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Home My WebLink About204-0322025-0715_Location_Clear_KRU_2P-443_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 07/18/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Site Clearance Petroleum Inspector KRU 2P-443 ConocoPhillips Alaska LLC. PTD 2040320; Sundry 324-582 07/15/2025: Went out to KRU 2P Pad for site clearance inspections and met with Roger Mouser (CPAI). We went over the surface area of KRU 2P-443 which has been P&A and buried. The area was clean of debris and had a settling mound for soil over the well location. We verified the well-site with the pad location map and well conductor “as built”. Marker plate and top of well are at 7 feet below original tundra. Overall, the site clearance was in good condition. The well site still had barriers around due to other work going on in the area. Only follow up would be a full pad site clearance once CPAI has completed all pad P&A work. Attachments: Photo 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.16 14:12:48 -08'00' 2025-0715_Location_Clear_KRU_2P-443_ksj Page 2 of 2 Surface Abandonment Inspection – KRU 2P-443 (PTD 2040320) Photo by AOGCC Inspector K. StJohn 7/15/2025 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 108' 9.625" L-80 2362' 5.5" L-80 5048' 3.5" L-80 5703' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 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, included above8.5" TUBING RECORD 650 sx GasBlok8.5" 5585' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 1/13/2025 204-032/324-582 50-103-20487-00-00 KRU 2P-443 ADL0373112 998' FNL, 1680' FWL, Sec. 17, T18N, R7E, UM 436' FSL, 1505' FEL, Sec. 8, T8N, R7E, UM ALK 32092 2/23/2004 6334' MD/ 5709' TVD Surface/Surface P.O. Box 100360, Anchorage, AK 99510-0360 443640 5868881 354' FSL, 1629' FEL, Sec. 8, T8N, R7E, UM WT. PER FT.GRADE 4/14/2004 CEMENTING RECORD 5870218 1368' MD / 1348' TVD SETTING DEPTH TVD 5870300 TOP HOLE SIZE AMOUNT PULLED 445616 445741 TOP 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 9. Ref Elevations: KB: 28' BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Abandoned N/A N/A PACKER SET (MD/TVD) 42" 12.25" 410 sx AS I 28"320 sx ArcticSet Lite, 225 sx LiteCrete 9.3# 28' 5584' 2488'28" 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 42'-2337' 198 bbls 15.8 ppg Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 3789' (SW TOC) - 5478' ABANDONED 6045-6065' MD and 5450-5468' TVD (below cement plug) 6065-6080' MD and 5468-5481' TVD (below cement plug) 6070-6080' MD and 5472-5481' TVD (below cement plug) Gas-Oil Ratio:Choke Size: 31 bbls 15.8 ppg Cement (T and IA) Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 20.7 bbl 15.8 ppg Cement 2337'-2560' 5584' SIZE DEPTH SET (MD) 6328' 28" 5048' 62.5# 40# 108' 28" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 10:52 am, Feb 12, 2025 Abandoned 1/13/2025 JSB RBDMS JSB 022725 xGDSR-4/7/25VTL 7/30/2025 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1368' 1348' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations, Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Digital Signature with Date:Contact Email: shane.germann@conocophillips.com Contact Phone:(907) 263-4597 Senior CTD/RWO 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: Formation Name at TD: 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- Abandoned Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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). Authorized Name and Authorized Title: N/A - Abandoned 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. 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. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2025.02.12 10:29:43-09'00' Foxit PDF Editor Version: 13.0.0 gggg Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 6,136.02P-4433/21/2024rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&A Well - AOGCC REP, Bob Noble, APPROVED THE TOC, MAKER PLATE AND CUT DEPTH 2P-4431/12/2025pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: Remove "Shoring Can" Backfill excavation till level with the Pad 1/13/2025pproven NOTE: Marker Plate & Cut Depth (7' Below Tundra) Welded the Marker Plate 1/12/2025pproven NOTE: SSV PANEL NOT HOLDING PRESSURE. HAVE TO HOOK UP DIRECTLY TO SSV BARREL TO OPEN SSV. 7/5/2024pproven Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 42.2 110.0 110.062.50 H-40 WELDED SURFACE 9 5/8 8.83 42.2 2,487.6 2,362.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @5584' 5 1/2 4.95 42.2 6,328.3 5,703.7 15.50 L-80 BTCMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 42.2 Set Depth … 2,327.0 Set Depth … 2,221.9 String Max No… 3 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Top (ftKB) 2,780.0 Set Depth … 5,584.8 Set Depth … 5,048.2 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 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) 3,581.63,319.7 31.47 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 4,415.6 4,032.930.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,030.9 4,568.929.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,456.6 4,937.5 30.91 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,506.3 4,980.230.63 SLEEVE-C 4.510 SLIDING SLEEVE - CLOSED 06/18/2024 BAKER CMU 2.810 5,522.4 4,994.130.37NIPPLE 4.550CAMCO D NIPPLE CAMCO D 2.750 5,567.0 5,032.7 29.65 LOCATOR 4.500 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 5,568.2 5,033.8 29.63 SEAL 4.000 BAKER SEAL ASSY BAKER 3.000 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) 42.1 42.10.00 MARKER PLATE NES Welder welded the marker plate to the well stub, 7' below tundra. 1/12/2025 0.000 2,560.02,425.7 29.17 CIBP CIBP set for cement 11/28/2024 0.000 2,780.02,618.228.81 CUT TUBING CUT (3.5" JET CUTTER) 9/4/2024 2.992 5,441.0 4,924.130.98 LEAK - TUBING Leak diagnostics done with Slickline holefinder. Appears leak is around GLM #5. Valve swapped out to Ext. Pkg DMY with no success. Holefinder suggests leak is between 5441' - 5470' RKB. 6/21/2024 0.000 5,475.0 4,953.3 30.84 TUBING PUNCH 2" x 3 FT Tubing Punch. 6 SPF. 8/5/2024 2.990 6,019.3 5,426.927.45 CIBP 2.63" CIBP (MID-ELEMENT AT 6020' RKB) OAL=1.39' TTSCIBP N/A 3/30/2024 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,045.06,065.0 5,449.7 5,467.5 T-3, 2P-443 5/13/2004 6.0 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,065.06,080.0 5,467.5 5,480.9 T-3, 2P-443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,070.06,080.0 5,472.0 5,480.9 T-3, 2P-443 4/30/2004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,045.06,080.0 1 FRAC 5/22/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 42.2 2,487.0 42.2 2,361.9 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 105000Drag up (lbs): 115000Time started reciprocating: 03:00Time stopped reciprocating: 07:00Annular flow after cement job (Y/N): NCirculating BHT (F): 74Static BHT (F): 57Pressure before cementing (psi): 425Hours circulated between stages: 1.75Bbls cmt to surf: 111.7Method used to measure density: DensometerMethod used for mixing cement in this stage: TubReturns (pct): FullTime cementing mixing started: 05:52 2/25/2004 2P-443, 2/10/2025 9:31:10 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 2,545.0-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB TUBING PUNCH; 5,475.0 GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 Cement Plug; 3,789.0 ftKB GAS LIFT; 3,581.6 CUT; 2,780.0 CIBP; 2,560.0 SURFACE; 42.2-2,487.6 Cement Plug; 2,337.0 ftKB Cement Casing; 42.2 ftKB CONDUCTOR; 42.2-110.0 Cement Cap; 42.2 ftKB MARKER PLATE; 42.1 KUP PROD KB-Grd (ft) 35.11 RR Date 4/19/2004 Other Elev… 2P-443 ... TD Act Btm (ftKB) 6,334.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048700 Wellbore Status PROD Max Angle & MD Incl (°) 31.58 MD (ftKB) 3,606.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 73 Date 12/11/2012 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,940.0 6,019.3 5,356.8 5,426.9 Cement Plug Slickline dump bailed cement on top of CIBP. Estimated TOC @ 5988' 6/22/2024 3,789.0 5,478.0 3,496.6 4,955.9 Cement Plug PUMPED INTERMEDIATE CEMENT BALANCE PLUG. PLACED 31 BBLS OF 15.8 PPG CEMENT IN TUBING & IA 8/26/2024 2,337.02,560.02,230.62,425.7 Cement Plug Pump 26.5 BBL of 10 PPG 1.5 FT3/SK 10.26 Gal/SK Spacer with .5 GAL/BBL Surf B and .5 Gal/BBL Musol A @ 2.5 BPM 135 PSI Load 4" Wiper Ball Pump 20.7 BBL of 15.8 PPH 1.195 FT3/SK 5.03 Gal/SK @ 2.8 BPM 260 PSI Pump 3.5 BBL of 10 PPG 1.5 FT3/SK 10.26 Gal/SK Spacer with .5 GAL/BBL Surf B and .5 Gal/BBL Musol A @ 2 BPM 140 PSI Pump 14.5 BBL of 9.8 PPG Brine @ 2.3 BPM 110 PSI Pump off line Well is Static pump Truck reading 0 PSI well is Balanced 11/29/2024 42.22,337.0 42.22,230.6Cement Cap Pump 198 bbls 15.8# cement, cement observed at surface 42.21' was 26.4' 11/30/2024 2P-443, 2/10/2025 9:31:17 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 2,545.0-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB TUBING PUNCH; 5,475.0 GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 Cement Plug; 3,789.0 ftKB GAS LIFT; 3,581.6 CUT; 2,780.0 CIBP; 2,560.0 SURFACE; 42.2-2,487.6 Cement Plug; 2,337.0 ftKB Cement Casing; 42.2 ftKB CONDUCTOR; 42.2-110.0 Cement Cap; 42.2 ftKB MARKER PLATE; 42.1 KUP PROD 2P-443 ... WELLNAME WELLBORE Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 2P-443 Well Final P&A Schematic Conductor: 16" Conductor 110' KB 1 2 5 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB (2362' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϲ͘ϰΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϱϲϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞ ;KƉĞŶĞĚϴͬϮϮͬϮϬϮϬͿ ϱ͕ϱϬϲ͘ϯΖ ϰ ĂŵĐŽEŝƉƉůĞ ϱ͕ϱϮϮ͘ϰΖ ϱ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϱ͕ϱϲϳΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůǇ ϱ͕ϱϲϴ͘ϮΖ C80 @ 2630' KB C80 @ 2630' KB Plug #1 – Reservoir TOC ±5940' RKB Plug #2 – Intermediate TOC ±3789' RKB BOC @ ±5478' RKB Plug #3 – Surface Shoe TOC 2337' RKB (2230' TVD) BOC @ ±2560' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2337' RKB DTTMSTART JOBTYP SUMMARYOPS 11/26/2024 RECOMPLETION Complete rig down from 406, MIRU on 2P-443. Accept rig @ 20:00. Circulate 35 BBl 9.8 PPG deep clean pill followed with 120 BBls 9.8. Good 9.8 sample in returns. Perform 30 min no flow test. ND tree 11/27/2024 RECOMPLETION Set BPV, ND tree. NU BOPE. Perform initial BOPE test. Pull BPV. Pull 3 1/2" tubing from cut @ 2350'. M/U BHA #1 CIBP. trip in and set @ 2560 top of plug. TOOH. Unable to get PT on plug. Make clean out run to top of plug. Pump hi vis sweep 11/28/2024 RECOMPLETION Trip out F /2559 with clean out BHA. M/U test packer. Trip in for 5 1/2" casing leak detect. CIBP test good. Suspect 5 1/2" casing. Cut 5 1/2" casing @ 2450. Pull casing from well. Run 3 1/2" casing to 2545 with light tag. PUH 4 feet. Space out 3 1/2". Install head pin. Circ S X S 11/29/2024 RECOMPLETION Wait for cement crew, Rig up cementers, pump cement per plan, TOOH 2090', circulate SxS see spacer in returns, shut down wait on cement 11/30/2024 RECOMPLETION Tag cement, perform final cement job, RDMO 12/10/2024 CHANGE WELL TYPE (P&A) IA DDT (COMPLETE), OA DDT (COMPLETE) READY FOR TREE AND VALVE REMOVAL TO VERIFY TOC (TOP OF CEMENT). ***NEXT STEP: REMOVE AND VERIFY TOC.*** 12/11/2024 CHANGE WELL TYPE (P&A) PREP IN PROGRESS- TREE , IA, OA VALVES REMOVED. TOC TREE @SF(GOOD CEMENT), IA @SF (BAD CEMENT), OA @SF (GOOD CEMENT). INSTALLED TAPPED BLIND FLANGES. ***NEXT STEPS: ACWR, OG REFERENCE POINT, CUT WELL HEAD AND CELLAR.*** 12/18/2024 CHANGE WELL TYPE (P&A) PREP, CUT WINDOWS IN CONDUCTOR, CLEAN OUT RG2401 BLUE GOO. (IN PROGRESS) ***NEXT STEP: CUT AND REMOVE WELLHEAD AND STEEL CELLAR.*** 12/19/2024 CHANGE WELL TYPE (P&A) PREP- CUT AND REMOVED 5' 11" OF WELL HEAD FROM 7' OG REFERENCE MARK. ADDITIONAL 5' 1" OF WELL STUB NEEDS TO BE REMOVED TO OBTAIN 4' BELOW OG (TUNDRA). ***NEXT STEP : OBTAIN ACWR , BEGIN EXCAVATION TO 14' TD FOR SHORE CAN INSTALLATION.*** 12/20/2024 CHANGE WELL TYPE (P&A) PREP CUT AND REMOVED CELLAR. POSTPONED FURTHER WORK FOR 3S-23 P&A. BARRICADED OPEN HOLE LEFT HEATER IN PLACE. NEX STEPS: RETURN AFTER 3S-23 P&A EXCAVATE TO 14'. 1/7/2025 CHANGE WELL TYPE (P&A) MOVE EQUIPMENT FROM 3S-23 TO 2P-443 (COMPLETE) 1/8/2025 CHANGE WELL TYPE (P&A) EXCAVATION TO 14' (IN PROGRESS ~5') 1/9/2025 CHANGE WELL TYPE (P&A) EXCAVATION TO 14' (IN PROGRESS ~12') 1/10/2025 CHANGE WELL TYPE (P&A) EXCAVATION TO 14' (COMPLETE) SET SHORING (COMPLETE) CUT AND REMOVE WELLHEAD (COMPLETE ~109" OF WELL STUB) 1/11/2025 CHANGE WELL TYPE (P&A) PREP THE WELL STUB FOR THE MARKER PLATE (COMPLETE) AOGCC INSPECTOR UNABLE TO MAKE IT TO LOCATION TO WITNESS TOC. RESCHEDULED WITNESS FOR 1-12-25 1/12/2025 CHANGE WELL TYPE (P&A) AOGCC REP, BOB NOBLE, APPROVED THE TOC, MAKER PLATE AND CUT DEPTH (COMPLETE 7' BELOW TUNDRA) WELDED THE MARKER PLAT (COMPLETE) REMOVE THE "SHORING CAN" (IN PROGRESS WAITING ON WIND) 1/13/2025 CHANGE WELL TYPE (P&A) REMOVE THE SHORING CAN (COMPLETE) BACKFILL EXCAVATION (IN PROGRESS WILL MOUND DIG SITE AFTER FINISHING 2P-441) 2P-443 Final Plug and Abandon Summary of Operations 2025-0112_Surface_Abandon_KRU_2P-443_bn Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/17/2025 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-443 ConocoPhillips Alaska Inc. PTD 2040320; Sundry 324-582 Date: 1/12/2025 I traveled to CPAI’s KRU 2P-443 to inspect the final cut off. When I arrived, I met with CPAI representative Brennen Green. I went over with him what the AOGCC expected be done with the well. I inspected the well and found it to be full of good hard cement. The well was cut off 7 feet below tundra grade. I then inspected the ¼-inch x 30 inch marker plate. It had all the proper markings as per Sundry 324-582. I instructed Brennen to weld the marker plate on and cover the well up. Attachments: Photos (3) 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.03 12:37:13 -09'00' 2025-0112_Surface_Abandon_KRU_2P-443_bn Page 2 of 3 Surface Abandonment – KRU 2P-443 (PTD 2040320) Photos by AOGCC Inspector B. Noble 1/12/2025 2025-0112_Surface_Abandon_KRU_2P-443_bn Page 3 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: Total Depth: 6334 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2488 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2" & 3 1/2" O.D. Shoe@ 6328 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 5585 Feet Tbg Cut@ 2780 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole Bridge plug 2560 ft 2337 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1700 1680 1680 IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Plug #3 shown in approved Sundry (surface casing shoe). 5K lbs down weight was put on the plug with 3 1/2-inch open ended pipe. November 30, 2024 Bob Noble Well Bore Plug & Abandonment KRU 2P-443 ConocoPhillips Alaska Inc. PTD 2040320; Sundry 324-582 none Test Data: P Casing Removal: Ronnie Dolton Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-1130_Plug_Verification_KRU_2P-443_bn 9 9 9 99 999 9 9 9 9 9 9 99999 999 9 9Plug #3 shown in approved Sundry (surface casing shoe). James B. Regg Digitally signed by James B. Regg Date: 2024.12.04 13:56:52 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6334'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/5/2024 3-1/2" Packer: Baker Seal Assy SSSV: None Perforation Depth MD (ft): L-80 2459' 6045-6080' (below cement plug) 6300' 5450-5481' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2488' 5704'6328' 16" 9-5/8" 81' 5585' MD 110' 2362' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20487-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5568' MD and 5034' TVD N/A Shane Germann Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: shane.germann@conocophillips.com (907) 263-4597 CTD/RWO Engineer KRU 2P-443 5709' 3789' 3497' 2278 3789', 5940', 6019' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:57 am, Oct 08, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.07 13:34:10-08'00' Foxit PDF Editor Version: 13.0.0 324-582 BOP Test to 2500 psig Annular preventer test to 2500 psig SFD 10/26/2024 See attached "Conditions of Approval" VTL 11/26/2024 DSR-10/10/24 SFD X XX X Abandon June 30, 2025 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.26 08:14:48 -09'00'11/26/24 RBDMS JSB 112624 KRU 2P-4ϰϯ Abandonment Conditions of Approval: 1. A variance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata. 2.A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. The plug must pass a State Witnessed pressure test and tag according to 20 AAC 25.112(g). 3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. 4. A failed pressure test of the surface casing shoe plug requires the submission of a new sundry (10-403) to cover the rigless abandonment scope if planned. Completion of workover operations under the original sundry will be complete and a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days following the completion of workover operations. 5. If surface abandonment operations are not initiated within 30 days after the successful placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days after the completion of workover operations to date. 6. Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. 7. AOGCC witness is required after the wellhead cutoff and prior to a top job. Variances granted provide for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or freshwater. 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It has no known tubing or IA integrity issues. This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for the Willow development project in 2026. This well was suspended via reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately execute final abandonment. Well Data Meltwater Formation: x Reservoir pressure 4/19/2018 = 2818 psi @ 5400’ TVD x MASP = 2278 psi C-80 Formation: x OAP = 227 psi (11/5/22) (fluid packed with diesel) x MASP = 819 psi Intermediate plug TOC = 3789’ MD Tubing cut depth = 2780’ MD Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 2P-443 Well Suspension Schematic Conductor: 16" Conductor 110' KB 1 2 5 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB (2362' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &DdƵďŝŶŐ,ĂŶŐĞƌ Ϯϲ͘ϰΖ Ϯ ĂŵĐŽ^EŝƉƉůĞ ϱϮϭ͘ϯΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞ ;KƉĞŶĞĚϴͬϮϮͬϮϬϮϬͿ ϱ͕ϱϬϲ͘ϯΖ ϰ ĂŵĐŽEŝƉƉůĞ ϱ͕ϱϮϮ͘ϰΖ ϱ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϱ͕ϱϲϳΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůǇ ϱ͕ϱϲϴ͘ϮΖ C80 @ 2630' KB C80 @ 2630' KB Plug #1 – Reservoir TOC ±5940' RKB Plug #2 – Intermediate TOC ±3789' RKB BOC @ ±5478' RKB Surface Casing Plugs – Rig Date: 9-25-2024 Prepared by: Shane Germann Estimated Start Date: 11-5-2024 MIRU 1. MIRU on 2P-443. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead before proceeding. 3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI. a. Will not set BPV due to two tested cement plugs below providing two barriers to formation. b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams 4. Circulate tubing and IA to brine. Retrieve Tubing 5. MU landing joint and BOLDS. 6. Pull tubing from pre-rig cut to surface and LD. Execute First Surface Casing Abandonment Plug 1. Set bridge plug in production casing 100’ below surface casing shoe 2. Cut production casing 50’ below surface casing shoe 3. Circulate OA to brine and complete 30-minute NFT. a. Punch holes in production casing at the surface casing shoe if unable to achieve circulation from production casing cut. 4. MU landing joint for production casing hanger and conƱrm casing is free from cut. a. Contingency: If unable to pull production casing from original cut depth i. Perform second cut inside surface casing shoe ii. Pull casing down to upper cut and laydown iii. PU DP and Ʊshing assembly iv. TIH and engage cut stub of prod casing. Fish stub free. v. Retrieve to surface. LD DP 5. Pump cement plug through the production casing cut. Utilize 20 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 5-1/2” casing is between 150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư- rig remediation. Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 2P-443 Well Surface Shoe Cement Schematic Conductor: 16" Conductor 110' KB 1 2 5 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB (2362' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϲ͘ϰΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϱϵϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞ ;KƉĞŶĞĚϴͬϮϮͬϮϬϮϬͿ ϱ͕ϱϬϲ͘ϯΖ ϰ ĂŵĐŽEŝƉƉůĞ ϱ͕ϱϮϮ͘ϰΖ ϱ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϱ͕ϱϲϳΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůǇ ϱ͕ϱϲϴ͘ϮΖ C80 @ 2630' KB C80 @ 2630' KB Plug #1 – Reservoir TOC ±5940' RKB Plug #2 – Intermediate TOC ±3789' RKB BOC @ ±5478' RKB Plug #3 – Surface Shoe TOC 2315' RKB (2212' TVD) BOC @ ±2590' RKB Base of 5-½” Casing 200'-250' MD Inside Surface Shoe Execute Final Abandonment Plug 8. Land workstring in casing hanger proƱle. 9. Circulate cement surface to surface until full cement returns observed on surface. See table below for cement volumes. RDMO 10. ND BOPE. NU dry hole tree. a. Note: this step may be performed prior to pumping Ʊnal surface to surface abandonment plug. 11. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 2540 2590 Open Hole 8.5 0.06460 3.2 Displacement of Prod Casing Stub Included in BBL/FT calc 2488 2540 Open Hole 8.5 0.07018 3.6 2315 2488 Surface Casing 8.83 0.07574 13.1 19.9 Total Volume of Plug Surface Casing 23 2315 Surface Casing 8.83 0.07016 160.8 Displacement of Prod Casing Included in BBL/FT calculation Execute Final Abandonment Surface Excavation 12. DHD to perform drawdown test on tubing, IA, and OA 13. Remove well house. 14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system. 15. Remove tree in preparation for excavation and casing cut. 16. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level. 18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 19. Send the casing head with stub to materials shop. Photo document. 20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 2P-443 c. PTD #: 204-032 d. API #: 50-103-20487-00-00 21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground level. 22. Obtain site clearance approval from AOGCC. RDMO. 23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location condition after work is completed Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 2P-443 Well Final P&A Schematic Conductor: 16" Conductor 110' KB 1 2 5 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB (2362' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϲ͘ϰΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϱϵϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞ ;KƉĞŶĞĚϴͬϮϮͬϮϬϮϬͿ ϱ͕ϱϬϲ͘ϯΖ ϰ ĂŵĐŽEŝƉƉůĞ ϱ͕ϱϮϮ͘ϰΖ ϱ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϱ͕ϱϲϳΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůǇ ϱ͕ϱϲϴ͘ϮΖ C80 @ 2630' KB C80 @ 2630' KB Plug #1 – Reservoir TOC ±5940' RKB Plug #2 – Intermediate TOC ±3789' RKB BOC @ ±5478' RKB Plug #3 – Surface Shoe TOC 2315' RKB (2212' TVD) BOC @ ±2590' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2315' RKB Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 6,136.0 2P-443 3/21/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut 2P-4439/4/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: NOTE: SSV PANEL NOT HOLDING PRESSURE. HAVE TO HOOK UP DIRECTLY TO SSV BARREL TO OPEN SSV. 7/5/2024 fergusp Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 29.0 110.0 110.062.50 H-40 WELDED SURFACE 9 5/88.8328.42,487.6 2,362.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @5584' 5 1/2 4.95 28.6 6,328.3 5,703.7 15.50 L-80 BTCMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.4 Set Depth … 5,584.8 Set Depth … 5,048.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 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) 26.4 26.4 0.00 HANGER 8.000 FMC TUBING HANGER 2.992 521.3 520.9 5.67 NIPPLE 4.550CAMCO DS NIPPLE CAMCO DS2.875 2,312.12,208.929.08 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 3,581.63,319.7 31.47 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 4,415.6 4,032.930.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,030.9 4,568.929.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,456.6 4,937.5 30.91 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,506.3 4,980.230.63 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE - CLOSED 06/18/2024 BAKER CMU2.810 5,522.4 4,994.130.37NIPPLE 4.550CAMCO D NIPPLE CAMCO D 2.750 5,567.0 5,032.7 29.65LOCATOR4.500BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 5,568.2 5,033.829.63 SEAL 4.000 BAKER SEAL ASSY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,780.0 2,618.2 28.81 CUT TUBING CUT (3.5" JET CUTTER) 9/4/2024 2.992 5,441.0 4,924.1 30.98 LEAK - TUBING Leak diagnostics done with Slickline holefinder. Appears leak is around GLM #5. Valve swapped out to Ext. Pkg DMY with no success. Holefinder suggests leak is between 5441' - 5470' RKB. 6/21/2024 0.000 5,475.0 4,953.330.84TUBING PUNCH 2" x 3 FT Tubing Punch. 6 SPF. 8/5/2024 2.990 6,019.3 5,426.927.45 CIBP 2.63" CIBP (MID-ELEMENT AT 6020' RKB) OAL=1.39' TTSCIBP N/A 3/30/2024 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) 2,312.1 2,208.9 29.08 1 GAS LIFT SOVBTM 1 0.08/2/2024 2K CSG Shear 0.000 3,581.63,319.7 31.47 2 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 4,415.6 4,032.930.46 3 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,030.9 4,568.929.46 4 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,456.6 4,937.5 30.91 5 GAS LIFT DMY BTM 1 6/20/2024 Ext. Pkg Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,045.0 6,065.0 5,449.7 5,467.5 T-3, 2P-443 5/13/2004 6.0 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,065.0 6,080.0 5,467.5 5,480.9 T-3, 2P-443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,070.0 6,080.0 5,472.0 5,480.9 T-3, 2P-443 4/30/2004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,045.0 6,080.0 1 FRAC5/22/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,940.06,019.3 5,356.8 5,426.9Cement Plug Slickline dump bailed cement on top of CIBP. Estimated TOC @ 5988' 6/22/2024 2P-443, 9/18/2024 7:55:20 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 FLOAT SHOE; 6,326.3-6,328.3 FLOAT COLLAR; 6,229.1- 6,230.5 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB SEAL; 5,568.2 CSR; 5,564.1-5,584.2 LOCATOR; 5,567.0 LOCATOR; 5,563.0-5,564.1 NIPPLE; 5,522.4 SLEEVE-C; 5,506.3 TUBING PUNCH; 5,475.0 GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 Cement Plug; 3,789.0 ftKB GAS LIFT; 3,581.6 CUT; 2,780.0 SURFACE; 28.4-2,487.6 FLOAT SHOE; 2,485.9-2,487.6 FLOAT COLLAR; 2,406.1- 2,407.6 GAS LIFT; 2,312.1 NIPPLE; 521.3 CONDUCTOR; 29.0-110.0 HANGER; 28.6-31.7 HANGER; 28.4-29.6 HANGER; 26.4 KUP PROD KB-Grd (ft) 35.11 RR Date 4/19/2004 Other Elev… 2P-443 ... TD Act Btm (ftKB) 6,334.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048700 Wellbore Status PROD Max Angle & MD Incl (°) 31.58 MD (ftKB) 3,606.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 73 Date 12/11/2012 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 3,789.0 5,478.0 3,496.6 4,955.9 Cement Plug PUMPED INTERMEDIATE CEMENT BALANCE PLUG. PLACED 31 BBLS OF 15.8 PPG CEMENT IN TUBING & IA 8/26/2024 2P-443, 9/18/2024 7:55:20 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 FLOAT SHOE; 6,326.3-6,328.3 FLOAT COLLAR; 6,229.1- 6,230.5 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB SEAL; 5,568.2 CSR; 5,564.1-5,584.2 LOCATOR; 5,567.0 LOCATOR; 5,563.0-5,564.1 NIPPLE; 5,522.4 SLEEVE-C; 5,506.3 TUBING PUNCH; 5,475.0 GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 Cement Plug; 3,789.0 ftKB GAS LIFT; 3,581.6 CUT; 2,780.0 SURFACE; 28.4-2,487.6 FLOAT SHOE; 2,485.9-2,487.6 FLOAT COLLAR; 2,406.1- 2,407.6 GAS LIFT; 2,312.1 NIPPLE; 521.3 CONDUCTOR; 29.0-110.0 HANGER; 28.6-31.7 HANGER; 28.4-29.6 HANGER; 26.4 KUP PROD 2P-443 ... WELLNAME WELLBORE ϮWͲϰϰϯϰĂůĐƵůĂƚĞĚWdKΛϯϱϬϱ͛Z<^^ŚŽĞΛϮϰϴϴ͛Z</WΛϮϱϵϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϯϭϱ͛Z<WƵƚΛϮϱϰϬ͛Z<ϴϬdŽƉ ΛϮϲϯϬ͛Z<ϴϬĂƐĞΛϯϳϮϬ͛Z< CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Germann, Shane To:Loepp, Victoria T (OGC) Cc:Hobbs, Greg S; O"Connor, Katherine Subject:RE: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag Date:Wednesday, October 23, 2024 11:56:20 AM Victoria, Adding the 2P-434 data below. This should get us up to date on the sundries already submitted. This data will be included in all future submissions. Well Name Previous plug tag depth (RKB) PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-451 3785' Pass 9/2/2024 50 psi 50 psi 75 psi 9/5/2024 2P-449 7187' Pass 8/2/2024 0 psi 75 psi 190 psi 9/3/2024 2P-448A 5076' Pass 10/5/2024 0 psi 0 psi 220 psi 10/6/2024 2P-443 3789' Pass 9/2/2024 0 psi 0 psi 175 psi 9/4/2024 2P-441 3846' Pass 10/5/2024 0 psi 0 psi 230 psi 10/17/2024 2P-438 6495' Pass 9/2/2024 0 psi 0 psi 175 psi 9/3/2024 2P-434 3887' Pass 9/15/2024 0 psi 0 psi 210 psi 10/22/2024 Shane From: Germann, Shane Sent: Monday, October 21, 2024 3:57 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: RE: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag Hi Victoria, See below table for the data requested. This should cover the sundries submitted so far except for the 2P- 434 which we’re checking pressures on. These pressures are the latest I had available which is from the most recent work done on the well. If more recent pressures are desired, please advise as we’ll have to request somebody take the readings. Keep in mind that other prep work being done on the wells may affect the T&IA pressures due to U-tubing, circ outs, temperature changes, etc. I’ll make sure to include this data for future submissions as well as show the actual TOC depths for previous plugs on the schematics. Well Name Previous plug tag depth (RKB) PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-451 3785' Pass 9/2/2024 50 psi 50 psi 75 psi 9/5/2024 2P-449 7187' Pass 9/2/2024 0 psi 75 psi 190 psi 9/3/2024 2P-448A 5076' Pass 10/5/2024 0 psi 0 psi 220 psi 10/6/2024 2P-443 3789' Pass 9/2/2024 0 psi 0 psi 175 psi 9/4/2024 2P-441 3846' Pass 10/5/2024 0 psi 0 psi 230 psi 10/17/2024 2P-438 6495' Pass 9/2/2024 0 psi 0 psi 175 psi 9/3/2024 Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, October 21, 2024 12:36 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag 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. Shane, Please provide the following information for each 2P well abandonment sundry. 1. Date and results of passing state witnessed PT and tag of previous plug. 2. Current pressures of all annuli and tubing. Please provide for 2P-448A, 2P-449 and 2P-451 asap and follow with the others. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 108' 9.625" L-80 2362' 5.5" L-80 5048' 3.5" L-80 5703' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 5584' SIZE DEPTH SET (MD) 6328' 28" 5048' 62.5# 40# 108' 28" Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 3789' (SW TOC) - 5478' 31 bbls 15.8 ppg Cement (T and IA) Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 6045-6065' MD and 5450-5468' TVD (below cement plug) 6065-6080' MD and 5468-5481' TVD (below cement plug) 6070-6080' MD and 5472-5481' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 42" 12.25" 410 sx AS I 28"320 sx ArcticSet Lite, 225 sx LiteCrete 9.3# 28' 5584' 2488'28" 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 4/14/2004 CEMENTING RECORD 5870218 1368' MD / 1348' TVD SETTING DEPTH TVD 5870300 TOP HOLE SIZE AMOUNT PULLED 445616 445741 TOP 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 9. Ref Elevations: KB: 28' BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20487-00-00 KRU 2P-443 ADL0373112 998' FNL, 1680' FWL, Sec. 17, T18N, R7E, UM 436' FSL, 1505' FEL, Sec. 8, T8N, R7E, UM ALK 32092 2/23/2004 6334' MD/ 5709' TVD 3789' MD/ 3497' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443640 5868881 354' FSL, 1629' FEL, Sec. 8, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 9/4/2024 204-032/324-396 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, included above8.5" TUBING RECORD 650 sx GasBlok8.5" 5585' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:40 pm, Sep 18, 2024 Suspended 9/4/2024 JSB RBDMS JSN 093024 xGDSR-10/14/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1368' 1348' Top of Productive Interval N/A 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: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 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: N/A - Suspended 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. 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. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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). Authorized Name and Authorized Title: Formation Name at TD: 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 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.09.18 15:01:00-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 6,136.02P-4433/21/2024rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut 2P-4439/4/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: NOTE: SSV PANEL NOT HOLDING PRESSURE. HAVE TO HOOK UP DIRECTLY TO SSV BARREL TO OPEN SSV. 7/5/2024 fergusp Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 29.0 110.0 110.062.50 H-40 WELDED SURFACE 9 5/8 8.83 28.4 2,487.6 2,362.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @5584' 5 1/2 4.95 28.6 6,328.3 5,703.7 15.50 L-80 BTCMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.4 Set Depth … 5,584.8 Set Depth … 5,048.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 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) 26.4 26.4 0.00 HANGER 8.000 FMC TUBING HANGER 2.992 521.3 520.9 5.67 NIPPLE 4.550CAMCO DS NIPPLE CAMCO DS2.875 2,312.12,208.929.08 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 3,581.63,319.7 31.47 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 4,415.6 4,032.930.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,030.9 4,568.929.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,456.6 4,937.5 30.91 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,506.3 4,980.230.63 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE - CLOSED 06/18/2024 BAKER CMU2.810 5,522.4 4,994.130.37NIPPLE 4.550CAMCO D NIPPLE CAMCO D 2.750 5,567.0 5,032.7 29.65LOCATOR4.500BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 5,568.2 5,033.829.63 SEAL 4.000 BAKER SEAL ASSY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,780.0 2,618.2 28.81 CUT TUBING CUT (3.5" JET CUTTER) 9/4/2024 2.992 5,441.0 4,924.1 30.98 LEAK - TUBING Leak diagnostics done with Slickline holefinder. Appears leak is around GLM #5. Valve swapped out to Ext. Pkg DMY with no success. Holefinder suggests leak is between 5441' - 5470' RKB. 6/21/2024 0.000 5,475.0 4,953.330.84TUBING PUNCH 2" x 3 FT Tubing Punch. 6 SPF. 8/5/2024 2.990 6,019.3 5,426.927.45 CIBP 2.63" CIBP (MID-ELEMENT AT 6020' RKB) OAL=1.39' TTSCIBP N/A 3/30/2024 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) 2,312.1 2,208.9 29.08 1 GAS LIFT SOVBTM 1 0.08/2/2024 2K CSG Shear 0.000 3,581.63,319.7 31.47 2 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 4,415.6 4,032.930.46 3 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,030.9 4,568.929.46 4 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,456.6 4,937.5 30.91 5 GAS LIFT DMY BTM 1 6/20/2024 Ext. Pkg Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,045.0 6,065.0 5,449.7 5,467.5 T-3, 2P-443 5/13/2004 6.0 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,065.0 6,080.0 5,467.5 5,480.9 T-3, 2P-443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,070.0 6,080.0 5,472.0 5,480.9 T-3, 2P-443 4/30/2004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,045.0 6,080.0 1 FRAC5/22/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,940.06,019.3 5,356.8 5,426.9Cement Plug Slickline dump bailed cement on top of CIBP. Estimated TOC @ 5988' 6/22/2024 2P-443, 9/18/2024 10:51:26 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB TUBING PUNCH; 5,475.0 GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 Cement Plug; 3,789.0 ftKB GAS LIFT; 3,581.6 CUT; 2,780.0 SURFACE; 28.4-2,487.6 GAS LIFT; 2,312.1 CONDUCTOR; 29.0-110.0 KUP PROD KB-Grd (ft) 35.11 RR Date 4/19/2004 Other Elev… 2P-443 ... TD Act Btm (ftKB) 6,334.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048700 Wellbore Status PROD Max Angle & MD Incl (°) 31.58 MD (ftKB) 3,606.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 73 Date 12/11/2012 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 3,789.0 5,478.0 3,496.6 4,955.9 Cement Plug PUMPED INTERMEDIATE CEMENT BALANCE PLUG. PLACED 31 BBLS OF 15.8 PPG CEMENT IN TUBING & IA 8/26/2024 2P-443, 9/18/2024 10:51:29 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB TUBING PUNCH; 5,475.0 GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 Cement Plug; 3,789.0 ftKB GAS LIFT; 3,581.6 CUT; 2,780.0 SURFACE; 28.4-2,487.6 GAS LIFT; 2,312.1 CONDUCTOR; 29.0-110.0 KUP PROD 2P-443 ... WELLNAME WELLBORE DTTMSTART JOBTYP SUMMARYOPS 7/30/2024 ACQUIRE DATA (P&A) T X IA DDT TO 0 PSI (COMPLETE) 8/2/2024 ACQUIRE DATA DRIFT FOR E-LINE TO 5670' RKB.REPLACE 1'' BTM INT DMY W/ CSG SOV (2000 PSI) IN ST#1 @ 2312 RKB. WELL READY FOR E-LINE. 8/5/2024 ACQUIRE DATA LOG CORRELATED TO TUBING TALLY DATED 4-18-2004 SHOOT 3' X 2" TUBING PUNCH FROM 5475'-5478' LRS CONFIRMS COMMUNICATION WELL LEFT S/I 8/26/2024 CHANGE WELL TYPE INTERMEDIATE CEMENT BALANCE PLUG. LOAD TBG & IA WITH 10.1 PPG KWF. PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 5 BBLS OF FRESH WATER FOLLOWED BY 30 BBLS OF 10.1 PPG KWF. PLACING TOC IN TBG & IA @ ~3970' MD. WAIT 48 HRS & FREEZE PROTECT. 8/29/2024 CHANGE WELL TYPE UNABLE TO SHEAR SOV. TURNED OVER TO SLICKLINE TO PULL VALVE. 8/29/2024 ACQUIRE DATA TAG TOC @ 3792' RKB. PULL SOV IN ST#1 @ 2312' RKB. CIRCULATE 50 BBLS OF DIESEL TO TBG & IA FOR FREEZE PROTECT. READY FOR SW TAG & TEST. 9/2/2024 CHANGE WELL TYPE STATE WITNESS TAG (Austin McLeod) TOC @ 3789' RKB (GOOD SAMPLE), PERFORM PASSING CMIT TO 1500 PSI. READY FOR E-LINE. NETWORK# 10460701 9/3/2024 CHANGE WELL TYPE UNABLE TO FIRE JET CUTTER DUE TO SHORT IN TOOLSTRING BELOW CCL JOB CONTINUED 9/4/2024 NETWORK# 10460701 9/4/2024 CHANGE WELL TYPE LOG CORRELATED TO TUBING TALLY DATED 18-APRIL-2001 CUT TUBING W/ 2.5" JRC JET CUTTER AT 2780' WELL LEFT S/I NETWORK #10460701 9/5/2024 ACQUIRE DATA (P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASSED) T PPPOT (PASSED), FUNCTION TEST ALL IC LDS/GNS (COMPLETE), IC POT (PASSED) IC PPPOT (PASSED), 2P-443 Intermediate Suspend Summary of Operations ORIGINATED TRANSMITTAL DATE: 9/10/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5034 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5034 2P-443 501032048700 Tubing Cut Record 3-Sep-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-032 T39534 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 11:23:21 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4980 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4980 2P-443 501032048700 Tubing Puncher Record 5-Aug-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-032 T39392 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:37:22 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:6334 ft MD Lease No.:ADL 0373112 Operator Rep:Suspend:X P&A:NA Conductor:16"O.D. Shoe@ 110 Feet Csg Cut@ NA Feet Surface:9-5/8"O.D. Shoe@ 2488 Feet Csg Cut@ NA Feet Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production:5-1/2" x 3-1/2"O.D. Shoe@ 6328 Feet Csg Cut@ NA Feet Liner:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing:3-1/2"O.D. Tail@ 5585 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 5475 ft MD 3789 ft MD 10.1/6.7 pgg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1900 1820 1785 IA 1750 1680 1660 OA 305 288 280 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to location to witness the slickline tag and combo mechanical integrity test (CMIT TxIA) of the intermediate cement plug that was pumped on 8/26/2024. With an 2-1/2 inch bailer assembly they tagged at 3789 ft MD (30°) with multiple hard set downs. Sample observed in bailer. With the top gas lift mandrel sheared they then completed a passing CMIT to a target of 1500psi. Tubing punched at 5475 ft MD (bottom depth of plug) prior to cement job. August 2, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-443 ConocoPhillips Alaska, Inc. PTD 2040320; Sundry 324-396 none Test Data: CMIT TXIA P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0902_Plug_Verification_KRU_2P-443_am                1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Suspend -Intermediate Plug 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6334'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/22/2024 3-1/2" Packer: Baker Seal Assy SSSV: None Perforation Depth MD (ft): L-80 2459' 6045-6080' (below cement plug) 6300' 5450-5481' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2488' 5704'6328' 16" 9-5/8" 81' 5585' MD 110' 2362' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20487-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5568' MD and 5034' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-443 5709' 5940' 5357' 5940' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:15 am, Jul 12, 2024 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.07.11 16:04:09-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-396 DSR-7/15/24SFD 7/15/2024 SFD X 10-407 VTL 7/17/2024 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.17 14:22:54 -08'00'07/17/24 RBDMS JSB 072324 2P-443 Intermediate Procedure Date Written: 6-3-24 Prepared by: Katherine O’Connor (214-684-7400) Background & Objective 2P-443 was a producer shut-in in mid 2021. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This has been suspended and the objective of this procedure is to pump a balanced cement plug before the full rig P&A in Q4 2024. Well Data Reservoir pressure 4/19/2018 = 2818 psi at 5400’ TVD = 0.52 psi/ft MASP = 2278 psi Cleanout to 6100’ CTMD in 2019 Tubing leak below St#5 @ 5441’ Suspended, passing CMIT-TxIA 3/31/24 Procedure Wireline & Pumping 1. Punch tubing at ±5,470’ RKB, 2. Pump the following schedule taking returns up the IA: a. ±30 bbls surfactant wash b. ±130 bbls KWF brine c. ±31 bbls cement d. ±30 bbls KWF displacement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 3970’ MD 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline 1. RIH with jet cutter and cut tubing at 2780’ KB. Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 5470 3.5" 9.3# 2.99" 0.0087 5470 47.5 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 5470 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 5470 65.1 84.0 from punch depth Tubing Cement 3970 5470 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 3970 5470 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 2P-443 Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 Item Depth - tops (KB) 1 FMC Tubing Hanger 26.4' 2 Camco DS Nipple 521.3' 3 Baker CMU Sliding Sleeve (Opened 8/22/2020)5,506.3' 4 Camco D Nipple 5,522.4' 5 Baker GBH-22 Locator 5,567' 6 Baker Seal Assembly 5,568.2' C80 @ 2630' KB C80 @ 2630' KB Plug #1 – Reservoir TOC ±5940' RKB Plug #2 – Intermediate TOC ±3970' RKB BOC @ ±5470' RKB Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 6,136.0 2P-443 3/21/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CIBP 2P-4433/30/2024bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: NOTE: SSV PANEL NOT HOLDING PRESSURE. HAVE TO HOOK UP DIRECTLY TO SSV BARREL TO OPEN SSV. 7/5/2024 fergusp NOTE: View Schematic w/ Alaska Schematic9.011/24/2010 ninam Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 29.0 110.0 110.062.50 H-40 WELDED SURFACE 9 5/88.8328.42,487.6 2,362.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @5584' 5 1/2 4.95 28.6 6,328.3 5,703.7 15.50 L-80 BTCMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.4 Set Depth … 5,584.8 Set Depth … 5,048.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 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) 26.4 26.4 0.00 HANGER 8.000 FMC TUBING HANGER 2.992 521.3 520.9 5.67 NIPPLE 4.550CAMCO DS NIPPLE CAMCO DS 2.875 2,312.12,208.929.08 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 3,581.63,319.7 31.47 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 4,415.6 4,032.930.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,030.9 4,568.929.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,456.6 4,937.5 30.91 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,506.3 4,980.230.63 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE - CLOSED 06/18/2024 BAKER CMU 2.810 5,522.4 4,994.130.37 NIPPLE 4.550CAMCO D NIPPLE CAMCO D 2.750 5,567.0 5,032.7 29.65LOCATOR4.500BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 5,568.2 5,033.829.63 SEAL 4.000 BAKER SEAL ASSY BAKER 3.000 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) 5,441.0 4,924.1 30.98 LEAK - TUBING Leak diagnostics done with Slickline holefinder. Appears leak is around GLM #5. Valve swapped out to Ext. Pkg DMY with no success. Holefinder suggests leak is between 5441' - 5470' RKB. 6/21/2024 0.000 6,019.3 5,426.927.45 CIBP 2.63" CIBP (MID-ELEMENT AT 6020' RKB) OAL=1.39' TTSCIBP N/A 3/30/2024 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) 2,312.1 2,208.9 29.08 1 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 3,581.6 3,319.7 31.47 2 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 4,415.6 4,032.9 30.46 3 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,030.9 4,568.9 29.46 4 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,456.6 4,937.5 30.91 5 GAS LIFT DMY BTM 1 6/20/2024 Ext. Pkg Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,045.06,065.0 5,449.7 5,467.5 T-3, 2P-443 5/13/2004 6.0 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,065.06,080.0 5,467.5 5,480.9 T-3, 2P-443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,070.06,080.0 5,472.0 5,480.9 T-3, 2P-443 4/30/2004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,045.06,080.0 1 FRAC 5/22/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,940.0 6,019.3 5,356.8 5,426.9 Cement Plug Slickline dump bailed cement on top of CIBP. Estimated TOC @ 5988' 6/22/2024 2P-443, 7/11/2024 1:20:16 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 GAS LIFT; 3,581.6 SURFACE; 28.4-2,487.6 GAS LIFT; 2,312.1 CONDUCTOR; 29.0-110.0 KUP PROD KB-Grd (ft) 35.11 RR Date 4/19/2004 Other Elev… 2P-443 ... TD Act Btm (ftKB) 6,334.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048700 Wellbore Status PROD Max Angle & MD Incl (°) 31.58 MD (ftKB) 3,606.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 73 Date 12/11/2012 Comment SSSV: NIPPLE 1a. Well Status:SuspendedAbandonedOtherSPLUGOil 1b. Well Class: 20AAC 25.11020AAC 25.105 ExploratoryDevelopment WDSPLGINJ WINJ No. of Completions: __________________Stratigraphic TestService 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):Top of Productive Interval: GL: BF: 10. Plug Back Depth MD/TVD: 18. Property Designation:Total Depth: 11. Total Depth MD/TVD: 19. DNR Approval Number:4b. Location of Well (State Base Plane Coordinates, NAD 27): Zone- 4y-x-Surface: 20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4y-x-TPI: Zone- 4y-x-Total 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 B16" 2362'L-809.625" 5048'L-805.5" 5703'L-803.5" 25.NoYes24. Open to production or injection? 26. Was hydraulic fracturing used during completion? Yes No DEPTH 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 5584' DEPTH SET (MD)SIZE 6328' 28" 5048' 62.5# 40# 28" Sr Res EngSr Pet GeoSr Pet Eng Water-Bbl:Oil-Bbl: 5940' (SW TOC) - 6019' Water-Bbl: PRODUCTION TEST N/A Oil-Bbl:Date of Test: Flow Tubing SUSPENDED 6045-6065' MD and 5450-5468' TVD (below cement plug) 6065-6080' MD and 5468-5481' TVD (below cement plug) 6070-6080' MD and 5472-5481' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 42" 12.25" 410 sx AS I 28"320 sx ArcticSet Lite, 225 sx LiteCrete 9.3# 28' 5584' 2488'28" 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 4/14/2004 CEMENTING RECORD 5870218 1368' MD / 1348' TVD SETTING DEPTH TVD 5870300 TOP HOLE SIZE AMOUNT PULLED 445616 445741 TOP 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 9. Ref Elevations: KB: 28' BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20487-00-00 KRU 2P-443 ADL0373112 998' FNL, 1680' FWL, Sec. 17, T18N, R7E, UM 436' FSL, 1505' FEL, Sec. 8, T8N, R7E, UM ALK 32092 2/23/2004 6334' MD/ 5709' TVD 5940' MD/ 5357' TVD P.O. Box 100360, Anchorage, AK 99510-0360 5868881443640 354' FSL, 1629' FEL, Sec. 8, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/5/2024 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, included above8.5" TUBING RECORD 650 sx GasBlok8.5" 5585' MD3-1/2" CASING Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022 AMOUNT AND KIND OF MATERIAL USED 0.26 bbls 15.8 ppg Class G 110'110' 14. Permit to Drill Number / Sundry: 204-032/323-598 By Grace Christianson at 1:36 pm, Jul 12, 2024 Suspended 7/5/2024 JSB RBDMS JSB 071724 xG DSR-8/27/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1368' 1348' Top of Productive Interval N/A 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: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 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: N/A - Suspended 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. 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. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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). Authorized Name and Authorized Title: Formation Name at TD: 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 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location:Date: 2024.07.11 14:33:02-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 6,136.02P-4433/21/2024rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CIBP 2P-4433/30/2024bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: NOTE: SSV PANEL NOT HOLDING PRESSURE. HAVE TO HOOK UP DIRECTLY TO SSV BARREL TO OPEN SSV. 7/5/2024 fergusp NOTE: View Schematic w/ Alaska Schematic9.011/24/2010 ninam Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 29.0 110.0 110.062.50 H-40 WELDED SURFACE 9 5/8 8.83 28.4 2,487.6 2,362.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @5584' 5 1/2 4.95 28.6 6,328.3 5,703.7 15.50 L-80 BTCMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.4 Set Depth … 5,584.8 Set Depth … 5,048.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 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) 26.4 26.4 0.00 HANGER 8.000 FMC TUBING HANGER 2.992 521.3 520.9 5.67 NIPPLE 4.550CAMCO DS NIPPLE CAMCO DS 2.875 2,312.12,208.929.08 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 3,581.63,319.7 31.47 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 4,415.6 4,032.930.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,030.9 4,568.929.46GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,456.6 4,937.5 30.91 GAS LIFT 4.725 CAMCO KBG-2-9CAMCOKBG-2-92.900 5,506.3 4,980.230.63 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE - CLOSED 06/18/2024 BAKER CMU 2.810 5,522.4 4,994.130.37NIPPLE 4.550CAMCO D NIPPLE CAMCO D 2.750 5,567.0 5,032.7 29.65LOCATOR4.500BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 5,568.2 5,033.829.63 SEAL 4.000 BAKER SEAL ASSY BAKER 3.000 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) 5,441.0 4,924.1 30.98 LEAK - TUBING Leak diagnostics done with Slickline holefinder. Appears leak is around GLM #5. Valve swapped out to Ext. Pkg DMY with no success. Holefinder suggests leak is between 5441' - 5470' RKB. 6/21/2024 0.000 6,019.3 5,426.927.45 CIBP 2.63" CIBP (MID-ELEMENT AT 6020' RKB) OAL=1.39' TTSCIBP N/A 3/30/2024 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) 2,312.1 2,208.9 29.08 1 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 3,581.6 3,319.7 31.47 2 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 4,415.6 4,032.9 30.46 3 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,030.9 4,568.9 29.46 4 GAS LIFT DMY BTM 1 0.0 4/18/2004 0.000 5,456.6 4,937.5 30.91 5 GAS LIFT DMY BTM 1 6/20/2024 Ext. Pkg Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,045.06,065.0 5,449.7 5,467.5 T-3, 2P-443 5/13/2004 6.0 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,065.06,080.0 5,467.5 5,480.9 T-3, 2P-443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,070.06,080.0 5,472.0 5,480.9 T-3, 2P-443 4/30/2004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,045.06,080.0 1 FRAC 5/22/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,940.0 6,019.3 5,356.8 5,426.9 Cement Plug Slickline dump bailed cement on top of CIBP. Estimated TOC @ 5988' 6/22/2024 2P-443, 7/11/2024 11:05:45 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 CIBP; 6,019.3 Cement Plug; 5,940.0 ftKB GAS LIFT; 5,456.6 LEAK - TUBING; 5,441.0 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 GAS LIFT; 3,581.6 SURFACE; 28.4-2,487.6 GAS LIFT; 2,312.1 CONDUCTOR; 29.0-110.0 KUP PROD KB-Grd (ft) 35.11 RR Date 4/19/2004 Other Elev… 2P-443 ... TD Act Btm (ftKB) 6,334.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048700 Wellbore Status PROD Max Angle & MD Incl (°) 31.58 MD (ftKB) 3,606.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 73 Date 12/11/2012 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 3/21/2024 CHANGE WELL TYPE BRUSH & FLUSH TBG TO TOP OF JET PUMP @ 5506' RKB, PULL 2.81" JET PUMP FROM SLEEVE @ 5506' RKB, DRIFT 2.623" DUMMY CIBP TO TD @ 6136' RKB, NO ANOMALIES OR WEIGHT SWINGS, READY FOR LOAD AND CIBP. 3/30/2024 CHANGE WELL TYPE BULLHEAD DOWN TUBING WHILE RIH 50 BBLS OF 10.1 BRINE AND 17 BBL DIESEL FREEZE PROTECT. ONLY ABLE TO PUMP AT 0.4 BPM TO KEEP IA PRESSURE UNDER 2300 PSI. SET CIBP AT 6020' RKB (MID- ELEMENT). LRS CMIT-TxIA TO 1500 PSI (PASS). JOB COMPLETE, READY FOR SLICKLINE 6/18/2024 CHANGE WELL TYPE DRIFT TO TOP OF CIBP @ 6019' RKB, ATTEMPT MULTIPLE TIMES TO SHIFT CMU @ 5506' RKB CLOSED, RIH W/ HOLEFINDER, ATTAIN GOOD TEST ABOVE ST#5 @ 5433' RKB, LDFN. JOB IN PROGRESS 6/19/2024 CHANGE WELL TYPE SET 2.81'' CAT SV @ 5506' RKB, ATTEMPT MITT FAILED, PULL 2.81'' CAT SV @ 5506' RKB, RIH W/ 3-1/2 SLIPSTOP HOLEFINDER & ATTAIN GOOD TEST ABOVE ST#5 @ 5446' RKB, SET 3-1/2 SLIPSTOP CATCHER @ 5472' RKB, PULL DMY VLV FROM ST#5 @ 5456' RKB, LDFN. JOB IN PROGRESS 6/20/2024 CHANGE WELL TYPE SET 1'' BTM INT DMY VLV IN ST#5 @ 5456' RKB, ATTEMPT MITT FAILED, PULL DMY & SET 1'' BTM INT DMY VLV W/ EXT PACKING IN ST#5 @ 5456' RKB, PULL 3-1/2 SLIPSTOP CATCHER @ 5472' RKB, LDFN. JOB IN PROGRESS 6/21/2024 CHANGE WELL TYPE RIH W/ 3-1/2 SLIPSTOP HOLEFINDER, GET GOOD TEST ABOVE ST#5 @ 5441' RKB, MULTIPLE RUNS OF DUMP BAILING CEMENT ON TOP OF CIBP @ 6019' RKB, LDFN. JOB IN PROGRESS 6/22/2024 CHANGE WELL TYPE TAG CEMENT @ 6002' RKB, SEVERAL RUNS OF DUMP BAILING CEMENT, RETAG CEMENT @ 5988' RKB, RDMO. 7/5/2024 CHANGE WELL TYPE TAG TOC @ 5940' SLM. PERFORM PASSING CMIT TO 1500 PSI. STATE WITNESSED BY BRIAN BIXBY. READY FOR NEXT CEMENTING PROCEDURE. NOTE: SSV PANEL NOT HOLDING PRESSURE. HAVE TO HOOK UP DIRECTLY TO SSV BARREL TO OPEN SSV. 2P-443 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: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Rig Elevation: Total Depth: 6334 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2488 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2"x3 1/2" O.D. Shoe@ 6328 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 5585 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 6019 ft 5949 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1725 1710 1700 IA 1804 1757 1745 OA 292 283 275 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Pre-test pressures Tbg = 320 / IA = 385 / OA 227 This was a combo test because known hole in tubing. July 5th 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-443 ConocoPhillips Alaska Inc. PTD 2040320; Sundry 323-598 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0705_Plug_Verification_KRU_2P-443_bb 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.14 14:49:51 -08'00' 204-032 T38911 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 14:52:02 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6334'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/20/2023 3-1/2" Packer: Baker Seal Assy SSSV: None Perforation Depth MD (ft): L-80 2459' 6045-6080' 6300' 5450-5481' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2488' 5704'6328' 16" 9-5/8" 81' 5585' MD 110' 2362' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20487-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5568' MD and 5034' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-443 5709' 6334' 5709' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:08 am, Nov 06, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.11.06 07:45:28-09'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 323-598 10-407 DSR-11/8/23 X X 12/31/24 VTL 11/14/2023 SFD 11/8/2023*&:JLC 11/15/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.15 14:28:28 -09'00'11/15/23 RBDMS JSB 111623 2P-443 Suspension Date Wrien: 10-03-23 Execuon Date: Nov 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-443 was a producer shut-in in mid 2021. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 4/19/2018 = 2818 psi at 5400’ TVD MASP = 2278 psi Cleanout to 6100’ CTMD in 2019 Well has history of parrafin/asphaltenes but able to be cleaned with B&F Procedure Wireline & Pumping 1. Pull jet pump from ~5506’ KB 2. Drift with dummy CIBP to TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 3. Fluid pack tubing with KWF and freeze protect 4. Set CIBP @ ±6,020’ RKB (must be set within 50’ of the top of perforations). 5. Perform CMIT-TxIA to 1500 psi, record results 6. Dump bail at least 30’ of cement on top of CIBP 7. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 8. RIH and tag TOC, approx. 5,590’ RKB (MUST BE AOGCC WITNESSED) 9. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 10. Perform DDT to 0 psi and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval 2P-443 Well Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 Item Depth - tops (KB) 1 FMC Tubing Hanger 26.4' 2 Camco DS Nipple 521.3' 3 Baker CMU Sliding Sleeve (Opened 8/22/2020)5,506.3' 4 Camco D Nipple 5,522.4' 5 Baker GBH-22 Locator 5,567' 6 Baker Seal Assembly 5,568.2' C80 @ 2630' KB C80 @ 2630' KB 2P-443 Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 128.2 bbls of 15.8# Latex Cement Calculated TOC @ 3,505' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 5,584' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 6,328.3’ KB T-3 Peforations: @ 6,045' – 6,080' KB (35') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,487.6' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 5,584.8' KB 6 Item Depth - tops (KB) 1 FMC Tubing Hanger 26.4' 2 Camco DS Nipple 521.3' 3 Baker CMU Sliding Sleeve (Opened 8/22/2020)5,506.3' 4 Camco D Nipple 5,522.4' 5 Baker GBH-22 Locator 5,567' 6 Baker Seal Assembly 5,568.2' C80 @ 2630' KB C80 @ 2630' KB Plug #1 – Reservoir TOC ±5990' RKB 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: GL to Jet Pump Conv 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 6334'feet N/A feet true vertical 5709'feet N/A feet Effective Depth measured 6334'feet N/A feet true vertical 5709'feet N/A feet Perforation depth Measured depth 6045'-6080'feet True Vertical depth 5450'-5481' feet Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 5585' MD 5048" TVD Packers and SSSV (type, measured and true vertical depth)SSSV Camco DS Nipple 521' MD 521' TVD Seal Assembly Seal Assembly 5568' MD 5034' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Contact Email: Contact Phone: Senior Engineer:Senior Res. Engineer: CollapseBurst 6328' TVD 110 2362 5704' 16" 9-5/8" 5-1/2" 81' 2459' 6300' Casing Structural Authorized Signature with date: Liner Kuparuk River Field/ Meltwater Oil Pool Conductor Surface Intermediate Production Length Junk measured N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-576 310 Size 5. Permit to Drill Number:2. Operator Name N 3. Address: 4. Well Class Before Work: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 27 Gas-Mcf measuredPlugs 3000 Casing Pressure Tubing Pressure KRU 2P-443 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-032 50-103-20487-0000 35 Oil-Bbl measured true vertical Packer 525 2280 0 Representative Daily Average Production or Injection Data ConocoPhillips Alaska, Inc. WINJ WAG 0 Water-Bbl MD 110 2488' ADL 0373112 (907) 265-1109 N/A P.O. Box 100360 Anchorage, AK 99510 Authorized Name: Sayeed Abbas Authorized Title: Staff Drillsite Petroleum Engineer Sayeed Abbas Sayeed.Abbas@conocophillips.com 11 t Fra O 204 6. A G L P s G 25.070, 2 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:57 am, Sep 28, 2020 Sayeed Abbas Digitally signed by Sayeed Abbas Date: 2020.09.24 19:16:38 -08'00' RBDMS HEW 10/26/2020 SFD 9/29/2020VTL 11/03/20 DSR-9/28/2020 !"#$% &!' !!#$()*% ')*% ! '(" **% & ' )'!" **% &$*!( "**% & !"**% !! # !! !''' ** +( ,,&! -#*+,& !! $*!("**% & ** ' !(!%' #!+ ,'%"**% & '!! ! !"**% "**% ' ! "**% ""**% ' "**% + .()#,* ' ' * ' !%/ 0 ! ())#1223456789 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: RKB 6,185.0 4/19/2018 2P-443 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced Jet Pump.9/11/2020 2P-443fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 110.0 Set Depth (TVD)… 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 28.4 Set Depth (ftKB) 2,487.6 Set Depth (TVD)… 2,362.5 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION 5.5"x3.5" @5584' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 28.6 Set Depth (ftKB) 6,328.3 Set Depth (TVD)… 5,703.7 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCMOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.4 Set Depth (ft… 5,584.8 Set Depth (TVD) (… 5,048.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 26.4 26.4 0.00 HANGER FMC TUBING HANGER 2.992 521.3520.95.67 NIPPLE CAMCO DS NIPPLE 2.875 5,506.3 4,980.2 30.63 SLEEVE-C BAKER CMU SLIDING SLEEVE - OPENED 8/22/2020 2.810 5,522.4 4,994.1 30.37 NIPPLE CAMCO D NIPPLE 2.750 5,567.0 5,032.7 29.65 LOCATOR BAKER GBH-22 LOCATOR 3.000 5,568.2 5,033.8 29.63 SEAL BAKER SEAL ASSY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 5,506.0 4,980.0 30.63 Jet Pump 2.81" C-Lock w/ 3" RC Jet Pump (8B Ratio) & Spartek Gauge (94" OAL) 9/11/2020 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,045.0 6,065.0 5,449.7 5,467.5 T-3, 2P-443 5/13/2004 6.0 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,065.0 6,080.0 5,467.5 5,480.9 T-3, 2P-443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6,070.0 6,080.0 5,472.0 5,480.9 T-3, 2P-443 4/30/2004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing Frac Summary Start Date 5/22/2004 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 5/22/2004 Top Depth (ftKB) 6,045.0 Btm (ftKB) 6,080.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 2,312.1 2,208.9 CAMCO KBG-2- 9 1GAS LIFT DMY BTM 0.000 0.0 4/18/2004 2 3,581.63,319.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/18/2004 3 4,415.6 4,032.9 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/18/2004 4 5,030.9 4,568.9 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/18/2004 5 5,456.6 4,937.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 7/28/2019 Notes: General & Safety End Date Annotation 11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2P-443, 9/12/2020 11:03:31 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @5584'; 28.6-6,328.3 IPERF; 6,070.0-6,080.0 RPERF; 6,065.0-6,080.0 FRAC; 6,045.0 APERF; 6,045.0-6,065.0 SEAL; 5,568.2 LOCATOR; 5,567.0 NIPPLE; 5,522.4 Jet Pump; 5,506.0 SLEEVE-C; 5,506.3 GAS LIFT; 5,456.6 GAS LIFT; 5,030.8 GAS LIFT; 4,415.6 GAS LIFT; 3,581.6 SURFACE; 28.4-2,487.6 GAS LIFT; 2,312.1 NIPPLE; 521.3 CONDUCTOR; 29.0-110.0 HANGER; 26.4 KUP PROD KB-Grd (ft) 35.11 Rig Release Date 4/19/2004 2P-443 ... TD Act Btm (ftKB) 6,334.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048700 Wellbore Status PROD Max Angle & MD Incl (°) 31.58 MD (ftKB) 3,606.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 73 Date 12/11/2012 Comment SSSV: NIPPLE THE STATE °fALASKA. woVERNOR MIKE DUNLEAVY Sayeed Abbas Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, KRU 2P-443 Permit to Drill Number: 204-032 Sundry Number: 319-576 Dear Mr. Abbas: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o o g c c. a l a s k a. g o v Enclosed is the approved application for the 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,` Price \Caommissi DATED this �— day of January, 2020. 'IBDMSL JAN 0 3 2920 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on nvr 25 280 DEC 10 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ _ sOperations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubingp ❑ Change Approved [� t(pL�r4qf�gyrljam Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: �L +Ch'ting 7L 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑� • StraGgraphic ❑ Service ❑ 204-032 ' 3. Address: 6. API Number: PO Box 100360, Anchorage, AK, 99510 50-103-20487-0000 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2P-443 ' Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO373112 Kuparuk / Meltwater Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): P3 , 929' S 7&T 6942' 5608' N/A N/A Casing /y Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 110 110 Surface 2334' 9.625" 2363' 2488' Intermediate Production 6300' J 5.5" 6328' 5704' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade:Tubing MD (ft): 6045-6080' 5450-5481' 3.5 L-80 5048' Packers and SSSV Type: No SSSV. Camco D nipple Packers and SSSV MD (ft) and TVD (ft): Camco Nipple: 521' MD, 521' TVD Seal Assy Seal Assy: 5568' MD, 5034' TVD 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� � Service ❑ 14. Estimated Date for 2/1/2020 15. Well Status after proposed work: Commencing Operations: OIL 0 - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: N/A Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sayeed Abbas Sayeed Abbas Contact Name: Authorized Title: Staff DrillSite Petroleum Engineer Contact Email: sa eed.abbas Conoco hilli S.Com Contact Phone: 907-365-1109 Authorized Signature: .E[O`- 7\y0 Date: I 1411011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: --" ' q _. _ 76- Plug Integrity ElBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El Other: 3BDMS kJAN 0 3 2020 Post Initial Injection MIT Req'd? Yes ❑ No Ef Spacing Exception Required? Yes ❑ No Subsequent Form Required: .10--+v4 APPROVED BY ` ZI t.•r�7 o Approved by: COMMISSIONER THE COMMISSION Date: I C) Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 December 16th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska Inc well KRU 2P-443 (PTD 204-032). The request is for approval to convert this producer i from a gas lifted well to jet pump. We currently do not have lift gas available in Meltwater 2P drillsite and the producers do not have enough reservoir pressure to naturally flow. Converting the producers to jet pump would enable to keep producing. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Email: sayeed.abbas(@conocophillips.com Ph: 907-265-1109 Attachments: Sundry Application Proposed Steps Well Schematic I. KRU 2P-443 DESCRIPTION SUMMARY OF PROPOSAL Jet Pump conversion for KRU 210-443 CPAI proposes the following plan: 1. Remove 2" GI spool piece connecting the GI header to individual well, install 2" WI spool piece connecting the WI header to individual well. 2. Slide sliding sleeve open 4. Set jet pump across sliding sleeve at 5506' 5. Submit 10-404 post -conversion KUP PROD WELLNAME 2P-443 WELLBORE 2P-443 ConoeoPl7illips Well Attributes�Marc TD 40Ske. hlD. ,IT)Angle&MD Fleltl Name Wellbore AP11UW1 FROG' Slalus ncl (° MO Puild a3340(kKB) MELTWATER 501032098>00 PROD 1.58 3,606'56 6,334.0 Comment H35 (Igml SSSV: NIPPLE J3 Oete Mnalalion Ena Dale K&G�tl ITI RIg Releese Oatt 1211112012 last WO: 35.11 411912004 ]Pi0.3.a2a(101g8ad38 AM Last Tag e. (.1.0 Annobtion DepIM1pla.) EndOaIe We11Eore WI MW By Last Tag: RKB a185.0 4/19/2018 21-443 kr us P 9 Last Rev Reason Annotation End DatewellMre Laat Moa By HMGER, 26.4 Rev Reason: Pulled Catcher&2.75"CA-2 Plug 8222019 2P -d43 tempt, Casing Strings easing DaeeNption CONDUCTOR oDOnl mpnf Top (XK81 semeptn (nNBI sal Oaplh jNDl... wYlen 16 15.Ofi 29.0 110.0 110.0 6250 Top TM1raaa g_. craaeJ�ELOE H -40D Lasing Desuiplion SURFACE OD(in) 10 (Inl Top (XK6) Bet 0eptn (XKBI $A U.IM1 f1VDl... wu1¢n 9518 8.83 284 248].fi 2362.5 40.00 (I... GmtleM1reait Lteeing De:crlpnon 5.5'x3.5" oDpn1 m(Inl rep (Pon seroepin (nrcBl $MDapin (IVDL.. N/aLen 5 t2 4.95 28.6 6,328.3 5.703.7 1550 g._GraeaTop rmeadPRODUCTION L-80BTCMOD @5584' Tubing Strings Tabing De"'a on s1anB Ma... l0 (In) Top (XK61 set Depot (n.. sal oepm (rv0)(... wl Obm) Graae Top Canneclion TUBING 31/2 2.99 264 5,584.8 S,W82 9.30 L-80 EUE-Brd CONWCTOR-2g G110.a NIPPLE: 5213 Completion Details TOp(IVD) Tappet Nominal Top(XK9l kIKB) m Nem Des tom LD(n) 264 26.4 0.00 HANGER FMC TUBING HANGER 2992 521.3 520.9 5.67 NIPPLE CANDO DS NIPPLE 2.875 5,506.3 4,980.2 30.63 SLEEVE -C BAKER CMU SLIDING SLEEVE- CLOSED 11115n009 2.810 GAS LIFT, 2,312.1 5,522.4 4,996.1 30.37 NIPPLE CAMCO D NIPPLE 2.750 5,5670 5,0.32.) 29.65 LOCATOR BAKER GBH -22 LOCATOR 3.W0 5,5682 5,033.8 29.63 SEAL BAKERSEALASSY 3000 Perforations & Slots snot Den I 91m Did (.I.. Top(kKB) (M(BI LInMM Zane pate 1 TVPo Oom suRFACe. ssaZ,8Ta- 604505461.5 T -32P-443 51132000. 6.0 APERF 2.5" HSD HJ 2506 RDX. 60 tOK tleg phasing 6,065,0548096.0 RPERF 2.5" HSD HJ 2506 RDX, 6.As urn ax1.6 tleg phasing 6,0]0.00 5,480.9 T -3.2P-043 4130I2W4 6.0 (PERF 25'HSD HJ 2505 RDX, 50 deg phasing Frac Summary WA UFT: d,Dl s ..a Dale proppant designed dig Pmppanl In Formation Up) 51222004 $Igp SIaN Date Top Deptn(XKBI Bim(W(e) Lin k to FI an Byatem Vol Clesn(Wg) VOISlaWablj 1 921120W 6.045.0 6,080.0 Mandrel Inserts at xi GAA UFT A,Pa3.e Tap(Ndl N Toppe,B) (XKB1 Valve lelah Pan Sim Moke ..I On (in) Sery type Type an ) TRORun (Pap Run Date eom 2,312.1 2.208.9 CAMCO KBG,- 1 GAS LIFT DMV DKt 0.000 40 41IW2004 9 2 3,581.6 3,319.7 CAMCO KBG-2- 1 GAS LIFT DMV DK1 0.000 0.0 4/18/2004 9 . 4,032.9 CAMCO KBG-2- 1 GAS LIFT DMV DK1 0.0W 0.0 411820049 5,030.9 4568.9 BAMCO KBG2- 1 GAS LIFT DMV DK30.000 0.0 411812004 144", 9 5.46.6 4,937.5 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.000 0.0 MW2019 sLEEUE.e. s.ebea : apparel& of Ena Date Mnalalion 111242010 NOTE: View Schematic w/ Alaska SchematicRO NIPPLE:5.=4 LOCATOR, I SEAL:4ssa2 MERF:6015.Ofi.6S0 FMC:4W5.0 RPERF:4WS..1.0 IPEflF, 6,070.66,M➢.0 PflOWCTION 55 W ®SSM`,...325] Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, March 01, 2015 1:54 PM To: Regg,James B (DOA);Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of sustained casing pressure Meltwater producer 2P-443 (PTD 204-032) 3-1-15 Attachments: 2P-443 90 day TIO 3-1-15.JPG; 2P-443 schematic.pdf Jim, Chris Meltwater gas-lifted producer 2P-443 (PTD 204-032) is being reported with sustained casing pressure of the inner annulus. The well has been shut in since 4-24-14. Per conservation order 494, Rule 3,the well is being reported for sustained IA pressure above 2000psi. While waiting on Slickline to begin troubleshooting, operations has performed multiple bleeds in the last couple weeks in an attempt to maintain the pressure below the required 2000psi. The well reached 2010psi on 2/25/15. Slickline is currently scheduled to perform wellwork as soon as logistically possible to repair the well via a gas lift valve changeout or secure the well if needed. The 5.5" 15.5# L-80 has a burst rating of 7000psi. Attached are the schematic and 90 day TIO plot. 1 Well Name 2P-443 Notes: Start Date 12/1/2014 Days 90 End Date 3/1/2015 Annular Communication Surveillance 4CC0 - — 70 _WHP _IAP 3500OA )1\\I\AI\ t WHPT — EC 3000 — 5-0 2E00 — »0 Q •tA 200C - : :: 1 E0C — 20 1CCC 500 — 10 C 0 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-1E Feb-1E Feb-15 Mar-15 0.9 uc, 03 —WC:, 0 07 04 wi d OS sw, 04 z-.J 03 0: 01 0 Sep-14 Dec-14 Idar-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 • KUP PROD 2P-443 Conoc PhiIIips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) tong(, ding 501032048700 MELTWATER PROD 31.58 3.606.56 6.334.0 ••• Comment H2S(ppm) Date Annotation End Dote KB-Grd(ft) Rig Release Date 2P-443,2/10/201410'.56.20 AM SSSV:NIPPLE Last WO: 35.11 4/19/2004 Vertical schematic(actual) Annotation Depth)ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6053.0 8/12/2011 Rev Reason:GLV C/O,PULL PLUG hipshkf 2/10/2014 IN Casing Strings HANGER.26.4 s r I i ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(111(8) Set Depth)TVD)... Wt/Len(I...Grade Top Thread pr-T CONDUCTOR 16 15062 29.0 110.0 110.0 62.50 H-40 WELDED _ = I- Casing Description OD(in) ID(in) Top(KKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len 11...Grade Top Thread SURFACE 95/8 8.835 28.4 2,487.6 2,362.5 40.00 L-80 BTC F Gsing Description OD(In) ID(in) Top(ftKB) Set Depth(KKB) Set Depth(TVD)...WELen(I...Grade •Top Thread IP + PRODUCTION 5.5"x3.5" 5 12 4.950 28.6 6,328.3 5,703.7 15.50 L-80 BTCMOD auu.@5584' Tubing Strings - , Tubing Description 'String Ma.,.I ID(in) I Top(KKB) I Set Depth(ft..1 Set Depth(ND)(...I WI(lb/ft) 'Grade 'Top Connection TUBING 31/2 2.992 26.4 5,58481 5,0482 9.30 L-80 EUE-8rd Completion Details No Top(ftKB) Top(ND)(ftKB) Top Inei('I Item Corn Des (in)ID cONouc7DR 2p.o-110 p� 26.4 26.4 0.00 HANGER FMC TUBING HANGER 2.992 .n.n-n.vvvvvvvv.:.nnn., 521.3 520.9 5.67 NIPPLE CAMCO DS NIPPLE 2.875 NIPPLE;521.3 fZX5,506.3 4,9802 30.63 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 11/15/2009 2.810 5,522.4 4,994.1 30.37 NIPPLE CAMCO D NIPPLE 2.750 5,5670 5,032.7 29.65 LOCATOR BAKER GBH-22 LOCATOR 3.000 GAS LIFT;2,312.1 , 5.568.2 5.0338 29.63 SEAL BAKER SEAL ASSY 3.000 4� Perforations&Slots Shot Dens Top(ND) Btm(TVD( (shobM Top(ftKB) Bhn(ftKB) )KKB) (NKB) Zone Date t) Type Com 6,045.0 6,065.0 5,449.7 5,467.5 T-3,2P-443 5/13/2004 6.0 APERF 2.5'HSD HJ 2506 RDX, 60 deg phasing 6,065.0 6,080.0 5,467.5 5,480.9 T-3,2P-443 5/4/2004 6.0 RPERF 2.5"HSD HJ 2506 RDX, SURFACE;28.4-2,487.8 60 deg phasing 6,070.0 6,080.0 5,472.0 5,480.9 T-3,2P-443 4/30/2004 6.0 IPERF 2.5"HSD HJ 2506 RDX. 60 deg phasing GAS LIFT;3,581.8 I Stimulations&Treatments Min Top Max Blm Depth Depth Top(ND) Blm(ND) - - (ftKB) (ftKB) (ftKB) (ftKB( Type , Date Co 6,045.0 6,080.0 5,449.7' 5,480.9 FRAC m 5/22/2004 185,0008 16/20 CARBO-LITE PLACED(FMC) //'' ++ Mandrel Inserts GAS LIFT;4,4156 , . SI ati C No Top(TVD) Valve Latch Port Sin TRO Run _ Top(ftKB) )KKB) Make Model OD(in) Sem Type Type (1n) (psi) Run Date m 1 2,312.1 2,208.9 CAMCO KBG-2-9 1 GAS LIFT DMY DK1 0.000 0.0 4/18/2004 2 3,581.6 3,319.7 CAMCO KBG-2-9 1 GAS LIFT DMY DK1 0.000 0.0 4/18/2004 GAS LIFT;5,0308 I i 3 4,415.6 4,032.9 CAMCO KBG-2-9 1 GAS LIFT DMY -DK1 0.000 0.0 4/18/2004 _ _ 4 5,030.9 4568.9 CAMCO KBG-2-9 1 GAS LIFT DMY DK3 0.000 0.0 4/18/2004 5 5,456.6 4,937.5 CAMCO KBG-2-9 1 GAS LIFT OV BTM 0.313 0.0 2/5/2014 GAS LIFT;5,460.8 ® Notes:General&Safety End Date Annotation L - 11/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 SLEEVE-C;5,500,3 i NIPPLE;5,522.1gi LOCATOR;5,587.04 SEAL;5,508.2 . - APERF;8,045.0-0,005.0 FRAC;0,045.0 RPERF;8,085.0-0.080.0 - IPERF;807006,080.0 PRODUCTION 5.5Y3.5- 8/5584';2884328.3 e e 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. JO<:l-- 03~Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 75 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VVES ~ Date:blra-Io~ If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 11I11111111 ""1111 R'7CAN ¢ Color Items: o Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: NOTES: BY: ~ Date (P/Ió/00 Project Proofing Date ft¡l¿jo In ~ X 30 = (Pb Date /; Ie If) it; BY: c-C'lVIaria ;:> Scanning Preparation BY: C. Maria ) BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed ""1111111 II "1111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: VUf III 1111111111111111 151 151 mP + lif = TOTAL PAGES 7'-1 (Count does not include cover sheet)~ AA P 151 r r t III 111111111111111I 151 NO 'W)IP YES NO 151 III 1111111111111111 1111111111111111111 151 Quality Checked 111111111111 II 11111 10/6/2005 Well History File Cover Page.doc IP 10, James B (DOA) torn: NSK Problem Well Supv [n1617 @conocophillips.com] cent: Sunday, November 06, 2011 11:37 AM fo: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: 2P -443 (PTD 204 -032) Report of sustained casing pressure 11 -06 -11 Attachments: 2P-443 90 day TIO.ppt; 2P-443 schematic.pdf Tom, Jim, Meltwater gas lifted producer 2P-443 (PTD 204 -032) is reported to have sustained casing pressure on the inner annulus after shutting in the well. An intermittently faulty OV is suspected and slickline should be getting on the well in a couple of days to troubleshoot. Following the similar event in September, a passing TIFL was obtained on September 27. Attached are the schematic and 90 day TIO plot. We will keep you apprised of the situation. Please call if you have any questions. 5Cp Brent Rogers / Kelly Lyons Problem Wells Supervisor tttP /P = 45 ConocoPhillips Alaska, Inc :. - 7.000F .' Desk Phone (907) 659 -7224 i }t� d ia' Pager (907) 659 -7000 pgr 909 {' ?" I`w tikAxtip 30, it 1 I "'i 20 4 -03-z_ Well Name 2P-443 Notes: ' -,1 . 1'i, , ,Inf , - Stalt Date 8/817011 Days 90 End Date 11/6)2011 Annular Communication Surveillance 4000 - WHP — 90 1AP OAP - 60 3500 - WHT - 70 3000 IL- - 60 2E - 50u. CO .Q ' - 30 1000 4 . - 20 500 - 10 0 r 0 Aug -11 Oct -11 DGI Mr • 6 StiNl m ..BLPD r51.".."""."14111.*-- = 60 40 20 0 d Aug-11 Sep-11 Oct-11 Nov -11 flat4 1 a P 2P-443 • ConocoP 1 rlr. 4 , = , • D ii ,`� � `ar a • Walther* APW WI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) AiaSk7• t g i 501032048700 MELTWATER PROD 31.58 3,606.56 6,334.0 " ` Comment H2S (ppm Date Annotation End Date KB -0rd (R) Rig Release Date ••• Well Con,. 2P-443 /101013440 PM SSSV: NIPPLE 120 10/21/2007 Last WO: 35.11 4/19/2004 ScMmele -Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 6,147.0 8/11/2009 Rev Reason: GLV C/O L_ Imosbor 8/7/2010 1: String OD String ID Set Depth Set Depth (ND) String Wt String Ca D e s cription (In) (In) Top (nKB) IRKS) (ftKB) (Ibs /n) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H-40 WELDED SURFACE 95/8 8.697 0.0 2,487.0 2,361.9 40.00 L-80 BTCM 1 r 11,.. I PRODUCTION 512 4.950 0.0 5,586.0 5,049.3 15.50 L -80 EUE HANGER, 28 PRODUCTION 3 1/2 2.992 5,586.0 6,328.0 5,703.4 9.30 L -80 BTCM ° 'e 31 11 11sS fi n:... j String 00 String ID Set Depth Set Depth (ND) String Wt String CONDUCTOR, Tubing Description (in) (in) Top (ftKB) (nKB) MKS) (Ibs /ft) Grade String Top Thrd TUBING 31/2 2.992 0.0 5,586.0 5,049.3 9.30 L -80 EUE Other In Hole (All Jewelry: Tubinc Run & Retrievable, Fish, etc.) To Depth (TVD) Top Inc! NIPPLE, 523 Top (IIKB) (nKB) ( °) De comment Run Date ID (in) 28 28.0 0.00 HANGER FMC TUBING HANGER 4/182004 3.500 523 522.5 5.86 NIPPLE CAMCO DS NIPPLE W/2.875" PROFILE 4/18/2004 2.875 2 ,313 2,209.7 29.09 GAS LIFT CAMCO/KBG -2 -9/1 /DMY/DK -1/// Comment: STA 1 4/18/2004 2.900 3,583 3,320.9 31.61 GAS LIFT CAMCO/KBG-2-9/1/DMY/DK-1/// Comment: STA 2 4/18/2004 2.900 '1 4,417 4,034.2 30.46 GAS LIFT CAMCO/KBG- 2- 9/1 /DMY/DK -1/// Comment: STA 3 4/18/2004 2.900 5,032 4, 570.0 29.63 GAS LIFT CAMCO/KBG-2-9/1/DMY/DK-3/// Comment: STA 4 4/18/2004 2.900 5,458 4,939.0 31.41 GAS LIFT CAMCO/KBG- 2- 9 /1/OVBTM /.25// Comment: STA 5 7/22/2010 2.900 SURFACE, 5,508 4,981.7 30.60 SLEEVE -C BAKER CMU SLIDING SLEEVE - CLOSED 11/152009 4/18/2004 2.810 2'461 5,524 4,995.5 30.34 NIPPLE CAMCO 'D' NIPPLE 4/18/2004 2.750 5,5691 5,034.51 29.62�SEAL BAKER 0-22 LOCATOR SEAL ASSEMBLY 4/182004 3.000 ,. ]t,.;r ) v �"ihl� "' "'r) I GASUrr, Perforations & Slots . ,,,, a , 0 r�-° ' .L 8 3,583 Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (nKB) (MB) (nKB) Zone Date (sh••• T Comment 6,045 6,065 5,449.7 5,467.5 T -3, 2P- 443 5/13/2004 6.0 APERF 2.5" HSD HJ 2508 RDX, 60 deg phasing GAS LIFT, 6,065 6,080 5,467.5 5,480.9 T -3, 2P- 443 5/4/2004 6.0 RPERF 2.5" HSD HJ 2506 RDX, 60 deg 4,417 phasing 6,070 6,080 5,472.0 5,480.9 T -3, 2P- 443 4/302004 6.0 IPERF 2.5" HSD HJ 2506 RDX, 60 deg p hasing Stimulations & Treatments Bottom MM Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (nKB) (nKB) (nKB) (nKB) Type Date Comment GAS LIFT, o32 - 6,045.0 6,080.0 5,449.7 5,480.9 FRAC 5/22/2004 185,000# 16/20 CARBO -LITE PLACED (FMC) i 7 s, r GAS LIFT, 5,458 I SLEEVE -C, 5,508 NIPPLE, 5,524 II.. .. 1 SEAL, 5,569 5. PRODUCTION. > MPf = 5 / P Gd I 1 �7 V APERF. 6,0404,065 ` _ FRAC, 6.045 91 RPERF, 6,0854,080 ti 8,070 -6,080 PRODUCTION, 6,320 TD, 6,334 ~ • • UVELL L!.?G T/4AN~~/I/~AL ,,. PrcoAcrive D'iaynosric SeRmES, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Aiaska 99501 (907) 659-5102 RE : Cased Hole/Open Hote/Mechanical Logs and/orTubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the following _ BP Exploration (Alaska], Inc. Petrotechnical CJata Center Attn: Joe Lastuflca LR2-1 (~~-C,° 1~~1-1b~ 900 Benson Blvd. ~ ~L~`~ ~ Anchorage, Alaska 99508 and ~,~ '~~-I -b~~ 1 ~/sc~ ProActive Diagnostic Services, lnc~ Attn: Robert /k. Richey , ~ ~~E.,;, 130 West International Airport Roa~,~,~,t~~:~~~% ~,~1::{ '~` Suite C Anchorage, AK 99518 Fax (907) 245,8952 1) Caliper Repo~t 1&Aug-09 2K 18 2) Caliper Report 20 Aug-09 2R443 Signed : Print Name: 1 Report / EDE 50-103-2017 7-00 1 Report ~ .~-~ 4~7-00 ~_ ~UG 2 8 2009 Date :. " _~ ~il ~ Gas Cuns. "L'orr~°~i~ic?~ . ,~nchorage PROACTiVE DIAGNOSTIC SERVICES, INC., 13Q W. MITERNATIONA~ AIRPORT RD SUITE C, ANCHORA6E, AK 99$18 PHONE: (907)245-8951 FAX: (907)24$-88952 E-MAiI: pdsanchoraaeCc~memoryloa.com WeBS~TE:www.memorvlog.com ~ C:~Documen6 and Setbngs\Owner~T)esktop\Ttansmit_BP.docx • • Memory Magnetic Thickness Too! ~ Log Results Summary _ - Company: --- ConocQPhillips Alaska, Ina Well: 2P-443 Log Date: August Z0, 2009 Field: Meltwater Log No. : 6771 State: Alaska RUn NO.: 2(1~ MIT, 2"d MTTj API NO.: 50-103-20487-00 Pipe1 Desc.: 3.5" 9.3 Ib. L-80 EUE / BTCM Top Log Irttvll.: 5urface Pipe1 Use: Tubing and Production Casing Bot. Log Intvl9.: 5,612 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib, L-80 EUE Top Lag Intvl2.: Surface (MTT only) F'ipe2 Use: Production Casing Bot. Log Intvl2.: 5,586 Ft. (MDj (MTT only) Pipe3 Desc.: 9.625" 40 Ib. L-80 BTCM Top Log Intv13.: Surtace (M'TT only) Pipe3 Use: Surtace Casing Bot. Log Intvl3.: 2,487 Ft. (MD) (MTT only) Pipe4 Desc.: 16" 62.51b H-40 Welded Top Log Intvl4.: Surtace (MTT only) Pipe4 Use: Conductor Bot. Log Infirl4.: 110 Ft. (MD) (MTT only) lnspection Type : Metal Loss to Tubing and Production Casing COMMENTS : Th/s caliper/MTT data is tied into the Tubing Tail ae 5,586 ft. (Dril/er's Depth). This is the flrst time this well has been logged with a PDS Multi-Finger Catiper and the second time with a 12 Arm Magne#ic Thickness Tool (MTT). Passes at 5Hz (surtace to 5,606') and 1QHz (bottom of the 9 5/8" surface casing to 5,606') were made at 20 fpm. The ability of the fower frequency signals to permeate more metal volume make it possible to assess the metal volume within the 9 518" surface casing with the 5Hz pass. Due to the high signal to noise ratio within the 9 5/8" sur#ace casing, data filtering has been apptied ta the 5Hz pass over the intenral that includes the 9.625" surface casing. ~~; r`~A.~'~~:~.~r ~:~.`tl~, ~. ?~' ~:Ul~~ w;~< COMPARISON TO PREVIOUS MTT LOG RESULTS : A comparison of the currer~t 10Hz pass to the previous 10Hz pass (July 29, 2007) indicates no significant change in metal thickness during the time between logs. A log ~ot overlay from 2,490' to 2,850' of the average metal thicknesses recorded by the MTT for the ~urrent and previous log is included in this report. The current logging speed is 20 fpm while the previous log was run at 40 fpm. 7he slower logging speed used for the current log results in a much more stable tool response to metal volume surrounding it, and is believed to be a significant facEor to any differences betweetr the twa consecutive logs. ~ INTERPRE7ATION OF CALIPER LOG RESULTS : ' This log was run to assess the condition of the tubing produotion casing with respect to internal corrosive and mschanical damage. The caliper recordings indicate the 3.5" tubing and casing fogged is in gaod condition, wi#h the exception of a 24°~ waH penetration recorded in an area of line corrosion in joint 172 {5,537'). Na other signifrcant watl penetrations are recorded throughout the 3.5" tubing and casing logged. No significant ' areas of cross-sectional walf loss or I.D. restrictions are recorded throughout the 3.5" tubing and casing Ivgged. 3.5" TUBING ~ CASING - MAXIMUM RECORDED WALL PENETRATIONS : ' Line Corrosion ( 24%) Jt. 172 ~ 5,537 Ft. (MD) ' No other significant wall penetrations (> 19%) are recorded throughout the 3.5" tubing and casing logged. ProActive Diagnostic Services, Inc. J P.Q. Box 136°, Stafford, TX ?7497 Phone: (281) or (888) 5b5-9085 Fax: (281} 565-1369 E-mail: PD,~memorylog.com ~ Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (9Q7) 659-2314 I , '' 1 ~f'~~d` - ~~c~ ~ `6~ ~c~ i ~ 3.5" TUBING ~ GASING - MAXIMUM RECORDED CRflSS-SEGTI~NAL METAL L~SS : No significant areas of cross-sectional wall loss (> 6°~} are recorded throughout the 3.5" tubing and casing logged. 3.5" TUBING & CASING - MAXIMUM REC~RDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the 3.5" tubing and casing togged. INTERPRETATION G1F MTT LOG RESULTS : Plots of average metal thickness as recorded by the MTT at 5Hz and 10Hz on a joirrt-by joint basis are included in this report. The 5Hz MTT fog results cwer the interval from surtace to 5,606', while the 10Hz MTT log results cover the interval ftom 2,486' (bottom of the 9 5/8° surface casing) to 5,606'. Changes in metal volume are relative to the calibration points at 870', 4,850' and 5,600', where the readings are assumed to represenfi undamaged pipe, All other readings are relative to these reference points, which indude influences fram the 3.5~ tubing and production casing, 5.5" production casing, 9.625" surtace casing and 16" conductor pipe. , The MTT lpg results indicate aver~ge overall metal foss ranging from 1% to 6°~ over the entire logged interval. Within the surface casing, apparent bands of isotated metal loss, revealed by the 12 radia! sensor readings, appears to be more prominent above 700' and below ~1,500', where greater metal loss is indicated ' by the Delta Metal Thickness curve. A maximum overall metal vofume loss of 6°~ indicated in joint 77 (2,445' - 2,475'), above the bottom of the surtace casing. A 1" scale log plbt of the 5Hz recordings (surface ta 2,486'), along with the filtered Delta Metal Thickness curve, is included in this report. ' ~elow the surface casing, most of the fluctuation in metat volume obsetved appears to be related to differences in manufactured toterances in the tubing and casing joints. A 5°r6 overall metal volume loss is indicated in joint 135 (4,284' -4,314') in both the 5Hz and 10H~ passes, which is believed to be associated , with a thinner tubing }oint. A comparison plot of the 5Hz and 10Hz from the bottom of the 9 5/8" surtace casing (2,486') to 5,606', presented on a 1" scale, is included in this report, An overlay of the overall change in metal thickness (%} as asse.ssed from the 5Hz and 10Hz passes is presented with the comparison plot of the data from the twa passes. In this plot, indications of isoiated metal Ivss, characterized by high frequency ' signal oscillation, are recorded in both the 10Hz and 5Hz passes, and appear to be more prevalent and prominent in the 5Hz pass than in the 10Hz pass. The greater frequency of isola#ed metal loss events in the 5Flz pass compared to the 90Hz pass suggests any damage represented throughout the loggec! interval is more heavily weighted toward the outer casing strings. However, the appearance of some indications of ' isolated metal loss in the 10Hz pass points to the possibility of damage to the outside of the tubing as well. The distribution of inetal loss between the concentric strings is speculative. An expanded log plot of tfie side- by-side 5Hz and 10Nz MTT recordings over the i~terval 3,325' to 3,680` is induded in this report. ' The percent circumferential metal (oss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5" tubing/casing, 5_5" production casing, 9.625" and 16" conductor pipe. If all of the metal loss is specific to the tubing or casing, the percent meta( loss from ' that pipe alone is probably higher than the numbers expressed. ' Field Engineer: N_ Kesseru Anatyst: HY. Yang Witness: C. Fifzpatrick ~ ProACtive Diagnostic Services, Inc. / P.O, Box 1369, Stafford, TX 77497 Phane: (281) or (888) 565-9085 Fax: {281) 565-1369 Email: PDS(amemarylog.com ~~ Prudhoe Bay Field {Jffice Phone: (907) 659-2307 Fax: (907) 659-2314 , ~ ~ Correlation of Recorded Damage to Borehole Profile S Pipe 1 3.5 in (15.2' - 5595.4') Well: 2P-443 Field: Meltwater Cornpany: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 20, 2009 LL~ Approx. Tool Deviabon . Approx. Borehole Profilc 1 ti 794 1576 GLM 1 2382 0 ~ 3168 - ~ GLM 2 •~ s ~ ~ a~ 3968 ~ GLM 3 4774 GLM 4 GLM S 173 5595 0 50 100 Damage Profile (% wall) / l~ool Deviation (degrees) Bottom of Survey = 173 1 25 50 75 a`, 100 ~ E ~ c ~ 125 150 • • PDS Report Overview ~t S. Body Region Analysis Well: 2 P-443 Survey Date: August 20, 2009 Field: Meltwater Tool Type: UW MFC 2Q No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 93 f L-80 EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 200 50 ~ 1 00 1 50 ~ d ~ 0 to 1 to 10 to 1%~ 10% 20% 20 to 40 to over 40% 8S°/p 85% Number of ~oints anal se d rotal = 193 pene loss . 2 184 6 131 62 0 1 0 0 0 0 0 Damage Configuration ( body ) 10 0 isolated qenetal Gne ring hole / poss pitting corrosion corrosion corrosion iblehole Number of ~oints dama ed total = 1 0 1 0 0 0 Damage Profile (% wall) ~ penetration body ,~~.~ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 173 Analysis Overview page 2 ~ • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE Well: 2P-443 Body Wali: 0.254 in Field: Meltwate~ Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 20, 2009 )oint No. )t. Depth (Ft.) I'c~n. tlExc~t (Ins.) Pen. Body (Ins.} Pc~n. % ~U~~t~al loss "~, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 15 U 0.01 2 1 2.96 PUP 1 18 t1 002 7 i 2. 6 1.1 5 t) 0.0 7 ~1 91 PUP 1. 52 U 0.02 t3 ~ 2.93 PUP 13 6 U 0.01 (~ l) 2.9 P 2 7 (~ 0.02 £i 0 .97 3 104 t) 0.01 6 1 2.96 4 1 5 0 0.01 5 1 .94 5 166 U 0.01 t~ ~' .97 6 198 t~ 0.02 7 I 2.98 7 229 l~ OA2 8 1 2.96 8 2 1 u 0.02 1 2.96 9 292 t~ 0.02 7 1 2. 7 1 3 4 ~~ 0.0 7 I 2.97 11 355 0 0.02 ~ 1 2.98 1 387 l~ 0.02 ' I 2.98 13 418 u 0 02 1 2.97 14 449 l ~ 0.01 6 I .98 15 480 t) 0.02 7 -l 2.93 15.1 511 u 0 t) U 2.88 Camco DS Ni le 16 513 l) 0.0 ti I .97 17 545 O 0.02 7 4 .94 18 576 U 0.01 6 _' 2.97 19 607 (~ 0.02 - ' 2.97 2 639 u 0. 2 t3 I 2.96 21 670 ~~ U.02 - 1 2.97 22 7 1 U 0.02 ~4 2. 3 23 733 ~~ 0.02 7 Z 2.94 763 ~~ 0.0 7 ~ 2. 6 25 794 (1 0.02 i ~ 2.94 26 826 ( i 0.0 7 Z .94 7 857 u 0.01 (~ ~' 2.94 8 888 ~ 1 0.02 i t~ 2.95 29 919 l~ 0.02 i -l 2.94 30 950 ~~ 0 02 1 2.94 31 982 ~ 1 0.02 i U 2.93 32 1012 ~> 0.0 i ' .93 33 1043 ~~ 0.02 7 > 2.93 34 1073 ~~ 0.02 t3 I 2.95 35 1105 U 0.02 i + 2.95 36 1136 ~~ 0.02 7 1 2. 37 1168 ~~ 0.02 7 ? 2.95 38 199 t) 0.02 i `i 2.94 39 1231 u 0.02 i -t 2.93 12 2 ~ ~ 0.01 ~, I 2.94 41 1294 0 0.02 ~) ~1 2.96 42 1326 l~ 0.0 7 5 .96 43 1357 U 0.02 i 1 2.94 44 13 8 ~? .02 % -1 2.93 45 1420 i~ 0.02 I 2.94 Penetration Body ' Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEf Pipe: 3.5 in 9.3 ppf L-80 EUE Well: 2P-443 Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 20, 2009 Joint No. Jt Depth (Ft.) I'~_•n. IIE„E~t (Irn.) Pen. Body (Ins.) Pen. %, Mctal loss °~'~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1451 ~? 0.02 7 1 2.93 47 1482 U 0.01 4 1 2.97 48 1513 ~~ 0.02 7 ' .93 49 1545 (~ 0.02 9 1 2.97 50 1576 ~~ 0.01 5 t 2.97 S1 1608 l~ 0.01 ~ -t 2.97 52 1639 u 0.02 - ;? 2. 3 53 1671 i~ 0.02 1 2.94 54 1702 i~ 0.02 ~ ' 2.92 55 1734 U 0.02 t3 I 2.97 56 1765 ~ 1 0.01 E.~ -3 2.97 57 1796 ll 0.0' fi U 2.98 58 1828 (~ 0.01 t, 1 2.96 59 186 t~ 0.01 G 1 2.97 60 1891 u 0.01 -~ ~~ 2.97 61 1 23 ~? 0.02 7 1 2.97 62 1954 ~~ 0.02 ~~ i 2.97 63 1986 ( t Q.01 i I 2.98 64 2017 U 0.01 (~ 1 2.97 65 2049 c ~ 0.02 - i 2.95 6 2080 (? 0.02 - 2.92 67 2112 ~ ) 0.02 - .92 68 2143 i) 0.02 ~~ U 2 95 69 2175 i~ 0.02 ~~ I 2.92 70 2206 ~~ 0.0 7 I 2.92 71 2238 U 0.02 i I 2.95 72 2269 U 0.01 6 I 2.94 72.1 2301 u 0.01 b u 2.96 PUP 72.2 2307 l~ 0 O 0 N GLM 1 atch C~ 1:30 23 2315 l) 0.01 2 1 2.95 PUP 73 2319 l1 0.01 2 1 2.96 74 2350 l~ 0.01 -1 I 2.97 75 2382 U 0.02 7 1 2.96 76 2413 ~1 0.01 5 1 2.97 77 2445 (~ 0.01 ~ ' 2 98 78 2476 ~~ OA2 ' I 2.97 79 2508 U 0.01 4 1 2.96 80 2539 t~ 0.02 7 I 2.97 81 2570 U 0.01 E~ 1 2 96 82 2602 ~~ 0.02 - I 2.95 83 2633 t~ 0.02 ff I 2. 5 84 2665 ~~ 0.01 4 1 2.96 85 2696 l~ 0.01 -1 2.96 86 2728 t~ 0.02 7 I 2.97 87 2759 U 0.02 i 1 2.98 88 2790 U 0.02 8 t~ 2.97 89 2821 i 1 0.01 5 U 2.96 90 2852 t) 0.02 t3 1 2.96 91 2884 ~~ 0.02 t9 1 2.97 92 2915 u 0.02 tt ti 2.95 ~Penetration Body Metal Loss Body Page 2 • . PDS REPORT J~INT TABULATION SHEEf Nipe: 3.5 in 93 ppf L-80 EUE Well: 2P-443 Body Wall: 0.254 in Field: Mellwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Suroey Date: August 20, 2009 Joint No. )t. Depth (Ft.) f'~~n. ~~F~sc•i (Irn.) Pen. Body (Ins.) I'c~n. °o Metal lo~s °~~, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 93 2947 i? 0.01 l) 2.97 94 2978 ~ 1 0.02 i I 2.97 95 3010 t~ . 1 2 1 2.96 96 3041 ~~ 0.02 t3 I 2.96 97 3 73 l~ 0.02 t~ I 2.96 98 3104 (~ 0.0 7 ' 2,97 99 3136 ~ ~ 0.02 ' 2.9 100 316II l1 0.02 ~ 1 2.97 101 3199 U 0.02 ' 1 2.98 102 3231 ~~ 0.02 8 ? 2.96 103 3262 U 0.02 t3 1 2.96 104 3294 ~~ 0.01 5 ~' 2.97 105 3325 ~~ 0.02 ~ ~' 2.94 106 356 t~ 0.01 5 2.96 107 3388 U 0.02 7 I 2.94 108 3419 U 0.02 ti 1 2.95 109 3450 U 0.02 7 I 2.95 110 3482 (~ 0.02 ~ I .95 111 3513 U 0.01 6 ~~ 2.9 112 3542 t~ .02 3 I 2.96 112.1 3573 u 0.02 7 ~ 2 94 PUP 11 .2 3579 U 0 U t) N A GLM 2 Latch ~ 730 11 3 3586 U 0.01 ' ~~ 2.93 PUP 113 3591 t) 0.01 ! ~~ 2.96 11 3623 U 0. 2 ~ I 2.95 115 3654 U 0.01 ~1 I 2.98 116 3685 O OA tf 1 2.94 117 3716 t~ OA 8 1 2.98 118 374f3 (1 0.0 7 2 .97 119 3780 (1 0.02 £3 ? 2.97 120 381 1 ~ ~ 0. 7 1 2. 121 3843 ~~ 0.02 ~ I 2.97 122 3874 U 0.02 t3 ' 2.98 123 3905 U 0.02 ~ ' 2.94 124 3937 (~ OA t~ I 2.96 125 3968 l) 0.01 b I 2.96 126 4000 U 0.02 7 I 2.98 127 4031 U 0.02 t3 1 2.97 128 4063 ~~ 0. 1 5 1 2.97 129 4094 ~? OA2 fi 1 2.97 130 4126 ~~ 0.01 (, .96 131 4157 0 0.02 7 1 2.97 32 4188 l) 0 02 ~ ~; 2.96 133 4221 u 0.02 7 1 2.96 134 252 U 0.02 8 u 2.95 135 4283 U 0.02 S I 2.96 136 4314 ~~ 0.02 7 1 2.96 137 4346 ~~ 0.0 £3 1 2.98 138 4377 0.03 11 1 .9 138.1 4409 i~ 0.01 i 1 2.97 PUP Penetration Body Metal Loss Body Page 3 • . PDS REPORT JOINT TABULATION SHEEf Pipe: 3.5 in 9.3 ppf 1_-80 EUE Weil: 2P-443 Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 20, 2009 Joint No. Jt. Depth (Ft.) I'en. l 1E„c•i Ilm.) Pen. Body (Ins.) Pen. %, ~1~~t.jl I c>ss °~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 138.2 4415 ~ a 0 U ~) N A L.M 3 latch C4 6:30 138.3 4420 ~~ 0.03 11 i 2.94 PUP 139 4427 !~ 0.01 ~ I 2.97 140 4458 u 0.02 f3 1 2.97 141 4490 ~ ~ 0.02 I .97 142 4521 la 0.01 ~i i 2.96 143 4553 U 0.01 ~ I 2.98 144 4585 (~ 0.02 ~ I 2.97 14 4616 (~ .0 8 I 2.97 146 4647 ~~ 0.02 t3 1 2.96 147 4679 t1 0.02 1 2.94 14f3 4710 U 0.02 8 I .96 149 4742 1 0.0 ti ~~ .96 150 774 t~ 0 02 8 I 2. 6 151 4805 i~ 0.02 fi I 2.97 15 4836 ~~ 0.02 t3 _' .96 153 4868 O 0.01 6 1 2.96 154 489 t~ 0 0 ~ I 2.96 155 4931 ~ 1 0.01 5 1 2.97 156 4962 tl 0.01 6 I .96 157 4994 (~ 0.03 11 I 2.90 157.1 5026 U 0.01 (_~ ~ 2.96 PUN 157.2 5031 ~~ 0 U U N A GLM 4 Latch ~ 430 157.3 5040 i1 0.00 1 I 2.95 PUP 15 5043 t) 0. 1 2 I 2.9 159 5075 U 0.02 £3 n 2.97 160 5106 U 0.02 8 I 2.95 161 5138 l~ 0.02 8 ' 2.96 16 5169 t) 0.01 (~ 2.95 163 5200 (1 0.02 F3 I 2.96 164 523 ll 0.0 5 _' 2.96 165 5263 U 0.01 ~' ' 2.96 166 5295 t~ 0.02 £3 1 2.95 167 5326 U 0.02 t3 _' 2.96 168 5358 ~~ 0. 2 ti I .96 169 5389 n 0.02 ti I 2.96 170 5 21 u 0. 2 t~ I 2.96 170.1 5452 t) 0.01 G I 2.96 PUP 170.2 5458 ~~ 0 0 ~~ N A GLM 5 Latch ~ 7: 0 1703 5466 ~~ 0.00 1 ~' 2.93 PUP 171 5470 t) 0.01 2 1 2.96 171.1 5502 +) 0.02 7 I 2.93 PUP 17 .2 5508 U 0 0 (1 2.81 aker CMU Slidin Sleeve 171.3 5513 ~~ 0.01 2 I 2.94 PUP 171.4 5 18 ~~ .Ot 5 I 2.95 PUP U1.5 5524 u 0 ~~ ~~ 2J5 Camco D Ni le 171.6 5526 ~) 0.04 17 2.96 PUP 172 5531 tl 0.06 ?4 .' 2.92 Line corrosion. 172.1 5562 i? OA £i u 2.92 PUP 172.2 5568 n 0 U l~ 3.00 Baker G22 Locator Seal Assembl ''' Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE Well: 2P-443 Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 20, 2009 )oint No. Jt Depch (Ft.) I'~•n. UF>sci (In~.) Pen. Body (Ins.) I'~~n. °I> Me~1,~1 lus~ "~~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 172.3 5 6 ~1 0 U U N A Tubin T il 172.4 5591 ~~ 0.05 1~ i ' 2 98 PUP 1 st t. 3.5" Produ ti n C sin 173 5595 ! ~ 0.05 1~ ~ .96 Penetration Body Metal Loss Body Page 5 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~S PDS Report Cross Sections bNell: 2P-443 Survey Date: August 20, 2009 Field: Meltwater Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Too! Size: 1.69 Country: USA No. of Fingers: 14 Tubin : 3.5 ins 9.3 f L-80 EUE Anal st HY. Yan Cross Section for Joint 172 at depth 5537.26 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviation = 28 ° Finger 11 Penetration = 0.06 ins Line Corrosion 0.06 ins. = 24% Watl Penetration HIGH SIDE = UP ~ r~ LJ Cross Sections page 1 ~ Comparison to Previous MT~ogs Overlay 2P-443 P~ ou-q«ont~ seR~ca„ ~~. August 20, 2Q09 and July 29, 2007 Database Fite: d:lwarrioridatal~ archive12~4431comp.db Dataset Pathname: run/comp Presentation Format: comparis Dataset Creation: Fri Aug 21 14:31:39 2009 Charted by: Depth in Feet scaled 1:240 -20 Delta Metal Thickness 2009 (10Hz) (%j -20 Delta Metal Thickness ~007 (10Hzy (%) 20 20 Bottom of 9.625" Surface Casin_ 2500 2520 ;-} ~ ~ ~ ~ ~ Delta Metal Thickness 2009 (10H~ , ~ ~ ~ ~ ~ ~ Delta Metal Thickness 2007 2540 ~560 2580 ~600 '~6"ZO 2640 ~ ~660 ~680 ~700 2720 2740 ~760 2780 ~800 28~0 elta Metal Thickness ~007 (10Hz)_ _ 2F340 - -- - Delta Metal Thickness 2009 (10Hz) -20 Delta Metal Thickness ~009 (10Hz) (%) 20 -20 Delta Metal Thir.,kness 2007 (10Hz) (%) 20 ~ ~ 5Hz Average Recorded Metal Thickness Relative to Calibration Point 3.5" Tu6ing / 5.5" Prod. Casing / 9 5/8" Surf. Casing Well: 2P-443 Field: Meltwater Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 20, 2009 ^ Decrease ^ Increase 1 18 25 794 50 1576 GLM 1 75 2382 ~ ~ v 100 3168 ~ ~ ~ " Z GLM 2 s c ~- ° 125 3968 0 GLM 3 150 4774 GLM 4 • GLM 5 Slitlirg Sleeve / D Nipple Seal Assembly 173 5595 -50% 0 50% Change in Metal Thickness (%) [3ottom of Survey = 173 • ! l OHz Average Recorded Metal Thickness Relative to Calibration Point 3.5" Tubing / 5.5" Prod. Casing Well: 2P-443 Field: Meltwater Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 20, 2009 ^ D ecrease ^ In crease 80 2539 90 2852 100 3168 110 3482 GLM 2 120 3811 ~ ` ~ a , ~ 130 - 4126 ~ ~ .~ Z s y W 'o GLM 3 v ~ 140 4458 150 4774 GLM 4 160 5106 GLM 5 5421 Sliding Sleeve / Nipple SealAssembty 173 5595 - 50% 0 5 0°/a C hange in Metal Thick ness (% ) Bottom of Survey = 173 ~ 5Hz MTT Recordings {Su~e - 2,48~') 2P-443 August 20, 2009 PnvAcdve dLiqr~a~te S~~pAc~, Inc. Database File: filtered mpcmn 5hzpass.db Dataset Pathname: ruNSHzPas.1 Presentation Format: 1.6bw30 Dataset Creatrcan: Sat Aug 2213:35:04 2009 Charted by: Depth in Feet scaled 1:1200 -5Q Delta Metal Thickness 5Q 1.6 MTfPa1 (rad) 31,6 d Line Speed (ft/min) -200 -24.8 MTTP12 (rad) 5.2 Tree Pup Pups 1p0 Metai Thickness 200 3Q0 40~ 500 600 700 800 ~ 900 1000 1100 120Q 1300 ~a~a 1500 1&00 1700 18D0 1900 ~ Comparison - 5Hz & 10Hz~T Passes 2P-443 August 20, 2009 Pwo,Ae~ive Diwqr~asde Sewvlee, Ine. Database File: merge.db Dataset Pathname: run/merge Presentation Format: 1.2&2.4 Dataset Creation: Sun Aug 23 14:~1:48 2009 Charted by: Depth in Feet scaled 1:1200 1.2 MTTP01 (5Hz) (rad) 11.2 2.4 MTTP01 (10Hz) (rad) 12.4 -1D 5Hz Delta Mtl. Thickness (%) 10 -7.6 MTTP12 (5Hz} (rad) 2.4 -6.4 MTTP12 (10Hz) (rad) 3.6 -10 10Hz Delta Mtl. Thickness (%) 10 '?5U0 Pass 26~0 FBottom of 9.625" Surtace Pass Data. 5Hz Delta Metal OHz Delta Metal Thicknes~ 2700 2800 2900 3000 3100 3~00 ~oo ~aoo 3500 GLM 2 :3600 3700 saao 3900 4000 4100 4200 4300 ~ ~oo M3 4500 4600 470U 4800 4900 5~00 GLM 4 5100 5200 53Q0 5400 GLM 5 • Details of 5Hz & 10Hz MTT Reco~gs (3,325' -3,680') 2P-443 August 20, 2009 R~oAcrive DI~qMOSifc Seavites, Iwc. Database File: d:lwarriorldatal2p-4431p1otslmerge.db Dataset Pathname: runlmerge Presentation Format: 1.2&2.4 Dataset Creation: Sun Aug 23 14:01:48 2Q09 Charted by: Depth in Feet scaled 1:240 1.2 MTTP01 (5Hz} (rad) 11.2 ~.4 MTTP01 (10Hz) (rad) -7.6 MTTP1~ (5Hz) {rad) 2.4 -6.4 MTfP12 {10Hz) (rad) ng Jt. 1 3340 Pas s 3360 Jt. 1 3380 OHz Pass 2.4 -1~ 5Hz Deita Mtl. Thickness (%) 10 3.6 -10 10Hz Delta Mtl. Thickness (%) 10 Deita Metal i 34fl0 Tubing Jt. 1 ~g Jt. 1 3440 3460 nq Jt. 1 ~-~~ KUP ~ 2P-443 ~OIlOCO ~'II~~IpS Well Att ributes Max le 8 ND TD a,, ,... ~ wdw«e 501032048700 dnnwne MELTWATER exstalus PROD rra nr+rype mc+l') (ltl( 31.58 3,606.56 a 1 6.334.0 Commm1 H2 8 (ppn) Oate ArmGtl on ErM Dae Im1iU ~ Rlg Nease D~e - ~ L_ ~, ~ .. SSSV: NIPPLE 120 7/1/2008 last WO: 35.11 4/19/2004 .c-naw~ . Mntatlon ~ FiMDate Last Tag: RICB 6,180.0 7/2&2007 Rev Reason: FORMAT UPDATE 1/4R009 Casi 9tr s ` casne o esa~non st~,e IM) s~meb IMI r pnce~ o~m I~el s~ ) IKKaI su+~yr~ IA~q ~ ~rrig rap nra ! CONDUC TOR 1 6 15.062 0.0 110.0 110.0 6.50 H-40 ELDED SURFACE 95 d8 8.697 0.0 2,487.0 2.361.9 40.00 L-80 BTCM HoN~ER PRODUC TION 51 Y2 4.950 0.0 5,586.0 5.649.3 15.50 L-80 EUE . `~ RODIK TION 3 t f2 2.992 5,586.0 6,328.0 5J03.4 9.30 L~0 BTCM Tubio SMn s nnn n sn oepn se~ oepm 1~1 ~g ~ ~s ~ CONWC(OR. lUEN19D BftllPtlofl IMI (w+) r ~nce~ !~& t~el 1~~4 ~~ strr~r mra 110 . TUBING 31 /2 2.992 0.0 i.586D 5049.3 9.30 L-80 EUE Ofhr I n Hola All Jawe l . TubM Run 8 Ratr Fish Top DepN (7ND) Top Y1q NIPPLE.523 T ~B~ ('~ 11 Ca111nM RVIDi[! ~ ~ 28.0 28.0 O.UG H AN GER FMCTUBINGHANGER 4/1&2004 3.500 i ~ 5 3 0 522.5 5-86 N IP P MCO DS NIPPLE W/2 .875" PROFILE M7 04 2.8 5 2,313.0 2.209.7 29.09G AS LJFT CAMCO/KBG-2-911/DMY /DK-1///Commerrt:5TA7 4/18/2004 2.900 cAS uFr - 3,5 3.0 3,320.9 31.61 G AS LI CAMCOIKBG-2-9/1/DAq1' /DK-1///CommeM: STA2 4! &2004 2. 0 , z.a~s 4.41 .0 4,0341 30.46G AS L1 CAMCOlKBG-2-9I1IDMV /DK-1///CommenC S A3 4/iS/2004 2.900 5,032.0 4.6/0.0 29.83 G AS LIFT CAMCOIKBG-2- l1l /pK-3!//Con'imenC STA4 M78l2004 2.900 - 5,458.0 ,979.0 31.41 G AS LIFT CAMCO/KBG-2-9I1lOMY 76TNV// CommeM: STA 5 5/25l2005 2.900 suHFnce. 2 as7 5,508.0 4,981.7 .605 LE EVEO BAKERCMUSLIDINGS LEEVE-O ENED7YL82007 4l18l2W4 2.810 . 5,508.0 4,98 .7 30.60 UM P TRICO ° RC JET PU P 1N 2.81" CMU ~ 5508' RKB. S/N: 7l29Y200 0.000 PH-1053, 9 NOZZLE, 9 THROAT, 9A RATIO on 2.81" CS-LOCK sct 7/29/2007 ~rvsuFr. 3 563 5,524.0 4,995.6 30.34 N IP P E CAMCO'D'NIPPLE 4/18I2004 2J50 5,569.0 5.034. 29.62 EA L BAKER G-22 LOCATOF3 SEAL AS3EMBLY M18/2004 3.000 Parfora Hons ToP (ivD) &m (TVO) sna Denc ~ns uFr T 6mi Iftlm ) I~W I~el Zone oate 1~- canment . <pv 6,045.0 6,065. D 5.449J 5,467.5 5l13l2004 6.0 APERF 2.5" HSD HJ 2506 DX, 60 deg D~~9 6.065.0 6,OSb. O 5,467.5 5,480.9 5I4f2064 6.0 RPERF 2.5° HSD HJ 2506 RDX, 6D deg P~~9 6,070.0 6,080. 0 5,472.0 5,480.9 M30/2004 6.0 IPERF 2.5' HSD HJ 2506 RDX, 60 deg P~~9 Stlmula tions 8 TreaN w~ ts cas ~iFr. eatan 5.032 MnTOp hYxBN1 TopDepVl DePN WPIh DePll~ (1VW (1VW I~i 1~81 I~a I~i oae onn~nc 6.045.0 6,080 A 5.4t9J 5,480.9 F RAC 5/22f2004 185,ODOp 16(20CARBOLffEPLACFD FMC) ens uFr. s ese SLEEVEL. 5 509 PUMP. 5 SOB NIPP~E,5,524 SEAL, S,v69 PRODUCTION. S,S88 pPERF, 600.5{~,OES FRAC. 6 MS R~ERF, 6 O65E 0?0 IPFFF fi OlOF.020 PROOUCTION, 6.328 TD, 6 334 • • ~.. ~~=~ -~ MICROFILMED 03/01/2008 DO NOT PLACE ,.~,' ~_°"~ , -k _ ~a.xY ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertsiMicrofilm Marker.doc -- ConocJ)'hillips Alaska RE -= ;~ ~ 7"'"'\ W 11 i\ oJ~' ;..".. u Î) 200S P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~ ~~23 G-Gmmi3$~Gn ;11i1thûr3~Je June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ... C \ì\.H\i!¡'-"i'\ J'~ q n ~1 2.0G6 Sr\lAr~r~~~' I v £ci= ~. ~ lOLt~03~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfill404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05,2006. Schlumberger Well Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18t\ 19th and 31 S\ 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. ~ ::lJo Perry KleIn ConocoPhillips Problem Well Supervisor \(..,:)f..,-d- d~ Ob/3.ù/tJ6 Attachment .-.- ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Corrosion Well Initial top Vol. of cement Final top of Cement top Royfill4048 inhibitor/ Name PTO# of cement pumped cement off date RG2041 vol vol. sealant date ft bbls ft gal gal 5/19/2006 2P~·., 204-022 4 o~o- 4 na 5.7 1.7.1 5/19/2006. 2P-415a 201-226 5.5 0.0 5.5 na 7.1 30.9 5/19/2006 '2P-4t7 20-1-069 7.5 0.7 2.5 . 5/1/2000- 5] ·9 5/1812006 2P-419 204-017 1 0.0 1 na 6.7 0 5/18/2006 2R;.420 201-182 . 3.5 0:0 3~5 na 7.1 .17.3 ~5I18/2006 2P-422a 202-067 13.5 2.3 2.5 5/1/2006 7.1 10.7 5/18/2006 2P~24a·· ~ 204-009 .4.5 0.0 4.5 na 5.7 17.6 5/18/2006' 2P-427 202-018 10 1.6 2.5 5/1/2006 7.1 13.7 5/18/2006 2Þ2429 . ~ . 201-102 2 0:0 ·2 na 3.8 5.7 5/18/2006 2P-431 202-053 13 1.9 2.5 5/1/2006 7.1 10.1 5/18/2006 2e.4t32 . 202-091 8.5 .0.9 2.5 511/2006 , 5.7 13.8 . 5/18/2006 2P-434 203-153 14 2.0 2.5 5/1/2006 5.7 6.2 5/18/2006 ·2P-438 ·201~082 5 0.0 5 na 5.7 21.9 5/1812006 , 2P-441 202-107 15 2.0 2.5 5/1/2006 7.1 13.1 5/18/2006 2P-443..·· . 2~32· 3.5 0.0 3.5 na 8~7 11.4 5/1812006 : . 2P-447 203-154 2.5 0.0 2.5 na 9.5 0 5/18/2006 2P-448a : 202-005· 1.5 0.0 1.5 na .9.5 0 51-18/2006 2P-449 204-026 3 0.0 3 na 5.7 11.5 5/31/2006 2P-451 202-008 10 2.1 2.5 5/1/2006 t1 6.5 . 5/18/2006 ) ConocóP'hiiii ps Alaska ~ \:c: T\;/fF ..l.~ ~~,} . :I~t¡ :~,~.-r:J'~ J U ¡\\ 1 :~? . i..: 'ì DiJi & G13 C'wij1);'1, J~m;h¡rmj)ír~a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~04-6~?~ June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUN 2 7 2006 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfill 404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05, 2006. Schlumberger Well Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. L ConocoPhillips Problem Well Supervisor Attachment ) ) ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Initial top Vol. of cement Final top of Cement top of cement ft .·4" 5.5 7:~_~.· '.' 1 ··~~5:' . 13.5 . ...: ··tS·.· " :. :' ¡. ,~. 10 .'2:"·' . . 13 ·.fkS·:: 14 5: '.' 15 ·3.5.:.: . 2.5 .1..5' . ..,' 3 . '.1·0 .'. Well Name ~ '.' '. ." , ~.:., -;;.:..: "~ . i.,. . ?·~~r~Bi~ .:":.,';' , . .4I:.h~;tIU . 2P-41 5 r·:Aiæ'iiì¡:î·. .... .."..... . . . 2P-419 rJ1îp~Ð·.' "::,";:.... 2P-422 t~::j~~~4r':: 2P-427 ).:2~9~·. ..,~ ': 2P-431 ·.,2~"2·:.:·':- : 2P-434 '.' ~·:.~2P~S¡à(:::' .~ '. ..' 2P-441 . "~ø/:·.~··· 2P-447 2· 'i"Ï\.....ÇA;o· . ." :. ..:'.'r:-~,:' ........ 2P-449 " ; 2~i:451t: . '.' . pumped bbls . ..Q:¡o·:· .. . ~ 0.0 'O~:7 . 0.0 'J)i()... :. ',' . 2.3 ··.·0':0::·: , .... ... . 1.6 :. ,Ot:è:r··. . ":.", 1.9 .:·0;9·. ' 2.0 .'. ltò::·.. 2.0 .<äo···· .. . f:'" 0.0 . . ····:··alo· 0.0 '. . 2:.1 '. cement ft '~4 . 5.5 . :2i5': " :.. 1 ';'·"3.5: .... 2.5 ¡~4~5· ..' ." 2.5 .~'2:·:~ ' . 2.5 ::;:l~5,~' . 2.5 ·..:·::,::·5'· ,., 2.5 ~3;5'·' 2.5 :;~1'~5,.· . . 3 2.5' Kuparuk Field June 6,2006 off date RG2041 vol gal '. '. ···5~:7. 7.1 .·S~J· 6.7 "·'·.7~·1.': 7.1 '. . 5;7:. 7.1 ·"3~.::8\· . 7.1 ¡ .. .S~:7··:.· 5.7 :" . ··.:5~1,< 7.1 . "~',' . ',';',': .. :'. .,"8·..1·~ -:' 'c',- " 9.5 ..' ·9.5:' 5.7 ',.' .7:1: aa· na ..$l112006... ': , ::-: na . .na¡:,.· 5/1/2006 ·ne;·i.·::,: 5/1/2006 . .;: ;;.' '..na.,:..;, 5/1/2006 . . ~'" 5£1/.6:': 5/1/2006 ':.: ·::-oa:·:;:.:.·: 5/1/2006 :·:-na:< '.' na .tlä·.:· . na ·5/.112006 . Royfill4048 vol. Qal . 1(7~1::' 30.9 ',.9<" o .' . J1.3·.,· 10.7 ··:fl.6:· 13.7 .·5i.7· . 10.1 .... . : 13.'8::' 6.2 ·;'·2t:á:·· 13.1 11'.4 o '0 . 11.5 6l5. Corrosion inhibitor/ sealant date 5/19/2006 .' '. '.:5/1·91200:6": 5/19/2006 . .' ;;- .~ßt.2œEr. 5/18/2006 .; :··:···:;Þ~SI~·:··~·:· 5/18/2006 "'. ··~5Jf8120o.6:~. :" 5/18/2006 ··...·:5l18i20Q'6} ":¡ 5/18/2006 ,,:: . ;:,~:: .$l~::':'>:~': 5/18/2006 ':."<: ";5f~:~ .:~, 5/18/2006 - .":' '.', ."~Mt1.œ: 5/18/2006 . . J:ttöf'o;m~··. .: 1.II·1:qI~~.·, ": . 5/31/2006 .' :511812006:· '" ')-(:) rfk, .~ t. DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040320 Well Name/No. KUPARUK RIV U MELT 2P-443 Operator CONOCOPHILLlPS ALASKA INC MD 6334 -""" TVD 5709"'- Completion Date 4/30/2004 / Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens/Neut Well Log Information: Log/ Data Type ,fRPt ~g Electr Digital Dataset Med/Frmt Number Name Directional Survey Induction/Resistivity "f'vl) Log Log Run Scale Media No Blu Blu Blu Blu /'Log Induction/Resistivity MD fi'og JL09 ..ßY C ~ Density IV" 0 Density fVÞ 12504 See Notes 12504 LIS Verification Cement Evaluation Blu ~ Perforation Well Cores/Samples Information: Name Current Status 1-01L ) r"'c, .Å J fit,..to. '1 API No. 50-103-20487-00-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received 6/17/2004 2496 6334 Open 6/1/2004 2493 6334 Open 6/1/2004 2496 6334 Open 6/1/2004 2496 6334 Open 6/1/2004 2490 6334 6/1/2004 2490 6334 6/1/2004 5430 6150 Case 5/27/2004 . Comments MULTIPLE PROPAGATION RESISTIVITY GR MULTIPLE PROPAGATION RESISTIVITY GR ADVANTAGE POROSITY LOGGING SERVICE ADVANTAGE POROSITY LOGGING SERVICE RWD-GR/MPR/CCN/ORD SCMT/ CEMENT BOND LOG & TEMP WARM BACK SCMT- CB/PBMS-A PERFORATING RECORD W/SBHP & JEWELRY LOG . Blu 5429 6174 Case 5/27/2004 Sample Interval Set Start Stop Sent Received Number Comments Permit to Drill 2040320 MD 6334 TVD 5709 ADDITIONAL INFORMATION y~ Well Cored? Chips Received? - Y / N ~ Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Well Name/No. KUPARUK RIV U MELT 2P-443 Operator CONOCOPHILLlPS ALASKA INC Completion Date 4/30/2004 Completion Status 1-01L Current Status 1·01L Daily History Received? ~: Formation Tops ~ ...... , Date: API No. 50-103-20487-00-00 UIC N ;J. ) r1; ).. ~h . . . ConocJP'hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 5, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 . f':~ r . ~.' ~. "f. ~. )- JU W (j 7 1JÐl),Ç Od 8~ ~->.:. ¡ (;,~: .. Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 2L-311 (PTD # 203-155), 2P-406 (PTD # 204-022), 2P-242A (PTD# 204-009),and 2P-443 (PTD # 204-032) The Sundries report the conversion of each well trom gas lift to surface powered jet pump artificial lift operations. Please call Marie McConnell or me at 659-7224 if you have a y/questions. Sincerely, ~ Problem Well Supervisor Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS , f';\ 'ii: ~bJ.¡.!£.l" I..!d '.::'. , .... '. "'IIi/mer ,.. ..... . Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Repair Well D Pull Tubing D Opera!. ShutdownD Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development _ 0 Stratigraphic D 1" Operations Performed: P. O. Box 100360 7. KB Elevation (ft): RKB 254' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth measured 6334' feet true vertical 5709' feet measured feet true vertical 6276' feet Length Size MD 110' 16" 110' 2233' 9-5/8" 2487' 5332' 5-1/2" 5586' 742' 3-1/2" 6328' Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION Perforation depth: Measured depth: 6045-6080' true vertical depth: 5450-5481' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5586' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 523' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A . jln~ G LÛes Stimulate D Waiver D Time Extension Service Re-enter Suspended Well D 5. Permit to Drill Number: 204-032 6. API Number: 50-103-20487 -00 Exploratory D D 9. Well Name and Number: 2P-443 10. Field/Pool(s): Kuparuk River Field I Meltwater Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 110' 2362' 5049' 5703' RBDMS BFL JUN 07 Z005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation 184 408 18 584 260 Subsequent to operation 42 13 1905 265 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Name MJ Loveland Title S;goaru.e ~j~ Pho", Form 10-404 Revised 04/2004 Problem Wells Supervisor 907-659-7224 Date øt-3D¡tJ¢~- Submit Original Only ,- . 2P-443 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary - Convert from GL to Suñace Powered Jet Pump 5/25/2005 SET 2.75 CA2 PLUG AT 5524' RKB. PULLED OV AT 5458' RKB. PUMPED 110 BBL DSL DOWN lA, UP TBG. MIT TBG & CSG 3000 PSI, PASSED. SET & TESTED DV @ 5458' RKB. OPENED CMU, OPENING VERIFIED. PULLED PLUG. IN PROGRESS. 5/26/20051 SET JET PUMP (SIN: PH1124, 9C RATIO) ON 2.81" CS LOCK AT 5508' RKB IN CMU. , . . . ConocoPhillips Alaska, Inc. Description Size Top Bottom TVD Wt Grade Thread SURFACE - CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED (0-2487, SURFACE 9.625 0 2487 2362 40.00 L-80 BTCM 00:9.625, PRODUCTION 5.500 0 5586 5049 15.50 L-80 EUE WI:40.00) PRODUCTION 3.500 5586 6328 5703 9.30 L-80 BTCM Size Top Bottom TVD Thread ROOUCTION 3.500 0 5586 5049 EUE (0-5586, 00:5.500, Interval TVD Zone Status Ft SPF Date Type Comment WI:15.50) 6045 - 6065 5450 - 5468 20 6 5/13/2004 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6065 - 6070 5468 - 5472 5 6 5/4/2004 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6070 - 6080 5472 - 5481 10 12 5/4/2004 RPERF 2.5" HSD HJ 2506 RDX, 60 TUBING (0-5586, 00:3.500, 10:2.992) KRU 2P-443 API: 501032048700 SSSV Type: NIPPLE Annular Fluid: Well Type: PROD Orig Completion: 4/19/2004 Last W/O: Angle @ TS: deg @ Angle @ TO: 26 deg @ 6334 Rev Reason: Open Sleeve, Set DMY, Set PUMP Last Update: 5/27/2005 Ref Log Date: lD: 6334 ftKB 32 3607 St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2313 2210 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 4/18/2004 2 3583 3321 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 4/18/2004 3 4417 4034 CAMeo KBG-2-9 DMY 1.0 DK-1 0.000 0 4/18/2004 4 5032 4570 CAMCO KBG-2-9 DMY 1.0 DK-3 0.000 0 4/18/2004 5 5458 4939 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 5/25/2005 Depth TVD Type Description ID 28 28 HANGER FMC HANGER 3.500 523 523 NIP CAMCO DS NIPPLE W/2.875" PROFILE 2.875 SLEEVE-O 5508 4982 SLEEVE-O BAKER eMU SLIDING SLEEVE - OPENED 5/25/2005 2.810 (5508-5509, 5508 4982 PUMP TRICO JET PUMP (SN #PH-1124) 9-C RATIO #9 NOZZLE, #11 THROAT ON 0.000 00:4.530) 2.81 CS LOCK, set 5/26/2005 5524 4996 NIP CAMCO 'D' NIPPLE 2.750 5569 5035 SEAL BAKER G-22 LOCATOR SEAL ASSEMBLY 3.000 NIP (5524-5525. 00:4.500) SEAL (5569-5570. 00:4.500) Perf :!III!: ... (6045-6065) ... ~ FRAC (6045-6080) ROOUCTION (5586-6328, 00:3.500. wt:9.30) Perf (6065-6080) Perf (6070-6080) ~ Producer MITIA Pre GL to lP Conversion . . Subject: Producer MITIA Pre GL to JP Conversion From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Sat, 04 Jun 2005 15:42:07 -0800 To: Thomas Maunder <tom_maunder@admin.state.akus>, James Regg <jimJegg@admin.state.akus>, bob _ fleckenstein@admin.state.akus Tom, Attached are MITIA forms for 4 producers prior to surface power jet pump conversion. The 10-404's are in the US mail. Please let me know if you have any questions. MJ Loveland «MITP KRU 2P-443 05-25-05.xls» «MITP KRU 2P-424A 05-21-05.xls» «MITP KRU 2P-406 05-23-05.xls» «MITP KRU 2L-311 05-28-05.xls» Content-Description: MITP KRU 2P-443 05-25-05.xls KRU 2P-443 05-25-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2P-424A 05-21-05.xls KRU 2P-424A 05-21-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2P-406 05-23-05.xls KRU 2P-406 05-23-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2L-311 05-28-05.xls KRU 2L-311 Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 6/6/2005 7:56 AM · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Meltwaterl KRUI 2P 05125/05 Marshall - HES Packer Depth Pretest Initial 15 Min. 30 Min. Well2P-443. Type Inj I N/A I TVD. I 5035 I Tubing I 5501 5501 5501 550I'ntervall 0 P.T.D. 2040320 Type Test P Test psi 1500 Casing 560 3000 2905 2850 P/F P Notes: MITIA for conversion to surface powered jet pump. OA = 150, 275, 275, 275 weill I Type Inj I 1 TVD. I I Tubing I Ilnterval P.TD. Type Test Test psi 1500 Casing P/F Notes: weill I Type Inj I I TVD. I I Tubing I Interval I P.TD. Type Test T est psi 1500 Casing P/F Notes: weill I Type Inj I I TVD. I I Tubing I Ilnterval P.TD. Type Test Test psi 1500 Casing P/F Notes: weill I Type Inj I I TVD. I I Tubing I I Interval I P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT Report Form Revised: 05/19/02 MITP KRU 2P-443 05-25-05.xls 6/6/2005 e Conoc~hillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 June 29, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 ErVED J¡JN 2 H '2D04 Subject: Report of Sundry Well Operations for 2P-443 (APD # 204-032) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent frac operations on the Kuparuk well 2P-443. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, U,J/!~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad OR1G\NAL e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28', 252' AMSL 8. Property Designation: ADL 373112, ALK 32092 11. Present Well Condition Summary: Repair Well 0 Pull Tubing 0 Opera!. ShutdownD Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development _ 0 Stratigraphic 0 Stimulate 0 Waiver 0 Other o o o Time Extension Exploratory Service o o Re-enter Suspended Well 5. Permit to Drill Number: 204-032 I 6. API Number: 50-103-20487-00 9. Well Name and Number: 2P-443 10. Field/Pool(s): Kuparuk Oil Field, Meltwater Oil Pool Total Depth measured 6334' feet true vertical 5709' feet Effective Depth measured 6196' feet true vertical 5585' feet Casing Length Size MD Structural CONDUCTOR 80' 16" 108' SURFACE 2460' 9-5/8" 2488' PRODUCTION 5557' 5-1/2" 5584' PRODUCTION 744' 3-1/2" 6328' CSG WINDOW Perforation depth: Measured depth: 6045'-6080' true vertical depth: 5450'-5481' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2362' 5048' 5703' JUN2 ~) 2004 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5586' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP landing nipple= 523' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6045'-6080' Treatment descriptions including volumes used and final pressure: 185K proppant pumped 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation SI Si SI Subsequent to operation 720 1217 241 398 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 265-4374 M~ ;r;;¡~ Title Phone Wells Group Team Leader 0 ~::red bv s~ro~~rf 263-4612 Printed Name Signature Form 10-404 Revised 04/2004 ORIGINAL RBDMS Bf';L JJ~m~ O~gin~~~~IY Date OS/22/04 OS/24/04 OS/25/04 e e 2P-443 Well Events Summary Summary ATTEMPT 3RD TRY TO FRAC STIM. PUMP BREAKDOWN, DATAFRAC, SCOUR, BRACKET FRAC AND FRAC USING YF150D XL GEL W/50PPG GEL LOADING, AND 185,000 # 16/20 CARBOLlTE.D WELL FRACTURED WITH 185K PROPANT PUMPED W/10.1PPA IN PERFS, AND 800# LEFT IN THE TUBING. SD ISI CLEANED OUT FRAC SAND TO 6172' CTD USING A 2.3" JET SWIRL NZL. WASHED MANDRELS WHILE PUH. HEAVY SAND RETURNS. LEFT WELL SI & FREEZE PROTECTED.D [FCO] DRIFT TAG W/2.70" CENT SB TO 6197' RKB, PULLED 1" INTER. PETRODAT SPMG, SET 1" INTER. 5/16" OV AFTER DISPLACING IA 65 BBLS DIESEL, DISPLACED TUBING 29 BBLS , NEED 19 MORE FOR TOTAL 113 BBLS PSI ON TUBING LOCKING UP 1500#, SLOWLY FALLING 0 [Tag, GLV, e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved ProgramD 2. Operator SuspendD RepairWellD Pull Tubing D Operation ShutdownD Plug PerforationsŒJ Perforate New Pool D 4. Current Well Class: Perforate Œ] WaiverD Stimulate D Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 200-1470 OtherD Name: BP Exploration (Alaska), Inc. Development ŒJ ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicD ServiceD 9. Well Name and Number: 05-25B 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool 6. API Number 50-029-21988-02-00 72.13 8. Property Designation: ADL-078326 11. Present Well Condition Summary: Total Depth measured 11582 feet true vertical 9044.7 feet Plugs (measured) 10060 Effective Depth measured 10060 feet Junk (measured) None true vertical 9051.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 101.1# H-40 41 121 41.0 121.0 1650 650 Liner 1164 3-1/2" 9.3# L-80 8806 - 9970 8129.6 9042.8 10160 10530 Liner 1102 5-1/2" 17# L-80 8868 - 9970 8183.0 9042.8 7740 6280 Liner 2007 2-3/8" 4.7# L-80 9574 - 11581 8808.3 9044.7 11200 11780 Production 9875 7-5/8" 29.7# L-80 39 - 9914 39.0 9029.6 6890 4790 Surface 3444 10-3/4" 45.5# J-55 40 - 3484 40.0 3483.1 3580 2090 Perforation depth: Measured depth: 9926 - 9951,9951 - 9976,9990 -10040 True vertical depth: 9033.17 - 9039.35,9039.35 - 9043.67,9045.71 - 9051.56 JUN :~ ~1 2004 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 38 8820 Packers & SSSV (type & measured depth): 4-1/2" Baker 5-3 Perm Packer 4-1/2" Baker S-3 Perm Packer 5-1/2" Baker ZXP Hydro Set Packer @ @ @ 3893 8765 8818 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~BÐMS 8Ft 1JN0' 2 9 ?nnl! 13 Prior to well operation: Subsequent to operation: Oil-Bbl 753 832 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 34.4 800 39.9 713 Tubing Pressure 1491 1107 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒJ Service D Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signaturé jj~ ~ Form 1 0-404 ReviseJ 12/2003 Title Production Technical Assistant Phone 564-4657 Date 6/25/04 O;.<!GfNAL ~~ e e 05-258 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/11/04 CTU #9: MEM GR/CCL, SET CIBP, ADDPERFS. MIRU CT #9, DRIFT COIL WI 5/8" BALL. MU WFRD MHA W/1-11/16" MEM GR/CCL. KNOCK DOWN WHP AND RIH. LOG FROM 10,200 TO 9875' AND FLAG COIL. FINISH LOGGING INTERVAL AND POOH. RIH WI BAKER 2-3/8" CIBP. SET CIBP @ 10060', POOH. <<<CONTINUED ON WSR 5/12/04>>> 05/12/04 CTU #9: SET CIBP, PERFORATE. «<CONTINUED FROM WSR 5/11104»> SIT DOWN ON CIBP POST SET. POOH WI CIBP SETTING TOOLS. RIH WI GUN #1. PERFORATE FROM 9951' - 9976' MD. MU GUN #2. PERFORATE FROM 9926' to 9951'. POOH. Well left shutin. Well and flowline are not freeze protected as per instruction from WOE/EOC. Well to be POP'd after rig down. RD CTU. FLUIDS PUMPED BBLS 80 50/50 Methonal 149 1% KCL 69 Diesel 298 TOTAL Page 1 DATE REV BY COr.IMENfS 05/12/04 KCF/KAK ADÆRFS & CORRECllONS . , Iii. ~ e TREE = 4-1/16" WCEVOY 5M WELLHEAD = AciuA:tÓR ;; KfCe.. EV ";- BF. EÎ.EV ;;; KOP= MâX Angle = 'Datum MD = DatumTVD = FWC '~---(m§ 72.1' m _____........._ 4000' 98 @ 1Ô169' 964-5' 8800' SS 110-314" CSG, 45.5#, J..55 BTC, ID = 9.953" H 3490' Minimum ID = 1.941" @ 9574' TOP OF 2-318" LINER 14-112" lBG, 12.6#, L-80 BTC-M, ID = 3.958" H /7-5/8" X 5-1/2" BKRZXP LNR HGR R<R H W/6'TI83AO< SLY, ID= 4.892" I 17 -5/8" X 5-1/2" BKR HY - FLO II H LNR Ho\NGER, ID4.892" I" 17-518" CSG, 29.7#, L-80 BTC-M, ID = 6.875" H 8820' 8818' 8874' 9920' PERFORA llON Sllv1MA RY REF LOG: SWS CQ/GRlWCNL ON 10/29/00 ANGLE A TTOP PERF: 73 @ 9926' Note: Refer 10 Production œ for historical perf data SIZE SPF INlERVAL OpnlSqz DATE 1-11/16" 6 9926 - 9976 0 05112/04 1-11/16" 6 9990-10040 0 11/22/03 1-11/16" 4 10128 -10300 C 10/31/00 1-11/16" 4 10470-10700 C 10/31/00 1-11/16" 4 10858 -11050 C 10/31/00 1-11/16" 4 11310 -11540 C 10/31/00 1-11/16" 6 11141 -11166 C 11/22/03 1-11/16" 6 11178 -11203 C 11/22/03 15-1/2"LNR, 17#, L-80FL4S, H 10031' I l0232 bpf, ID =4.892" I 13-1/2' LNR, 9.3#, L-80 NSGr/STL, H 11916' I .0087 bpf, ID = 2.992" I - DATE 01/12/90 08/27/96 10/31/00 05/07/01 09/24/03 05/11/04 REV BY COMfllENfS ORIGINAL COMPLETION RWO - SIDETRACK CTD- SIDETRACK (05-258) Œi/KAK CORREGrIONS JAFfTLP 5-1/2' CSG SHOE RELOCATION KCF/KAK SEf BKR CIßp 05-258 . ~ L - :8: z :8: ~ .~ t--~ r-- ~ J ~ - ... e SAFETY NOTES: 05-25A SIDETRACK 3-1/2" SL TD LNR P&A'DW/CMT. 05-25BGOES HORIZONTAL @ 10045'. 2189' H 4-1/2" CAMCO BAL-O SSSVN, ID = 3.812" I ~ GAS LIFT MANDRa.S ST MD lVD ŒV lYPE VLV LATCH 1 3583 3516 0 KBMG-N DV BK 2 3826 3758 8 KBMG-N SO BK FQRf DATE 08/28/96 08/28/96 3893' H7-5I8" X 4-1/2" BAKER &3 PKR, ID = 3.958" I 8765' H7-5I8"X 4-1/2' BAKER &3 PKR, ID= 3.958" 8798' H4-1/2" HES XN NP, ID = 3.725" I 8820' H4-1/2"WLEG, ID =3.958" 1 HELM) TTL NOT LOGGED 1 H5-1/2"X 3-1/2' XO,ID=2.992" I 8840' 9574' H2.70" BAKERDER..OYfllENT SLV, D = 1.969" I 3-1/2" MILLOur WINDOW 9970' - 9975' ~TOPOFWHPSTOO< I ~ RATAG I 2-318" BKR CIBP (05/11/04) I ~ 11544' I IBKR O-Rlt-JG SUBlFLAPÆR ID = 1.000" 12-318" LNR, 4.6#, L-80 FL4S, .0030 bpf, ID = 1.941" H 11581' I PRUDHOE BAY UNrr Wa.L: 05-25B ÆRMTNo: 2001470 API No: 50-029-2198-02 SEe 32, T11 N, R15E 2558' SNL & 173' EWL 8P Exploration (Alaska) e Conoc~hillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. o. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-443 (APD # 204-032 / 304-061) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-443. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, \<-~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEIVED ,JUN 1 !j 2004 .~Iask<¡ 011 í-l" Go/'!:; I STATE OF ALASKA e ALAs A OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U GINJ 0 WINJ 2. Operator Name: o WDSPL 0 Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 998' FNL, 1680' FWL, Sec. 17, T8N, R7E, UM At Top Productive Horizon: 354' FSL, 1629' FEL, Sec. 8, T8N, R7E, UM Total Depth: 436' FSL, 1505' FEL, Sec. 8, T8N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 443640' y- TPI: x- 445616 y- Total Depth: x- 445741 " y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res/Dens/Neut 22. CASING SIZE WT. PER FT. 16" 62.5# 9.625" 40# 5.5" 15.5# 3.5" 9.3# GRADE B L-80 L-80 L-80 5868881 . 5870218 5870300 - Zone- 4 Zone- 4 Zone- 4 Suspended 0 20AAC25.110 Other WAG 0 5. Date Comp., Susp., :;0 or Aband.: April.~ 2004 6. Date Spudded: February 23, 2004 7. Date TD Reached: April 14, 2004 8. KB Elevation (It): 28' RKB /252' AMSL 9. Plug Back Depth (MD + TVD): 6196' MD /5585' TVD 10. Total Depth (MD + TVD): . 6334' MD / 5709' TVD . 11. Depth where SSSV set: Landing Nipple @ 523' 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 2488' 28' 2362' 28' 5584' 28' 5048' 5584' 6328' 5048' 5703' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 6045'-6080' MD 5450'-5481' TVD 6spf 26. Date First Production May 29, 2004 Date of Test Hours Tested 24. SIZE 3.5" 1b. Well Class: Development 0 Service 0 Exploratory 0 Stratigraphic Test 0 þÞ . Ÿ 12. Permit to Drill Number: '" . ¡{.Ii' . 204-032 I 304-061 13. API Number: 50-103-20487-00 14. Well Name and Number: 2P-443 15. Field/Pool(s): Kuparuk River Field Meltwater Oil Pool 16. Property Designation: ADL373112 17. Land Use Permit: ALK 32092 feet MSL 20. Thickness of Permafrost: 1368' MD HOLE SIZE AMOUNT PULLED CEMENTING RECORD 42" 410 sxAS I 320 sx ArcticSet Lite, 225 sx LiteCrete 650 sx GasBlok included above 12.25" 8.5" 8.5' TUBING RECORD DEPTH SET (MD) 5586' PACKER SET none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6045'-6080' PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Flowing GAS-MCF 763 GAS-MCF 6/8/2004 Flow Tubing press. 244 psi 27. 22.5 hours Casing Pressure 731 Production for OIL-BBL 623 OIL-BBL WATER-BBL 10 W A TER-BBL 920 2130 CORE DATA 11 CHOKE SIZE IGAS-OIL RATIO 1226 Test Period --> Calculated 24-Hour Rate -> 100% OIL GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 10-407 Revised 12/2003 NONE RE:(;ElVED jUN 1 t; 2004 & CONTINUED ON REVERSE .\ØlØS \9fl -f~~'d¿1 ,db Jj~ 1 6 1ß04 [. ç- .'" 28. e GEOLOGIC MARKERS 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested. and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2P-443 T3 T3.1 T2 6034' 5999' 6130' 5440' 5409' 5526' N/A 30. LIST OF A IT ACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed Name~ThomaS Title: Signature \ - __, \. ~hone Kuparuk Drillina Team Leader LbJ 6>-63D Date " ( (1-116 '(' 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 2/22/2004 12:00 - 12:30 0.50 MOVE MOVE MOVE Blow dn rig - Prep rig for move 12:30 - 14:30 2.00 MOVE MOVE MOVE Move Sub and all modules off 2P-449 14:30 - 15:30 1.00 MOVE POSN MOVE Spot and Set sub over well 15:30 - 19:30 4.00 MOVE POSN MOVE Lay Matting boards - Spot all complexs to sub 19:30 - 23:00 3.50 MOVE RURD MOVE Connect all service lines 23:00 - 00:00 1.00 MOVE RURD MOVE Rig Accept 2300 hrs 2/22/04 - Start taking on water in pits - N/U Diverter System 2/23/2004 00:00 - 01 :00 1.00 WELCTL NUND RIGUP Continue to Nipple up Diverter system. 01 :00 - 02:00 1.00 MOVE RURD RIGUP Jack up sub & shim same for cattle chute alignment on pipe shed, Mix spud mud. 02:00 - 03:30 1.50 DRILL PULD RIGUP Pick up BHA to rig floor to thaw, Inspect saver sub, Strap drill pipe, Continue to mix spud mud. 03:30 - 04:30 1.00 RIGMNT RSRV RIGUP Slip & cut drilling line 176'. 04:30 - 09:00 4.50 DRILL PULD RIGUP Pick up 48 jts. 5" drill pipe, 29 jts. HWDP, 3 NMDC's from pipe shed and stand back in derrick. 09:00 - 11 :30 2.50 DRILL PULD SURFAC Pick up bit, motor, Short NMDC, NMstab, NMXO, MPR, MWD, Program MWD, Orient same. 11 :30 - 12:00 0.50 WELCTL BOPE SURFAC Function test Diverter system, Test waived by AOGCC John Crisp. 12:00 - 12:30 0.50 DRILL CIRC SURFAC Fill conductor and check for leaks- OK. 12:30 - 13:15 0.75 DRILL REAM SURFAC RIH w/ BHA tag ice @ 94', Clean out same to 108'. 13:15·14:45 1.50 DRILL DRLG SURFAC Spud well @ 13:15 hrs 2/23/2004, Drill f/108' to 189'. ,/ 14:45 - 15:15 0.50 DRILL TRIP SURFAC Stand back 1 stand HWDP and pick up 1 stand NMDC's. 15:15 - 00:00 8.75 DRILL DRLG SURFAC Drlg & Slide 12.25" hole 189' to 1,103' MD - PR 140 SPM, 594 GPM, PP 1700 PSI Off Bttm, RPMs 60, Up wt 80k , ON wt 88k, RW 86k. Torq on bttm 3/4k, off bttm 2k. Note; Held pre-spud meetings with both crews. 2/24/2004 00:00 - 15:30 15.50 DRILL DRLG SURFAC Drill f/1, 1 03' to 2,496' ART = 8.3 hrs AST = 2.6 hrs, Pump Hi-vis weighted sweeps every 4 to 5 stands, WOB 15/35K, 80 RPM, 635 GPM @ 2300 psi, UP 108K, ON 109K, ROT 110K, TQ 5K on/3K off, Raised mud weight to 10.5 ppg @ 1,100' w/ vis 180, BGG 50 to 180 units. 15:30 - 16:30 1.00 DRILL CIRC SURFAC Pump Hi-vis weighted sweep, Circ hole clean, Monitor well- OK. 16:30 - 19:45 3.25 DRILL TRIP SURFAC Back ream out of hole to 1,482', Hole unloading Hi volume of cuttings and plugging up possum belly, Circ at reduced rate and unplug possum belly, Stage rate back up to full rate of 635 GPM @ 2000 psi and circ hole clean. 19:45 - 22:30 2.75 DRILL TRIP SURFAC Lay down Ghost reamer, POOH and stand back HWDP, Jars, NMDC's, Down load MWD/LWD, Stand back same, Break off bit and lay down motor. 22:30 - 23:30 1.00 CASE RURD SURFAC Rig to run 9-5/8" casing. 23:30 - 00:00 0.50 CASE RUNC SURFAC PJSM, Run 9-5/8" casing. 2/25/2004 00:00 - 03:00 3.00 CASE RUNC SURFAC Continue to run 9-5/8", 40#, L-80, BTC csg., ( Ran total 64 jts) - M/U hanger - MU landing jt, Tag landing ring w/ Shoe @ 2,487' and Float collar @ 2,406', UP 115K, ON 105K. 03:00 - 03:30 0.50 CEMENTCIRC SURFAC Circ btm's up, Stage rate up to 6 bpm @ 450 psi, Btm's up gas 90 units. 03:30 - 04:00 0.50 CEMENT PULD SURFAC Rig down Frank tool, Blow down top drive, Rig up Dowell cmt. head. 04:00 - 05:15 1.25 CEMENTCIRC SURFAC Circ & condition mud at rate of 6 bpm @ 425 psi, Vis 50, Wt 10.5 ppg, Gels 2/5, PV 23, YP 14, PJSM with all rig personnel on cement job, Start batch mix spacers. 05:15 - 07:30 2.25 CEMENT PUMP SURFAC Rig Dowell, Mix & pump 10 bbls CW1 00 at 8.3 ppg at rate of 4.0 bpm @ 70 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.0 bpm @ 120 psi, Shut down and drop btm plug, Mix & pump 320 sxs (254.0 bbls) Lead ArcticSet III cmt mixed Printed: 5/14/2004 3:52:51 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 2.25 CEMENT PUMP SURFAC at 10.7 ppg wI additives at rate of 6.5 bpm @ 200 psi, Followed by 225 sxs (99.0 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg w/ additives at rate of 6.5 bpm @ 290 psi, Shut down and drop top plug, Displace cmt w/ 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 162.0 bbls 10.5 ppg mud (total of 182.0 bbls to bump plug) at rate of 7.0 bpm @ 600 to 725 psi, Slowed rate to 3.0 bpm @ 425 psi for last 10 bbls of displacement, Bump plug w/11 00 psi, Floats held- OK, CIP @ 07:22 hrs 2/25/04, Had good retums thru out job, Reciprocate csg. 15' until cement to surface then landed on landing ring, Had 111.7 bbls good cmt returns to surface. Rig & test 9-5/8" csg to 3500 psi- OK. Rig down cement head, Lay down landing joint, Clear rig floor. Nipple down Diverter system and remove from cellar area. Nipple up BOPE. Safety shut down after accident with siege hammer, Investigate incident. Hold safety meeting with crew. Continue to nipple up BOPE. Rig and test flange from well head to BOPE to 5000 psi. Rig & run 3-1/2" Mule shoe, 52 joints 3-1/2",9.3#, L-80, EUE 8rd tubing as kill string, Make up hanger and land same @ 1,655', Install 2-way check. Nipple down BOPE. Install & nipple up FMC Tree. Finish Nipple up Tree, Test same to 250 psi low and 5000 psi high. Pump 125 bbls diesel down 3-1/2" x 9-5/8" annulus to freeze protect well at rate of 3 bpm @ 550 psi. Set BPV, Install bind flanges to annulus valves, Secure well. Release rig to move to 2P-406 at 04:30 hrs 2/26/2004. Moving Nordic 3 f/ Placer #2 to 2P-443 Move Rig from "Placer Location to 2P pad Spot sub over well 2P-443 - Set sub shim to level - Drop wheel tarps and install entry doors. "'Note"" Accept Rig 1900 hrs 4/8/2004 Install Handy Berm around celler area BPV in hanger - N/D tree N/U BOPs and all surface lines Cleaning mud pits - Load pipe shed w/ BHA componets & 4" DP - NU BOP riser modification & trip tank line Service rig Install double valves an well head annulus Pull BVP PU 3 1/2" landing jt. MU into tbg hanger - Rig up to reverse out diesel f/ well - Check all surface equipment for proper allignment - -Reverse circulate out diesel cap fl well(113 bbls) - Back out lock down screws - unseat tbg hanger & pull to rig floor - Circulate & rig up to pull 3 1/2" kill string LD tbg hanger & landing jt. - pull & stand back 17 stds (51 jts) 31/2" EUE 8 rd tbg - LD 1 jt 3 1/2" tbg & mule shoe Drain BOP stack - MU & set test plug - Fill stack wI water Attempt low pressure test of flanges & lines - fluid leak by test plug - Pull test plug - inspect (seal OK) reintall test plug - fill stack wlwater Begin testing BOPE - Tested gas alarms - Pressure up for 1 st test- found leak on mud cross flange - tight flange - Resume testing - Blind 2/25/2004 05:15 - 07:30 2/26/2004 07:30 - 08:30 1.00 CEMENT SEOT SURFAC 08:30 - 09:30 1.00 CEMENT PULD SURFAC 09:30 - 13:00 3.50 WELCTL NUND SURFAC 13:00 - 14:45 1.75 WELCTL NUND SURFAC 14:45 - 16:45 2.00 DRILL SFTY SURFAC 16:45 - 17:45 1.00 WELCTL NUND SURFAC 17:45 - 18:30 0.75 WELCTL BOPE SURFAC 18:30 - 21:45 3.25 WELCTL TRIP SURFAC 21 :45 - 23:00 1.25 WELCTL NUND SURFAC 23:00 - 00:00 1.00 WELCTL NUND SURFAC 00:00 - 01 :00 1.00 WELCTL NUND SURFAC 01 :00 - 03:30 2.50 CMPL TN FRZP SURFAC 03:30 - 04:30 1.00 CMPL TN NUND SURFAC 12:00 - 00:00 12.00 MOVE MOVE MOVE 00:00 - 14:00 14.00 MOVE MOB MOVE 14:00 - 19:00 5.00 MOVE POSN MOVE 4m2004 4/8/2004 19:00 - 20:00 1.00 DRILL RIRD PROD 20:00 - 22:00 2.00 WELLSR NUND PROD 22:00 - 00:00 2.00 WELLSR NUND PROD 4/9/2004 00:00 - 06:00 6.00 DRILL OTHR PROD 06:00 - 07:00 1.00 RIGMNT RSRV PROD 07:00 - 08:00 1.00 DRILL OTHR PROD 08:00 - 08:15 0.25 DRILL OTHR PROD 08:15 - 15:00 6.75 DRILL CIRC PROD 15:00 - 16:45 1.75 DRILL TRIP PROD 16:45 - 18:30 1.75 WELCTL BOPE PROD 18:30 - 20:30 2.00 WELCTL BOPE PROD 20:30 - 00:00 3.50 WELCTL BOPE PROD Printed: 5/14/2004 3:52:51 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 4/9/2004 20:30 - 00:00 3.50 WELCTL BOPE PROD rams, choke & kill line valves, choke manifold valves 11,12,4,7,9,10, & 3 4/10/2004 00:00 - 04:00 4.00 WELCTL BOPE PROD Finish testing choke manifold valves - lower & upper pipe rams - TIW,dart valve,TD IBOP's to 250 psi low & 5000 psi high - Hydril to 250 psi low & 3500 psi high - performed accumuilator closure test - BOP test witnessed & approved by Jeff Jones AOGCC 04:00 - 05:00 1.00 WELCTL OTHR PROD Pull test plug - set wear bushing RI 4 lock downs - LD tools 05:00 - 08:15 3.25 RIGMNT RSRV PROD MU 31/2" mule shoe - Prep to PU 4" DP - adjust chain on pipe skate while servicing TO & rig 08:15 - 13:15 5.00 DRILL PULD PROD PU & stand back 129 jts.(43 stds) 4" Dp fl pipe shed 13:15 - 14:15 1.00 DRILL PULD PROD PU BHA componets to rig floor - bit, XO, stabs, ect. 14:15 - 19:00 4.75 DRILL PULD PROD MU 8 1/2" BHA . bit, motor(AKO 1.0) stab, XO, MWD(uplad MWD & orient w/ motor) - Held PJSM on RA sources - Install RA sources in MWD - PU NM flex De's 19:00 - 20:00 1.00 DRILL OTHR PROD MU TO - Test MWD - 160 SPM 700 psi wI 20 rpm survey & calibrate MWD 20:00-21:15 1.25 DRILL TRIP PROD RIH - PU HWDP & jars - PU ghost reamer on top of HWDP 21 :15 - 22:45 1.50 DRILL TRIP PROD RIH wI BHA f/1037' to 2173' - PU 36 jts. 4' DP fl pipe shed 22:45 - 00:00 1.25 RIGMNT RSRV PROD Service man rider winch - pull test same 4/11/2004 00:00 - 01 :30 1.50 RIGMNT RSRV PROD Slip & cut drlg line - check COM 01 :30 - 02:00 0.50 DRILL OTHR PROD Circulate through choke & gas buster 02:00 - 02:45 0.75 DRILL TRIP PROD Pull & stand back 3 stds. DP - PU & RIH w/9 jts. DP f/ pipe shed 02:45 - 03:30 0.75 DRILL REAM PROD Wash & ream down f/2173' to 2378' (tagged top of cmt) 03:30 - 05:00 1.50 CEMENT DSHO PROD Clean out shoe track - drill wiper plugs - FC@ 2409' - cmt. to 2454' - Calibrate Baker Inteq. - Epoch & Totco 05:00 - 06:00 1.00 CEMENT DSHO PROD Continue drill out cmt f/ 2454 to 2489' - drill out shoe @ 2489' to 2490' - clean out rat hole to 2498' - Drill 22' new hole to 2520' 06:00 - 06:30 0.50 DRILL CIRC PROD Circulate hole clean for FIT - 10.3 ppg mud wt in & out 06:30 - 07:30 1.00 DRILL FIT PROD RU & perform FIT to 18.0 ppg EMW - RD 07:30 - 08:45 1.25 DRILL DRLG PROD Drill 8 1/2" hole f/2520' to 2646' 08:45 - 09:15 0.50 DRILL REAM PROD MAD pass wI MWD f/ 2551' to 2643' 09:15 - 12:00 2.75 DRILL DRLG PROD Drill 8 1/2" hole f/2646' to 2858' MD 2686' rvD RPM 85 WOB 15/18 k GPM 470 @ 2300 psi String wt. PU 75 SO 70 Rot 72 Torque on/off btm - 4300/2700 ft. Ibs. ADT - 2.8 hrs. ART - 2.6 hrs. AST - .2 hrs. ECD - 10.6 to 11.2 12:00 - 16:00 4.00 DRILL DRLG PROD Drill 8 1/2" hole f/2858' to 3225' MD RPM 85 WOB 15/18 GPM 450 @ 2350 psi String wt. PU 80 SO 63 Rot. 77 Torque on/off btm - 4600/3400 ft. Ibs. ECD - 10.9 to 11.6 16:00 - 17:30 1.50 DRILL OTHR PROD Flow line plugged with clay - unplug flow line (no spill) 17:30 - 20:15 2.75 DRILL DRLG PROD Drill 8 1/2" hole f/ 3225' to 3401' 20:15 - 20:45 0.50 DRILL OTHR PROD Obtain Slow pump rates - service TO 20:45 - 00:00 3.25 DRILL DRLG PROD Drill 8 1/2" hole f/3401' to 3600' MD - 3335' rvD RPM - 80 WOB 12/18 k GPM 453 @ 2300 psi String wt. PU 80 SO 68 Rot.. 77 Torque on/off btm - I 6200 ft. Ibs. Drillling time 1200 to 0000 hrs. ADT - 7 hrs. ART 4.6 hrs AST 2.4 hrs. Printed: 5/14/2004 3:52:51 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 4/11/2004 4/12/2004 20:45 - 00:00 00:00 - 12:00 3.25 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12:00 - 16:00 4.00 DRILL DRLG PROD 16:00 - 17:00 17:00 - 00:00 1.00 DRILL DEQT PROD 7.00 DRILL DRLG PROD 4/13/2004 00:00 - 07:15 7.25 DRILL DRLG PROD 07:15 - 07:45 0.50 DRILL OBSV PROD 07:45 - 09:30 1.75 DRILL DRLG PROD 09:30 - 11 :00 1.50 DRILL CIRC PROD 11:00 -11:15 0.25 DRILL OBSV PROD 11 :15 - 12:30 1.25 DRILL CIRC PROD 12:30 - 12:45 0.25 DRILL OBSV PROD 12:45 - 14:30 1.75 DRILL WIPR PROD 14:30 - 15:15 0.75 DRILL CIRC PROD 15:15 - 16:00 0.75 RIGMNT RGRP PROD 16:00 - 17:00 1.00 DRILL WIPR PROD 17:00 - 19:00 2.00 DRILL WIPR PROD 19:00 - 20:00 1.00 RIGMNT RGRP PROD 20:00 - 20:30 0.50 DRILL REAM PROD 20:30 - 00:00 3.50 DRILL DRLG PROD 4/14/2004 00:00 - 06:00 6.00 DRILL DRLG PROD . Note - Rig on high line power @ 2330 hrs. Drill 8 1/2" hole f/3600' to 4567' MD - 4164' rvD RPM - 80 WOB - 10/15 k GPM 450 @ 2650 psi String wt. PU 95 SO 88 Rot. 90 Torque on/off btm. - 9400/5500 ft. Ibs. ADT - 8.3 hrs. ART - 6.7 hrs. AST - 1.6 hrs. ECD - 11.3 to 11.5 Drill 8 1/2" hole f/ 4567' to 4836' MD RPM - 80 WOB 5/15 k GPM 450 @ 2600 psi String wt. PU 108 SO 90 Rot. 97 Torque on/off btm - 10,000/6000 ft Ibs. ECD 10.9 to 11.5 Calibrate MWD depth counter Drill 8 1/2' hole f/4836' to 5143' MD - 4666' rvD RPM - 80 WOB 5/20 k GPM 429 @2500 psi String wt. PU 105 SO 98 Rot 100 Torque on/off btm - 6900/5500 ft. Ibs. ECD - 10.8 to 11.2 ADT f/1200 hrs to 0000 hrs. ADT -7.3 hrs. ART - 3.7 hrs. AST - 3.6 hrs. Drill from 5143' to 5438'. Pump 390 gpm w/2500 psi. on and 2200 psi off. Torque = 9600 ftlb on and 6400 ftlb off. PU = 11 OK. SO = 100K. ROT = 100K. Hole loosing mud. P/U and monitor well. Lost 12 bbl total. Well stabilized after flowing back 8 bbl. Drilled ahead to 5580'. Conducted "Kick while drilling" drill. Start LCM pretreat. Pump 455 gpm wI 3100 psi. on and 2700 psi off. Torque = 10400 ftlb on and 6400 ftlb off. PU = 110K. SO = 110K. ROT = 105K. TST = 2.3 hr. TRT = 4.4 hr. TDT = 6.7 hr. Pump sweep, circulate and condition hole. Monitor well. Hole stable. Circulate and condition for Short trip. Monitor well. Hole stable. Pump and backream from 5580 - 4160'. Circulate hole. Flowline plugged with clay balls. Possum belly overflow due to plugging. Mud spill to pad out screen room door.( 8 gals) Clear plugging and clean up. Pump and backream from 4160 to 3590'. (Ghost reamer just below shoe) Blow down Top Drive. Trip in hole to 5484'. Change out TO washpipe and service Top drive. Wash last stand to bottom. No fill observed. Survey at 5497'. Drill from 5580' to 5707'. Pump 430 gpm wI 3100 psi. on and 2700 psi off. Torque = 10400 ftlb on and 7700 ftlb off. at 80 RPM. PU = 11 OK. SO = 107K. ROT = 105K. TST = 2.1 hr. TRT = 0.4 hr. TOT = 2.5 hr. Drill from 5707' to 6108'. Pump 390 gpm w/2500 psi. on and 2225 psi off. ECD = 10.8 ppg. Torque occasionally grabbing pipe from 6090 to 6108'. Torque = 10400 ftlb on and 7700 ftlb off. at 80 RPM. Pipe free when weight taken off. PU = 115K. SO = 11 OK. ROT = 105K. Mud weight = 10.4 ppg Printed: 5/14/2004 3:52:51 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 4/14/2004 06:00 - 06:45 0.75 DRILL CIRC PROD Circulate for geologic sample 06:45 - 07:00 0.25 DRILL DRLG PROD Drill 10' to 6128'. Torque smoothing out at 8100 ftlb on and 6300 ftlb off. 07:00 - 07:30 0.50 DRILL CIRC PROD Circulate sample to confirm Top of Bermuda formation. 07:30 - 15:15 7.75 DRILL DRLG PROD Drill to 6326'. Pump 390 gpm w/2400 psi. on and 2300 psi off. ECD = 10.8 ppg. Torque = 7300 ftlb on and 6200 ftlb off. at 80 RPM. PU = 120K. SO = 115K. ROT = 110K. BGG = 90 units. 15:15 - 15:45 0.50 DRILL OBSV PROD Noted unexplained pit gain. Flow check and well appeared to be flowing. Driller shut in per procedure. Monitor with no pressure buildup. Open well through choke. No flow. Open well and observe, no flow. " Note" After talking to all crew members and contractors it appears this gain may? have come from the solids unit transfering fluid. Explained to crew members for better communication while moving fluid. 15:45 - 16:00 0.25 DRILL DRLG PROD Drill to 6334' MD 5707' TVD. Pump 390 gpm w/2400 psi. on and 2300 psi off. ECD = 10.8 ppg. Torque = 7400 ftlb on and 6700 ftlb off. at 80 RPM. PU = 125K. SO = 115K. ROT = 120K. TRT = 11.5 hrs BGG = 80 units. 16:00 - 17:00 1.00 DRILL CIRC PROD Pump weighted sweep and monitor gas readings. Gas peak of 2900 units coresponding to BU from 5350 to 5400' by stroke count. 17:00 - 17:15 0.25 DRILL OBSV PROD Shut down pumps and monitor well. Hole stable. 17:15 - 21 :45 4.50 DRILL CIRC PROD Circulate and condition mud. Raise weight to 10.6 ppg. Reduce pump rate to 75 spm to accomodate for increased mud weight and ECD hard line of 10.8 ppg. BGG = 30 units. 21 :45 - 22:00 0.25 DRILL OBSV PROD Observe well. No flow. 22:00 - 23:45 1.75 DRILL CIRC PROD Circulate bottoms up. Max Gas = 87 units at 6127 strokes. 23:45 - 00:00 0.25 DRILL WIPR PROD Short trip out with no rotation, Pump at 75 spm & 790 psi. 4/15/2004 00:00 - 01 :30 1.50 DRILL WIPR PROD Short trip out with no rotation to 5393. Pump at 75 spm & 790 psi. PU = 125K. SO = 107K. 01 :30 - 02:30 1.00 DRILL OTHR PROD Change out grabber dies. 02:30 - 03:00 0.50 DRILL WIPR PROD Short trip out with no rotation to 5014. Pump at 75 spm & 790 psi. PU = 120K. SO = 100K. 03:00 - 04:00 1.00 DRILL WIPR PROD Run back to bottom. No exess drag. Lost 8 bbl to hole durring short trip. 04:00 - 05:30 1.50 DRILL CIRC PROD CBU. Mud weight at 10.6+. Maximum gas at BU = 125 units. 05:30 - 05:45 0.25 DRILL OBSV PROD Flow check. Well stable. 05:45 - 11 :30 5.75 DRILL TRIP PROD Pump out of hole to 2457'. Hole taking fluid. Lost 20 bbl total. Mud weight at 10.8 ppg. 11 :30 - 11 :45 0.25 DRILL OBSV PROD Flow check. Well stable. 11 :45 - 14:45 3.00 DRILL CIRC PROD Circulate and cut mud weight to 10.5 ppg. 14:45 - 15:00 0.25 DRILL OBSV PROD Flow check. Well stable. 15:00 - 20:00 5.00 DRILL TRIP PROD POOH slow from 2457' to 2360'. Not taking proper fill. Pump out from 2360' to 1037' with proper fill. Attempt to pull HWDP. Hole not taking proper fill. Hole swabbing slightly. Pump out HWDP. 20:00 - 20:15 0.25 DRILL SFTY PROD Clear floor and hold PJSM for down loading MWD tool Nuclear sources. 20:15 - 22:30 2.25 DRILL PULD PROD LD BHA. Remove sources and download MWD data. 22:30 - 22:45 0.25 DRILL OBSV PROD Flow check. Well stable. 22:45 - 23:00 0.25 CASE NUND PROD RIU stack washer and start washing stack. Top riser boot leaking. 23:00 - 00:00 1.00 CASE NUND PROD Replace riser boot. 4/16/2004 00:00 - 00:30 0.50 CASE NUND PROD Replace riser boot seal. 00:30 - 04:00 3.50 CASE NUND PROD Drain stack. Stack completely lined w/ sheathed clay buildup, wear ring tool would not pass through. Clean out clay. 04:00 - 04:30 0.50 CASE NUND PROD Pull wear ring. Blow down top drive. 04:30 - 09:00 4.50 CASE NUND PROD Change out BOP rams. Installed 5 1/2" casing rams in bottom and left 2 3/8" x 5" VBR in top cavity. (NOTE: Nordic has ordered 2 7/8" x 5 1/2" Printed: 5/14/2004 3:52:51 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 4/16/2004 04:30 - 09:00 4.50 CASE NUND PROD VBR for upper ram unit.) 09:00 - 09:30 0.50 CASE NUND PROD Run test plug and test door seal to 2500 psi. 09:30 - 10:15 0.75 CASE RURD PROD Finish RIU to run production casing 10:15 - 10:30 0.25 CASE SFTY PROD PJSM for production casing. 10:30 - 13:30 3.00 CASE RUNC PROD Run casing. P/U shoe track and test floats Run 23 jts 3 1/2", 9.3 # L-80 casing to 780'. 13:30 - 14:00 0.50 CASE RUNC PROD Flow check OK while change over to 5 1/2" tools. M/U CSR and Franks tool. 14:00 - 14:30 0.50 CASE CIRC PROD Circulate surface to surface. Flowcheck OK. 14:30 - 17:30 3.00 CASE RUNe PROD Run 5 1/2" casing to 2470'. Fill casing as run. Running slow for surge avoidance. 17:30 - 18:30 1.00 CASE CIRC PROD Circulate bottoms up at surface casing shoe. 18:30 - 21 :30 3.00 CASE RUNC PROD Run in hole to 4296'. Casing mud displacement at calculated value. 21 :30 - 23:00 1.50 CASE CIRC PROD Break circulation at 5 spm and circulate bottoms up. Staged to 4.5 bpm at 420 psi. Maximum mud weight at BU was 10.6 ppg. Max gas was 85 units. 23:00 - 00:00 1.00 CASE RUNe PROD Continue running casing to 5014' with correct mud displacement. Total of 100 jts. 51/2' and 23 jt 31/2' in hole. 4/17/2004 00:00 - 02: 15 2.25 CASE RUNC PROD Continue RIH with 5 1/2" production casing to 6283' with full displacement. 02:15 - 05:00 2.75 CASE CIRC PROD PU casing hanger and Landing joint. Break circulation with Franks tool and stage up to 5 bpm at 600 psi. Wash to 6325'. Circulate w/ full returns. Maximum mud weight at bottoms up = 10.8 ppg FV = 100 sec. Maximum gas = 830units. Reciprocat with 120K PU and 80K SO 05:00 - 05:45 0.75 CASE RUNC PROD Land Casing at 6328.30'. RD FU tool. Blow down top drive. MU cement head. 05:45 - 07:00 1.25 CEMENTCIRC PROD Circulate and recriprocate while batch mixing cement. 07:00 - 10:00 3.00 CEMENTCIRC PROD PJSM for cement job. Pump 10 bbl CW 100. Test lines to 3500. Pump 50 bbl CW 100. Pump 30 bbl. Mud Push at 11.5 #. Pump 128 bbl Gas Block cement at 15.8 ppg. Land casing. Drop wiper dart and displace with 138.5 bbl. sea water. Plug did not bump. Pumped .3 bbl over calculated ( 1/2 of shoe track) saw slight pressure increase before shutting down. Check floats OK. Had full returns throughout job. 10:00 - 12:00 2.00 CEMENTOTHR PROD LD landing joint. PU Pack off on test joint. Set pack off and test to 5000 psi for 10 min. LD running tool. 12:00 - 20:45 8.75 CMPL TN RURD CMPL TN Load remaining completion tubing, drift, strap and install seal rings. RD casing and cementing tools. Clear floor and shed. RU 3 1/2" tubing tools. Strap 17 stds. 3 1/2" in derrick.Offloading mud and service TO. 20:45 - 21 :00 0.25 CMPL TN SFTY CMPL TN PJSM for 3 1/2" completion. 21 :00 - 00:00 3.00 CMPL TN RUNT CMPL TN RUN completion. Ran seal assembly, 4 GLM and 90 jts. 3 1/2" tubing. 4/18/2004 00:00 - 00:45 0.75 CMPLTN RUNT CMPL TN Continue running 3 1/2" tubing, 100 jts. in hole. 00:45 - 02:45 2.00 CMPL TN RUNT CMPL TN Run tubing stands from derrick. NOTE: Tubing rabbit would not drop due to ice in top of stands. Each stand required steam thawing for rabbiting. 02:45 - 03:15 0.50 CMPL TN OTHR CMPL TN Noted pinhole leak developing in tubing power tong hydraulic hose. Fabricate and install replacement hose. 03:15 - 05:00 1.75 CMPL TN RUNT CMPL TN Continue steaming, rabbiting and running 31/2" stands from derrick. 05:00 - 06:00 1.00 CMPL TN RUNT CMPL TN Run remaining completion tubing from pipe shed. 06:00 - 08:00 2.00 CMPL TN SOHO CMPL TN Pick up space out joints and circulating head. PU = 70 K SO = 55 K. Locate and sting into CSR. Repeat process to verify spacing. 08:00 - 09:30 1.50 CMPL TN CIRC CMPL TN PU to top of CSR and circulate well to clean sea water. Pumped a total of 390 bbl. 09:30 - 10:15 0.75 CMPL TN SOHO CMPL TN LD 3 jts tubig. PU spacer pups,1 jt. tubing and tubing hanger. Drain Printed: 5/14/2004 3:52:51 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-443 2P-443 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/22/2004 Rig Release: 2/26/2004 Rig Number: Spud Date: 1/5/2004 End: 2/26/2004 Group: 4/18/2004 09:30 - 10:15 0.75 CMPL TN SOHO CMPL TN stack and land tubing. 10:15 -11:30 1.25 CMPL TN DEOT CMPL TN RILDS and RlU to test tubing and casing. PJSM for high pressure testing. 11 :30 - 13:45 2.25 CMPL TN DEOT CMPL TN Test tubing to 3500 psi for 30 min. Bleed tubing to 2000 psi. Test casing to 3500 psi for 30 min. Bleeed tubing pressure and shear RP Valve. 13:45 - 15:15 1.50 CMPL TN DEOT CMPL TN RlU on outer annulus and perform Annular Injectivity test. 15:15 - 15:45 0.50 CMPL TN NUND CMPL TN UD landing joint and install BPV. 15:45 - 18:15 2.50 CMPL TN FRZP CMPL TN Flush outer annulus with139 bbl sea water at 3 bpm & 650 psi liP increasing to 820 psi FIP. Follow with 85 bbl diesel at 1/2 bpm @ 920 psi liP and finished injection at 1 bpm @ 800 psi. ISIP = 600 psi. Changed bottom rams to 4' while FP. 18:15 - 21 :00 2.75 CMPL TN NUND CMPL TN N/D choke and kill lines, flow riser and BOP tumbuckles. PIU and set back BOP. 21 :00 - 00:00 3.00 CMPL TN RURD CMPL TN NIU surface production tree. Pull BPV and set TWC. RlU to body test tree. 4/19/2004 00:00 - 01 :00 1.00 CMPL TN NUND CMPL TN Test tree to 5000 psi. Pull BPV 01 :00 - 01 :30 0.50 CMPL TN FRZP CMPL TN RlU hoses for Freeze protecting inner annulus. 01 :30 - 01 :45 0.25 CMPL TN SFTY CMPL TN PJSM for diesel freeze protect. 01 :45 - 03:00 1.25 CMPL TN FRZP CMPL TN Pressure test lines. Pump 55 bbl diesel down inner annulus. Taking returned sea water to cuttings tank. RID oil pumper. 03:00 - 03:45 0.75 CMPL TN FRZP CMPL TN Open to U-tube annulus to tubing. 03:45 - 04:00 0.25 CMPL TN NUND CMPL TN Install BPV - RID Hoses - Release Rig @ 4:00 AM 4/19/04 Printed: 5/14/2004 3:52:51 PM e e 2P-443 Well Events Summary Date Summary 04/21/04 TAGGED DRILLING MUD @ 5800' RKB, 280' ABOVE PROPOSED BOTTOM PERF. PULLED 1" DCR @ 5458' RKB, REPLACED WITH DV. TESTED TBG & IA TO 3000 PSI, GOOD TESTS. D [PT Tbg-Csg, Tag] 04/23/04 MILLED TO HARD TAG @ 5949' CTD WITH WEATHERFORD MHA AND 2.7" THREE BLADE JUNK MILL. UNABLE TO MILL THROUGH, MINIMAL PROGRESS ACHIEVED AFTER 4 HOURS OF MOTOR ST ALLSfTlME DRILLING; SUSPECT WIPER PLUG LEFTOVER FROM DRILLING. 04/24/04 EMPLOYED A 2.70" PARABOLIC HIGH SPEED DIAMOND MILL TO PENETRATE THROUGH BTM OF WIPER PLUG AND INTO CEMENT REACHING 5957' CTD. WILL CONTINUE IN AM WITH CEMENT MILL AND MOTOR. ENCOUNTERED A TIGHT SPOT AT 3572' CTD.D [Cement-Poly Squeeze] 04/24/04 TAGGED OBSTRUCTION @ 5940' WLM. RECOVERED SAMPLE OF MILLED WIPER PLUG @ 5940' WLM.D [Tag] 04/25/04 MILLED 222' OF CEMENT DOWN TO TD @ 6179 CTD USING A 2.74" 5-BLADE JUNK MILL. PUMPED 60 BBLS 2# BIO TO ASSIST IN CLEANING OUT CEMENT. WILL RETURN IN AM WITH UNDEREAMER TO CLEAN WELLBORE. D [Cement-Poly Squeeze] 04/26/04 MILLED 220' TO TD @ 6176' CTD THROUGH 3.5" LINER WITH A 2.375" WEATHERFORD MHA AND REEVES UNDERREAMER; 2.89" BLADES. PUMPED 100 BBLS OF 2.0# BIOZAN GEL. DROPPED A 0.625" BALL TO CIRCULATE WHILE POOH. WASHED ALL MANDRELS. WELLBORE HAS DIESEL TO SURFACE. 04/27/04 TAG @ 6174' SLM ESTIMATED CORRECTED DEPTH OF 6192' RKB W/ 22' X 2.5" DUMMY GUN.D [Tag, Perf] 04/30/04 PERFORATED 6070' - 6080' WITH WHP= 3500 PSI -- SBHP AT 5450'= 2674.9 PSIA, Ý TEMP= 123.5 DEGF AND SBHP AT 6075'= 2855.3 PSIA, TEMP= 141.3 DEGF, PRESS WAS INCREASING DURING BOTH SBHP MEASUREMENTS (SEE AWGRS LOG)D [Perf, Pressure Data] 05/02/04 ATTEMPTED INITIAL FRACTURE TREATMENT. COMPLETED BREAKDOWN, SAW GOOD PRESSURE BREAK. COMPLETED STEP-DOWN TEST, HAD 1700 PSI PERF FRICTION. STARTED SCOUR STAGE, PRESSURE DECLINING WITH SAND THROUGH PERFS, THEN STARTED BUILDING RAPIDLY AS PERFS WERE PLUGGING. 45 BBLS INTO SCOUR STAGE, PRESSURED OUT. 05/03/04 CLEANED OUT SAND DOWN TO 6178' CTD USING SLICK DIESEL AND 30 BBLS OF DIESEL GEL. GOOD CARBOLlTE RETURNS AT THE TANK. WILL RETURN IN AM FOR UNDEREAMER MILLING JOB.D [FCO] 05/04/04 UTILIZED A 2.125" BAKER MHA WITH A 2.99" BLADE DB UNDEREAMER FOR MILLING CEMENT DOWN TO 6106' CTD. PUMPED SLICK SW AND 30 BBLS GEL. DROPPED 5/8" BALL TO CIRCULATE WHILE PUH. HAD TO SHUT DOWN PUMP TO PASS THROUGH TIGHT PIPE @ 3010' CTD.D 05/04/04 PERFORATED: 6065' - 6080', 6SPF, 2.5" HYPERJET. RANDOM ORIENTATION. PENETRATION=13.1". HOLE DIA=.43" ".' e e 2P-443 Well Events Summary 05/05/04 PUMP BREAKDOWN STAGE AT 40 BPM USING 20# LINEAR GEL. PRESSURED OUT DURING SCOUR STAGE. TRY TO FLOW WELL BACK TO TANKS, THEN RESUME PUMPING. COULD NOT PUMP BACK INTO WELL.o [F rac-Refrac] 05/07/04 POST FRAC FILL CLEAN OUT TO 6174' CTM USING SLICK DIESEL AND GEL DIESEL. PUMPED 2 BPM THROUGH A 2" JET SWIRL NOZZLE WITH 4 PASSES FROM 6000' TO 6174'. PUMPED BOTTOMS UP CLEAN DIESEL VOLUME ENSURING VOID OF FRAC SAND AND GEL - THEN COMPLETED AN INJECTIVITY WITH COIL AT 5950'. 05/11/04 PERFORMED TEMP WARMBACK LOG. PUMPED 300 BBL 65 DEGF SEAWATER & 25 BBL DIESEL PRIOR LOGGING. TEMP OVERLAY SHOWS ALL WATER WENT INTO THE ZONE BEHIND THE PERFS (6065'-6080').0 05/11/04 PERFORATED INTERVAL 6045'-6065' USING 2.5" HSD GUN LOADED 6 SPF WITH ,/ HYPERJET CHARGES. e ConocoPhillips Alaska, Inc. TUBING (26-5586. OD:3.500. ID:2.992) SURFACE ~ (29-2487, OD:9.625. Wt:40.00) 'RODUCTION (29-5586, OD:5.500. Wt:15.50) Gas Lift MandrelNalve 5 (5458-5459, SLEEVE-O (5508-5509, OD:4.530) NIP (5524-5525, OD:4.500) SEAL (5569-5570, OD:4.500) Perf ~ =- (6045-6065) .... ~ FRAC \ (6045-6080) -I- --I: 'RODUCTION ~ (5586-6328. ( OD:3.500, -: Wt:9.30) Perf =;;: (6065-6080) t t Perf (6070-6080) Ii ! -\- ~ ....L API: 501032048700 SSSV Type: NIPPLE Annular Fluid: Reference Log: 28' RKB Last Tag: 6192 Last Tag Date: 4/27/2004 Cà$ÎOg··Str¡og·;;·ALI..STRINGS Description CONDUCTOR SURFACE PRODUCTION PRODUCTION e KRU 2P-443 Well Type: PROD Orig 4/19/2004 Completion: Last W/O: Ref Log Date: TD: 6334 ftKB Max Hole 32 3607 Angle @ TS: deg @ Angle @ TD: 26 deg @ 6334 Rev Reason: Set OV Last Update: 5/28/2004 Size 16.000 9.625 5.500 3.500 TVD Wt Grade Thread 110 62.50 H-40 WELDED 2362 40.00 L-80 BTCM 5049 15.50 L-80 EUE 5703 9.30 L-80 BTCM Grade Thread L-80 EUE Top o 29 29 5586 Bottom 110 2487 5586 6328 Bottom 5586 Interval TVD Zone Status Ft SPF Date Type Comment 6045 - 6065 5450 - 5468 20 6 5/1312004 APERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6065 - 6070 5468 - 5472 5 6 5/4/2004 RPERF 2.5" HSD HJ 2506 RDX, 60 deg phasing 6070 - 6080 5472 - 5481 10 12 5/4/2004 RPERF 2.5" HSD HJ 2506 RDX, 60 Interval I Comment 6045 - 6080 185,000# 16/20 CARBO-LITE PLACED St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2313 2210 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 4/18/2004 2 3583 3321 CAMeO KBG-2-9 DMY 1.0 DK-1 0.000 0 4/18/2004 3 4417 4034 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 4/18/2004 4 5032 4570 CAMCO KBG-2-9 DMY 1.0 DK-3 0.000 0 4/18/2004 5 5458 4939 CAMCO KBG-2-9 OV 1.0 BTM 0.313 0 5/25/2004 Description ID 28 FMC HANGER 3.500 523 523 CAMCO OS NIPPLE W/2.875" PROFILE 2.875 5508 4982 BAKER CMU SLIDING SLEEVE - OPEN 2.810 5524 4996 CAMCO '0' NIPPLE 2.970 5569 5035 BAKER 13-22 LOCATOR SEAL ASSEMBLY 3.000 Conoc;p.,illips . ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 1 Wellbore: 443 Well path: MWD w/Sag <0-6334'> Date Printed: 7-May-2004 ,&¡. BAKER HUGHES INTEQ Name 443 I Created 24-Feb-2004 3 8.7035 Name AK-4 on NORTH AMERICAN DATUM 1927 Field Name Meltwater I Eastil1<1 441964.2388 I NorthinQ .. . 5869891.4660 I Coord SYStem Name I NorthAliönment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2534.97 Feet on azimuth 55.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated (À D c..(- 0 ~ ;t. Conoc;p.,illips ConocoPhillips Alas~nc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LaG Page 2 Well bore: 443 Wellpath: MWD w/Sag <0-6334'> Date Printed: 7-May-2004 '&ií. BAKER HUGHES INTEQ Well path (Grid) Report MD{ft] Inc(deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionfftl 2.30 0.00 0.00 2.30 O.OON O.OOE 0.00 0.00 443640.26 5868880.80 110.30 0.00 0.00 110.30 O.OON O.OOE 0.00 0.00 443640.26 5868880.80 211.23 0.31 82.40 211.23 O.04N 0.27E 0.31 0.24 443640.53 5868880.84 303.57 1.23 40.76 303.56 0.82N 1.17E 1.10 1.42 443641.43 5868881.61 390.14 2.87 27.77 390.07 3.44N 2.78E 1.96 4.24 443643.07 5868884.2? 481.19 4.36 28.90 480.94 8.49N 5.52E 1.64 9.34 443645.84 5868889.25 572.18 7.34 24.11 571 .45 16.82N 9.56E 3.32 17.38 443649.95 5868897.55 663.75 10.09 22.78 661.95 29.56N 15.06E 3.01 29.09 443655.54 5868910.25 754.13 11.79 26.90 750.68 45.10N 22.30E 2.07 43.83 443662.89 5868925.73 845.42 12.67 28.00 839.90 62.25N 31.22E 1.00 60.87 443671.94 5868942.82 936.00 13.25 32.08 928.18 79.82N 41.40E 1.20 79.17 443682.25 5868960.31 1028.23 13.47 40.16 1017.92 96.99N 53.94E 2.04 99.20 443694.91 5868977.38 1127.18 14.04 44.10 1114.03 114.42N 69.73E 1.11 122.06 443710.83 5868994.69 1219.76 13.92 43.34 1203.87 130.58N 85.19E 0.24 143.94 443726.40 5869010.73 1313.48 14.00 45.76 1294.82 146.69N 101.05E 0.63 166.12 443742.38 5869026.72 1406.27 14.80 53.52 1384.71 161.56N 118.62E 2.25 189.02 443760.06 5869041.47 1498.21 16.60 57.22 1473.21 175.66N 139.10E 2.24 213.88 443780.65 5869055.41 1591.09 18.82 60.30 1561.69 190.27N 163.28E 2.59 242.08 443804.92 5869069.84 1684.76 21.75 58.45 1649.54 206.84N 191.19E 3.20 274.49 443832.96 5869086.20 1777.83 23.88 57.47 1735.33 225.99N 221.78E 2.32 310.54 443863.68 5869105.12 1870.46 25.63 58.32 1819.44 246.60N 254.63E 1.93 349.30 443896.69 5869125.48 1963.05 27.53 58.05 1902.24 268.44N 289.84E 2.06 390.69 443932.05 5869147.06 2056.39 27.93 58.55 1984.86 291.26N 326.79E 0.50 434.08 443969.16 5869169.61 2148.21 28.83 56.95 2065.65 314.55N 363.69E 1.28 477.69 444006.23 5869192.63 2239.81 29.23 56.56 2145.74 338.92N 400.87E 0.48 522.13 444043.58 5869216.72 2333.88 29.04 56.47 2227.90 364.19N 439.06E 0.21 567.93 444081.96 5869241.70 2422.26 28.83 56.80 2305.25 387.71N 474.78E 0.30 610.68 444117.85 5869264.95 2565.49 29.18 54.32 2430.52 426.99N 532.04E 0.87 680.12 444175.39 5869303.80 2661.24 28.88 54.48 2514.24 454.03N 569.82E 0.32 726.57 444213.36 5869330.56 2756.06 28.86 53.52 2597.28 480.94N 606.85E 0.49 772.33 444250.60 5869357.19 2850.62 28.67 56.12 2680.17 507.16N 644.04E 1.34 817.82 444287.97 5869383.13 2945.14 28.56 56.47 2763.15 532.27N 681.70E 0.21 863.08 444325.81 5869407.97 3039.94 28.91 59.66 2846.28 556.37N 720.36E 1.66 908.60 444364.65 5869431.77 3134.70 28.55 60.67 2929.37 579.03N 759.87E 0.64 954.02 444404.32 5869454.14 3230.34 28.57 59.18 3013.38 601.94N 799.44E 0.75 999.61 444444.05 5869476.75 3322.81 27.74 59.68 3094.91 624.14N 837.01E 0.93 1043.15 444481.78 5869498.67 3418.03 28.77 60.89 3178.78 646.47N 876.16E 1.24 1088.08 444521.09 5869520.71 3512.89 31.16 61.87 3260.95 669.15N 917.75E 2.57 1135.23 444562.84 5869543.08 3606.55 31.58 58.62 3340.93 693.35N 960.06E 1.86 1183.81 444605.33 5869566.96 3702.79 31.44 57.72 3422.98 719.88N 1002.79E 0.51 1234.07 444648.25 5869593.17 3797.41 31.31 56.04 3503.76 746.79N 1044.05E 0.93 1283.31 444689.70 5869619.77 3891.31 31.03 56.74 3584.11 773.69N 1084.52E 0.49 1331.91 444730.37 5869646.37 3986.34 31.36 56.86 3665.40 800.64N 1125.71 E 0.35 1381.12 444771.75 5869673.01 4082.42 31.48 55.99 3747.39 828.34N 1167.44E 0.49 1431.20 444813.68 5869700.40 4175.88 31.38 55.59 3827.14 855.74N 1207.74E 0.25 1479.94 444854.18 5869727.50 4271.05 30.91 55.93 3908.59 883.44N 1248.43E 0.53 1529.16 444895.07 5869754.89 4365.68 30.57 55.89 3989.92 910.55N 1288.49E 0.36 1577.53 444935.33 5869781.70 4460.49 30.37 54.64 4071.64 937.94N 1328.00E 0.70 1625.60 444975.03 5869808.80 4553.45 30.22 55.16 4151.91 964.90N 1366.37E 0.33 1672.49 445013.59 5869835.47 4648.70 29.68 55.60 4234.44 991.92N 1405.50E 0.61 1720.04 445052.92 5869862.20 4742.45 28.96 56.24 4316.18 1017.65N 1443.52E 0.84 1765.95 445091.13 5869887.64 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2534.97 Feet on azimuth 55.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¥ ConocOPhillips ConocoPhillips Alas~c.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY utltm Page 3 Wellbore: 443 Wellpath: MWD w/Sag <0-6334'> Date Printed: 7-May-2004 ,&¡. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionrftl 4839.32 28.88 57.59 4400.97 1043.22N 1482.77E 0.68 1812.78 445130.56 5869912.92 4932.74 28.33 57.73 4482.98 1067.15N 1520.55E 0.59 1857.48 445168.52 5869936.56 5026.46 29.45 59.21 4565.04 1090.81 N 1559.15E 1.42 1902.71 445207.28 5869959.94 5120.73 29.57 58.02 4647.08 1114.99N 1598.79E 0.63 1949.08 445247.10 5869983.83 5214.42 29.51 58.45 4728.59 1139.31N 1638.06E 0.24 1995.23 445286.55 5870007.85 5310.84 30.10 56.58 4812.26 1165.06N 1678.48E 1.14 2043.12 445327.15 5870033.29 5407.47 31.12 57.54 4895.42 1191.80N 1719.78E 1.17 2092.31 445368.64 5870059.73 5499.97 30.73 56.46 4974.77 1217.69N 1759.64E 0.73 2139.83 445408.69 5870085.32 5593.06 29.23 56.50 5055.41 1243.38N 1798.42E 1.61 2186.35 445447.66 5870110.72 5687.82 30.43 57.73 5137.61 1268.96N 1838.01E 1.42 2233.46 445487.43 5870136.01 5783.23 30.17 56.68 5219.99 1295.03N 1878.4 7E 0.62 2281.58 445528.08 5870161.77 5877.52 29.06 57.55 5301.96 1320.34N 1917.60E 1.26 2328.16 445567.38 5870186.78 5973.40 27.87 55.61 5386.25 1345.49N 1955.74E 1.57 2373.85 445605.71 5870211.65 6067.66 27.01 57.10 5469.90 1369.56N 1991.90E 1.17 2417.28 445642.04 5870235.45 6162.42 26.47 56.37 5554.53 1392.94N 2027.55E 0.67 2459.91 445677.86 5870258.57 6255.31 25.74 55.97 5637.94 1415.70N 2061.50E 0.81 2500.78 445711.97 5870281.07 6334.00 25.74 55.97 5708.83 1434.82N 2089.82E 0.00 2534.95 445740.43 5870299.98 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2534.97 Feet on azimuth 55.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska y ConocoPhillips Comments MÐfftl TVDfftl 2498.30 2371.81 6334.00 5708.83 I Northrftl 408.20N 1434.82N HoleSections Diameter Start !inl MDrftl 12 1/4 2.30 8 1/2 2498.30 start TVDrftl 2.30 2371.81 Casinas Nàme Top MDfftl 2.30 2.30 Top TVDfftl 2.30 2.30 16" Conductor 9 5/8" CasinQ SURVEY LING Page 4 Well bore: 443 Wellpath: MWD w/Sag <0-6334'> Date Printed: 7-May-2004 r&i. BAKER HUGHES INTEQ I Eastrftl 505.31 E 2089.82E ¡Comment Proiected to TO Proiected Data - NO SURVEY Stàrt Northrftl O.OON 408.20N Start Eastrftl O.OOE 505.31 E End MDrftl 2498.30 6334.00 End Northrftl 408.20N 1434.82N End TVDCftl 2371.81 5708.83 Start Wellbore Eastrftl 505.31E 443 2089.82E 443 Top Northrftl O.OON O.OON Shoe TVDfftl 110.30 2364.81 Shoe Wellbore Eastrftl O.OOE 443 502.11E 443 Top Eastrftl O.OOE O.OOE Shoe MÐfftl 110.30 2490.30 Shoe Northrftl O.OON 406.00N All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2534.97 Feet on azimuth 55.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e -- Transmittal Form &OLf-032- INTEQ r'¡_ BAKER HUGHES _'" _',.,..C<'>:..;' ,... _:.1 "..,. - _«v,;:; ., _~: . . -~~;;-- ";". ~... i Anchorage GEOScience Center i-__~_Lj To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 2P-443 Contains the following: 1 LDWG Compact Disc ¿... I J >'0 i..( (Includes Graphic Image files) 1 LDWG lister summary _" 1 blue line - MPR Measured Depth Log ¡..--. 1 blue line - MPR TVD Log'-- 1 blueline - CCN/ORD Measured Depth Log -. 1 blueline - CCN/ORD TVD Log __ LAC Job#: 640243 Sent By: Gle~7rel J,H reI Received By: ~ ()iJJ Date: May 26, 2004 Date: / j P"L. ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -- ==~. ConoctPhillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com February 26, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval for temporary shutdown of operations on Meltwater producer 2P-443 Dear Sir / Madam ConocoPhillips Alaska, Inc. hereby applies for a Sundry approval to temporarily shutdown operations on Meltwater well 2P-443. In order to more efficiently utilise our drilling rig resources and Doyon 141 in particular before it departs the Meltwater pad for exploration we would like to temporarily shutdown operations on this well and move drilling operations to well 2P-406 (already approved by the commission, Permit to Drill # 204-022). Please find attached for the review of the Commission Form 10-403. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, -\<:c'-4~~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ECEIVE':. FES 2 6 2004 A.liEka 9, CorM ,1,nfhor3Qf OR\G\NAL ALA! OIL AND ~:~~g~S~':;A~ON COM!SION E C E IV . Ü~I Jì APPLICATION FOR SUNDRY APPROV ALFEB 26 2004 ~> . 20 AAC 25.280 .l:.JJ b Gal! r;¡)(\~ Cmr:¡"¡,,SlOn ~ Operational shutdown 0 PerforateL:J Vari~Rr;hI)P.\t1;O Annular Dispos.D Plug Perforations D Stimulate D Time Extension' D Other D D I 1. Type of Request: D Alter casing D D Abandon Suspend Repair well Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' RKB, 252' AMSL 8. Property Designation: ADL 3731121 L 32092 11. Total Depth MD (ft): 2496 Casing Structural Conductor Surface Total Depth TVD (ft): Effective Depth MD (ft): 2369 2406 Length Size 80' 2459 16" 9.625" Intermediate Production Liner Perforation Depth MD (ft): D D D Perforate New Pool Re-enter Suspended Well D 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D 5. Permit to Drill Number: 204-032 ./ 6. API Number: / 50-103-20487-00 . 9. Well Name and Number: 2P-443 10. FieldlPools(s): Kuparuk River Field / Meltwater Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 2291 MD TVD Burst Collapse 108 2487 108 2362 5750 3090 Perforation Depth TVD (ft): Packers and SSSV MD (ft): Packers and SSSV Type: 12. Attachments: Description Summary of Proposal D Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Yes (email) Commission Representative: Tom Maunder 2/25/2004 Date:2/22/2004 Tubing Size: Tubing Grade: Tubing MD (ft): 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Service D Plugged D WINJ D Abandoned D WDSPL D Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Philip Havden @ 265-6481 Printed Name R. Thomas Title Kuparuk Team Leader Signature ~\~ Phone 265-6830 COMMISSION USE ONLY 2 (z .,l '" <-~ Date Prenared hv Phitin havdAn Conditions of approval: Notify Commission so that a representative may witness ~«Ð~'m-~\O "-~ hot""\. ~Q: \ \. C. <CH-, f 'e: \\ c ~ Plug Integrity D BOP Test D Mechanical Integrity Test D Form 10-403 Revised 2/2003 Sundry Number: .3~- tt;b I Location Clearance D RØDMS BfL MAR 0200\ COMMISSIONER BY ORDER OF THE COMMISSION -rff ORiGINAL SUBMIT IN DUPLICATE . . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA.. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk 2P-443 Kuparuk Team Leader Permit No: 204-032 Surface Location: 998' FNL, 1680' FWL, SEC. 17, T8N, R7E, UM Bottomhole Location: 474' FSL, 1424' FEL, SEC. 8, T8N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law :ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. PIe provide at least twenty-four (24) hours notice for a representative of the Commission t wit ss any required test. Contact the Commission's North Slope petroleum field· ctor 6 - 607 (pager). BY ORDER OF ;rHE COMMISSION DATED thisæðay of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocJT>'hillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com February 12, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Meltwater producer well 2P-443 Dear Sir / Madam / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill onshore production well 2P-443 in the Bermuda sands of the Meltwater oil pool. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for this well. The planned spud date for this well is 02/25/2004. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, T<.--.;., \ ~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEiV FEB 1 2 2004 Ala:¡ka 01\ ,& Gas Com: Am~ìw(agF ORIGINAL 1 a. Type of Work: Drill 0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: ExploratoryU DevelopmentOill:d Am:!WraYJJlultipleZone D Service D Development Gas D Single Zone 0 5. Bond: l:d Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 2P-443 6. Proposed Depth: 12. Field/Pool(s): MD: 6396'" TVD: 5720' / Kuparuk River Field 7. Property Designation: AD'- ~73112"ÁÞ 8. Land Use Permit: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 998' FNL, 1680' FWL, Sec. 17, T8N, R7E, UM ,- Top of Productive Horizon: 380' FSL, 1573' FEL, Sec. 8, T8N, R7E, UM Total Depth: 474' FSL, 1424' FEL, Sec. 8, T8N, R7E, UM / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 443640 ¡' 16. Deviated wells: Kickoff depth: 400 ft. 18. Casing Program Size Hole 42" 12.25" Casing 16" 9.625" 51/2" 31/2" 8.5" 8.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): ADL 32092 9. Acres in Property: 5760 10. KB Elevation f'"c... ", J'~I Kt:GI:: IV L It) FEB 1 2 2004 ~;IiL KE Q ., ( Meltwater Oil Pool . 13. Approximate Spud Date: 2/25/2004 14. Distance to Nearest Property: 4282' @ Surface 15. Distance to Nearest / y- 5868881 Zone- 4 (Height above GL): 252 feet Well within Pool: 2P-420, 1750 17. Anticipated Pressure (see 20 AAC 25.035) Maximum Hole Angle: 30.43° Max. Downhole Pressure: 2900 psig I Max. Surface Pressure: 2389 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Grade Coupling Length MD TVD MD TVD (including stage data) H-40 Weld 80 28 28 108 108 410 sx Artic Set I (preinstalled) L-80 BTC 2482 28 28 2510 2369 313 sx ASLite, 217 sx LiteCRETE tail L-80 BTCM 5570 28 28 5598 5032 499 sx of GasBLOK L-80 EUE8RDM 798 5598 5032 6396 5720 Included above Weight 62.5# 40# 15.5# 9.3# PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD Length Size None 20. Attachments: Filing Fee 0 Property Plat D BOP Sketch U Diverter Sketch D Perforation Depth TVD (ft): None Drilling Programl:d Time v. Depth Plot D Seabed Report D Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Signature R. Thomas ~- ·.øi'- \ ~ l Contact Philip Hayden @ 265-6481 Title Kuparuk Team Leader Phone u,~ 10 Date Vt ~rDC'f PreDared bv PhiliD havden Permit to Drill ~ / I Number: 2-D f...( ,....032, Conditions of approval : Sam Commission Use Only API Number: , /n I Permit Approval 50- /() 3 ~ L.O Y1:5 7-(X) Date: ~ ;2.-/0 c¡ DYes g No Mud log required DYes RNO Directional survey required BY ORDER OF o R I C&lISÑÃ L THE COMMISSION Isee cover letter for other requirements DYes g No )rYes D No Date: ¥t/ft Submit in duplicate · APPle for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 Permit It - Meltwater Well #2P-443 Application for Permit to Drill Document MoximiZI!! Well "'glue Table of Contents 1. Well Name... ........... ... .............. ................ ........... ........ ................ ........... ....... ...... ....... 2 Requirements of 20 AAC 25.005 (f)........ .......... ... ..... .... ...................................... ................... ........ .........2 2. Location Sum mary ....... ............... ....... ......... ........ .............. .......... ........... ........ ..... ..... 2 Requirements of 20 AAC 25.005(c)(2) ........................... ............................... .........................................2 Requirements of 20 AAC 25. 050(b )....... ..................................... ......................... ........... .......... .............. 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ....... .......... ............................. ............. ............. .... ....................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................4 6. Casing and Cementing Program............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ....... .... .... .................... ......... ....... ........ ......... ...... ...... ...... ...... ....... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ........ ......... ............. ............................... ......... .... ................ ......... 4 8. Dri II i ng FI u id Program ......... ....................... ......... ............. ........... .......... ......... ......... 5 Requirements of 20 AAC 25.005(c)(B) .... ....................... .... ....... ............ ........ ........ ......... ........................ 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Production Hole Mud Program (LSND) ..... ........... .................. ......... ......... .......... ................... ......... ........ 5 9. Abnormally Pressured Formation Information...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 1 O. Seismic Analysis .......... ......... .................. ........... ........ ...... ....................... ........ ......... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ...............................................................................................6 ORIGINAL 2P-443 PERMIT IT.doc Page 1 of 7 Printed: 11-Feb-04 · APPI. for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ................... .......... ...................... ........ ........ .................. ............. ........... 7 Attachment 1 Directional Plan (14 pages) .............................................................................................. 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 7 Attachment 4 Well Schematics (1 page) ................................................................................................ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique flame designated by the operator and a unique API number assigned by the commission uflder 20 AAC 25.040(b). For a wel/ with multiple well branches, each branch must simi/arly be identified by a unique flame and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2P-443. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item a/ready on file with the commission and identifìed in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of [I¡e proposed location of the well at the surrac~ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we!1 at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,868,881 / Eastings: 443,640 " 998' FNL, 1680' FWL, Section 17, TBN, R7E, UM ./ I RKB Elevation I 252' AMSL Pad Elevation 224' AMSL Location at Top of Productive Interval (Bermuda Sand) ~ NGS Coordinates Northings: 5,870,244 380' FSL, 1573' FEL, Section 8, TBN, R7E, UM Eastings: 445,672 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6,049 5,420 5,168 Location at Total Depth NGS Coordinates Northings: 5,870,337 Eastings: 445,821 474' FSL, 1424' FEL, Section 8, T8N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6,396 5,720 5,468 ,/ and ORIGINAL 2P-443 PERMIT IT.doc Page 2 of 7 Printed: 11-Feb-04 · APPI. for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 (D) other information required by 20 MC 25.050(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviat~ the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wel/bore, including all adjacent well bores within 200 feet of any portion of the proposed welt Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wel/bore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified mail/ or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with tIle commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 MC 25.03fi or 20 MC 25.03~ as applicable/ An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2P-443. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fOr a Pemlit to Dril/ must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on dJilling hazard~ including (A) the maximum downhole pressure that may be encountere4 criteria us'"ed to determine it, and maximum potential surface pressure based on a methane gradient,· The expected reservoir pressures in the Bermuda sands in the 2P-443 area vary from 0.43 to 0.54 psi/ft, /' or 8.3 to 10.3 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 2389 psi, calculated as follows: MPSP =(5556 ft)(0.54 - 0.11 psi/ft) / =2389 psi (B) data on potential gas zone~' Due to the presence of high annular pressures on some of the Meltwater wells (2P-431, 451 & 438) and ./ the occurrence of gas in some of the wells drilled to date in the current program there is the risk of encountering a pressured shallow zone. This interval may be encountered through the C-80 formation to the top of the Bermuda. The original high pressures recorded in these annuli were of concern but as can be seen from the following table a series of annular bleeds together with an observed natural decline in pressures have reduced the potential maximum pressure considerably: Original C-80 Pressure 1751 1541 Well Surface Pressure 1600 1380 Fluid Level 2387 2160 C-80 Equivalent Gradient (ppg) 13.85 12.23 Surface Pressure 1200 750 Fluid Level 193 1392 Latest C-80 Pressure 1678 1020 (-80 Equivalent Gradient (ppg) 13.27 8.10 2P-431 2P-451 ORIGINAL 2P-443 PERMIT IT. doc Page 3 of 7 Printed: 11-Feb-04 · APPI. for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 I 2P-438 I 879 I 895 I 1245 9.83 800 I 768 I 1216 9.60 Using the latest annular pressures available the highest pressure that would be expected is approximately V' 1678 psi at 2464 ft 1VD or 13.1 ppg EMW. Most of the previously drilled Meltwater wells have had an FIT/LOT of approximately 16 ppg thus indicating that this pressured interval, should it exist, can be safely - controlled with standard well control methods. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tesf0 as required under 20 MC 25. 030{f); 2P-443 will be completed with 9 5/8" surface casing landed above the C-80 mudstone interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 42 Top MDITVD (ft) 28 / 28 Btm MDITVD (ft) 108 /108 Csg/Tbg 00 (in) 16 Weight (/b/ft) 62.5 Length (ft) 80 Grade H-40 Connection Welded 9 5/8 12 V4 2482 28 / 28 2510/2369 40 L-80 BTC 5'/2 8 V2 15.5 L-80 BTCM 28 / 28 5598 / 5032 5598 / 5032 6396 / 5720 5570 3'/2 8 V2 9.3 L-80 EUE8RD Mod 798 Cement Program Cemented to surface with 410 sx ArticSet I Cement to Surface with 313 sx ASLite Lead, 217 sx LiteCRETE Tail Cement Top planned @ 5298' MD/ 4773'1VD. Cemented w/ 499 sx GasBLOK 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: ORIGINAL 2P-443 PERMIT IT.doc Page 4 of 7 Printed: 11-Feb-04 · APPI. for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 (7) a diagram and description of the diverter system as required by 20 MC 2£035, unless this requirement is waived by the commission under 20 MC 2£03S(II){2); A 21 V4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2P-443. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a drill1Í7g fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 2£033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) pH API Filtrate (cc / 30 min)) Chlorides (mg/I) Initial Value 8.6 250 35-45 9-9.5 6 <600 *9.6 ppg if hydrates are encountered Final Value ~9.2 250 35-45 9-9.5 6 <600 Production Hole Mud Program (LSND) 95/8" Casin,q Shoe to TO Initial Value Final Value 9.6 10.3 - 10.7 22-28 10-15 Density (ppg) Yield Point (cP) pH API Filtrate (cc /30 min)) HTHP @ 15d' (cc)) 9-9.5 4-6 <12 9-9.5 4 <12 Base of Permafrost to 9 5/8" Casing Point milialVallie FmalVæue ~9.2* 10.5 150-200 55-65 ,.- 30- 35 12-15 9-9.5 9-9.5 4-6 4-6 <600 <600 / Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an Item already on flle with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel!¡ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 2£033(f),' Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL 2P-443 PERMIT IT.doc Page 5 of 7 Printed: 11-Feb-04 · APPle for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform mobile bottom-founded stroctl.lre, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met,· Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fol/owlilg Items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test (conductor has already been installed and cemented). 2. Spud and directionally drill 12 V4" hole to casing point at 2510' MD /2369' 1VD as per directional plan. Run MWD tools as required for directional monitoring and LWD tools (GR & resistiv!!y) as required for data acquisition. 3. Run and cement 95/8",40# L-80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system and install wellhead and test. Install and test 13 5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. ./' 5. PU 8 V2" bit and 6 V4" drilling assembly, with MWD and LWD (GR, resistivity & neutron density). RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 6. Drill out cement and 20' of new hole. Perform LOT or FIT to 18.0 ppg EMW, recording results. 7. Directionally drill to 5 112" x 3 112" casing point at 6396' MD / 5720' 1VD. 8. Run 5 V2", 15.5# L-80, BTC Mod x 3 V2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and displace with water and mud. Note that the cross over and seal bore extension for the completion will be positioned 200' MD above the Cairn interval, if present, as this is an interval that may be produced later in the life of the field. 9. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 10. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV ORIGINAL 2P-443 PERMIT IT.doc Page 6 of 7 Printed: 11-Feb-04 · APPI. for Permit to Drill, Well 2P-443 Revision No.O Saved: 11-Feb-04 11. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Carry out LOT and injection test on the outer annulus. Sweep the annulus with water and freeze protect. 12. Set BPV and move rig off. 13. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). Perforate well and rig down wire line unit. 14. Carry out fracture stimulation. 15. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an Item already on file with the commission and identífìed in the application: (14) a general description of how the operator plans to dispose of drilling mud and cutt/ÌJgs and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids ........ into a permitted annulus on 2P Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2P Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. At the end of drilling operations, an application may be submitted to permit 2P-443 for annular disposal of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 Directional Plan (14 pages) Attachment 2 Dril/íng Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) ORIGINAL 2P-443 PERMIT IT.doc Page 7 of 7 Printed: 11-Feb-04 Scale 1 cm = 80 ft -160 0 160 o :::0 - iG) - z: I» r- Base Permafrost I SURFACE LOCATION: t 998' FNL, 1680' FWL SEC. 17, T8N, R7E 320 ~ EOC Base West Sak ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Meltwater Installation: Drill Site 2P 480 640 C80 9 S/8in Casing 800 East (feet) -> 1120 1280 1440 960 ~ ~'Î ~\ C37 C40 C50 ConocJPhillips Slot: slot #443 Well: 443 Wellbore: 2P-443 Created by: Planner Date plotted: 28-Jan-2004 Plot reference is 2P-443. Ref wellpath is 2P-443 Version #4.A Coordinates are in feet reference slot #443. True Vertical Depths are reference Ri9 Datum, Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North, 1600 1760 1920 2080 2240 2400 2560 2720 - 1760 . I ' - I TO LOCATION: I 474' FSL, 1424' FEL 1- f- TD, Casing PI. SEC. 8, T8N, R7E I I ~ C35(Top Albian) T2(Base Bermuda) T3(Top Bermuda) YGT T4.1 ~ ~ T4.2(Top Cairn) /' _ 51/2x31/2XO 1600 - 1440 - 1280 T7 ! TARGET LOCATION: I - 1120 1380' FSL, 1573' FEL SEC. 8, T8N, R7E ^ 960 I Z 0 800 ~ :T - c;r . 640 () .... - I r 480 320 160 Cf) 0 Q) CD 0 0 3 II - -160 co 0 = ¡;:: 0 -400 0 C'\I II E 0 0 Q) (ij 0 CJ) 400 800 1200 1600 - ã) 2000 .æ - ;; 2400 Co CI> C 2800 CO 0 :e 3200 CI> > CI> ;j 3600 .... l- I V 4000 4400 4800 5200 5600 6000 6400 e-- -~~. ConocoPhillips Alaska, Inc. ConocJÃ,illipS .,a: --~---_. Location: North Slope, Alaska Slot: slot #443 Field: Meltwater Well: 443 Installation: Drill Site 2P Wellbore: 2P-443 --- ._'''~,_..~"'_..~--,"" INTEQ Created by: Planner Date plotted: 28-Jan-2004 Plot reference is 2P-443. Ref wellpath is 2P-443 Version #4A Coordinates are in feet reference slot #443. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North. Ii RKB Elevation: 252' WELL PROFILE DATA Point MD Inc Azi TVD North East deg/100ft V. Sect KOP -~-~-----~- Tie on 000 000 0.00 0.00 0.00 0.00 0.00 0.00 ./ 4.00 8.00 End of Hold 400.00 0.00 000 400.00 0.00 0.00 0.00 0.00 BldlTrn 2/100 KOP 900.00 10.00 25.00 897.47 39.44 18.39 2.00 37.42 13.13 End of BuildlTurn 2029.01 30.43 57.51 1953.87 285.01 304.68 2.00 412.29 16.63 Base Permafrost Target 2P-414 Top Berm 6048.70 30.43 57.51 5420.00 1378.33 2021.80 0.00 2446.93 DLS: 2.00 deg/100ft End of Hold 6206.42 30.43 57.51 5556.00 1421.23 2089.17 0.00 2526.76 26.00 29.86 " .. TD. & End of Hold 6396.42 30.43 57.51 5719.84 1472.91 2170.33 0.00 2622.93 Base West Sak ~-~--~-~- EOC v;\v 9 518in Casing C80 C50 C40 C37 5 1/2 x 31/2 XO v;\v T4.2(Top Cairn) T4.1 T3(Top Bermuda) TGT T2(Base Bermuda) \ C35(Top Albian) \þ\ \> TO. Casing Pt. -400 -0 400 800 1200 1600 2000 2400 2800 3200 Seale 1 em = 200 ft Vertical Section (feet) -> Azimuth 55.72 with reference 0.00 N, °ð f<lm~1 f\JÌ\ L ConoeoPhillips Alaska, Ine.. Location: Field: Insta lIation: North Slope, Alaska Meltwater Drill Site 2P Slot: Well: Wellbore: slot #443 443 2P-443 G ¡nips CIBatecFEy "P!a-nner 340 20 Ref well path is 2P-443 Version #4.A Coordinates are in feet reference slot #443 True Vertica! Depths are reference Rig Datum Measured Depths are reference Rig Datum Rig Datum: Doyon #141 Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North, TRUE NORTH 350 o 10 90 All depths shown are depths on Reference Well Normal Plane Travelling Cylinder - Feet I Created by Planner Date plotted 4-Feb-2004 ConocoPhiUips Alaska" Inc. píotœfe'œnce is 2P-443 Ref wellpatl1 is 2P-443 Version #4.A Location: North Slope, Alaska Slot: Canoe ¡lIips Coordinates are in feet reference slot #443 slot #443 True Vertical Depths are reference Rig Datum Field: Meltwater Well: 443 Measured Depths are reference Rig Datum -~"--~_.._--_.-_.~ Installation: Drill Site 2P Well bore: Rig Datum: Doyon #141 INTEQ 2P-443 Rig Datum to mean sea level: 252.00 ft ~~<:~_N_~_i!~,_!~_ aligned to TRUE North Seale 1 em = 20 ft East (feet) -> -120 -80 -40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 440 P 440 400 400 400 360 360 320 320 ¿ooo 280 280 1900 240 240 ^ , Z 200 200 0 2000 ;:¡ :::r - 160 15f)(j 160 ¡:¡r (!) '800 - - 1400 120 120 80 1400 80 13DO 120CI 1000 40 1200 40 700 800 <t= (/) 0 0 -0 (') N ß) II ro E (') u -40 -40 3 1300 (j) II -¡¡¡ tv u 0 (j) -80 -80 ~ -120 -80 -40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 Seale 1 em = 20 ft East (feet) -> Created by ConocoPhillips Alaska., Inc. ~/ Date plotted Location: North Slope, Alaska Slot: ConocoPhillips Plot reference is 2P-443 slot Ref we!lpath is 2P-443 Version #4.A Field: Meltwater Well: 443 Coordinates are in feet reference slot #443 True Vertical Depths are reference Rig Datum Installation: Dríll Site 2P Wellbore: 2P-443 Measured Depths are reference Rig Datum Rig Datum: Doyon #141 Rig Datum to mean sea level: 252.00 ft Plot North is aligned to TRUE North Seale 1 em = 60 ft East (feet) -> 0 120 240 360 480 600 720 840 960 1080 1200 1320 1440 1560 1680 1800 1920 2040 2160 2280 2400 2520 1560 1560 1440 - 1440 1320 ,,200 1320 5000 1200 1200 1080 1080 960 960 ^ , J,IOO :z 840 840 0 :::i. :::::r 720 720 - (i ,200 ~ - 600 600 480 2Boo 480 'DO 360 360 000 ¢::ó (j) 0 240 240 (") <D ill II (i) E (") Q 120 120 3 (\) II -¡¡¡ (j) Q 0 (f) 0 -0 ;::Þ 0 120 240 360 480 600 720 840 960 1080 1200 1320 1440 1560 1680 1800 1920 2040 2160 2280 2400 2520 Seale 1 em = 60 ft East (feet) -> . Conocri'Phillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 2P-443 Well path: 2P-443 Version #4.A Date Printed: 4-Feb-2004 INTEQ Wellbore Name 2P-443 Well Name 443 I Govemment ID I Last Revised I 12-Sep-2003 Slot Name slot #443 I Grid NorthinQ I Grid Eastina I Latitude 5868880.8016 ..- 443640.2600 /" N70 3 8.7035 I LonQitude W150 273.6676 Installation Name Drill Site 2P Coord System Name I North AIiQnment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True . Field Name Meltwater I EastinQ 441964.2388 I NorthinQ 5869891.4660 I Coord System Name ./ I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . ConocriPhillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska . PROPOSAL LISTING Page 2 Well bore: 2P-443 Well path: 2P-443 Version #4.A Date Printed: 4-Feb-2004 INTEQ Wellpath (Grid & LatlLong) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Northing Easting Latitude Longitude Vertical Sectionlftl 0.00 0.00 0.00 0.00 5868880.80 443640.26 N70 3 8.7035 W150 27 3.6676 0.00 100.00 0.00 0.00 100.00 5868880.80 443640.26 N70 3 8.7035 W150 27 3.6676 0.00 200.00 0.00 0.00 200.00 5868880.80 443640.26 N70 3 8.7035 W150 27 3.6676 0.00 300.00 0.00 0.00 300.00 5868880.80 443640.26 N70 3 8.7035 W150 27 3.6676 0.00 400.00 0.00 0.00 400.00 5868880.80 443640.26 N70 3 8.7035 W150 27 3.6676 0.00 500.00 2.00 25.00 499.98 5868882.38 443641.01 N70 3 8.7191 W150 27 3.6463 1.50 600.00 4.00 25.00 599.84 5868887.10 443643.26 N70 3 8.7657 W150 27 3.5826 6.00 700.00 6.00 25.00 699.45 5868894.97 443647.00 N70 3 8.8434 W150 27 3.4765 13.49 800.00 8.00 25.00 798.70 5868905.98 443652.23 N70 3 8.9520 W150 27 3.3282 23.97 900.00 10.00 25.00 897.47 5868920.11 443658.94 N70 3 9.0915 W150 27 3.1377 37.42 1000.00 11.50 32.13 995.71 5868936.35 443668.03 N70 3 9.2519 W150 27 2.8793 54.02 1100.00 13.13 37.58 1093.41 5868953.70 443680.39 N70 3 9.4234 W150 27 2.5271 73.94 1200.00 14.85 41.81 1190.45 5868972.13 443695.99 N70 3 9.6059 W150 27 2.0815 97.17 1300.00 16.63 45.17 1286.69 5868991.63 443714.82 N70 3 9.7991 W150 27 1.5431 123.68 1400.00 18.45 47.89 1382.04 5869012.17 443736.86 N70 3 10.0027 W150 27 0.9126 153.43 1500.00 20.31 50.13 1476.37 5869033.73 443762.09 N70 3 10.2165 W150 27 0.1906 186.39 1600.00 22.19 52.00 1569.57 5869056.27 443790.46 N70 3 10.4403 W150 26 59.3781 222.51 1700.00 24.09 53.60 1661.52 5869079.77 443821.94 N70 3 10.6738 W150 26 58.4760 261.75 1800.00 26.00 54.98 1752.11 5869104.21 443856.50 N70 3 10.9166 W150 26 57.4855 304.07 1900.00 27.93 56.18 1841.24 5869129.55 443894.10 N70 3 11.1686 W150 26 56.4078 349.42 2000.00 29.86 57.23 1928.78 5869155.76 443934.68 N70 3 11.4294 W150 26 55.2442 397.73 2029.01 30.43 57.51 1953.87 5869163.52 443947.01 N70 3 11.5066 W150 26 54.8907 412.29 2100.00 30.43 57.51 2015.08 5869182.61 443977.47 N70 3 11.6965 W150 26 54.0171 448.22 2200.00 30.43 57.51 2101.31 5869209.49 444020.39 N70 3 11.9640 W150 26 52.7865 498.84 2300.00 30.43 57.51 2187.54 5869236.37 444063.30 N70 3 12.2315 W150 26 51.5559 549.46 2400.00 30.43 57.51 2273.77 5869263.24 444106.21 N70 3 12.4990 W150 26 50.3253 600.07 2500.00 30.43 57.51 2360.00 5869290.12 444149.13 N70 3 12.7664 W150 26 49.0946 650.69 2600.00 30.43 57.51 2446.23 5869317.00 444192.04 N70 3 13.0339 W150 26 47.8640 701.31 2700.00 30.43 57.51 2532.46 5869343.88 444234.95 N70 3 13.3014 W150 26 46.6334 751.92 2800.00 30.43 57.51 2618.68 5869370.76 444277.87 N70 3 13.5689 W150 26 45.4027 802.54 2900.00 30.43 57.51 2704.91 5869397.64 444320.78 N70 3 13.8363 W150 26 44.1720 853.16 3000.00 30.43 57.51 2791.14 5869424.52 444363.70 N70 ;3 14.1038 W150 26 42.9414 903.77 3100.00 30.43 57.51 2877.37 5869451.40 444406.61 N70 3 14.3713 W150 26 41.7107 954.39 3200.00 30.43 57.51 2963.60 5869478.28 444449.52 N70 3 14.6387 W150 26 40.4800 1005.01 3300.00 30.43 57.51 3049.83 5869505.16 444492.44 N70 3 14.9062 W150 26 39.2493 1055.62 3400.00 30.43 57.51 3136.06 5869532.04 444535.35 N70 3 15.1737 W150 26 38.0186 1106.24 3500.00 30.43 57.51 3222.29 5869558.92 444578.26 N70 3 15.4411 W150 26 36.7878 1156.86 3600.00 30.43 57.51 3308.51 5869585.80 444621.18 N70 3 15.7086 W150 26 35.5571 1207.47 3700.00 30.43 57.51 3394.74 5869612.68 444664.09 N70 3 15.9760 W150 26 34.3264 1258.09 3800.00 30.43 57.51 3480.97 5869639.56 444707.00 N70 3 16.2435 W150 26 33.0956 1308.71 3900.00 30.43 57.51 3567.20 5869666.44 444749.92 N70 3 16.5109 W150 26 31.8649 1359.32 4000.00 30.43 57.51 3653.43 5869693.32 444792.83 N70 3 16.7784 W150 26 30.6341 1409.94 4100.00 30.43 57.51 3739.66 5869720.20 444835.74 N70 3 17.0458 W150 26 29.4033 1460.56 4200.00 30.43 57.51 3825.89 5869747.08 444878.66 N70 3 17.3133 W150 26 28.1726 1511.17 4300.00 30.43 57.51 3912.12 5869773.96 444921.57 N70 3 17.5807 W150 26 26.9418 1561.79 4400.00 30.43 57.51 3998.35 5869800.84 444964.48 N70 3 17.8481 W150 26 25.7110 1612.41 4500.00 30.43 57.51 4084.57 5869827.72 445007.40 N70 3 18.1156 W150 26 24.4802 1663.03 4600.00 30.43 57.51 4170.80 5869854.60 445050.31 N70 3 18.3830 W150 26 23.2493 1713.64 4700.00 30.43 57.51 4257.03 5869881.48 445093.23 N70 3 18.6504 W150 26 22.0185 1764.26 4800.00 30.43 57.51 4343.26 5869908.35 445136.14 N70 3 18.9179 W150 26 20.7877 1814.88 4900.00 30.43 57.51 4429.49 5869935.23 445179.05 N70 3 19.1853 W150 26 19.5568 1865.49 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . ConocÓPhillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska . PROPOSAL LISTING Page 3 Wellbore: 2P-443 Well path: 2P-443 Version #4.A Date Printed: 4-Feb-2004 Well path (Grid & Lat/Lona) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Northing Easting Latitude Longitude Vertical Section 1ft 1 5000.00 30.43 57.51 4515.72 5869962.11 445221.97 N70 3 19.4527 W150 26 18.3260 1916.11 5100.00 30.43 57.51 4601.95 5869988.99 445264.88 N70 3 19.7201 W150 26 17.0951 1966.73 5200.00 30.43 57.51 4688.18 5870015.87 445307.79 N70 3 19.9876 W150 26 15.8643 2017.34 5300.00 30.43 57.51 4774.40 5870042.75 445350.71 N70 3 20.2550 W150 26 14.6334 2067.96 5400.00 30.43 57.51 4860.63 5870069.63 445393.62 N70 3 20.5224 W150 26 13.4025 2118.58 5500.00 30.43 57.51 4946.86 5870096.51 445436.53 N70 3 20.7898 W150 26 12.1716 2169.19 5600.00 30.43 57.51 5033.09 5870123.39 445479.45 N70 3 21.0572 W150 26 10.9407 2219.81 5700.00 30.43 57.51 5119.32 5870150.27 445522.36 N70 3 21.3246 W150 26 9.7098 2270.43 5800.00 30.43 57.51 5205.55 5870177.15 445565.27 N70 3 21.5920 W150 26 8.4789 2321.04 5900.00 30.43 57.51 5291.78 5870204.03 445608.19 N70 3 21.8594 W150 26 7.2479 2371.66 6000.00 30.43 57.51 5378.01 5870230.91 445651.10 N70 3 22.1268 W150 26 6.0170 2422.28 6048.70 30.43 57.51 5420.00 5870244.00 445672.00 N70 3 22.2570 W150 26 5.4175 2446.93 6100.00 30.43 57.51 5464.24 5870257.79 445694.01 N70 3 22.3942 W150 26 4.7860 2472.89 6200.00 30.43 57.51 5550.47 5870284.67 445736.93 N70 3 22.6616 W150 26 3.5551 2523.51 6206.42 30.43 57.51 5556.00 5870286.39 445739.68 N70 3 22.6788 W150 26 3.4761 2526.76 6300.00 30.43 57.51 5636.69 5870311.55 445779.84 N70 3 22.9290 W150 26 2.3241 2574.13 6396.42 30.43 57.51 5719.84 5870337.47 445821.22 N70 3 23.1868 W150 26 1.13721 2622.93 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . )or' ConocOPhillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 2P-443 Well path: 2P-443 Version #4.A Date Printed: 4-Feb-2004 ... BAKER HUGHES INTEQ Comments MDfft] TVDfft] Northfftl East[ft] Comment 400.00 400.00 O.OON O.OOE KOP 900.00 897.47 39.45N 18.39E BldlTrn 21100 1368.38 1352.00 125.43N 88.37E Base Permafrost 2026.84 1952.00 284.42N 303.75E Base West Sak 2029.01 1953.87 285.01 N 304.68E EOC 2510.44 2369.00 415.96N 510.33E 9 5/8" CasinQ 2620.61 2464.00 445.92N 557.40E C80 3271.21 3025.00 622.88N 835.32E C50 3584.33 3295.00 708.04N 969.07E C40 3780.32 3464.00 761.35N 1052.80E C37 4945.82 4469.00 1078.36N 1550.67E T7 5598.20 5031.54 1255.80N 1829.35E 5 1/2 x 3 1/2 XO 5798.20 5204.00 1310.20N 1914.79E T4.2(Top Cairn) 5903.74 5295.00 1338.90N 1959.87E T4.1 6048.70 5420.00 1378.33N 2021.80E T3(Top Bermuda) TGT 6206.42 5556.00 1421.23N 2089.17E T2(Base Bermuda) 6259.77 5602.00 1435.74N 2111.96E C35(ToP Albian) 6396.42 5719.84 1472.91 N 2170.34E TO. CasinQ PI. Hole Sections Diameter Start Start Start Start End End End Start Wellbore fin] MOfft] TVD[ft] Northfftl Eastfft] MOfft] TVDfft] Northfft] East[ft] 121/4 0.00 0.00 O.OON O.OOE 2510.44 2369.00 415.96N 510.33E 2P-443 81/2 2510.44 2369.00 415.96N 510.33E 6396.42 5719.84 1472.91N 2170.34E 2P-443 Casinas Name iTop Top Top Top Shoe Shoe Shoe Shoe Wellbore MOfft] TVDfft] Northfft] Eastfft] MDfft] TVDfft] Northfftl East[ft] 9 5/8in CasinQ 0.00 0.00 O.OON O.OOE 2510.44 2369.00 415.96N 510.33E 2P-443 5 1/2in CasinQ 0.00 0.00 O.OON O.OOE 5598.20 5031.54 1255.80N 1829.35E 2P-443 3 1/2in CasinQ 5598.20 5031.54 1255.80N 1829.35E 6396.42 5719.84 1472.91N 2170.34E 2P-443 Taraets Name I Northfft] I East[ft] I TVOfft] I latitude 1l0nQitude 1 EastinQ 2P-414 Top Berm! 1378.33N 2021.80E· 5420.00 N70 3 22.257 W150 265.4 445672.00 TQt 22 Jul 03 I I NorthinQ I last Revised 5870244.00 6-Jan-2004 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . ~',... ConocòPhillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska Well bore Name 2P-443 I Created 12-Sep-2003 . PROPOSAL LISTING Page 1 Well bore: 2P-443 Wellpath: 2P-443 Version #4.A Date Printed: 4-Feb-2004 I Last Revised 29-Jan-2004 Name slot #443 Latitude N70 Installation Name Drill Site 2P I EastinQ 441964.2388 I NorthinQ 5869891.4660 Field Name Meltwater I EastinQ 441964.2388 I NorthinQ 5869891.4660 North 997.96S I Coord System Name I North AliQnment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True I Coord System Name I North AIiQnment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . ConocóPhillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska . PROPOSAL LISTING Page 2 Wellbore: 2P-443 Well path: 2P-443 Version #4.A Date Printed: 4-Feb-2004 INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Station Comment IdeQ/100ftl Sectionfftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 O.OON O.OOE 0.00 0.00 200.00 0.00 0.00 200.00 O.OON O.OOE 0.00 0.00 300.00 0.00 0.00 300.00 O.OON O.OOE 0.00 0.00 400.00 0.00 0.00 400.00 O.OON O.OOE 0.00 0.00 KOP, End of Hold 500.00 2.00 25.00 499.98 1.58N 0.74E 2.00 1.50 600.00 4.00 25.00 599.84 6.33N 2.95E 2.00 6.00 700.00 6.00 25.00 699.45 14.22N 6.63E 2.00 13.49 800.00 8.00 25.00 798.70 25.27N 11.78E 2.00 23.97 900.00 10.00 25.00 897.47 39.45N 18.39E 2.00 37.42 BldlTrn 2/100, 3DJ Kick off Point 1000.00 11.50 32.13 995.71 55.76N 27.36E 2.00 54.02 1100.00 13.13 37.58 1093.41 73.20N 39.59E 2.00 73.94 1200.00 14.85 41.81 1190.45 91.75N 55.06E 2.00 97.17 1300.00 16.63 45.17 1286.69 111.39N 73.75E 2.00 123.68 1368.38 17.87 47.08 1352.00 125.43N 88.37E 2.00 143.68 Base Permafrost 1400.00 18.45 47.89 1382.04 132.09N 95.64E 2.00 153.43 ~O.OO 20.31 50.13 1476.37 153.84N 120.70E 2.00 186.39 1600.00 22.19 52.00 1569.57 176.59N 148.91E 2.00 222.51 1700.00 24.09 53.60 1661.52 200.33N 180.22E 2.00 261.75 1800.00 26.00 54.98 1752.11 225.02N 214.60E 2.00 304.07 1900.00 27.93 5f;ì.18 1841.24 250.64N 252.02E 2.00 349.42 2000.00 29.86 57.23 1928.78 277.16N 292.41 E 2.00 397.73 2026.84 30.38 57.49 1952.00 284.42N 303.75E 2.00 411.19 Base West Sak 2029.01 30.43 57.51 1953.87 285.01 N 304.68E 2.00 412.29 EOC. End of BuildlTurn 2100.00 30.43 57.51 2015.08 304.32N 335.00E 0.00 448.22 2200.00 30.43 57.51 2101.31 331.52N 377.72E 0.00 498.84 2300.00 30.43 57.51 2187.54 358.72N 420.44E 0.00 549.46 2400.00 30.43 57.51 2273.77 385.92N 463.16E 0.00 600.07 2500.00 30.43 57.51 2360.00 413.12N 505.88E 0.00 650.69 2510.44 30.43 57.51 2369.00 415.96N 510.33E 0.00 655.97 95/8" CasinQ, 9 5/8in CasinQ 2600.00 30.43 57.51 2446.23 440.32N 548.59E 0.00 701.31 2620.61 30.43 57.51 2464.00 445.92N 557.40E 0.00 711.74 C80 2700.00 30.43 57.51 2532.46 467.52N 591.31E 0.00 751.92 2800.00 30.43 57.51 2618.68 494.71N 634.03E 0.00 802.54 2900.00 30.43 57.51 2704.91 521.91 N 676.75E 0.00 853.16 3000.00 30.43 57.51 2791.14 549.11 N 719.46E 0.00 903.77 3100.00 30.43 57.51 2877.37 576.31 N 762.18E 0.00 954.39 3200.00 30.43 57.51 2963.60 603.51 N 804.90E 0.00 1005.01 3271.21 30.43 57.51 3025.00 622.88N 835.32E 0.00 1041.05 C50 3300.00 30.43 57.51 3049.83 630.71 N 847.62E 0.00 1055.62 3400.00 30.43 57.51 3136.0& 657.91 N 890.33E 0.00 1106.24 3500.00 30.43 57.51 3222.29 685.11N 933.05E 0.00 1156.86 3584.33 30.43 57.51 3295.00 708.04N 969.07E 0.00 1199.54 C40 3600.00 30.43 57.51 3308.51 712.31N 975.77E 0.00 1207.47 3700.00 30.43 57.51 3394.74 739.51 N 1018.49E 0.00 1258.09 3780.32 30.43 57.51 3464.00 761.35N 1052.80E 0.00 1298.74 C37 3800.00 30.43 57.51 3480.97 766.71 N 1061.20E 0.00 1308.71 3900.00 30.43 57.51 3567.20 793.90N 1103.92E 0.00 1359.32 4000.00 30.43 57.51 3653.43 821.10N 1146.64E 0.00 1409.94 4100.00 30.43 57.51 3739.66 848.30N 1189.36E 0.00 1460.56 4200.00 30.43 57.51 3825.89 875.50N 1232.08E 0.00 1511.17 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . eonocJ'Phillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P Meltwater,North Slope, Alaska . PROPOSAL LISTING Page 3 Wellbore: 2P-443 Wellpath: 2P-443 Version #4.A Date Printed: 4-Feb-2004 mi. BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft) Dogleg Vertical Station Comment IdeQ/100ftJ Sectionrftl 4300.00 30.43 57.51 3912.12 902.70N 1274.79E 0.00 1561.79 4400.00 30.43 57.51 3998.35 929.90N 1317.51E 0.00 1612.41 4500.00 30.43 57.51 4084.57 957.10N 1360.23E 0.00 1663.03 4600.00 30.43 57.51 4170.80 984.30N 1402.95E 0.00 1713.64 4700.00 30.43 57.51 4257.03 1011.50N 1445.66E 0.00 1764.26 4800.00 30.43 57.51 4343.26 1038.70N 1488.38E 0.00 1814.88 4900.00 30.43 57.51 4429.49 1065.90N 1531.10E 0.00 1865.49 4945.82 30.43 57.51 4469.00 1078.36N 1550.67E 0.00 1888.69 T7 5000.00 30.43 57.51 4515.72 1093.09N 1573.82E 0.00 1916.11 5100.00 30.43 57.51 4601.95 1120.29N 1616.53E 0.00 1966.73 5200.00 30.43 57.51 4688.18 1147.49N 1659.25E 0.00 2017.34 5300.00 30.43 57.51 4774.40 1174.69N 1701.97E 0.00 2067.96 5400.00 30.43 57.51 4860.63 1201.89N 1744.69E 0.00 2118.58 5500.00 30.43 57.51 4946.86 1229.09N 1787.41E 0.00 2169.19 5598.20 30.43 57.51 5031.54 1255.80N 1829.35E 0.00 2218.90 5 1/2 x 3 1/2 XO. 5 1/2in CasinQ 5600.00 30.43 57.51 5033.09 1256.29N 1830.12E 0.00 2219.81 5700.00 30.43 57.51 5119.32 1283.49N 1872.84E 0.00 2270.43 5798.20 30.43 57.51 5204.00 1310.20N 1914.79E 0.00 2320.13 T4.2(Top Cairn) 5800.00 30.43 57.51 5205.55 1310.69N 1915.56E 0.00 2321.04 5900.00 30.43 57.51 5291.78 1337.89N 1958.28E 0.00 2371.66 5903.74 30.43 57.51 5295.00 1338.90N 1959.87E 0.00 2373.55 T4.1 6000.00 30.43 57.51 5378.01 1365.09N 2000.99E 0.00 2422.28 6048.70 30.43 57.51 5420.00 1378.33N 2021.80E 0.00 2446.93 T3(Top Bermuda) TGT, 2P-414 Top Berm Tgt 22 Jul 03, End of Hold 6100.00 30.43 57.51 5464.24 1392.28N 2043.71E 0.00 2472.89 6200.00 30.43 57.51 5550.47 1419.48N 2086.43E 0.00 2523.51 6206.42 30.43 57.51 5556.00 1421.23N 2089.17E 0.00 2526.76 T2(Base Bermuda), End of Hold 6259.77 30.43 57.51 5602.00 1435.74N 2111.96E 0.00 2553.76 C35(Top Albian) 6300.00 30.43 57.51 5636.69 1446.68N 2129.15E 0.00 2574.13 6396.42 30.43 57.51 5719.84 1472.91 N 2170.34E 0.00 2622.93 TO, Casing PI., 3 1/2in Casing, End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . Conoc6Phillips ConocoPhillips Alaska, Inc.,slot #443 Drill Site 2P, Meltwater,North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 2P-443 Wellpath: 2P-443 Version #4.A Date Printed: 4-Feb-2004 '&ií. BfaLs INTEQ Comments MDlftl TVDlftl Northlftl Eastlftl Comment 400.00 400.00 O.OON O.OOE KOP 900.00 897.47 39.45N 18.39E BldlTrn 2/100 1368.38 1352.00 125.43N 88.37E Base Permafrost 2026.84 1952.00 284.42N 303.75E Base West Sak 2029.01 1953.87 285.01 N 304.68E EOC 2510.44 2369.00 415.96N 510.33E 9 5/8" Casinç¡ 2620.61 2464.00 445.92N 557.40E C80 3271.21 3025.00 622.88N 835.32E C50 3584.33 3295.00 708.04N 969.07E C40 3780.32 3464.00 761.35N 1052.80E C37 4945.82 4469.00 1078.36N 1550.67E T7 5598.20 5031.54 1255.80N 1829.35E 5 1/2 x 3 1/2 XO 5798.20 5204.00 1310.20N 1914.79E T4.2(Top Calm) 5903.74 5295.00 1338.90N 1959.87E T4.1 6048.70 5420.00 1378.33N 2021.80E T3(Top Bermuda) TGT 6206.42 5556.00 1421.23N 2089.17E T2(Base Bermuda) 6259.77 5602.00 1435.74N 2111.96E C35(Top Albian) 6396.42 5719.84 1472.91 N 2170.34E TO. Casinç¡ pt. Hole Sections Diameter Start Start Start Start End End lEnd Start Wellbore [inl MOlftl TVDlftl Northlftl Eastlftl MOrftl TVOlftl Northlftl Eastlftl 121/4 0.00 0.00 O.OON O.OOE 2510.44 2369.00 415.96N 510.33E 2P-443 81/2 2510.44 2369.00 415.96N 510.33E 6396.42 5719.84 1472.91N 2170.34E 2P-443 Casinas Name Top Top Top Top Shoe Shoe ¡Shoe Shoe Wellbore MDlftl TVOlftl Northlftl Eastlftl MOlftl TVDrftl Northlftl Eastlftl 9 5/8in Casinç¡ 0.00 0.00 O.OON O.OOE 2510.44 2369.00 415.96N 510.33E 2P-443 5 1/2in CasinQ 0.00 0.00 O.OON O.OOE 5598.20 5031.54 1255.80N 1829.35E 2P-443 3 1/2in CasinQ 5598.20 5031.54 1255.80N 1829.35E 6396.42 5719.84 1472.91 N 2170.34E 2P-443 T araets Name I Northlftl 2P-414 Top Berm 1378.33N Tç¡t 22 Jul 03 I Eastlftl I TVDlftl I Latitude I LonQitude j EastinQ 2021.80E 5420.00 N70 3 22.2570 W150 265.411 445672.00 I NorthinQ 5870244.00 I Last Revised 6-Jan-2004 Survey Tool Proaram Reference I Survev Name 643138 I Planned IMDlftl 6396.42 I TVDlftl 5719.84 I Survey Tool ISCWSA MWD I Error Model I MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 55.72 degrees Bottom hole distance is 2622.94 Feet on azimuth 55.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGfNAL · . Baker Hughes Incorporated Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.0 ft Depth Range: 0.0 to 6396.4 ft Maximum Radius: 5280.0 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 1/16/2004 Validated: No Planned From To Survey ft ft 0.0 6396.4 Planned: 2P-443 Vers#4.A V6 Version: 4 Toolcode Tool Name MWD+SAG MWD + Sag correction Summary 443.2P-443.2P-443 Vers 6396.4 6396.4 0.0 170.3 -170.3 FAIL: Major Risk 2P Pad 406 2P-406 V3 Plan: 2P-406 1125.2 1000.0 744.8 22.2 722.6 Pass: Major Risk 2P Pad 414 2P-414 V3 Plan: 2P-414 1197.9 1100.0 578.5 24.7 553.8 Pass: Major Risk 2P Pad 415 2P-415 VO 299.9 300.0 560.3 4.9 555.4 Pass: Major Risk 2P Pad 415 2P-415A VO 299.9 300.0 560.3 4.9 555.4 Pass: Major Risk 2P Pad 416 2P-416 V1 Plan: 2P-416 981.6 925.0 543.7 19.9 523.8 Pass: Major Risk 2P Pad 417 2P-417 VO 2195.5 2100.0 246.4 52.6 193.9 Pass: Major Risk 2P Pad 419 2P-419 V5 992.2 950.0 481.9 21.4 460.6 Pass: Major Risk 2P Pad 420 2P-420 VO 2078.1 2000.0 228.1 48.7 179.4 Pass: Major Risk 2P Pad 422 2P-422 V7 880.5 850.0 421.8 17.7 404.0 Pass: Major Risk 2P Pad 422 422A VO 880.5 850.0 421.8 17.7 404.0 Pass: Major Risk 2P Pad 424 2P-424 V5 692.2 675.0 378.8 13.5 365.3 Pass: Major Risk 2P Pad 424 2P-424A VO 692.2 675.0 378.8 13.5 365.3 Pass: Major Risk 2P Pad 427 2P-427 VO 995.6 975.0 303.9 20.9 282.9 Pass: Major Risk 2P Pad 429 2P-429 VO 911.7 900.0 277.4 19.0 258.4 Pass: Major Risk 2P Pad 431 2P-431 V1 957.2 950.0 226.2 19.8 206.4 Pass: Major Risk 2P Pad 432 2P-432 V12 1238.4 1225.0 169.3 25.8 143.5 Pass: Major Risk 2P Pad 434 2P-434 V4 1431.7 1425.0 61.0 29.5 31.6 Pass: Major Risk 2P Pad 438 2P-438 VO 773.6 775.0 81.0 15.1 65.9 Pass: Major Risk 2P Pad 441 2P-441 VO 776.3 775.0 30.9 13.7 17.2 Pass: Major Risk 2P Pad 445 2P-445 Vers#4 VO Plan: 449.6 450.0 40.7 8.5 32.2 Pass: Major Risk 2P Pad 447 2P-447 V6 400.0 400.0 82.9 6.9 76.0 Pass: Major Risk 2P Pad 448 2P-448 V2 424.5 425.0 102.2 7.7 94.6 Pass: Major Risk 2P Pad 448 2P-448A VO 424.5 425.0 102.2 7.7 94.6 Pass: Major Risk 2P Pad 448 2P-448PB1 VO 424.5 425.0 102.2 7.7 94.6 Pass: Major Risk 2P Pad 449 2P-449 V2 Plan: 2P-449 350.0 350.0 120.6 6.5 114.2 Pass: Major Risk 2P Pad 451 2P-451 VO 325.0 325.0 160.5 5.5 155.0 Pass: Major Risk Meltwater North#1 MWN#1 MWN#1 VO Out of range Meltwater South #1 MWS#1 MWS#1 VO Out of range MWN#2 MWN#2 MWN#2A VO 5788.7 6800.0 893.3 207.3 686.0 Pass: Major Risk ORIGINAL . . MEL TW A TER - DRILLING HAZARDS SUMMARY 12 IA" Open Hole & 9 5/8" Surface Casine; Interval Event Broach of conductor Gas Hydrates Running sands & gravel Drill surface hole into shallow pressured interval- C-80 charged Hole swabbingfTight hole on trips Stuck surface casing Stuck pipe Lost circulation Risk level Low Low Moderate Low Moderate Low Low Low Mitigation Strategy I Contingency Monitor cellar continuously during interval If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Do not exceed the surface hole TD as detailed in the individual well plans, ensure that all stands (in the derrick or in the hole) are accounted for at all times Circulate hole clean prior to trip, proper hole filling (use of trip sheets), pumping out of hole as needed Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever possible Keep hole clean. If losses occur - reduce pump rates and mud rheology, use LCM 8 Iii' Open Hole & 5 Iii' x 3 Iii' Production Casine; Interval Event Drill through a shallow pressured interval: C-80 to C-37 Insufficient or undetermined LOT High ECD / Tight hole on trips/ Swabbing Differential sticking Barite sag Lost circulation Risk level Moderate Moderate Moderate Moderate Low High Mitigation Strategy I Contingency Carry out well control drills. Kill fluid stored on location, contingency 7" casing string on location, heightened awareness Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 ppg MW equivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible Good drilling practices as documented in well plan Pretreat mud before drilling reservoir section, keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheology, use LCM Meltwater Drilling Hazards Summary Prepared by Philip Hayden 2/11/2004 ORIGINAL Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/26/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com . t < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD < Base of Permafrost at 1,368 ft. MD (1,352 ft. TVD) < Top of Tail at 1,410 ft. MD < 95/8",40.0#, L-80 grade BTC, AB Modified in 12 1/4" OH TO at 2,510 ft. MD (2,369 ft. TVD) Mark of Schlumberger p Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 225% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 42' below base of permafrost.) Lead Slurry (minimum pump time 186 min.) ArcticSet III Lite @ 10.7 ppg, - 4.43 ft3/sk 3 0.7632 ft 1ft x (108') x 1.00 (no excess) = 0.3132 ft3/ft x (1368' -108') x 3.25 (225% excess) = 3 0.3132 ft 1ft x (1410' - 1368') x 1.45 (45% excess) = 82.4 ft3 + 1282.6 ft3+ 19.1 ft3 = 1384.1 ft3 14.43 ft3/sk = Round up to 313 sks 82.4 fe 1282.6 ft3 19.1 ft3 1384.1 ft3 312.4 sks Have 230 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 151 min.) LiteCRETE @ 12.0 ppg - 2.47 ft3/sk 3 0.3132 ft 1ft x (2510' - 1410') x 1.45 (45% excess) = 0.4257 ft3/ft x 80' JShoe Joint) = 499.6 ft3 + 34.1 ft = 533.7 ft31 2.47 ft3/sk = Round up to 217 sks 499.6 ft3 34.1 ft3 533.7 ft3 216.1 sks BHST = 5rF, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2SF/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 30 6.0 18.0 MudPUSH II 7 40 5.7 23.7 Drop bottom plug 4.0 27.7 ArcticSET Lite III 7 247 35.3 63.0 LiteCRETE 5 95 19.0 82.0 Drop plug 4.0 86.0 Water displace 5 20 4.0 90.0 Switch to rig 4.0 94.0 Displacement 7 149 21.3 115.3 Bump Plug 3 15 5.0 120.3 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15 Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-20, Ty ? 20-25 Centralizers: Recommend 1 per joint on bottom 700' of casing ORIGINAL Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/26/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 95/8",40.0#, L-80 grade BTC, AB Modified at 2,510 ft. MD Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing Cairn formation. Tail Slurry (minimum thickening time 128 min.) GasBLOK wI Class G + D600G, B155, 0047, 0065, per lab testing @ 15.8 ppg, 1.17 ft3/sk 0.2291 fe/ft x 300' x 1.75 (75% excess) = 0.3272 ft3/ft x (6396' - 5598') x 1.75 (75% excess) = 0.0488 ft3/ft x 120' (Shoe Joint) = 120.3 ft3 + 456.9 ft3 + 5.9 ft3 = 583.1 ft31 1.17 ft3/sk = Round up to 499 sks 120.3 ft3 456.9 ft3 5.9 ft3 583.1 ft3 498.4 sks BHST = 141°F, Estimated BHCT = 120°F. (BHST calculated using a gradient of 2 SF/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative < 51/2", 15.5#, L-80 grade Stage (bpm) Volume (min) Time BTC, AB Modified (bbl) (min) in 8 1/2" OH CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 30 6.0 18.0 MudPUSH II 5 40 8.0 26.0 Tail Slurry 5 104 20.8 46.8 Drop Combo Plug 5.0 51.8 < Top of Tail at Displacement 5 124 24.8 76.6 5,298 ft. MD Bump Plug 3 15 5.0 81.6 < X-over at 5,598 ft. MD < TopofCaim Fm. at 5,798 ft. MD < 3 1/2", 9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH TO at 6,396 ft. MD (5,720 ft. TVD) Mark of Schlumberger MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv? 16-20, Ty ? 30-34 Centralizers: Recommend 1- ~ per joint to 300' above proposed TOC ORIGINAL Meltwater 2P-443 prclucer Proposed Completion Schematic 3-1/2" Completion String 30" x 16" 62.6# @ +1- 108' MD (Insulated) Depths are based on Doyon 141 RKB Surface csg. 9 5/8" 40.0# L-80 BTC +1- 2510' MD 12369' TVD I I ~ I ~ I ~ I I I I I ~ I J I ~ I ~ ~ I ~ ~ ~ ~ I I I I I ~ ~ ~ I ~ ~ i I ~ ~ .ìIífI. 5 %" 15.5# L-80 BTCM x 3 %" 9.3# L-80 EUE8RD Mod crossover at +1- 5598' MD I 5032' TVD Future Perforations Production csg 5 %" 15.5# L-80 STeM x 3 %" 9.3# L-80 EUE8RD Mod +1- 6396' MD I 5720' TVD I ~ ~ ~ ~ ~ I ~ I I ~ iii ~ I l I ~ !! l~l I ~ ¡ I I II I I I __ ~ ~ I ~ ~ ~ I III I I I I ~ ~ l I I ~ I I I i!i I I I I l ~ i!i ~ I I I I I I II I I ~ 2 I ~ ~ I ~ I II I I I I I I I iiil ~ I L.. I .-- I _ I l I ~ I '" I I I ~ I ~ !! ~ ~ . iJi ~ I I ~ iJi iii ~ I ~l ~ I I !! I ~ I ~ I I I ~ I I .. I '" I '" I ~ I I ~ I.... ...I....tI...- ~ IIIII!IIiIIiIII 1""'--- ~ .!! -.:(' ~II r , , , ~ · ~Ph·II· OCO JL .,. 3 %" FMC Gen 5 Tubing Hanger, 3 %" L-80 EUE8RD Mod pin down 3 %" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 %" 9.3# L-80 EUE8RD Mod Tubing to Surface 3 %" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 3 %" 9.3# L-80 EUE8RD Mod tubing to landing nipple 4 x 3 %" x 1" Camco 'KBG-2-9' mandrels 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 %" x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 %" Baker 'CMU' sliding sleeve wI 2.813" Cameo OS profile, EUE8RD Mod box x pin. 3 %" x 6' L-80 EUE8RD Mod handling pup installed above 3 %" Camco 'D' nipple wI 2.75" No-Go profile. 3 %" x 12' L-80 EUE8RD Mod spacaeout pup installed above, 3 %" x 6' handling pup installed below 3 %" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 %" L-80 EUE8RD Mod box up, 3 %" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 %" BTCM x 3 %" EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) ORIGINAL 02/11/2004 N ~ o 0 2/1 · IVIEMO._____ _____ 1:03. .00 .~~I: 2 .B~ 7 R8, e " " THE [/~:' /ll..l'l<:;,r,/7 (' OF___ ::__,___, -", {// .... t~ .,' .J/jf Ill.. . (/ ¡'I ,.,- . . ,,~ ?¿i" 'i>i..,'t,,,,¡.-'t,,~.(,,; '7/t!:;"'~"~ ""'I'C.:.' C'¡;'¿--Þ"':,. ~;~'\"_;_'/I"'" //.( '-- ~.' ''-~-~-_._-.:..~.__:'::...._---~----_.- ..... CHASE Chase Manhattan Bank USA. N.A. Valid Up To 5000 Dollars ~, 200 Whit. Cloy C.n'" D,.. N.W.". DE '.711 DOLl.JIBS $ 6J PAY TO ORDER SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 DATE ( ',;14/31 1044 . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# / Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL (If API number last two (2) digits are between 60-69) KRt{ 2-;:/- V'/3 '20,-/- 03¿ D(L Exploration Stratigraphic ~'CLUEn Tbe permit is for a new wellbore segment of existing weD . Permit No, . API No. Production. sbould continue to be reported as a function 'of tbe original API number. stated above. HOLE ]n accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EX CEPT] ON DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ;¡ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacinge:Jception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample h:itervals tbrougb target zones. Field & Pool KUPARUK RIVER, MELTWATER OIL - 490140 Well Name: 1<UPARUK RIV U1/IEL T 2P-4~ Program DEV Well bore seg ~~ CQPHILLlPS ALASKA ~ -- Initial ClassfType DEV / PEND_ GeoArea 890 ~_ Unit jj1tHL___ On/Off Shore -D.-n Annular Disposal D Administration Peunit fee attached ~ ~ - - - - - - Yes - - - - 2 lease ~number ~appropriate ~ Yes~ - - - - - - - - - - 3 ~U~nlque welt name ~and ol!mb~er ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - - - - ~ Ves ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4 WellJQcated inactefine~pool~ ~ Yes ~ ~ ~ ~ ~ Meltwater Oil POQI;-'~Q 456~ ~ ~ 5 WellJQcated proper ~dlstance from driJling unitb9und~acy~ ~ ~ Yes~ - - - - - - - - - - 6 Well IQcated proper ~dlstance from Qtber welJs~ ~ Ves ~ 7 Suffiçir¡!I']t acrea~e~available indrilliog unit Ves~ ~ ~ ~ - - - - - ~ ~ 8 JtdeViÇlted, js wellbQre pl¡;¡tincJu~ded ~ Yes~ - - - - - - I~o Qperator onl)' affected party ~ Yes~ - - - - - ~Oper:ator bas~apprpprla!e~ b.ond tnJQrce ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . . . . . . . Y~s _ . . . ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ . . . . . . . . . . . . . . . . . . . . . ~ . . ~ 11 Permit can be tSSl!ed witbQu! conserva.tiQn Qrder. . . . . . . Y.es - - - - - Appr Date 12 P~rmit can be issued witbQut Çlctministratille.apprpval . . .. Yes. SFD 2/12/2004 13 Can permit be approved before 15-day wait Yes 114 Well ~IQcated wàh\n area and str¡;¡ta authQrtzed by.lnjectioo Order # (put 100 in comments) (For. NA - - - - - 15 AJI wells. withtn J/4.mile .area.of review ideot!fied (For s.ervjce well ol)lYL . . ~ . ~ . . . . ~ . . . . NA. . . - . . . . ~ . . . . . . . . . . . . . . . . . . . . . . . . . - . . . . . . . . . . . . . . - . . . . . . . . . . . 16 Pre-produ.cect injector; duration of pre-:)ro.ductionless. than. 3 mOl)tbs (For.servtce well QnJy) . . NA . 17 ACMP.F.inding .of CQnsistencyh.as been .issued. for. tbis prpject . - - - -- NA... . . Well drtlled from eXÎstio9 pad, . -~ - - - Engineering 18 Condu.ctor string.prQvided . . . . Yes. - - - - - 19 S.urfacec¡;¡s.in9.prQtects. altkoown USDWs . . NA. All aq.uifers ex.empted 40 CfR 147..102(b)(3) . 20 CMT vol ad!'!quateJo circJJlate.oncond.uctor: & surf.csg . . .Yes 21 CMT vol ad!'!qu.ate.to tie-inJQng .string to.surf cs.g . No. . Annular disposal m.ay be propo.sed. . 22 .CMTwill cover.all kOQwn.pro.ductive bQrizQn.s. Y~s. 23 .Casing designs adequate fPr C,T., B.& permafrpst. Yes. - - - - - - - - 24 Adeq u¡;¡te tanJ<¡;¡ge or reserve pit Yes Rig is equipped.with steelpjts.. NQ r!'!servepjtplarmed, Waste to ÇlPprQved annulus or.djspos.al wel 25 Jfare-drilt baS. a 10-40;3 for ¡;¡bandon.ment be~n apprQved . . . - - - - - - NA. - - - - - 26 Adequate.welll::1ores.ep~Hatio.n.propos.ed. . . . _ . _ . . . . . . . . . . . . . . . . . . .Y~s. . I?rp¡çimi.tl' an¡;¡lysi$ perf.orme.d, Jrayeltng c)'linqer plotpJQvided.. . . _ . . . . . . . . . . . . _ . . _ 127 Ifdiverter reQ.uired, does it meet reguJatiol)s . . Ye$. - - - - - - - - - - Appr Date 28 DrilJiog fJuid.pro~ram schematic.& eQ.uipJist.adequate . . . Yes . MÇlximum !,!xP!'!cted formation pres.sure .at TD 8.;3.10.;3 .EMW. . MWpJanned 1.0,3. -.10.7, . TEM 2/12/2004 29 SOPEs,dp they meet r!,!gula.tiol) . - - - - - - . .Y~s. . . $Qme.locali~ed sba.llow press.ures .h¡;¡lle b.een $een in oJher wells, Pos.sible. hazard i.dentified. ~("}qh7 30 BOPE.press ratiog appropÖate; .test to (put psig iJ1colTlments) . Y~s. CalcuJated.MASP 2389 psi. 3500 psi.appropriate, .cPAI us.u¡;¡lIy Jeststo 500.0 psi. 31 Choke manifold cQmplies w/APIRF'-53 (May 84) .Yes - - - - . 32 Work will occur without.operatioJ1sl1utdown. . - - - - - - Yes - - - - - 33 .Is presence of H2S gas. probabl!'!. . . - - - - - No 1::i2S has .not. be!'!n Seen at Alpine. . Rig is .equípp.ed with se.nsors and alarms.. 34 Meçha.n[c¡;¡Lconditlonpf wells within AOR verifiect (For service welJ only). . NA. - - - - - - - - - - - --- - -- - Geology 35 Permit c.an be tssu.ed '1110 hydrogen s.ulfide m!'!as!Jres. . Yes. - - - - - 36 .D.ata.preseoted on. pote.ntial oyerpres.sure .zol)es. . . '(es. !;xpected rese.f\lor press.ure.from. a.3 -1.0~3. RP9~ wm be. QriJlect with1P..3- .10.7 ppg mud. Appr Date 137 .SeismicaJ1Ç1lysjs of sballow gas.zPoes . . . . . . . . . . . . NA Operator is. aware of.sl1allow pressure along western margin of.pad; wet! wiJl be drill!'!d from - " - - - - SFD 2/12/2004[38 .Se¡;¡bed .conditio!) survey.(if off-sh.ore) . . .NA western $ide Qf p¡;¡d toWÇlrd !,!Çlst. I?r!'!ss.ure. d.is.cu$sed [nDrilling !:Iazards section. 39 . CQntact n.am.e/p/'1oneforweekly progres.srep.orts [e¡q:¡IQratoryonly1. . NA Geologic Date: Engineering Public Date Commissioner: Commissioner Date Commissioner DFJ 2-/ / 3/1--- e e 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 simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e **** REEL HEADER **** LDWG 04/05/26 AWS 01 **** TAPE HEADER **** LDWG 04/05/26 01 *** LIS COMMENT RECORD *** e ) 0 ~I - 0) .)... # f ). ç G L/ !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !! ! ! ! ! !! !! !! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER MELTWATER UNIT MWD/MAD LOGS * WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: * JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 2 G. SUTING D. GLADDEN * SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 2P-443 501032048700 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 26-MAY-04 MWD RUN MWD RUN 17 8N 7E 254.20 224.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 # REMARKS: 16.000 9.625 110.0 2490.0 6334.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N 70 DEG LONG: W 150 DEG LOG MEASURED FROM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD) , Caliper Corrected Neutron (CCN), along with Drill Collar Pressure (DCP) and MPR Resistivity services from 2496 - 6334 feet MD (2369 - 5709 TVD). (2) It was determined upon post well examination of the ORD tool (Optimized Rotational Density) and the density data, that severe wear had occurred on the outside surface of the tool. The wear resulted in irregular metal loss of up to several millimeters in the vicinity of the ORD source port. It is believed that the wear occurred when a piece of abrasive debris was lodged between the wear pad above the source and the fluid displacer over the detectors. The wear on the ORD tool effected the response characteristics of the density measurement. Initially, the bulk density and Delta-Rho measurements were reading anomalously high. The ORD tool was recalibrated in the shop to compensate for the new response characteristics caused by the wear. The data was then reprocessed utilizing the new ORD calibration. The density correction measurement, Delta-Rho, was adversely effected by the imperfect recalibration which results from the irregular wear surface. The reprocessed Delta-Rho curve reads predominately negative values and thus the use of the atypical Delta-Rho curve scale -0.25 to +0.25 g/cc. The bulk density is the curve of primary importance and was the focus of the recalibration effort. In spite of the difficulties associated with the irregular wear and the negative correction, it was found that the reprocessed bulk density measurement is in good agreement with offset well data. (3) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Depth of 9 5/8" Casing Shoe - Logger: 2490 feet MD (2365 TVD) Depth of 9 5/8" Casing Shoe - Driller: 2490 feet MD (2365 TVD) (2) The interval from 6300 to 6334 feet MD (5678 - 5709 TVD) was not logged due to sensor-bit offset at TO. $ 3' 8.703" 27' 3.668" D.F. AT 254.2 FT. ABOVE PERM. DATUM Tape Subfile: 1 95 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 e e *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOOl.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2490.0 STOP DEPTH 6334.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 2490.0 MERGE BASE 6334.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 2p-443 5.xtf 150 ConocoPhillips Alaska, Inc. 2P-443 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP FET GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP FET 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 GRAM RPCLM RPCSLM RPCHM RPCSHM BDCM DRHM DPEM NPCKSM ROPA RPTH * FORMAT RECORD (TYPE# 64) e e Data record type is: 0 Datum Frame Size is: 48 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 21 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 ------- 44 Total Data Records: 367 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2490.000000 6334.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 412 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: 2 RAW MWD e e header data for each bit run in separate files. 2 .2500 Curves and log BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 2450.0 STOP DEPTH 6334.0 # 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 DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 14-APR-04 MSB 18704 6.75 TC MEMORY 6334.0 2496.0 6334.0 o 25.7 30.7 TOOL NUMBER DHA 90427 CCN 29572 ORD 28636 MPR 67280 SRIG 5078 8.500 2490.0 LSND 10.40 .0 .0 600 .0 .000 .000 .000 .000 126.0 .0 .0 .0 Sandstone .00 .000 .0 o BIT RUN 2 (MWD Run 2). GR/MPR/oRD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) REMARKS: e e DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2p-443.xtf 150 ConocoPhillips Alaska, I 2P-443 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 64 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 15 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F ~ .~ t .. e e 15 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPA MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 ------- 60 Total Data Records: 1036 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2450.000000 6333.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 1144 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/05/26 01 **** REEL TRAILER **** LDWG 04/05/26 AWS 01 Tape Sub file: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes