed completion diagram with open hole isolation options. . Pressure information as required by 20 ACC 25.035 (d)(2). . CD2-22 Cementing Requirements. 1. 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 layout as required by 20 ACe 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~rel~ Vern Johnson Drilling Engineer RECE'VED APR 1 6 ZOOZ AlaskaOil&GasConl. Commission AncbOrage ORIGINAL .) Attachments cc: CD2-22 Well File I Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATO 1530 A TO 868 A TO 848 ATO 844 Anadarko - Houston Kuukpik Corporation a-mail : Tommy- Thompson@anadarko.com RECEIVED APR 1 6 2002 AlllkaOiI I GIs COOl. Commission AßdIaagt r I" I 1 i, .. II :1 f ~ L.- PHilliPS ALASKA, INC. PAl PA YABLES P.O. Box 102776 Anchorage, AK 99510-2776 73-426/839 CHECK NUMBER 205113534 0997579 PAY TO THE ORDER OF: STATE OF ALASKA AOGCC 333 W. 7TH AVENUE, SUITE 100 APRIL 05, 2002 *H VO 10 AFTER 90 DAYS *H ~ .... BANK = ONE. -- BANK ONE, NA - 0710 Chicago, IL Payable through Republ ic Bank & Trust Company EXACTLY ********** 100 DOLLARS AND 00 CENTS $******** 100.00 c frd~ ,-,' TRACE NUMBER: 205113534 (! D;2-d-d- II' 2 0 5 . . j 5 j 1.. II' I: 0 a j go 1.. 2 b 2 I : 0 g g 7 5 7 g /I' RECEIVED ~. APR 1 6 2002 AlaskaOil&GasConl. ~~- tjJjœ AnfJr~ ) "l TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LEITER CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL v INJECTION WELL RED RILL WELL NAME CI'! ú CO Z - 22- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) , ANNULAR DISPOSAL L-J NO ANNUL~ ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a new wellbore segment of existing well -'---' Permit No, ,API No. . " Production should continue to be reported as a function of the original API number stated above. ' In accordance with 2,0 AAC 25.005(1), all ~ords, data and logs acquired for the pilot bole, must be clearly differentiated in both name (name OD permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (n~me on permit). , Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved... DISPOSA'i2:INT OTHER Please note that an disposal of fluids generated... . ANNULUS YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed Is the approved application for permit to drill the above referenced well. The permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY 41/)s WELLNAME~¿¡ C/)2-¿2 FIELD & POOL / 2ð/ð~ INIT CLASS /-~_J¡J'1v¡( (" ~e:1). ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . fV) N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N Aßg.J ,,' /9~~...- 12. Permit can be issued without administrative approval.. . . . . Y N ~ fP ~ /"}:.... 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGliiEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . q.} N ( Í:> r( P t It/; , . 15. Surface casing protects all known USDWs. . . . . . . . . . . éi2 N . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~) N Æd..e 1{'~ tA .p""-('p~ ç . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y gJ (} l -L:. 18. CMT will cover all known productive horizons. . . . . . . . . . .V--N- 0 ~"- ~vp RA--t w-. 19. Casing designs adequate for C, T, B & permafrost. . . . . . . fi2.. N 20. Adequate tankage or reserve pit.. . . , . , . . . , , . . . . . (:j¿ N Dv~ t q . 21. If a re-drill, has a 10-403 for abandonment been approved. . . ' AI IA-O-- 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N t 26. BOPE press rating appropriate; testto 5000 psig. N M ~ e = 25 ~ 2. f <,I. M()...,i?~í :k<;' 3 ~oo f)( i 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . Ql N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y. N A~ 9m/: 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ffC ~¡::¡/ð2 34. Contact name/phone for weekly progress reports [exploratory on 1 Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . .. d N (B) will not contaminate freshwater; or cause drilling waste. .. Z3? N to surface; (C) will not impair mechanical integrity of the well used for disposal; rY2 N (D) will not damage producing formation or impair recovery from aOJN pool; and /::\ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. LYjN GEOLOGY: ENGI~~~~ING: UIC/Annular: COMMISSION: RP~ TEMJdJ.-~( COT SFD- WGAi¡JC,k DTSCit-/<~/o è JMH --- APPR Df\T~ kJG'1\- ïf(tl/o (... 1~1JV'l ~/"#'-\~ GEOLOGY APPR ,~/E /P ~-¿ PROGRAM: Exp - Dev - Redrll - Serv 2( Wellbore seg - Ann. disposal para req X GEOLAREA $?91'? UNIT# -.ço.~CCJ ON/OFF SHORE nJ0 ( ( ~\) ~\~W~~\\ ~\Q~Nt~. ~~S ~ ~ C>.~~~ ~û.-~~~\\J~/ Comments/Instructions: G: \geology\templates \checklist. doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. , To improve the readability of the Well History file and to simplrty finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically , . organize this category of infonnation. ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 09 15:57:57 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN C omme n t s . . . . . . . . . . . . . . . . . S T S LIS Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name..... .......... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22077 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD ) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CD2-22 501032042100 PHILLIPS Alaska, Inc. Sperry Sun 09-0CT-02 MWD RUN 3 AK-MW-22077 R. KRELL D. MICKEY MWD RUN 4 AK-MW-22077 R. KRELL D. MICKEY 2 llN 4E 1785 1537 .00 52.40 15.90 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2381.0 8.500 7.000 7845.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY G<Dd-09d 1//<61 ,) ) (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY LOGGED BEHIND CASING FROM 2360' MD, 2359' TVD, TO 2381' MD, 2380' TVD. 5. GAMMA RAY LOGGED BEHIND CASING FROM 7829' MD, 7182' TVD, TO 7845' MD, 7182' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 7821' MD, 7182' TVD TO 7845' MD, 7182' TVD. 6. GAMMA RAY DATA HAS BEEN CORRECTED FOR 6% KCL MUD AND BOREHOLE SIZE ON MWD RUN 4. 7. MWD CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 4 REPRESENT WELL CD2-22 WITH API # 50-103-20421-00. THIS WELL REACHED A TOTAL DEPTH OF 11134' MD, 7135' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2359.5 2371.0 2371.0 2371.0 2371.0 2371. 0 2390.5 STOP DEPTH 11089.0 11096.5 11096.5 11096.5 11096.5 11096.5 11134.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ) ) # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 2359.5 3 7075.5 4 7856.5 MERGE BASE 7075.0 7856.0 11134.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.......... .......... ..-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 2359.5 11134 6746.75 17550 2359.5 11134 ROP MWD FT/H 0.16 254.85 135.822 17488 2390.5 11134 GR MWD API 29.23 367.73 90.7759 17460 2359.5 11089 RPX MWD OHMM 0.2 1663.6 10.8445 17452 2371 11096.5 RPS MWD OHMM 0.09 1834.53 12.0604 17452 2371 11096.5 RPM MWD OHMM 0.33 2000 13.9077 17452 2371 11096.5 RPD MWD OHMM 0.16 2000 17.2859 17452 2371 11096.5 FET MWD HR 0.18 54.91 0.994712 17452 2371 11096.5 First Reading For Entire File......... .2359.5 Last Reading For Entire File.......... .11134 File Trailer Service name............ .STSLIB.001 Service Sub Level Name.. ~ Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name.......... ...STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: 2 ) RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ ') header data for each bit run in separate files. 2 .5000 START DEPTH 2359.5 2371.0 2371.0 2371.0 2371.0 2371.0 2390.5 STOP DEPTH 7043.5 7036.0 7036.0 7036.0 7036.0 7036.0 7075.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.......... ......... ...-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 21-MAY-02 Insite 4.05.5 66.37 Memory 7075.0 .2 38.2 TOOL NUMBER PBOO173HWRGV6 PBOO173HWRGV6 8.500 LSND 9.60 42.0 9.1 450 5.1 1. 200 .652 1. 350 1. 600 70.0 134.6 70.0 70.0 " , Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2359.5 7075 4717.25 9432 2359.5 7075 ROP MWD020 FT/H 0.16 254.85 159.302 9370 2390.5 7075 GR MWD020 API 48.12 367.73 111.674 9369 2359.5 7043.5 RPX MWD020 OHMM 0.32 66.66 4.6341 9331 2371 7036 RPS MWD020 OHMM 0.09 1503.98 4.91198 9331 2371 7036 RPM MWD020 OHMM 0.33 1504.03 4.93929 9331 2371 7036 RPD MWD020 OHMM 0.16 2000 8.73907 9331 2371 7036 FET MWD020 HR 0.18 39.7 0.851362 9331 2371 7036 First Reading For Entire File....... ...2359.5 Last Reading For Entire File.......... .7075 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. .... ..02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name..... .... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 7036.5 7036.5 7036.5 7036.5 7036.5 7044.0 7075.5 STOP DEPTH 7821.0 7821.0 7821.0 7821.0 7821.0 7828.5 7856.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 22-MAY-02 Insite 4.05.5 66.37 Memory 7856.0 ) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................ .... .60 .1IN Max frames per record.......... ...Undefined Absent value................... ...-999 Depth units....................... Datum Specification Block sub-type. ..0 ) 41.0 87.3 TOOL NUMBER PBOO173HWRGV6 PBOO173HWRGV6 8.500 7845.0 LSND 9.65 40.0 9.6 400 4.4 1. 300 .671 1.200 1.400 70.0 142.0 69.0 70.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7036.5 7856 7446.25 1640 7036.5 7856 ROP MWD030 FT/H 2.18 175.34 64.6076 1562 7075.5 7856 GR MWD030 API 43.16 303.52 115.351 1570 7044 7828.5 RPX MWD030 OHMM 1.9 24.12 8.7747 1570 7036.5 7821 RPS MWD030 OHMM 1. 92 24.89 9.05876 1570 7036.5 7821 RPM MWD030 OHMM 1. 88 25.42 9.48098 1570 7036.5 7821 RPD MWD030 OHMM 1. 97 25.45 9.66188 1570 7036.5 7821 FET MWD030 HR 0.37 12.8 1. 45214 1570 7036.5 7821 ) First Reading For Entire File. ........ .7036.5 Last Reading For Entire File.......... .7856 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 ') header data for each bit run in separate files. 4 .5000 START DEPTH 7821.5 7821. 5 7821.5 7821.5 7821. 5 7829.0 7856.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11096.5 11096.5 11096.5 11096.5 11096.5 11089.0 11134.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): 27-MAY-02 Insite 4.05.5 66.37 Memory 11134.0 89.1 93.0 TOOL NUMBER PBOO174HAGR4 PBOO174HAGR4 6.125 FLO PRO 9.10 49.0 9.0 29000 ) ) FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 3.5 .090 .036 .130 .100 60.0 159.8 60.0 60.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point.......... ... .Undefined Frame Spacing............. ....... .60 .1IN Max frames per record............ .Undefined Absent value...................... -999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7821.5 11134 9477.75 6626 7821.5 11134 ROP MWD040 FT/H 0.89 200.21 119.231 6556 7856.5 11134 GR MWD040 API 29.23 101.11 54.8335 6521 7829 11089 RPX MWD040 OHMM 0.2 1663.6 20.1864 6551 7821.5 11096.5 RPS MWD040 OHMM 0.23 1834.53 22.9618 6551 7821. 5 11096.5 RPM MWD040 OHMM 4.4 2000 27.7428 6551 7821.5 11096.5 RPD MWD040 OHMM 1.6 2000 31. 287 6551 7821. 5 11096.5 FET MWD040 HR 0.24 54.91 1.08927 6551 7821.5 11096.5 First Reading For Entire File... ..... ..7821.5 Last Reading For Entire File.......... .11134 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... ....... ...UNKNOWN ) ') Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File