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Home My WebLink About203-1532025-0715_Location_Clear_KRU_2P-434_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-434 ConocoPhillips Alaska LLC. PTD 2031530; Sundry 324-603 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-434 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 7.16 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 14:05:16 -08'00' 2025-0715_Location_Clear_KRU_2P-434_ksj Page 2 of 2 Surface Abandonment Inspection – KRU 2P-434 (PTD 2031530) 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 2356' 7" L-80 5296' 3.5" L-80 5578' 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 5711' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 6025' 26' 5128' 62.5# 40# 108' 26' WT. PER FT.GRADE 442330 442218 CEMENTING RECORD 5870073 1354' MD / 1351' TVD SETTING DEPTH TVD 5870159 TOP HOLE SIZE AMOUNT PULLED Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Balanced Plug 30 bbl 15.8 ppg Cement 41-2198' (Tubing/ PC) 5.8 ppg Cemtn to surface Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 2198-2480' 3887' (SW TOC) -5479' ABANDONED 5712-5772' MD and 5297-5350' TVD (below cement plug) 5780-5784' MD and 5357-5361' TVD (below cement plug) 5790-5794' MD and 5366-5370' TVD(below cement plug) Gas-Oil Ratio:Choke Size: 53 bbls 15.8 ppg Class G cement Per 20 AAC 25.283 (i)(2) attach electronic information 5524' MD / 5129' TVD PACKER SET (MD/TVD) 42" 12.25" 90 sx AS I 28'530 sx AS Lite, 220 sx LiteCrete 9.2# 28' 5524' 2421'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 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 BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Abandoned N/A 50-103-20467-00-00 KRU 2P-434 ADL0373112 957' FNL, 1855' FWL, Sec. 17, T8N, R7E, UM 270' FSL, 253' FWL, Sec. 8, T8N, R7E, UM ALK 32092 11/24/2003 6030' MD / 5582' TVD Surface/ Surface P.O. Box 100360, Anchorage, AK 99510-0360 443815 5868921 184' FSL, 365' FWL, Sec. 8, T8N, R7E, UM 12/2/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/20/2025 203-153 / 324-603 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, 120 sx Class G6.125" TUBING RECORD 170 sx Class G8.5" 5575' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:30 pm, Mar 24, 2025 Abandoned 2/20/2025 JSB RBDMS JSB 032825 xGDSR-4/7/25VTL 7/30/2025 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1354' 1351' 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: Shane Germann Digital Signature with Date:Contact Email: Shane.Germann@conocophillips.com Contact Phone:(907) 263-4597 Senior RWO/CTD 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 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: 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 N/A- Abandoned N/A - Abandoned Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this documentLocation: Date: 2025.03.24 14:48:16-08'00' Foxit PDF Editor Version: 13.0.0 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 3,887.0 2P-434 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Final P&A, Added Marker Plate and backfilled 2P-434 2/20/2025 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: NES removed the "Shoring Can" from the excavation. 2/20/2025 pproven NOTE: NES backfilled and mounded the excavation. 2/20/2025 pproven NOTE: NES welder welded the marker plate to the well stub. Kam StJohn gave the "ok" for backfilling 2/19/2025 pproven NOTE: AOGCC Rep, Kam StJohn, witnessed the TOC, cut depth the marker plate (7.16' below tundra) 2/19/2025 pproven NOTE: NES Welder prepped the well stub for the Marker Plate. 2/19/2025 pproven NOTE: Waivered for water injection only with known TxIA on gas. 11/11/2019 jbyrne Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.9 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.9 2,421.4 2,356.2 40.00 L-80 BTC Production 7 6.28 2,188.0 6,025.0 5,577.7 26.00 L-80 BTCMD LINER 3 1/2 2.99 5,524.8 6,025.0 5,577.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 2,690.0 Set Depth … 5,575.1 String Max No… 3 1/2 Set Depth … 5,174.1 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) 5,459.1 5,070.0 26.19 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,508.1 5,114.0 26.16 SLEEVE-C 4.500 SLIDING SLEEVE (Opened 4/29/18. Re-closed 4/29/18) BAKER CMU 2.813 5,524.1 5,128.4 26.20 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,537.2 5,140.1 26.23 LOCATOR 5.000 BAKER G-22 LOCATOR BAKER G-22 3.000 5,538.4 5,141.2 26.24 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSY BAKER 80-40 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) 40.9 40.9 0.00 MARKER PLATE 1/4" x 30" Marker plate 2/19/2025 0.000 2,690.0 2,599.4 25.87 CUT JET CUT 9/17/2024 2.992 5,475.0 5,084.3 26.13 TUBING PUNCH TUBING PUNCH, 4.5FT @ 4 SPF, 0 DEGREE PHASE. 8/6/2024 2.992 5,677.3 5,265.6 26.56 CIBP CIBP MID-ELEMENT AT 5678' RKB, OAL = 1.37' 6/30/2024 0.000 5,685.0 5,272.4 26.55 LINER IMPINGEMEN T Identified Tight Spot in Liner W/ Relay CCL (Able to drift w/1.75" tools) 2/4/2020 2.000 5,882.0 5,449.0 26.01 FISH FISH TOOL SAVER BROKE AFTER FIRING 3RD GUN LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5' 1/1/2004 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,524.8 5,129.0 26.20 PACKER 5.980 BAKER ZXP LINER PACKER BAKER ZXP 4.370 5,543.7 5,145.9 26.25 NIPPLE 5.590 RS PACKOFF SEAL NIPPLE RS PACKOFF 4.250 5,574.9 5,173.9 26.33 XO BUSHING 5.020 XO TKC BUSHING TKC 3.000 5,926.9 5,489.3 25.81 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,712.0 5,772.0 5,296.6 5,350.3 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,780.0 5,784.0 5,357.5 5,361.1 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,790.0 5,794.0 5,366.4 5,370.0 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.9 2,421.0 40.9 2,355.9 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 115000Drag up (lbs): 125000Time started reciprocating: 17:30Time stopped reciprocating: 23:00Annular flow after cement job (Y/N): NPressure before cementing (psi): 300Hours circulated between stages: 3Bbls cmt to surf: 249Method used to measure density: DensometerMethod used for mixing cement in this stage: TubReturns (pct): FullTime cementing mixing started: 21:53 11/25/2003 5,603.0 5,677.3 5,199.1 5,265.6 Cement Plug Dump Bail Cement on CIBP 7/7/2024 3,887.0 5,479.5 3,667.0 5,088.3 Cement Plug Pumped 53 Bbls OF 15.8 PPG Class G Cement 9/8/2024 2,198.0 2,480.0 2,153.3 2,409.4 Cement Plug 12/23/2024 2P-434, 3/18/2025 11:49:54 AM Vertical schematic (actual) Production; 2,188.0-6,025.0 LINER; 5,524.8-6,025.0 FISH; 5,882.0 IPERF; 5,790.0-5,794.0 IPERF; 5,780.0-5,784.0 IPERF; 5,712.0-5,772.0 LINER IMPINGEMENT; 5,685.0 CIBP; 5,677.3 Cement Plug; 5,603.0 ftKB TUBING PUNCH; 5,475.0 GAS LIFT; 5,459.1 Cement Plug; 3,887.0 ftKB CUT; 2,690.0 SURFACE; 40.9-2,421.4 Cement Plug; 2,198.0 ftKB TUBING PUNCH; 2,000.0 TUBING PUNCH; 1,992.0 Cement Casing; 40.9 ftKB CONDUCTOR; 40.9-108.0 MARKER PLATE; 40.9 Plug – Plug Back / Abandonment Plug; 40.9 ftKB KUP INJ KB-Grd (ft) 33.79 RR Date 12/5/2003 Other Elev… 2P-434 ... TD Act Btm (ftKB) 6,030.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032046700 Wellbore Status INJ Max Angle & MD Incl (°) 28.19 MD (ftKB) 4,183.83 WELLNAME WELLBORE2P-434 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: N/A Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.9 2,198.0 40.9 2,153.3 Plug – Plug Back / Abandonment Plug Pumped 5.8# cement to surface. Filled 3 1/2" Tubing and 7" Production Casing to surface. 12/25/2024 2P-434, 3/18/2025 11:49:54 AM Vertical schematic (actual) Production; 2,188.0-6,025.0 LINER; 5,524.8-6,025.0 FISH; 5,882.0 IPERF; 5,790.0-5,794.0 IPERF; 5,780.0-5,784.0 IPERF; 5,712.0-5,772.0 LINER IMPINGEMENT; 5,685.0 CIBP; 5,677.3 Cement Plug; 5,603.0 ftKB TUBING PUNCH; 5,475.0 GAS LIFT; 5,459.1 Cement Plug; 3,887.0 ftKB CUT; 2,690.0 SURFACE; 40.9-2,421.4 Cement Plug; 2,198.0 ftKB TUBING PUNCH; 2,000.0 TUBING PUNCH; 1,992.0 Cement Casing; 40.9 ftKB CONDUCTOR; 40.9-108.0 MARKER PLATE; 40.9 Plug – Plug Back / Abandonment Plug; 40.9 ftKB KUP INJ 2P-434 ... WELLNAME WELLBORE2P-434 Production Casing Cement: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Final P&A Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB (2355' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ&D,E'ZϮϯ͘ϯΖ Ϯ ^d/ZKEZ/'W>h' ϮϰϴϬΖ ϯ <ZDh^>//E'^>s;KWE ϰͬϮϵͬϭϴ͘ZͲ>K^ϰͬϮϵͬϭϴͿ ϱ͕ϱϬϴ͘ϭΖ ϰ DKE/WW> ϱ͕ϱϮϰ͘ϭΖ ϱ <ZyW>/EZW<Z ϱ͕ϱϮϰ͘ϴΖ ϲ <Z'ͲϮϮ>KdKZ ϱ͕ϱϯϳ͘ϮΖ ϳ <Z'ͲϮϮ>KdKZ ϵ͕ϵϬϴ͘ϮΖ ϴ <ZϴϬͲϰϬ',ͲϮϮ^>^^D>z ǁͬ,>&Dh>^,Kϵ͕ϵϬϵ͘ϰΖ ϵ Z^W<K&&^>E/WW> ϵ͕ϵϭϭ͘ϵΖ ϭϬ <Z&>yͲ>K<>/EZ,E'Z ϵ͕ϵϭϰ͘ϳΖ ϭϭ <ZϴϬͲϰϬ^>KZydE^/KE ϵ͕ϵϮϰ͘ϳΖ ϭϮ ZK^^KsZh^,/E' ϵ͕ϵϰϯ͘ϯΖ 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5603' RKB Liner impingement 5685' KB Plug #2 – Intermediate TOC ±3887' RKB BOC @ ±5475' RKB Plug #3 – Surface Shoe TOC 2198' RKB (2153' TVD) BOC @ ±2480' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2198' RKB Page 1/2 2P-434 Report Printed: 3/18/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2024 12:00 12/21/2024 15:00 3.00 MIRU, MOVE MOB P Set mats for pulling off well on doubles // Pull off well and stage on pad 0.0 0.0 12/21/2024 15:00 12/21/2024 21:30 6.50 MIRU, MOVE MOB P Spot mats and herculite around new well // pull rig on well and center/level MIRU 0.0 0.0 12/21/2024 21:30 12/22/2024 00:00 2.50 MIRU, MOVE COND P Take on 9.8 Brine R/U hard lines test lines t/2500psi All good OA 220 psi IA 0 Tubing 0 0.0 0.0 12/22/2024 00:00 12/22/2024 01:30 1.50 MIRU, WELCTL KLWL P Continue R/U t/ Kill well and test lines t/2500 psi IA 0 Tubing 0 0.0 0.0 12/22/2024 01:30 12/22/2024 03:30 2.00 MIRU, WELCTL CIRC P Start pumping down tubing taking returnes throu-choke manifold @ 4 bbls min w/195 psi 250 bbls 9.8 brine Shut down No flow monitor well 30 mins All good Blow down all lines 0.0 0.0 12/22/2024 03:30 12/22/2024 09:00 5.50 MIRU, WHDBOP NUND P N/D tree and N/U BOP // Grease valve and fluid pack lines, Shell test BOPs 0.0 0.0 12/22/2024 09:00 12/22/2024 15:30 6.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 3.5" and 7", UVBR's, w/ 3 ½” donut test joints. Test blinds rams. Test LPR 7" on 7" test joint, Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 4 1/2" FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1650 PSI, 200 PSI attained = 25 sec, full recovery attained =126 sec. UVBR's = 4 sec Annular = 24 sec. Simulated blinds = 5 sec. HCR choke & kill = 1 sec each. 4 back up nitrogen bottles average = 1925 PSI. Test gas detectors, PVT and flow show. Witnessed by AOGCC Inspector Brian Bixby Choke valve # 5 F/P Grease ok 0.0 0.0 12/22/2024 15:30 12/22/2024 15:45 0.25 COMPZN, RPCOMP RURD P Rig down test equipment 0.0 0.0 12/22/2024 15:45 12/22/2024 17:15 1.50 COMPZN, RPCOMP MPSP P Pull H-BPV and R/U landing jt BOLDS 0.0 0.0 12/22/2024 17:15 12/22/2024 18:45 1.50 COMPZN, RPCOMP PULL P Pull Hanger to Floor P/U wt 55K No issue L/D hanger Monitor well 30 mins all good 0.0 12/22/2024 18:45 12/22/2024 21:00 2.25 COMPZN, RPCOMP PULL P POOH L/D 3 1/2" TBG L/D Tot 83 jts 10' cut jt 1 nipple 2 jts perforated TOT 85 jts 12/22/2024 21:00 12/22/2024 23:00 2.00 COMPZN, RPCOMP TRIP P M/U YJOS BHA #1 w/ 7" CIBP RIH w/ 3 1/2" D.P. F/Derrick and set CIBP @ 2480' 12/22/2024 23:00 12/23/2024 00:00 1.00 COMPZN, RPCOMP TRIP P POOH l/d Running tool 12/23/2024 00:00 12/23/2024 01:00 1.00 COMPZN, RPCOMP MPSP P R/U toTest CIBP @ 1000 PSI 10 mins All good 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/25/2024 Page 2/2 2P-434 Report Printed: 3/18/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/23/2024 01:00 12/23/2024 01:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 w/ 7" casing Cutter 0.0 16.0 12/23/2024 01:30 12/23/2024 03:00 1.50 COMPZN, RPCOMP TRIP P RIH Tag a collor @ 1550' Hard tag POOH and Check cutter 16.0 0.0 12/23/2024 03:00 12/23/2024 03:30 0.50 COMPZN, RPCOMP BHAH P Redress Cutter and RIH 0.0 16.0 12/23/2024 03:30 12/23/2024 04:15 0.75 COMPZN, RPCOMP TRIP P RIH w/ BHA# 3 MSC // Tag CIBP pick up 5' // 16.0 2,480.0 12/23/2024 04:15 12/23/2024 05:00 0.75 COMPZN, RPCOMP CPBO P Tag plug // Pick up 5' // Perform cut OA pressure jump 300 psi // 2,480.0 2,475.0 12/23/2024 05:00 12/23/2024 07:00 2.00 COMPZN, RPCOMP CIRC P Pump 70 bbls Hot deep clean pill followed by 9.8# brine // 2.5 bpm @ 500 psi pump pressure 2,475.0 2,475.0 12/23/2024 07:00 12/23/2024 08:15 1.25 COMPZN, RPCOMP TRIP P POOH L/D Cutter 2,475.0 2,475.0 12/23/2024 08:15 12/23/2024 09:15 1.00 COMPZN, RPCOMP FISH P M/U Landing Jt RIH BOLDS Pull 7" casing to floor UP WT 102K no over pull All good L/D hanger and space out 2,475.0 2,475.0 12/23/2024 09:15 12/23/2024 15:15 6.00 COMPZN, RPCOMP WAIT P Wait on Cementers spot and R/U 2,475.0 2,475.0 12/23/2024 15:15 12/23/2024 19:15 4.00 COMPZN, RPCOMP CMNT P Hold PJSM w/crew pump 5 bbls and test t/2500 psi All good Max and pump 12 bbls spacer drop ball chase w/ 21.30 bbls PTA cement 15.8 PPG and drop #2 ball chase w/ 10 bbls spacer chase w/ 9.8 Brine CIP @ 1900 Hrs 2,475.0 2,475.0 12/23/2024 19:15 12/23/2024 21:15 2.00 COMPZN, RPCOMP TRIP P R/D Cements POOH l/d 7" casing t/1850' 2,475.0 1,853.0 12/23/2024 21:15 12/23/2024 22:15 1.00 COMPZN, RPCOMP CIRC P CBU @ w/ 4 bbs min 40 psi No loss 1,853.0 1,853.0 12/23/2024 22:15 12/24/2024 00:00 1.75 COMPZN, RPCOMP WOC P WOC 12/24/2024 00:00 12/24/2024 21:00 21.00 COMPZN, RPCOMP WOC P WOC working pipe every 40' every 1.5 hours. PUW 78K/SOW 70K Clean and organize cellar. 1,853.0 1,853.0 12/24/2024 21:00 12/24/2024 23:00 2.00 COMPZN, RPCOMP WASH P RIH F/1853'-T/2053'. Wash down F/2053' T/2198' Set down 15K on cement plug Witnessed by Brian Bixby (AOGCC) 1,853.0 2,053.0 12/24/2024 23:00 12/24/2024 23:30 0.50 COMPZN, RPCOMP CIRC P Circulate bottoms up at 5 bpm /65 psi taking returns to cuttiongs box. 2,053.0 2,053.0 12/24/2024 23:30 12/25/2024 00:00 0.50 COMPZN, RPCOMP RURD P RU to test casing. 2,053.0 2,053.0 12/25/2024 00:00 12/25/2024 01:00 1.00 COMPZN, RPCOMP PRTS P Test casing cemnt to 1000 psifor 10 minutes.Good test. Bump pressure up to 1800 psi and chart test for 30 minutes.Good test. Witnessed by Brian Bixby. 0.0 0.0 12/25/2024 01:00 12/25/2024 01:30 0.50 COMPZN, RPCOMP HOSO P PU and space out 5' off top of cement. 0.0 0.0 12/25/2024 01:30 12/25/2024 03:00 1.50 COMPZN, RPCOMP PRTS P Set Packoff. Set down 10K and RILDS. Test hanger void to 5K for 10 minutes. Good test. 0.0 0.0 12/25/2024 03:00 12/25/2024 06:30 3.50 COMPZN, RPCOMP NUND P ND BOPE stack/ NU tree 0.0 0.0 12/25/2024 06:30 12/25/2024 11:00 4.50 COMPZN, RPCOMP CMNT P R/U Halliburton Cementers F/Stage #2 Plan F/ Surf to Surf Cement in place @ 11:00 AM 0.0 0.0 12/25/2024 11:00 12/25/2024 12:00 1.00 COMPZN, WHDBOP RURD P RDMO Move Off well. Rig release at 12:00 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/25/2024 DTTMSTART JOBTYP SUMMARYOPS 10/22/2024 CHANGE WELL TYPE (MISC) T AND IA DDT TO 0 PSI PASSED. 12/21/2024 RECOMPLETION Pull off 2P-438/MIRU on 2P 434 12/22/2024 RECOMPLETION N/D tree N/U bop, grease and fluid pack surface lines Test BOP 250/2500 AOGCC witnessed Brian Bixby, 12/23/2024 RECOMPLETION Cut 7" casing P/U Circ out OA w/ 70 bbls heated deep clean pill chase w/ 9.8 brine 12/24/2024 RECOMPLETION WOC. State witness tag cement at 2198'. PT cement 1500 psi for 30 minutes and chart. ND BOPE and NU tree. 12/25/2024 RECOMPLETION Pump Cement down 7" and up backside until full cement returns are observed. NFT then RDMO. 1/12/2025 CHANGE WELL TYPE (P&A) T X IA, & OA DDT (PASSED) 1/26/2025 CHANGE WELL TYPE (P&A) REMOVE TREE, IA AND OA VALVES (COMPLETE) TOC 48" BELOW THA, IA SF, OA SF. NEXT STEP CUT/REMOVE WELLHEAD AND CELLAR BOX. 1/27/2025 CHANGE WELL TYPE (P&A) PREP IN PROGRESS. CUT WINDOWS IN CONDUCTOR (COMPLETE) ***NEXT STEP- CUT WINDOWS IN SC & IA CUT CELLAR BOX/REMOVE WELLHEAD.*** 1/28/2025 CHANGE WELL TYPE (P&A) PREP IN PROGRESS. CUT/ REMOVED ~5’-8" OF WELLHEAD/CONDUCTOR. ***NEXT STEP- REMOVE STEEL CELLAR AND BEGIN EXCAVATING TO 14' FOR SHORE CAN INSTALL.*** 1/29/2025 CHANGE WELL TYPE (P&A) PREP- PULLED STEEL CELLAR. ***NEXT STEP: EXCAVATE TO 14' SET SHORE CAN, CUT AND REMOVE MINIMUM OF 5' 6" MORE OF WELL STUB TO MEET 4' BELOW OG REQUIREMENT.*** 2/11/2025 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (IN PROGRESS @ ~3') 2/12/2025 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (IN PROGRESS @ ~7.5') 2/13/2025 CHANGE WELL TYPE (P&A) WAITING ON WEATHER (PHASE 2) 2/14/2025 CHANGE WELL TYPE (P&A) WAITING ON WEATHER (PHASE 2) 2/15/2025 CHANGE WELL TYPE (P&A) CLEAN UP POST PHASE (COMPLETE) EXCAVATE TO 14' (IN PROGRESS) 2/16/2025 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (IN PROGRESS ~11') 2/17/2025 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (COMPLETE) SET "SHORING CAN" (COMPLETE) 2/18/2025 CHANGE WELL TYPE (P&A) CUT AND REMOVE WELL STUB (8' 9" OF WELL) 2/19/2025 CHANGE WELL TYPE (P&A) AOGCC REP, KAM STJOHN, WITNESSED & APPROVED THE TOC, CUT DEPTH, & MARKER PLATE (7.16' BELOW TUNDRA) WELDED THE MARKER PLATE (COMPLETE) 2/20/2025 CHANGE WELL TYPE (P&A) REMOVE "SHORING CAN" (COMPLETE) BACKFILL EXCAVATION (COMPLETE) 2P-434 Final Plug and Abandon Summary of Operations 2025-0219_Surface_Abandon_KRU_2P-434_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 02/21/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-434 ConocoPhillips Alaska Inc. PTD 2031530; Sundry 324-603 02/19/2025: I witnessed the marker plate installation with Brennen Green (CPAI) on KRU 2P-434 after the surface cement job was complete. The PTD #, API #, operator name, and well name were correct on the ¼-inch steel marker plate. The well cutoff was clean and flush, and the cement was hard in all sections of the tubing and casing. This was verified by hitting with a hammer. The depth below tundra was at 7.16 feet. Marker plate was fit as per regulations, and I witnessed welding the plate to the well stub. No follow up needed. Attachments: Photos (2) 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.03.25 15:38:48 -08'00' 2025-0219_Surface_Abandon_KRU_2P-434_ksj Page 2 of 2 Surface Abandonment – KRU 2P-434 (PTD 2031530) Photos by AOGCC Inspector K. StJohn 2/19/2025 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: 6030 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: P&A: XXX Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2421 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 5711 Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 6025 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 5575 Feet Tbg Cut@ 2690 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 2480 ft 2198 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1790 1695 1660 IA 1790 1695 1660 OA 1790 1695 1660 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: December 24, 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-434 ConocoPhillips Alaska Inc. PTD 2031530; Sundry 324-603 none Test Data: P Casing Removal: Ron Phillips Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-1224_Plug_Verification_KRU_2P-434_bb STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U MELT 2P-434 JBR 02/03/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 3 1/2" and 7" test joints, CMV #5 was greased and passed retest, Precharge Bottles = 11 at 1000psi each. BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold. Test Results TEST DATA Rig Rep:A. HansenOperator:ConocoPhillips Alaska, Inc.Operator Rep:C. Erdman Rig Owner/Rig No.:Nordic 3 PTD#:2031530 DATE:12/22/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopBDB241224071613 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 814 Sundry No: 324-603 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8x5 1/2 P #2 Rams 1 Blinds P #3 Rams 1 7"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 2 3 1/8,3 P Check Valve 0 NA BOP Misc 2 2 1/16 P System Pressure P3000 Pressure After Closure P1650 200 PSI Attained P25 Full Pressure Attained P126 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@1925 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P4 #2 Rams P4 #3 Rams P4 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9999 9 9 9 9 9 9 9 CMV #5 was greased and passed retest FP 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): 6030'5882' 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 (907) 263-4597 Senior CTD/RWO Engineer KRU 2P-434 5582' 3887' 3677' 3887', 5603', 5677' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5525' MD and 5129' TVD N/A Shane Germann STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 203-153 P.O. Box 100360, Anchorage, AK 99510 50-103-20467-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst 5575' MD 108' 2356' 108' 2421' 5296'5711' 16" 9-5/8" 80' 2393' 5712-5772', 5780-5784', 5790-5794' (below cement plug 5686' 3-1/2" 5297-5350', 5358-5361', 5366-5370' (below cement plug) 7' Perforation Depth TVD (ft): 12/8/2024 6025'500' 3-1/2" 5578' Packer: Bake ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 814 By Grace Christianson at 12:03 pm, Oct 17, 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: 2024.10.17 09:56:51-08'00' Foxit PDF Editor Version: 13.0.0 324-603 BOP test to 2500 psig Annular preventer test to 2500 psig See attached "Conditions of Approval" SFD 10/27/2024 June 30, 2025 VTL 11/27/2024 X X X DSR-10/23/24 10-407 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.29 09:52:43 -09'00'11/29/24 RBDMS JSB 112924 KRU 2P-4ϯϰ Abandonment Conditions ŽĨƉƉƌŽǀĂů ϭ͘ ǀĂƌŝĂŶĐĞŝƐŐƌĂŶƚĞĚĨƌŽŵϮϬϮϱ͘ϭϭϮ;ĂͿ;ϭͿ;ͿǁŚŝĐŚƌĞƋƵŝƌĞƐĂĐĞŵĞŶƚƉůƵŐĨƌŽŵϭϬϬΖ ďĞůŽǁƚŚĞďĂƐĞŽĨƚŚĞŚǇĚƌŽĐĂƌďŽŶͲďĞĂƌŝŶŐƐƚƌĂƚĂ͘ ʹǤ 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). ͵Ǥ A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. ͶǤ 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. ͷǤ If surface abandonment operations are not initiated within ͸0 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 within30 days after the completion of workover operations to date. ͸Ǥ Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. ͹Ǥ 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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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 9/15/2017 = 2778 psi @ 5400’ TVD x MASP = 2238 psi C-80 Formation: x OAP = 228 psi (8/19/23) (fluid packed with diesel) x MASP = 814 psi Intermediate plug TOC = 3887’ MD Tubing cut depth = 2690’ MD Production Casing Cement: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Suspension Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB (2355' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D'Esdh/E',E'Z Ϯϯ͘ϯΖ Ϯ DK^>E/E'E/WW>ϰϵϵ͘ϴΖ ϯ <ZDh^>//E'^>s;KWE ϰͬϮϵͬϭϴ͘ZͲ>K^ϰͬϮϵͬϭϴͿ ϱ͕ϱϬϴ͘ϭΖ ϰ DKE/WW>ϱ͕ϱϮϰ͘ϭΖ ϱ <ZyW>/EZW<Z ϱ͕ϱϮϰ͘ϴΖ ϲ <Z'ͲϮϮ>KdKZ ϱ͕ϱϯϳ͘ϮΖ ϳ <ZϴϬͲϰϬ^>^^D>z ϱ͕ϱϯϴ͘ϰϬ ϴ Z^W<K&&^>E/WW>ϱ͕ϱϰϯ͘ϳΖ ϵ <Z&>yͲ>K<>/EZ,E'Z ϱ͕ϱϰϲ͘ϰΖ ϭϬ <ZϴϬͲϰϬ^>KZyd ϱ͕ϱϱϲΖ ϭϭ yKd<h^,/E'ϱ͕ϱϳϰ͘ϵΖ 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5603' RKB Liner impingement 5685' KB Plug #2 – Intermediate TOC ±3887' RKB BOC @ ±5475' RKB Surface Casing Plugs – Rig Date: 10-16-2024 Prepared by: Shane Germann Estimated Start Date: 12-8-2024 MIRU 1. MIRU on 2P-434. 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 19 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 7” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 7” 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 Production Casing Cement: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Surface Shoe Cement Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB (2355' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,E'Z Ϯϯ͘ϯΖ Ϯ ^d/ZKEZ/'W>h'ϮϱϮϭΖ ϯ <ZDh^>//E'^>s;KWE ϰͬϮϵͬϭϴ͘ZͲ>K^ϰͬϮϵͬϭϴͿ ϱ͕ϱϬϴ͘ϭΖ ϰ DKE/WW>ϱ͕ϱϮϰ͘ϭΖ ϱ <ZyW>/EZW<Z ϱ͕ϱϮϰ͘ϴΖ ϲ <Z'ͲϮϮ>KdKZ ϱ͕ϱϯϳ͘ϮΖ ϳ <Z'ͲϮϮ>KdKZ ϵ͕ϵϬϴ͘ϮΖ ϴ <ZϴϬͲϰϬ',ͲϮϮ^>^^D>z ǁͬ,>&Dh>^,Kϵ͕ϵϬϵ͘ϰΖ ϵ Z^W<K&&^>E/WW>ϵ͕ϵϭϭ͘ϵΖ ϭϬ <Z&>yͲ>K<>/EZ,E'Z ϵ͕ϵϭϰ͘ϳΖ ϭϭ <ZϴϬͲϰϬ^>KZydE^/KE ϵ͕ϵϮϰ͘ϳΖ ϭϮ ZK^^KsZh^,/E'ϵ͕ϵϰϯ͘ϯΖ 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5603' RKB Liner impingement 5685' KB Plug #2 – Intermediate TOC ±3887' RKB BOC @ ±5475' RKB Plug #3 – Surface Shoe TOC 2254' RKB (2205' TVD) BOC @ ±2521' RKB Base of 7” 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 2471 2521 Open Hole 8.5 0.060898 3.0 Displacement of Prod Casing Stub Included in BBL/FT calc 2421 2471 Open Hole 8.5 0.070187 3.5 2254 2421 Surface Casing 8.83 0.075742 12.6 19.1 Total Volume of Plug Surface Casing 23 2254 Surface Casing 8.83 0.066453 148.3 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-434 c. PTD #: 203-153 d. API #: 50-103-20467-00-00 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: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Final P&A Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB (2355' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,E'Z Ϯϯ͘ϯΖ Ϯ ^d/ZKEZ/'W>h'ϮϱϮϭΖ ϯ <ZDh^>//E'^>s;KWE ϰͬϮϵͬϭϴ͘ZͲ>K^ϰͬϮϵͬϭϴͿ ϱ͕ϱϬϴ͘ϭΖ ϰ DKE/WW>ϱ͕ϱϮϰ͘ϭΖ ϱ <ZyW>/EZW<Z ϱ͕ϱϮϰ͘ϴΖ ϲ <Z'ͲϮϮ>KdKZ ϱ͕ϱϯϳ͘ϮΖ ϳ <Z'ͲϮϮ>KdKZ ϵ͕ϵϬϴ͘ϮΖ ϴ <ZϴϬͲϰϬ',ͲϮϮ^>^^D>z ǁͬ,>&Dh>^,Kϵ͕ϵϬϵ͘ϰΖ ϵ Z^W<K&&^>E/WW>ϵ͕ϵϭϭ͘ϵΖ ϭϬ <Z&>yͲ>K<>/EZ,E'Z ϵ͕ϵϭϰ͘ϳΖ ϭϭ <ZϴϬͲϰϬ^>KZydE^/KE ϵ͕ϵϮϰ͘ϳΖ ϭϮ ZK^^KsZh^,/E'ϵ͕ϵϰϯ͘ϯΖ 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5603' RKB Liner impingement 5685' KB Plug #2 – Intermediate TOC ±3887' RKB BOC @ ±5475' RKB Plug #3 – Surface Shoe TOC 2254' RKB (2205' TVD) BOC @ ±2521' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2254' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 3,887.0 2P-434 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-434 9/15/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water injection only with known TxIA on gas. 11/11/2019 jbyrne NOTE: View Schematic w/ Alaska Schematic9.0 11/23/2010 ninam NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/27/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,421.4 2,356.2 40.00 L-80 BTC PRODUCTION 7 6.28 25.5 5,711.0 5,295.7 26.00 L-80 BTCMD LINER 3 1/2 2.99 5,524.8 6,025.0 5,577.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.3 Set Depth … 5,575.1 Set Depth … 5,174.1 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) 23.3 23.3 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 499.8 499.8 0.65 NIPPLE 4.520 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 5,459.1 5,070.0 26.19 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,508.1 5,114.0 26.16 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (Opened 4/29/18. Re-closed 4/29/18) BAKER CMU 2.813 5,524.1 5,128.4 26.20 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,537.2 5,140.1 26.23 LOCATOR 5.000 BAKER G-22 LOCATOR BAKER G-22 3.000 5,538.4 5,141.2 26.24 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSY BAKER 80-40 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) 1,992.0 1,963.6 21.33 TUBING PUNCH TBG PUNCH FROM 1992' TO 1996.5' RKB W/ 4 SPF 9/11/2024 2.992 2,000.0 1,971.0 21.42 TUBING PUNCH TUBING PUNCH (2000' - 2003' RKB) 9/9/2024 2.992 2,690.0 2,599.4 25.87 CUT JET CUT AT 2690' RKB 9/17/2024 2.992 5,475.0 5,084.3 26.13 TUBING PUNCH TUBING PUNCH, 4.5FT @ 4 SPF, 0 DEGREE PHASE. 8/6/2024 2.992 5,677.3 5,265.6 26.56 CIBP CIBP MID-ELEMENT AT 5678' RKB, OAL = 1.37' 6/30/2024 0.000 5,685.0 5,272.4 26.55 LINER IMPINGEMEN T Identified Tight Spot in Liner W/ Relay CCL (Able to drift w/1.75" tools) 2/4/2020 2.000 5,882.0 5,449.0 26.01 FISH FISH TOOL SAVER BROKE AFTER FIRING 3RD GUN LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5' 1/1/2004 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) 5,459.1 5,070.0 26.19 1 GAS LIFT DMY BTM 1 0.0 11/7/2005 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,524.8 5,129.0 26.20 PACKER 5.980 BAKER ZXP LINER PACKER BAKER ZXP 4.370 5,543.7 5,145.9 26.25 NIPPLE 5.590 RS PACKOFF SEAL NIPPLE RS PACKOFF 4.250 5,574.9 5,173.9 26.33 XO BUSHING 5.020 XO TKC BUSHING TKC 3.000 5,926.9 5,489.3 25.81 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,712.0 5,772.0 5,296.6 5,350.3 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,780.0 5,784.0 5,357.5 5,361.1 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,790.0 5,794.0 5,366.4 5,370.0 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,603.0 5,677.3 5,199.1 5,265.6 Cement Plug Dump Bail Cement on CIBP 7/7/2024 3,887.0 5,479.5 3,667.0 5,088.3 Cement Plug PUMPED 53 BBLS OF 15.8 PPG CLASS G CEMENT 9/8/2024 2P-434, 9/17/2024 9:56:38 AM Vertical schematic (actual) LINER; 5,524.8-6,025.0 FLOAT SHOE; 6,023.1-6,025.0 FLOAT COLLAR; 5,960.1- 5,961.4 LANDING COLLAR; 5,926.9- 5,928.3 FISH; 5,882.0 IPERF; 5,790.0-5,794.0 IPERF; 5,780.0-5,784.0 IPERF; 5,712.0-5,772.0 PRODUCTION; 25.5-5,711.0 FLOAT SHOE; 5,709.5-5,711.0 LINER IMPINGEMENT; 5,685.0 CIBP; 5,677.3 FLOAT COLLAR; 5,630.1- 5,631.4 Cement Plug; 5,603.0 ftKB XO BUSHING; 5,574.9-5,576.8 SBE; 5,556.0-5,574.9 SEAL ASSY; 5,538.4 HANGER; 5,546.4-5,555.3 NIPPLE; 5,543.7-5,546.4 LOCATOR; 5,537.2 PACKER; 5,524.8-5,543.7 NIPPLE; 5,524.1 SLEEVE-C; 5,508.1 TUBING PUNCH; 5,475.0 GAS LIFT; 5,459.0 Cement Plug; 3,887.0 ftKB CUT; 2,690.0 SURFACE; 28.1-2,421.4 FLOAT SHOE; 2,419.7-2,421.4 FLOAT COLLAR; 2,333.4- 2,334.9 TUBING PUNCH; 2,000.0 TUBING PUNCH; 1,992.0 NIPPLE; 499.8 CONDUCTOR; 28.0-108.0 HANGER; 28.1-29.6 HANGER; 25.5-27.2 HANGER; 23.3 KUP INJ KB-Grd (ft) 33.79 RR Date 12/5/2003 Other Elev… 2P-434 ... TD Act Btm (ftKB) 6,030.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032046700 Wellbore Status INJ Max Angle & MD Incl (°) 28.19 MD (ftKB) 4,183.83 WELLNAME WELLBORE2P-434 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: N/A ϮWͲϰϯϰϳĂůĐƵůĂƚĞĚ WdKΛϰϲϵϵ͛Z<^^ŚŽĞΛϮϰϮϭ͛Z</WΛϮϱϮϭ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϮϱϰ͛Z<WƵƚΛϮϰϳϭ͛Z<ϴϬdŽƉΛϮϱϮϬ͛Z<ϴϬĂƐĞΛϯϲϬϱ͛Z< ORIGINATED TRANSMITTAL DATE: 9/19/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5063 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 5063 2P-434 50103204670000 Tubing Cut Record 17-Sep-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 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 203-153 T39574 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.19 10:05:38 -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 tom.osterkamp@conocophillips.com 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:N/A Rig Elevation:N/A Total Depth:6,030 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 2,421 Feet Csg Cut@ Feet Intermediate:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 5,711 Feet Csg Cut@ Feet Liner:3-1/2"O.D. Shoe@ 6,025 Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 5,575 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 5,475 ft 3,859 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result CMIT TxIA Tubing 1750 1670 1645 IA 1775 1710 1685 OA 325 298 289 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Traveled to KRU 2P-pad to witness tag and test of the intermediate balanced plug, Wireline tagged up at 3,859 ft MD and brought back a good cement sample in the bailer. There was 1.1 bbls pumped in during MIT and 1.1 bbls returned. Passing CMIT TxIA. September 15, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-434 ConocoPhillips Alaska Inc. PTD 2031530; Sundry 324-415 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0915_Plug_Verification_KRU_2P-434_ss                      Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 T39668 ORIGINATED TRANSMITTAL DATE: 9/10/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5048 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5048 2P-434 50103204670000 Tubing Puncher Record 9-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 203-153 T39541 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 11:33:19 -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: Delivered to:22-Aug-24 Alaska Oil & Gas Conservation Commiss 22Aug24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 2P-429 50-103-20378-00-00 201-102 Kuparuk River WL Puncher FINAL FIELD 4-Aug-24 2P-431 50-103-20417-00-00 202-053 Kuparuk River WL Puncher FINAL FIELD 5-Aug-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Puncher FINAL FIELD 6-Aug-24 2P-422A 50-103-2040-01-00 202-067 Kuparuk River WL Puncher FINAL FIELD 7-Aug-24 2W-05 50-029-21208-00-00 184-191 Kuparuk River WL IPROF FINAL FIELD 8-Aug-24 WSW-05 50-029-20838-00-00 182-164 Kuparuk River WL Lee LDL FINAL FIELD 9-Aug-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL Patch FINAL FIELD 13-Aug-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL Patch FINAL FIELD 14-Aug-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39470 T39471 T39472 T39473 T39474 T39475 T39476 T39477 P-434 50-103-20467-00-00 203-153 Kuparuk River WL Puncher FINAL FIELD 6-Aug-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.23 08:12:18 -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: 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): 6030'5882' 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 6025'500' 3-1/2" 5578' Packer: Bake ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 2393' 5712-5772', 5780-5784', 5790-5794' (below cement plug 5686' 3-1/2" 5297-5350', 5358-5361', 5366-5370' (below cement plug) 7' Perforation Depth TVD (ft): 108' 2421' 5296'5711' 16" 9-5/8" 80' 5575' MD 108' 2356' 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 203-153 P.O. Box 100360, Anchorage, AK 99510 50-103-20467-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5525' MD and 5129' 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-434 5582' 5603' 5199' 2238 5603' 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 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: 2024.07.17 15:35:41-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-415 By Grace Christianson at 4:51 pm, Jul 17, 2024 DSR-7/17/24 10-407 X X A.Dewhurst 19JUL24 VTL 7/18/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.22 11:18:23 -08'00'07/22/24 RBDMS JSB 072324 2P-434 Suspension Prepared by: Katherine O’Connor (214-684-7400) Network Number: Background & Objecve 2P-434 was an injector shut-in in late 2021. 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 was suspend via reservoir plug. The objective of this procedure is to pump an intermediate cement plug before rig P&A in Q4 2024. Well Data Reservoir pressure 9/15/2017 = 2778 psi at 5400’ TVD = 0.51 psi/ft MASP = 2238 psi Last TD tag 5892’ KB with 1.75” bailer Liner impingement at 5685’ KB, tagged with 2.25” bailer Procedure Wireline & Pumping 1. Punch tubing at ±5475’ RKB 2. Pump the following schedule taking returns up the IA: a.±50 bbls surfactant wash b. ±210 bbls KWF c. ±53 bbls cement d. ±35 bbls KWF displacement 3.This should leave TOC in tubing and IA hydrostatically balanced with cement top at 3975’ MD 1. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 4. Cut tubing at ±2690’ RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 5475 3.5" 9.3# 2.99" 0.0087 5475 47.5 115.1 from punch depth 3-1/2" x 7" Annulus 0 5475 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 5475 144.6 37.9 from punch depth Tubing Cement 3975 5475 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 3975 5475 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 1500 39.6 37.9 Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Suspension Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 Item Depth - tops (KB) 1 FMC GEN V TUBING HANGER 23.3' 2 CAMCO DS LANDING NIPPLE 499.8' 3 BAKER CMU SLIDING SLEEVE (OPENED 4/29/18. RE-CLOSED 4/29/18)5,508.1' 4 CAMCO D NIPPLE 5,524.1' 5 BAKER ZXP LINER PACKER 5,524.8' 6 BAKER G-22 LOCATOR 5,537.2' 7 BAKER 80-40 SEAL ASSEMBLY 5,538.40 8 RS PACKOFF SEAL NIPPLE 5,543.7' 9 BAKER FLEX-LOCK LINER HANGER 5,546.4' 10 BAKER 80-40 SEAL BORE EXT 5,556' 11 XO TKC BUSHING 5,574.9' 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Liner impingement 5685' KB Plug #1 – Reservoir TOC 5603' RKB Plug #2 – Intermediate TOC ±5475' RKB BOC @ ±3975' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Known liner impingement) 5,685.0 2P-434 6/21/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump Bail Cement on CIBP 2P-434 7/8/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water injection only with known TxIA on gas. 11/11/2019 jbyrne NOTE: View Schematic w/ Alaska Schematic9.0 11/23/2010 ninam NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/27/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,421.4 2,356.2 40.00 L-80 BTC PRODUCTION 7 6.28 25.5 5,711.0 5,295.7 26.00 L-80 BTCMD LINER 3 1/2 2.99 5,524.8 6,025.0 5,577.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.3 Set Depth … 5,575.1 Set Depth … 5,174.1 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) 23.3 23.3 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 499.8 499.8 0.65 NIPPLE 4.520 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 5,459.1 5,070.0 26.19 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,508.1 5,114.0 26.16 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (Opened 4/29/18. Re-closed 4/29/18) BAKER CMU 2.813 5,524.1 5,128.4 26.20 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,537.2 5,140.1 26.23 LOCATOR 5.000 BAKER G-22 LOCATOR BAKER G-22 3.000 5,538.4 5,141.2 26.24 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSY BAKER 80-40 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) 5,677.3 5,265.6 26.56 CIBP CIBP MID-ELEMENT AT 5678' RKB, OAL = 1.37' 6/30/2024 0.000 5,685.0 5,272.4 26.55 LINER IMPINGEMEN T Identified Tight Spot in Liner W/ Relay CCL (Able to drift w/1.75" tools) 2/4/2020 2.000 5,882.0 5,449.0 26.01 FISH FISH TOOL SAVER BROKE AFTER FIRING 3RD GUN LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5' 1/1/2004 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) 5,459.1 5,070.0 26.19 1 GAS LIFT DMY BTM 1 0.0 11/7/2005 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,524.8 5,129.0 26.20 PACKER 5.980 BAKER ZXP LINER PACKER BAKER ZXP 4.370 5,543.7 5,145.9 26.25 NIPPLE 5.590 RS PACKOFF SEAL NIPPLE RS PACKOFF 4.250 5,574.9 5,173.9 26.33 XO BUSHING 5.020 XO TKC BUSHING TKC 3.000 5,926.9 5,489.3 25.81 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,712.0 5,772.0 5,296.6 5,350.3 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,780.0 5,784.0 5,357.5 5,361.1 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,790.0 5,794.0 5,366.4 5,370.0 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,603.0 5,677.3 5,199.1 5,265.6 Cement Plug Dump Bail Cement on CIBP 7/7/2024 2P-434, 7/16/2024 4:51:04 PM Vertical schematic (actual) LINER; 5,524.8-6,025.0 FISH; 5,882.0 IPERF; 5,790.0-5,794.0 IPERF; 5,780.0-5,784.0 IPERF; 5,712.0-5,772.0 PRODUCTION; 25.5-5,711.0 LINER IMPINGEMENT; 5,685.0 CIBP; 5,677.3 Cement Plug; 5,603.0 ftKB GAS LIFT; 5,459.0 SURFACE; 28.1-2,421.4 NIPPLE; 499.8 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 33.79 RR Date 12/5/2003 Other Elev… 2P-434 ... TD Act Btm (ftKB) 6,030.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032046700 Wellbore Status INJ Max Angle & MD Incl (°) 28.19 MD (ftKB) 4,183.83 WELLNAME WELLBORE2P-434 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: N/A 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 2356' 7" L-80 5296' 3.5" L-80 5578' 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, 120 sx Class G6.125" TUBING RECORD 170 sx Class G8.5" 5575' 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 7/12/2024 203-153 / 323-549 50-103-20467-00-00 KRU 2P-434 ADL0373112 957' FNL, 1855' FWL, Sec. 17, T8N, R7E, UM 270' FSL, 253' FWL, Sec. 8, T8N, R7E, UM ALK 32092 11/24/2003 6030' MD / 5582' TVD 5603' MD / 5199' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443815 5868921 184' FSL, 365' FWL, Sec. 8, T8N, R7E, UM 12/2/2003 CEMENTING RECORD 5870073 1354' MD / 1351' TVD SETTING DEPTH TVD 5870159 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 5524' MD / 5129' TVD PACKER SET (MD/TVD) 42" 12.25" 90 sx AS I 28'530 sx AS Lite, 220 sx LiteCrete 9.2# 28' 5524' 2421'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 5603 (SW TOC) -5677' ~0.26 bbls 15.8 ppg Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 5712-5772' MD and 5297-5350' TVD (below cement plug) 5780-5784' MD and 5357-5361' TVD (below cement plug) 5790-5794' MD and 5366-5370' TVD(below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 5711' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 6025' 26' 5128' 62.5# 40# 108' 26' WT. PER FT.GRADE 442330 442218 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by James Brooks on 7/17/2024 at 9:59AM Suspended 7/12/2024 JSB RBDMS JSB 071824 xGDSR-8/27/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1354' 1351' 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: 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 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 - 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 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 documentLocation: Date: 2024.07.17 08:56:59-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Known liner impingement) 5,685.0 2P-434 6/21/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump Bail Cement on CIBP 2P-434 7/8/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water injection only with known TxIA on gas. 11/11/2019 jbyrne NOTE: View Schematic w/ Alaska Schematic9.0 11/23/2010 ninam NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/27/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,421.4 2,356.2 40.00 L-80 BTC PRODUCTION 7 6.28 25.5 5,711.0 5,295.7 26.00 L-80 BTCMD LINER 3 1/2 2.99 5,524.8 6,025.0 5,577.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.3 Set Depth … 5,575.1 Set Depth … 5,174.1 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) 23.3 23.3 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 499.8 499.8 0.65 NIPPLE 4.520 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 5,459.1 5,070.0 26.19 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,508.1 5,114.0 26.16 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE (Opened 4/29/18. Re-closed 4/29/18) BAKER CMU 2.813 5,524.1 5,128.4 26.20 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,537.2 5,140.1 26.23 LOCATOR 5.000 BAKER G-22 LOCATOR BAKER G-22 3.000 5,538.4 5,141.2 26.24 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSY BAKER 80-40 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) 5,677.3 5,265.6 26.56 CIBP CIBP MID-ELEMENT AT 5678' RKB, OAL = 1.37' 6/30/2024 0.000 5,685.0 5,272.4 26.55 LINER IMPINGEMEN T Identified Tight Spot in Liner W/ Relay CCL (Able to drift w/1.75" tools) 2/4/2020 2.000 5,882.0 5,449.0 26.01 FISH FISH TOOL SAVER BROKE AFTER FIRING 3RD GUN LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5' 1/1/2004 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) 5,459.1 5,070.0 26.19 1 GAS LIFT DMY BTM 1 0.0 11/7/2005 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,524.8 5,129.0 26.20 PACKER 5.980 BAKER ZXP LINER PACKER BAKER ZXP 4.370 5,543.7 5,145.9 26.25 NIPPLE 5.590 RS PACKOFF SEAL NIPPLE RS PACKOFF 4.250 5,574.9 5,173.9 26.33 XO BUSHING 5.020 XO TKC BUSHING TKC 3.000 5,926.9 5,489.3 25.81 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,712.0 5,772.0 5,296.6 5,350.3 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,780.0 5,784.0 5,357.5 5,361.1 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation 5,790.0 5,794.0 5,366.4 5,370.0 T-3, 2P-434 1/1/2004 6.0 IPERF 2.5" HSD PJ, DP; 60 deg phase, random orientation Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,603.0 5,677.3 5,199.1 5,265.6 Cement Plug Dump Bail Cement on CIBP 7/7/2024 2P-434, 7/16/2024 4:51:04 PM Vertical schematic (actual) LINER; 5,524.8-6,025.0 FISH; 5,882.0 IPERF; 5,790.0-5,794.0 IPERF; 5,780.0-5,784.0 IPERF; 5,712.0-5,772.0 PRODUCTION; 25.5-5,711.0 LINER IMPINGEMENT; 5,685.0 CIBP; 5,677.3 Cement Plug; 5,603.0 ftKB GAS LIFT; 5,459.0 SURFACE; 28.1-2,421.4 NIPPLE; 499.8 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 33.79 RR Date 12/5/2003 Other Elev… 2P-434 ... TD Act Btm (ftKB) 6,030.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032046700 Wellbore Status INJ Max Angle & MD Incl (°) 28.19 MD (ftKB) 4,183.83 WELLNAME WELLBORE2P-434 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: N/A DTTMSTART JOBTYP SUMMARYOPS 6/21/2024 CHANGE WELL TYPE DRIFT TBG TO KNOWN LINER IMPINGEMENT @ 5685' RKB W/ 2.69" DUMMY CIBP DRIFT, NO TIGHT SPOTS OR WEIGHT SWINGS ENCOUNTERED, WELL READY FOR E-LINE. IN PROGRESS. 6/30/2024 CHANGE WELL TYPE LOAD TBG W/ 60 BBLS 10.2 PPG BRINE AND 17 BBLS DIESEL. SET CIBP MID-ELEMENT AT 5678', PERFORM 1500 PSI MIT-T (PASS), PERFORM 1500 PSI MIT-IA (PASS). JOB COMPLETE, READY FOR SL 7/7/2024 CHANGE WELL TYPE DRIFT & TAG CIBP @ 5677' RKB. DUMP BAIL SIX BAILERS OF CEMENT ON TOP OF CIBP @ 5677' RKB, LDFN. JOB IN PROGRESS 7/8/2024 CHANGE WELL TYPE DUMP BAIL ONE MORE BAILER OF CEMENT FINISHING UP DUMP BAILING. LEAVING TOC @ ~ 5635' RKB. READY FOR STATE WITNESS IN 72 HOURS. 7/12/2024 CHANGE WELL TYPE STATE WITNESS (SEAN SULLIVAN) TAG TOC @ 5603' RKB. MIT-T TO 1500 PSI PASSED. READY FOR NEXT P&A STEPS. 2P-434 Suspend Summary of Oerations 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:N/A Rig Elevation:N/A Total Depth:6,030 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 2,421 Feet Csg Cut@ Feet Intermediate:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 5,711 Feet Csg Cut@ Feet Liner:3-1/2"O.D. Shoe@ 6025 Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 5,575 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 5,677 ft 5,603 ft 9.6 ppg KWF Wireline tag Initial 15 min 30 min 45 min Result Tubing 1750 1670 1645 IA 505 512 512 OA 224 224 224 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): Traveled to KRU 2P pad for multiple P&A's .This is the initial witnessed Tag and MIT-T of the 1st cmt plug for 2P-434. Upon arival I met with Conoco rep Sid Ferguson, Little Red Services (LRS) operators, and wireline crew to go over the plan for the day. They began with a wireline tag with bailer and 300 lbs weight bar. A solid tag was made at 5,630 ft MD and returned a good cmt sample that was grey in color and clay like. E-line rigged down and started rigging up on the next well while LRS rigged up for MIT-T. The MIT was performed with no noticable losses to the plug or to the IA. Data was recorded and we moved to the next well. July 12, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-434 ConocoPhillips Alaska LLC PTD 2031530; Sundry 323-549 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0712_Plug_Verification_KRU_2P-434_ss                  ORIGINATED TRANSMITTAL DATE: 7/1/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4904 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 4904 2P-434 50103204670000 Plug Setting Record 30-Jun-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 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 203-153 T39099 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.01 11:44:18 -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 tom.osterkamp@conocophillips.com 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): 6030'5882' 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 6025'500' 3-1/2" 5578' Packer: Bake ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 2393' 5712-5772', 5780-5784', 5790- 5794' 5686' 3-1/2" 5297-5350', 5358-5361', 5366- 5370' 7' Perforation Depth TVD (ft): 108' 2421' 5296'5711' 16" 9-5/8" 80' 5575' MD 108' 2356' 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 203-153 P.O. Box 100360, Anchorage, AK 99510 50-103-20467-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5525' MD and 5129' 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-434 5582' 5892' 5458' 2238 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 Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=USReason: I am the author of this documentLocation:Date: 2023.10.04 10:58:32-08'00'Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 323-549 By Grace Christianson at 9:28 am, Oct 05, 2023 SFD DSR-10/5/23 December 31, 2024 SFD 10/6/2023 10-407 VTL 11/20/2023 X X JLC 11/20/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.20 12:41:14 -09'00'11/20/23 RBDMS JSB 112023 2P-434 Suspension Date Wrien: 9-21-23 Execuon Date: Nov 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-434 was an injector shut-in in late 2021. 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 9/15/2017 = 2778 psi at 5400’ TVD MASP = 2238 psi Last TD tag 5892’ KB with 1.75” bailer Liner impingement at 5685’ KB, tagged with 2.25” bailer Procedure Wireline & Pumping 1. Drift with dummy CIBP. If unable to get within 50’ of perforations, contact Katherine O’Connor 2. Fluid pack tubing with KWF and freeze protect 3. Set CIBP @ ±5,675’ RKB (must be set within 50’ of the top of perforations). 4. Perform MIT-T to 1500 psi, record results 5. Dump bail at least 30’ of cement on top of CIBP 6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 7. RIH and tag TOC, approx. 5,645’ RKB (MUST BE AOGCC WITNESSED) 8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 9. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 Item Depth - tops (KB) 1 FMC GEN V TUBING HANGER 23.3' 2 CAMCO DS LANDING NIPPLE 499.8' 3 BAKER CMU SLIDING SLEEVE (OPENED 4/29/18. RE-CLOSED 4/29/18)5,508.1' 4 CAMCO D NIPPLE 5,524.1' 5 BAKER ZXP LINER PACKER 5,524.8' 6 BAKER G-22 LOCATOR 5,537.2' 7 BAKER 80-40 SEAL ASSEMBLY 5,538.40 8 RS PACKOFF SEAL NIPPLE 5,543.7' 9 BAKER FLEX-LOCK LINER HANGER 5,546.4' 10 BAKER 80-40 SEAL BORE EXT 5,556' 11 XO TKC BUSHING 5,574.9' 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Liner impingement 5685' KB Liner Cement: 25 bbls of 15.8# Class G Cement Calculated TOC @ 5,524.8' KB 2P-434 Well Suspension Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 35.5 bbls of 15.8# Class G Cement Calculated TOC @ 4,139' KB 1 2 3 5 Production Casing: 7" 26# L-80 BTCMD Set @ 5,711’ KB T-3 Peforations: @ 5,712' – 5,794' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,421.4' KB Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,575.1' KB 7 Item Depth - tops (KB) 1 FMC GEN V TUBING HANGER 23.3' 2 CAMCO DS LANDING NIPPLE 499.8' 3 BAKER CMU SLIDING SLEEVE (OPENED 4/29/18. RE-CLOSED 4/29/18)5,508.1' 4 CAMCO D NIPPLE 5,524.1' 5 BAKER ZXP LINER PACKER 5,524.8' 6 BAKER G-22 LOCATOR 5,537.2' 7 BAKER 80-40 SEAL ASSEMBLY 5,538.40 8 RS PACKOFF SEAL NIPPLE 5,543.7' 9 BAKER FLEX-LOCK LINER HANGER 5,546.4' 10 BAKER 80-40 SEAL BORE EXT 5,556' 11 XO TKC BUSHING 5,574.9' 6 8 4 9 10 11Liner: 3.5" 9.2# L-80 SLHT Set @ 6,025’ KB C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5675' RKB Liner impingement 5685' KB 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Wednesday, August 17, 2022 10:00 AM To:Regg, James B (OGC); Wallace, Chris D (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:CPAI 2P-Pad shut in tests 08-16-22.xlsx Attachments:MIT KRU 2P PAD SI TESTS 08-16-22.xlsx All Attached is the 10 426 form for the shut in tests performed on 2P pad on the 16 th of Aug 2022. Please let me know if you have any questions or concerns. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 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. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040170 Type Inj N Tubing 2605 2620 2610 2610 Type Test P Packer TVD 5209 BBL Pump 3.2 IA 470 3590 3500 3480 Interval V Test psi 2900 BBL Return 3.1 OA 203 360 310 290 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011820 Type Inj N Tubing 827 827 828 828 Type Test P Packer TVD 5428 BBL Pump 1.0 IA 460 3210 3145 3130 Interval V Test psi 2900 BBL Return 0.9 OA 277 363 319 309 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020180 Type Inj N Tubing 808 1001 980 953 Type Test P Packer TVD 5456 BBL Pump 2.3 IA 410 3200 3090 3075 Interval V Test psi 2900 BBL Return 2.0 OA 277 576 515 484 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011020 Type Inj N Tubing 875 876 876 876 Type Test P Packer TVD 5219 BBL Pump 2.1 IA 390 3200 3110 3100 Interval V Test psi 2900 BBL Return 1.8 OA 236 569 539 531 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020910 Type Inj N Tubing 1091 1091 1091 Type Test P Packer TVD 5177 BBL Pump 3.2 IA 450 3200 2105 Interval V Test psi 2900 BBL Return OA 278 405 345 Result F Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031530 Type Inj N Tubing 886 887 887 887 Type Test P Packer TVD 5141 BBL Pump 1.6 IA 470 3210 3110 3090 Interval V Test psi 2900 BBL Return 1.6 OA 254 356 321 312 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010820 Type Inj N Tubing 112 288 298 294 Type Test P Packer TVD 5274 BBL Pump 1.7 IA 950 3210 3110 3100 Interval V Test psi 2900 BBL Return 1,6 OA 211 428 303 253 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031540 Type Inj N Tubing 882 882 882 882 Type Test P Packer TVD 5234 BBL Pump 2.0 IA 210 3210 3110 3110 Interval V Test psi 2900 BBL Return 1.8 OA 438 444 444 443 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 2P-438 2P-447 MITIA every 2 yr to max anticipated injection pressure per AIO 21C.002 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-429 2P-432 2P-434 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-427 Notes:MITIA every 2 yr to max anticipated injection pressure per AIO 21C.001 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 ConocoPhillips Alaska Inc, Kuparuk / KRU / 2P Pad Witness Waived by Guy Cook Beck / Borge 08/16/22 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Tubing plug set at 8110' MD Notes: Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-419 2P-420 Form 10-426 (Revised 01/2017)2022-0816_MIT_KRU_2P-pad_8wells 2P-434 MEMORANDUM To: Jim Regg P.I. Supervisor �I FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 6, 2020 14 (-4,1 w SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2P-434 KUPARUK RIV U MELT 21`434 NON -CONFIDENTIAL Src: Inspector Reviewed n P.I. SuprvV ht— Comm Well Name KUPARUK RIV U MELT 2P-434 API Well Number 50-103-20467-00-00 Inspector Name: Guy Cook Permit Number: 203-153-0 Inspection Date: 8/1/2020 ' IRSp Num: mitGDC200803112206 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2P-434 'Type Inj w TVI) 5141 TUhIRg 1000 - to 1010' 1010 i PTD 20315301 e SPT Test psi 2900 I,I IA 330 3220 ' 3120 3110 BBL Pumped: p /'j'eSt 2 BBL Returned: 2 r OA 608 615 615 Interval REQVAR IP[F___] P ✓ - Notes' MIT -IA every 2 years to max anticipated injection pressure per AIO 2l C.002. Testing was completed with a Little Red Services pump truck and calibrated gauges. Thursday, August 6, 2020 Page 1 of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, February 2, 2020 1:42 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: FW: Kuparuk Meltwater Injector 2P-434 (PTD# 203-153) pressure decrease in the OA Attachments: 2P-434 90 day TIO.PNG Chris, Kuparuk Meltwater Injector 2P-434 (PTD# 203-153) was recently reported for an unexplainable OA pressure decrease. The well was shut in and secured with a tubing plug as required per AIO 21C.002. Initial diagnostics determined that the pressure anomaly was due to frozen OA surface jewelry. Operations has mitigated the frozen jewelry and the OA will be monitored as normal for further pressure anomalies . The well will return to normal injection status under A1021C.002. Attached is a 90 -day TIO plot. Thank you, Paul Duffy for Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM CawcoPhi91ps From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, January 26, 2020 4:01 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Subject: Kuparuk Meltwater Injector 2P-434 (PTD# 203-153) pressure decrease in the OA Chris- Kuparuk Meltwater Injector 2P-434 (PTD# 203-153) has an unexplainable pressure decrease in the OA. The well will be shut in and secured as soon as reasonably possible to accommodate NO 21C.002 criteria, which the well is currently operating under. Once the well is secured, DHD will perform an initial set of diagnostics to investigate the falling OA pressure. Depending on the results of the testing, the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the well bore schematic and 90 -day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, January 26, 2020 4:01 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPH & 2 Subject: Kuparuk Meltwater Injector 213-434 (PTD# 203-153) pressure decrease in the OA Attachments: 2P-434 90 Day TIO plot.JPG; 2P-434.pdf Chris- Kuparuk Meltwater Injector 2P-434 (PTD# 203-153) has an unexplainable pressure decrease in the OA. The well will be shut in and secured as soon as reasonably possible to accommodate NO 21C.002 criteria, which the well is currently operating under. Once the well is secured, DHD will perform an initial set of diagnostics to investigate the falling OA pressure. Depending on the results of the testing, the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the well bore schematic and 90 -day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM CaincaPNMips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, November 2, 2019 12:58 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU injection well 2P-434 (PTD 203-153) water injection monitor period has been completed. Attachments: 213-434 AA application packer.pdf, MIT KRU 213-434 10-14-19.xlsx Chris, KRU injection well 2P-434 (PTD 203-153) water injection monitor period has been completed. The well did not display TxIA communication throughout the monitor period. CPAI intends to apply for administrative approval to continue water injection only with known TxIA communication on gas injection only. The paper application is in the mail and digital copy of the AA application packet is attached. The well will be left on water injection while the AA application is being processed. Please let us know if you disagree or have any questions with this plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM conocXIMPs MEMORANDUM State of Alaska Insp Num: mitLOL191015121530 Alaska Oil and Gas Conservation Commission Rel Insp Num: DATE: Monday, October 21, 2019 TO: Jim Regg p� I -y�'� (V J Z4 )1 h SUBJECT: Mechanical Integrity Tests P.I. Supervisor 2P-434 l ConocoPhillips Alaska, Inc. 2P-434 FROM: Lou Laubenstein KUPARUK RIV U MELT 2P-434 Petroleum Inspector 1000 ' Src: Inspector PTD Reviewed B Type Test -y: pp P.I. Supry .11�L NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U MELT 2P-434 API Well Number 50-103-20467-00-00 Inspector Name: Lou Laubenstein Permit Number: 203-153-0 Inspection Date: 10/14/2019 ' Insp Num: mitLOL191015121530 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2P-434 Type Inj w "TVD 5141 - Tubing 1000 1000 1000 - 1000 ' PTD 2031530 Type Test sPT Tes[ psi zvoo - IA 00 3200 020 3050 BBL Pumped: 2 BBL Returned: 2.1 OA aoo n0 0 - n0 - Interval oTFTR PIF P ✓ ✓ Notes: MIT -IA to maximum anticipated surface pressure per AIO 21C and Sundry # 318-451, conversion form GI to WAG injection. Monday, October 21, 2019 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate LJ Pull Tubing L1 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: Water Injection startup 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑� o —( 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 6. API Number: 50-103-20467-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: Surface: ADL 373112 KRU 2P-434 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Ku aruk River Field/Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 6,030' feet Plugs measured NA feet true vertical 5,582' feet Junk measured 5,882- feet Effective Depth measured 5,794- feet Packer measured 5,525' feet true vertical 5,370' feet true vertical 5,129' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2,393' g2 4 2,421' 2,356' N �� Intermediate �� Production 5,686' kP1" T 5,711' 5,296' Liner 500' 3.5" 6,025' 5,578' OCT 16 2619 Perforation depth Measured depth 5,712-5,794 feet AOGCC True Vertical depth 5,297-5,370' feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 5,575' 5,174' Packers and SSSV (type, measured and true vertical depth) Packer: BAKER ZXP LINER PACKER Packer: MD= 5525' TVD= 5129' No SSSV 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:1 0 6500 1 0 750 psi 2600 psi Subsequent to operation:1 0 0 1 4140 114 psi 1020 psi 14. Attachments (required per20 AAc 25.070, 25.071, a 25.283) 15.W 11 Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-451 Authorized Name: Sayeed Abbas Contact Name: Sayeed Abbas Authorized Title: Staff Petroleum Engineer Contact Email: sa eed.abbas conocophillips.conn Authorized Signature: --5 ��A`-Jf Date: Contact Phone: 907-265-1109 P7 G !O/ZZ M p p� q q 1 Form 10-404 Revised 4/2017 X f41,A1 ABDMS�QCT I L 12019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 October 14th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. has completed changing the service of the Kuparuk River Unit (Meltwater) Well 2P-434 from Gas Injection to Water Alternating Gas Injection. Enclosed you will find a 10-404 report of Sundry Well Operations for ConocoPhillips Alaska, Inc. A separate submission for a state witnessed MIT -IA for 2P-434 was also made. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Report of Sundry Well Operations Daily report of Well Operations Well Schematic I 2P-434 DAILY REPORT WELL OPERATIONS 10/04/2019: 2P-434 started water injection as part of the process to change the well from Gas Injection (GINJ) designation to Water -Alternating -Gas (WAG) designation 10114/2019: 2P-434 passed state witnessed MITIA KUP INJ WELLNAME 2P-434 WELLBORE 2P-434 ConoCoPhillip5 Aiiiiiiiii A Fieeg Attnnetes Max Angle & MD TD Ate. t, Field .ELTam¢ Wellbo,a APINNI W<IIEore Status MELTWATER 501032046]00 INJ ncl l°) MO IRKS) qct Slm(XKB) 8.19 4,183.83 6.030.0 n SG$VeWRDP NyS(am.)pate pn nataGaEntl pa Lest WO: te KBG,J (X) RIO Release Dale 33.J9 121512003 N -<3d, Bl9lN18a33%pM Last Tag Ve,li[al <tltematic lsclwl) Mnata[un p<pIM1 (ttKR) EnE Dale Wellbare Iasi Mm By Last Tag: RKB 5,913.06/201201] 2P-034 DPrOven ------ ------ '---- Last Rev Reason Mnohnon EndDah wellWre I Usen ey ,NNGER ]3.3 Rev Reason: Pulled 2]5 -CA -2 Plug 8/222019 2P-034 zembaej Casing Strings CasimDescrution OU (in) Men) Top IXKB) Set Depte(XKIg SrtOepm (ND)... WULen (I... G,atle Top TM1reatl CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-00 WELDED Casing p_,'is"" OD in) 10 (in) Top IXKB) Set OePh (Ideal Set Depte ITVO)... WOL<n D... Grade TopThenad SURFACE 9518 8.83 28.1 2,421.4 2,356.2 40.00 L-80 BTC Casino DescrlIF00(in ID (in) Top (XKB) -7'.aSet Da-'TVp)... WHLen (I... Grade Tap Timead PRODUCTION ] 6.28 25.5 5,]11.0 5,295.] 2. Wi L-80 BTCMD Casing Descrlplion on lin) ID (In) Tap IXKB) Set Depth (GNP, Sel DepiM1 (NO).,. WVLen (I... Grade Tap TMexl LINER 3112 2.99 5,524.8 6,025,0 4577.7 9.30 L-80 SLHT Liner Details rop XKB) Top(p)(fK) TpIa41'1 MDa toroidal l lD (IN 558 5,129.0 26.20 PACKER BAKER ZXP LINER PACKER 4.370 5,543) 5,145.9 26.25 NIPPLE RS PACKOFF SEAL NIPPLE 4.250 5,546,0 5,148.4 26.26 HANGER BAKER FLEXLOCK LINE -HANGER 4.410 cOxpuciGF-2sat%.0 5,556.0 5,15>.0 26.28 SBE BAKER 80-00 SEAL BOREEXT 4.000 5,5]4.9 5,1]39 26.33 XO BUSHING XO TKC BUSHING 3.000 NIPPLE;4We Tubing Strings -...._ Time Dee upd- 341ng Ma... ID(m) Tap(XKS) Sat Derah ett..5el Depth (ND)(... W umf!) jGrade Top Conne[[ion TUBING 3112 2.99 23.3 5,575.1 S,D4.1 9.30 L-60 EVE-Brd coral on Detalls Top IXKB To'IND) ) Top;;; Nominal IXKB) 1°Item Das Cam ID (In) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 3.500 49.8 499.8 0.65 NIPPLE CAMCO DS LANDING NIPPLE 2.875 suRFACE 2e.1-21214- 51508.1 5.114.0 26.16 SLEEVE -C BAKER CMU SLIDNGSLEEVE 2.813 (Opened 41212 9118. Re -dosed 4)29118) 5.524.1 5,1284 2610 NIPPLE CAM CO D NIPPLE 2750 5.5372 5,140.1 2623 LOCATOR BAKER G-22 LOCATOR 3.000 GAS LIFT: 5,459, 5,538.4 5,1412 26.24 SEAL ASSY BAKER 80.40 SEAL ASSY 3,000 Other in Hole (Wlrellne retrievable plugs, valves, pumps, fish, etc.) Tap(ND) Tap ma Topree.) (m P, P) Des com Run Dale l0 (in) 5,862.0 5,449.0 26.01 FISH FISH TOOL SAVER BROKE AFTERFIRING 3RD GUN 11112004 LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5 sleEVE-a sspal Perforations B Slots wwLe 55244 Tap (1120 Top BE) Bud IN DVD) BIm MKS) (XKB) IXKB) Linkm2one Data Den Dens (ehm:m ) Type CV. 5.712.0 5,772.0 5,296.6 5,350.3 T -3.2P-034 1/10004 6.0 IPERF .a-HSD PJ, DP; 60 deg Dbase, Random Oriame.D0n WCATOR; 55372 5,7800 5,7840 5,35].5 5.361.1 L$2P<34 1/18004 6.0 IPE F 2.5"HSD PJ,OP;fiO Deg phase, rantlom orientation g 5,]90.0 5,]94.0 5,366.4 43]0.0 T -3,2P-034 1118004 60 (PERF 2.5'HSD PJ. DP;fiD tleg pM1ase, rantlom Otlenlalion Mandrel Inserts Sl di N Top IXKB 1 TOPINDI IXKB) Make MWeI OO gra) Sery valve Type Pari)ixe type Type IIn) T0.0 Run Ip0 Run Oale Com SERLASSV;553a.1 1 5,459.1 5,0)0.0 CAMCO KBG-2- 1 GAS LIFT DMV BTM 0.000 0.0 111712115 9 Notes: General& Safe Ene Dam Annousion 71272009 NOTE: ZONES NOT LOADED INTO WELLVIEW YET 712812009 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR 1183/2310 NOTE:View Schematic wl Alaska Schematic9.0 PROMCTON', 25.55.711.0 IPEFF,5,712MMe- IPERF', 11...4D - PERF 5,]91.p5,]OIO� EAKSa920 DNFN.5524.9$0250� THE STATE GOVERNOR BILL WALKER Adam Childs Staff Petroleum Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Meltwater Oil Pool, KRU 2P-434 Permit to Drill Number: 203-153 Sundry Number: 318-451 Dear Mr. Childs: Alaska Oil and Cas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov 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, Hollis S. French Chair �l DATED this t9 day of October, 2018. RBAMs:L(` OCT912018 Loepp, Victoria T (DOA) From: Childs, Adam G <Adam.G.Childs@conocophillips.com> Sent: Thursday, October 11, 2018 9:59 AM To: Loepp, Victoria T (DOA) Subject: 2P Injector Sundry Requests Victoria, I received your voicemail regarding the 2P sundry requests. The majority of those MITIAs performed last month were state witnessed, but not all of them. Three of the injectors were shut-in at the time of testing, and were therefore non - state witnessed tests. A separate 10-426 form was sent to the state with the results of these tests. Please see table below including which of the wells tested in August were state witnessed, and when the last witnessed tests were for those that were shut-in. Well Name 2P-419 August 2018 State Witnessed Test? Yes Status Of Test Passed Last State Witnessed Test Status of Last Test 2P-420 Yes Passed 2P-427 No Passed 8/20/16 Passed 2P-429 Yes Passed 2P-432 Yes Passed 2P-434 No Passed 11/09/14 Passed 2P-438 No Passed 9/30/16 Passed 2P-447 Yes Passed Let me know if you have any other questions. Thanks, Adam Childs 907-263-4690 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 OCT (n 8 201:8 , 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 ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: _Convert GINJ to WAG_ ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli s Alaska Inc. Exploratory ❑ Development B- Stratigraphic ❑ Service [R/ 203-153 3. Address: 6. API Number: X0'8 P. O. Box 100360, Anchorage, Alaska 99510 Lp 50-103-20467-00-00 7. If perforating: 8. Well ame and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑Q KRU 2P-434 9. Pr pf llyesigna'ion (Lease Number): �rT1fg 10. Field/Pool(s): ,13 a : ADL 373112/ 13SI-feBr-3880a8_ Kuparuk River Field / Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (11): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,030' 5,582' 5,794' 5,370' 5,524' Fish @ 5,882' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2,393' 12" 2,421' 2,356' Intermediate Production 5,686' 10" 5,711' 5,296' Liner 500' 3.5" 6,025' 5,578' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,712 - 5,794 5,297 - 5,370' 3.500" L-80 5,537' Packers and SSSV Type: No SSSV Packers and SSSV MD (ft) and TVD (ft): Packer: BAKER ZXP LINER PACKER Packer: MD= 5525' TVD= 5129' 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ SOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Developmi Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2018 OIL❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑✓ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: 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: Adam Childs Contact Name: Adam Childs Authorized Title: Staff Vetroleurn Engineer Contact Email: adam.g.childs@conocphillips.com Contact Phone: 907-263-4690 Authorized Signature: Date: U it COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ l{l� Other: Post Initial Injection MIT Req'd? Yes e No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /a —4 0 4. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I O t l 9 l l Q> Caw I c iD r3 i8 aQ In6 �i3�f�7 9D t� t'I \ Submit Farm and Form u-�t�y�auei11M767Z OCT z11rg1�9NPPPlic a 2 the date a p % Attachments i Duplicate to/8it8 is ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 October 8th. 2018 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to change the service of the Kuparuk River Unit (Meltwater) Well 213-434 from Gas Injection to Water Alternating Gas Injection. Enclosed you will find a 10-403 Application seeking Sundry Approval for ConocoPhillips Alaska, Inc. If you have any questions regarding this matter, please contact me at 907-263-4690. Sincerely, , Adam Childs Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary Well Schematic 2P-434 DESCRIPTION SUMMARY OF PROPOSAL Commensurate with the recently revised and approved AIO 21C, ConocoPhillips Alaska Inc. is in the process of facility and wellbore modifications to enable water injection in Meltwater. As part of these changes, ConocoPhillips Alaska Inc. is seeking approval to change the service type of Meltwater injector 2P-434 from its current Gas Injection (GINJ) designation to Water -Alternating -Gas (WAG). The 2P-434 successfully passed an MIT -IA test to 3300 psia on 8/15/18. KUP INJ 2P-434 wnocclPhillips . ell Attributes Maz Angis $:MD 727 JUa$kB, ft. WellEore P%7001 FINtl Nanre WpIIbD,e SWI,s ncl r) MDXKB) RCI B[m lryKBj 50103204000 MELTWATER INJ 20.19 6.183.83 6.030.0 Comment Has loom) Delp gnnalallon EnO Dale KBGrtl try) qig Rele35e Dale SSSV: 33]9 1215/2003 Last WU: zv.4x.gdoTmle lo:4a:n un Last Taagg NnnWMion Dawn lliKR1 ena091e Lae Moa ey Leat Tag:RKB 5,813.0 U2012017 pproven Last Rev Reason Annotation Entl Dale LssI MM BY Rev Reason. Shin CMU open/Nosed Updated Plug date on Plug C 5S24 FIND 4/288010 "Busp Casing Strings Caning Descnpnon OBOn) IDlin) Tnp ME aw Deptn nlee1 sw Demonl Id" wNLen D._e,mp Top rmma CONDUCTOR tfi 15062 280 1080 108.0 6250 H-40 WELDED erring DecriPtion ODlinl IS an) TOP IM oN atlDemon lryK81 Set Depth ITVD)... WIILen IL_Orad Top TnrW SURFACE 9510 8835 213A 2,4214 2,356.2 40.00 L-80 BTC Casing essmiPtlon WRI ID lin) Tap (X Re SeIDepO(MKBI SADeMh ITVDL.. WVLen 11... Grehe TOPToratl PRODUCTION ] 6276 25.5 5,]110 5,295] 2600 680 BTCMO Casing Descopllon Oo(1n) IO G) Top(NKD) Se10,&IXKB) Set DepinlNDl.. WNLen(I... Grade Top Tbrad LINER 3112 2992 55248 6025.0 5,5]]] 930 L-80 SLHT Liner Details j TopINKu Tup UTul(It. rap incl V) Item Des Com No'in'l10 55260 5,1290 26.20 PACKER BAKER ZXP LINER PACKER 4.370 5543] 51459 26.25 NIPPLE RS RACKOFF SEAL NIPPLE 6250 5.54845,1404 26.26 HANGER BAKER FLE%LOCK LINER HANGER 4610 55560 5,15].0 2628 SBE BAKER 80-40 SEAL BORE EXT 4000 55749 51739 26.33 XO BUSHING NO TAC BUSHING 3000 Tubing Strings Tubing Descnpnon Sbing Ma... ID (nl Top (NKO Se10ep1n (M. Sel Oeptn Iry0) I... WtgbXl) GraEc lop ConnMion TUBING 31/2 2992 23.3 5.5]5.1 5.1]4.1 930 L-80 EUE-Bra Completion Details ropiml Nom; al Top MKB) (•) Item Oss eom mRn) 23.3 0.00 HANGER FMC GEN V TUBING HANGER 3.500 SURFRCE; 261 2.421 4-4998 0.65 NIPPLE CAMCO DS LANDING NIPPLE 2.875 5,508.1 26.16 SLEEVE -C BAKER CMU SLIDING SLEEVE 2.813 1499 (Opened 429/18. Re -dosed 4/29/18) 5.524.1 2620 NIPPLE CAMCO D NIPPLE 2]50 553 2 28.2J LOCATOR BAKER G22 LOCATOR 3000 GPaLIFT:5p5g0 5,5384 2624 SEALASSY BAKER 8040 SEAL ASSY 3.000 Other In Hole 1Wireline retrievable plugs, valves, pumps, fish, etc.) rop UrvD) Top tool Top INKBf XKB) 1') pas Com quo Date ID(in) 5.524.0 5,1283 2620 Piog 1 Set2]5"CA2 Plug(26" UAL) 9/1512017 0000 swEVE�Q saa9.f 58820 54490 25.01 1-1511 FISH T0OL SAVER BROKEAFTER FIRING 3RU GUN 17112006 LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5' NIPPLE; 5.584.1 Perforations & Slots %q;55i10 Snot I I Top RVD) BIM UW) (sh.t Top(XKIu Btm MKB) MKS) MKB) Zone DMe 1 Tyt Com LOCATOR;5ST2 5,7120 5,780 5,296.fi 5,3503 TG, 2P434 1112004 80 IPERJ, DP', 60 deg Phase,dom onentatlon 4 5,700.0 5,]86.0 5.35].5 5,361.1 T-3, 2P-434 1/112004 6.0 IPERJ. DIP 60deg dem orientation T -3,2P-434 V12006 80 (PERJ, OP;60deg om odentat'Ion Mandrel Inserts sFxusY; s.s».4 gt tll N cop MK81 Tlrtl(R D) 1 MaXe Motlel OD in 1 Sery IlTalve Ype T. Type PotlSXe pnl TRORun Ipeil Run Gate Com 1 5459.1 50]00 CAMCO KBG 2 1 GA6 LIFT pMY BTM 8000 0.0 11/]/2005 9 Notes: General & Safety Eea Date A—Le"n ]/2]/2009 NOTE'. ZONES NOT LOADED INTO WELLVIEW YET ]/2812009 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR 11/232010 NOTE: View Schematic al Alaska Schematic9.0 PRODUCTION', 25 Sfi.]110— IPERF:S]I365.]Y1.0— IPERK5,ND.eS,]840� I1ERFSILD..1940— FISH;v.8820 LINER; S5i48dI Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday,April 17, 2018 5:01 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of unexplained IA pressure anomaly 2P-434 (PTD 203-153)4-17-18 Attachments: 2P-434 90 day TIO 4-17-18.JPG; 2P-434 180 day TIO 4-17-18.JPG;2P-434 schematic.pdf Chris, Meltwater injector 2P-434(PTD 203-153) is experiencing an unexplained slow rise in IA pressure. A gas-only tubing leak is suspected at this time. The well has been shut in since August 2015 and has had a retrievable tubing plug set since September 2017. There are indications that the wing is leaking and may be the source of the gas in the tubing. Therefore we intend to blind off the flowline,confirm the plug is still holding,circulate in fresh fluid and monitor the well for several months to ensure the unexplained IA repressurization is not repeated. The Meltwater gas line is being converted to water later this year(currently anticipated in September). At that point,when there is water injection capability,we intend to put the well on a 30-day water monitor in anticipation for an AA submittal to make this a water only injector. Please let us know if you disagree with the path forward. Attached is the schematic and 90 day and 180 day TIO plots. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) %ANNE° :Y t • 1 K�� ZP-4.34- • ZU3/S3c Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, August 21, 2016 1:58 PMcl e'Z.4-fi(, To: Wallace, Chris D (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Subject: Recent MIT's performed at KRU Attachments: MIT KRU 2P PAD Non-witnessed 8-20-16.xls; MIT KRU 2P PAD 8-20-16.xls; MIT KRU 2N-306 8-20-16.xls Attached are copies of the test forms for the recent MIT's performed at Kuparuk. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 4PIWELLS TEAM comaPhaups SCANNED JAN 2 7 2017 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.redd(6talaska.gov AOGCC.Insoectors(d)alaska.aov phoebe.brooks(c.alaska.aov chris.wallace(rhalaska.gov 1% l (?"1 I l'(42OPERATOR: ConocoPhillips Alaska,Inc. (( FIELD/UNIT/PAD: Kuparuk/KRU/2P Pad DATE: 08/20/16 OPERATOR REP: Duffy/Miller AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2P-434 , Type In>. N ' TVD '5,129' Tubing 2,275 2,275 2,275 2,275 Interval v P.T.D.2031530 - Type test P ' Test psi "2900 Casing 920 3,300 3,175 3,150 P/F P ✓ Notes: MITIA per AIO 21B Rule 4 OA 70 70 70 70 to maximum anticipated surface pressure. (Non-witnessed) Well 2P-438 Type Inj. N TVD 5,274' Tubing 875 875 875 875 Interval v P.T.D.2010820 Type test P Test psi 2900 Casing 580 3,300 3,230 3,220 P/F P Notes: MITIA per Ala 21B Rule 4 OA 258 449 365 326 to maximum anticipated surface pressure. (Non-witnessed) Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F - Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) 2016-0820_MIT_KRU_2P-pad_2wells.xlsx 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. ~D3 - J S~ Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 RES CAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: Date d- ~ D0 D Other:: NOTES: BY: ~ l ,~~~rra ./ Isl YhP 11I111111111111111I Y11f Project Proofing BY: ~ Date :J- ~I 00 I .3 X 30 - qo Date 3-f ~ 0 (p Isl Scanning Preparation + ) = TOTAL PAGES q / (Count does not include cover sheet) vvtn Isl r I rr BY: ~ Production Scanning Stage 1 Page Count from Scanned File: q,;) (Count does include cover sheet) Page Count Matches Number in Scannirg P7paration: V YES BY: ~- Date: ;).- d--- 0 to , If NO in stage 1, page(s) discrepancies were found: 1111111111111111111 Isl NO VY1,p Stage 1 YES NO BY: Maria Date: Isl 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: Isl Comments about this file: Quality Checked 11I1111111111111111 10/6/2005 Well History File Cover Page.doc w-i)1%%yam s THE STATE Alaska Oil and s Conservation Commission 1 }®L �,,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue *h: OF Q. Anchorage, Alaska 99501-3572 ALAr�Y' Main: 907.279.1433 Fax: 907.276.7542 h T omas Nenahlo n e a SCAHHED Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ao 3- 1 5-3. Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P-434 Sundry Number: 313-568 Dear Mr. Nenahlo: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair, ommissioner DATED this Oray of November, 2013. Encl. i I STATE OF ALASKA di 4,Of 1111SKA OIL AND GAS CONSERVATION COMM ION \' 1 01:1 2 5 2013 . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 tai. / ' 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Atter casing r Other Logging 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 203-153 3.Address: 6.API Number: Stratigraphic r Service 17 P.O. Box 100360,Anchorage,Alaska 99510 50-103-20467-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2P-434 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0373112 Kuparuk River Field/Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6030 5582 Casing Length Size MD TVD Burst Collapse • CONDUCTOR 80 16 108' 108' SURFACE 2393 9 5/8 2421' 2356' PRODUCTION 5686 7 5711' 5296' LINER 500 3 1/2 6025' 5578' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5712-5772,5780-5784,5790-5794 5296-5350,5356-5361,5366-5370 3.5 L-80 5575 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL ASSY-BAKER 80-40 SEAL ASSY MD=5538 TVD=5141 12.Attachments: Description Summary of Roposal F7 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory r Stratigraphic r Development r Service P 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ W.. WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tommy Nenahlo Email: Thomas.L.Nenahlo(a cop.com Printed Name Thomas,.Nenahlo //JJ�� Title: Drillsite Petroleum Engineer Signature 7 ,raj ii( .. Phone:265-6934 Date:10/25/2013 ( _ Commission Use Only Sundry Number: o� Conditions of approval: Notify Commission so that a representative may witness ?jk3— S—Ct.% 1 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBE`3M NOV 1 5 Other: Akil /0 Opckftal In acc6 &'nce Ai , /ktb 2i Al-oo 3 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / ,r; 4 F APPROVED BY ��.. ^I Approved by: COMMISSIONER THE COMMISSION Date: 9v( /3 ( 12) App UV NIA LITTUfith-S r'rur the udle ul appluvdl.Form 10-403 Revised 10/2 12 / (�N/ 1013'J�13 Submit Form and Attachments in Duplicate • • RE4L;;t4,1 'illip OCT 17 2013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 17th, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SUBJECT: Requests for Administrative and Sundry Approvals for Meltwater Surveillance Initiatives Dear Mr. Wallace: As discussed in the meeting held on September 26th, 2013, between the Alaska Oil and Gas Conservation Commission(AOGCC) and ConocoPhillips Alaska, Inc. (CPAI),the Meltwater team is pursuing a number of surveillance initiatives to aid in the characterization and understanding of the Meltwater shallow gas issue while collecting further data for the evaluation of development options. Attached within this communication are the technical justifications for the necessary administrative and sundry approvals to achieve the objectives of these surveillance initiatives. The surveillance initiatives that are currently being pursued are as follows: • An extended outer annulus bleed at well 2P-431 o Pertaining to this initiative, please find a request for Administrative Approval via Rule 10, Area Injection Order 21A (Amended), for Meltwater production well 2P-431 (PTD 202-053) in regard to Rule 3 (annular pressure limits). Also enclosed is an Application for Sundry Approval (10-403) for authorizing annular flow from 2P-431. • Video and Spectra-Flow®logging at wells 2P-419, 2P-420, 2P-427, 2P-429, 2P- 434, 2P-447 o Pertaining to this initiative, please find a request for Administrative Approval via Rule 10, Area Injection Order 21A (Amended), for Meltwater injection wells 2P-419 (PTD#204-017), 2P-420 (PTD# 201- 182), 2P-427 (PTD# 202-018), 2P-429 (PTD#201-102), 2P-434 (PTD# 203-153), 2P-447 (PTD# 203-154) in regards to Rule 7 (authorized injection pressure) and Rule 8 (authorized fluids for injection). Please call Tommy Nenahlo at 265-6934, or me at 265-1464 if you have any questions. . • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Sincerely, Zddo Jerry Dethlefs ConocoPhillips Well Integrity Director Tommy Nenahlo ConocoPhillips Meltwater Drill Site Petroleum Engineer Enclosures: Technical Justification for Administrative Relief Requests Application for Sundry Approval Welibore Schematic • • • ConocoPhillips Alaska,Inc. Kuparuk River Unit Meltwater Pool Injection Wells Technical Justification for Administrative Relief Request,AIO 21A,from Rules 7 and 8 Purpose ConocoPhillips Alaska,Inc. (CPAI)requests that the AOGCC approve this Administrative Relief as per Area Injection Order(AIO)21A(Amended),Rule 10, for temporary relief from criteria set forth in Rules 7 and 8 that defines the authorized pressure and fluids for injection,respectively. CPAI requests temporary relief from these rules to conduct video and Spectra Flow®logging on six Meltwater injectors, 2P-419(PTD#204-017),2P-420 (PTD#201-182),2P-427(PTD#202-018),2P-429(PTD#201-102), 2P- 434(PTD#203-153), and 2P-447(PTD# 203-154). By conducting video logging on these injectors,the Meltwater team is looking to inspect possible collapsed liner,as has been indicated by recent and historic well work. By conducting Spectra Flow®logging,the Meltwater team is looking to determine if there is fluid movement around the production casing cement shoe over a range of sand face injection pressures. Video Logging Campaign Summary During recent and historic well work,indications of potentially collapsed liner in injectors 2P-419,2P- 420, 2P-429,2P-434, and 2P-447 have arisen. In a number of these injectors it is believed that these potential collapsed liner locations are limiting our injection into the Bermuda formation. To aid in characterizing and understanding these potential collapsed liner locations, as well as to formulate a plan to remediate this issue,it is necessary to run video logs to inspect the locations. To safely execute a video log on a miscible injectant(MI)injector it is necessary to adequately displace the near wellbore formation to ensure that MI returns are not taken to surface. Therefore, it is recommended that the near wellbore formation be displaced with a minimum three tubing volumes of hot diesel. Upon adequately displacing the near wellbore formation,the video log will be run while injecting filtered sea water to allow for the optimum video resolution to inspect these potential collapsed liner locations. The ability to provide a sufficient injection rate at Meltwater is critical as it is necessary to ensure that adequate lift gas temperatures are maintained at the Meltwater's Drill Site, 2P. Drill Site 2P is located approximately twelve miles from the nearest drill site,2N. This distance provides a significant amount of time for cooling of the MI that is used as injection fluid as well as a lift gas for the producers. During winter months and low injection rate periods,the temperature of the lift gas has historically become low enough to cause rapid paraffin deposition in the upper wellbore of the producers and can choke flow to a point at which the well would need to be shut in. If enough production is shut in the temperature of the Meltwater produced oil line could become low enough to require it to be shut in and de-inventoried to mitigate the potential for the line to freeze. In 2012,modeling was completed to determine the minimum MI gas delivery temperature at Meltwater to ensure that this issue can be mitigated. As anticipated,the variable with the greatest effect on the MI gas delivery temperature at Meltwater is the MI injection rate. By completing video logs on these potential collapsed liner locations to aid in developing a remediation strategy it is believed that this risk of low lift gas temperature and a produced oil line freezing scenario can be reduced. To successfully complete this video logging campaign,temporary relief from AIO 21A(Amended) Rules 7 and 8 is requested to adequately displace the formation and conduct these video logs. CPAI Well Integrity Director 10/17/2013 1 • ID Spectra Flow®Logging Campaign Summary To successfully complete this Spectra Flow®logging campaign,temporary relief from AIO 21A (Amended)Rule 8 is requested to allow for the temporary injection of sea water into the Bermuda formation. Sea water is not an authorized injection fluid in AIO 21A(Amended). The Halliburton® Spectra-Flow logging technology is capable of identifying fluid movement around the production casing shoe by identifying the presence of oxygen. Sea water will provide the oxygen in the injection fluid to ensure the logging campaign can be completed successfully. To achieve the most information from the logging campaign,temporary relief from AIO 21A(Amended) Rule 7 is requested for exceeding the established pressure limit during injection of sea water into the Bermuda formation while logging. The Meltwater team would like to vary the injection pressures of the sea water while performing Spectra Flow®logging runs to complete the following objectives: 1. To confirm there is not fluid movement around the production casing shoe when injecting within the sand face injection pressure limit established by Rule 7 in AIO 21A(Amended). 2. To determine if MI migration is a result of historic sand face injection pressures at Meltwater prior to the issuance of AIO 21A(Amended). The second objective stated above is intended to further the Meltwater team's understanding of the MI migration mechanism. As discussed in the November 2012 hearing with the AOGCC,the Meltwater team proposed two potential MI migration mechanisms. One of these migration mechanisms includes the possibility of MI migration around the production casing cement shoe. By completing the aforementioned objectives,the Meltwater team will be able to make more informed decisions to ensure the field is operated safely and effectively. Video and Spectra Flow®Logging Procedure Outline The following is an outline of the procedure for the proposed Spectra Flow°Logging campaign to be performed on each of the six injectors. 1. Displace the near wellbore formation with a minimum three tubing volumes of hot diesel to mitigate the risk of taking MI returns at surface during well work operations. o Injection pressure at surface not to exceed 2,495 psig with diesel(4475 psig at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs) 2. Rig up E-Line with Spectra-Flow®Logging tools and IPROF string to monitor bottomhole conditions. 3. Little Red Services(LRS)to pump sea water down on well using a step rate approach as defined below. During each step,the Spectra-Flow®logging tool will be passed up and down to identify the possible height of injected fluid above the perforations. a. Step 1: 500 psi WHIP (2975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) b. Step 2: 750 psi WHIP(3225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) c. Step 3: 1,000 psi WHIP(3475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs)\ d. Step 4: 1,250 psi WHIP(3725 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) e. Step 5: 1,500 psi WHIP (3975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) CPAI Well Integrity Director 10/17/2013 2 • • f. Step 6: 1,750 psi WHIP(4225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) g. Step 7: 2,000 psi WHIP(4475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) 4. Upon completion of the step rate logging runs,E-Line and LRS will rig down and move off the well. 5. Injection of seawater will cease on each individual well after the logging runs are completed. 6. The well bores will then be freeze protected with the injection of hot diesel with the injection pressure at surface not to exceed 2,495 psig(4475 psig at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs) Administrative Approval Request: CPAI requests temporary relief from(AIO)21A(Amended),Rules 7 and 8 to conduct Video and Spectra Flow logging on six Meltwater injectors: 2P-419(PTD#204-017), 2P-420(PTD#201-182), 2P-427 (PTD#202-018), 2P-429(PTD#201-102), 2P-434(PTD#203-153), 2P-447(PTD#203-154). 1. Temporary relief from AIO 21A(Amended)Rule 7 is requested for exceeding the pressure limit during injection of sea water into the Bermuda formation during the logging operations only. The approval is requested for a period of six months from the date of the AOGCC approval. 2. Temporary relief from AIO 21A(Amended)Rule 8 is requested to allow for injection of sea water into the Bermuda formation for the purposes of performing the logging operations only. The approval is requested for a period of six months from the date of the AOGCC approval. CPAI Well Integrity Director 10/17/2013 3 ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 25th 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 RE: Response to Questions Regarding Requests for Administrative and Sundry Approvals for Meltwater Surveillance Initiatives Dear Mr. Wallace: Thank you for your reply regarding our requests for Administrative and Sundry Approvals for the Meltwater surveillance initiatives. Please find below the responses to your questions in your emails that were sent October 22nd, 2013. Injected Volumes and Duration Per the plan developed by the Meltwater team, it is expected that no more than 6,000 barrels of Beaufort seawater will be required to be injected at each injector to complete the video and Spectra-Flow®logging initiatives. This estimate of 6,000 total barrels includes the procedures to complete the miscible injectant displacement, video logging, and Spectra-Flow®logging procedures. Below is a high level breakdown of this estimate for clarity: • Displacement volume estimate: 1,000 BBLs of seawater per well o This is volume that we may need during the video and/or Spectra-Flow®logging campaign to mitigate the potential for having miscible injectant present in the wellbore. • Video Logging volume estimate: 1,600 BBLs of seawater per well o To minimize the turbidity of the fluid, and thus increase our video resolution at the potential collapsed liner locations, filtered seawater will be used to displace the wellbore and ensure it remains displaced throughout the video logging procedure. • Spectra-Flow®Logging volume estimate: 3,400 BBLs of seawater per well o This estimated volume of 3,400 BBLs is planned to be split evenly amongst the seven pressure stages outlined in the Technical Justification for Administrative Relief Request, AIO 21A(Amended), from Rules 7 and 8, that was submitted to the AOGCC on October 17th, 2013. o It is preferred that seawater be used for the Spectra-Flow®logging as upright tanks will be on location at Drill Site 2P to store the seawater that will support the aforementioned video logging. Operationally, it is preferred that Kuparuk produced water be kept separated from seawater due to corrosion concerns. The above logging initiatives may require up to 168 hours(7 days)to complete, per well. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Beaufort Seawater Compatibility Study A Meltwater field fluid sensitivity and stimulation study was completed in March of 2001. This study utilized core samples from the Meltwater North #1 and Meltwater North #2 wells that included an investigation into the sensitivity of preserved reservoir samples to the proposed flood waters. These proposed flood waters included a Kuparuk produced water blend and a 75% Kuparuk produced water/25% Beaufort seawater blend. The investigation into the sensitivity of the Meltwater North#1 and Meltwater North#2 core samples to the proposed flood waters concluded that there were no adverse reactions to the75% Kuparuk produced water/25% Beaufort seawater blend identified. The Meltwater team plans to inject 100% Beaufort seawater to minimize the turbidity of the fluid while conducting video logging. Although we do not have fluid sensitivity studies completed with 100% Beaufort seawater, the salinities of the Kuparuk produced water and the Beaufort seawater are similar, and no appreciable compatibility problems for either the Meltwater formation or its confining zones are expected. If injectors do incur damage from sea water injection the damage will be contained within a small radius of the wellbore due to the small volume of fluid required to complete the logging initiatives. Any damage to the near wellbore formation that may arise can be reversed by employing remedial treatments. Sundry Requests Attached you will find six Application for Sundry Approvals, one for each of the six wells that we are requesting approval to conduct video and Spectra-Flow®logging. If you require any further information, please do not hesitate, I would be more than happy to address them for you. Thanks, .97e.fz2lLLO Tommy Nenahlo Drill Site Petroleum Engineer 2T (Kuparuk&Tabasco) &2P (Meltwater) North Slope Operations& Development ConocoPhillips Alaska Anchorage: (907)265-6934 Mobile: (720) 273-2685 Enclosures: Applications for Sundry Approval (Quantity 6) Wellbore Schematics (Quantity 6) .. . - KUP 2P-434 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Itl Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) 501032046700 MELTWATER INJ 28.19 4,183.83 6,030.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 33.79 12/5/2003 Well Conti(: •2P-434,6/10/2013 1:35:03 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod... End Date Last Tag:SLM 5,674.0 5/29/2013 Rev Reason:TAG,DRILLING DEPTHS/DATES osborl 6/10/2013 Casing Strings s g Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt...'String... String Top Thrd CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELDED HnNCER 23 Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd SURFACE 95/8 8.835 28.1 2,421.4 2256.4 40.00 L-80 BTC Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd h , , pi PRODUCTION 7 6.276 25.5 5,711.0 5,295.7 26.00 L-80 BTCMD Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd LINER 31/2 2.992 5,524.8 6,025.0 5,577.7 9.30 L-80 SLHT Liner Details 1 Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) III 5,524.8 5,129.0 26.20 PACKER BAKER ZXP LINER PACKER 4.370 5,543.7 5,145.9 26.25 NIPPLE RS PACKOFF SEAL NIPPLE 4.250 5,546.4 5,148.4 26.26 HANGER BAKER FLEXLOCK LINER HANGER 4.410 5,556.0 5,157.0 26.28 SBE BAKER 80-40 SEAL BORE EXT 4.000 5,574.9 5,174.0 26.67 XO BUSHING XO TKC BUSHING 3.000 CONDUCTOR, Tubing Strings Tubing 28-108 g Des cription String 0... String ID... Top(ftKB) iSet Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd TUBING 31/2 2.992 i 23.3 5,575.1 5,174.2 9.30 L-80 EUE-8rd NIPPLE,500 lak Completion Details - IMF Top Depth' (TVD) Top Inc! Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 232 233 -0.51 HANGER FMC GEN V TUBING HANGER 3500 499.8 4992 055 NIPPLE CAMCO DS LANDING NIPPLE 2275 5508.1 5,114.0 26.16 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 4. 5524.1 5,128.3 26.20 NIPPLE CAMCO D NIPPLE 2.750 SURFACE, 4 ■ 5,5372 5,140.1 26.23 LOCATOR BAKER G-22 LOCATOR 3.000 28-2,421 - 5,538.4 5,141.2 26.24 SEAL ASSY BAKER 80-40 SEAL ASSY 3.000 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) r-----4 Top Depth (TVD) Top Inc! GAS LIFT, (ftKB) (ftKB) r) Description Comment Run Date ID(In) 5,459 5,882.0 5,449.0 26.00 FISH FISH TOOL SAVER BROKE AFTER FIRING 3RD GUN 1/1/2004 LEAVING THE 20'GUN AND SAFE ADAPTER IN THE HOLE(24.5' Perforations&Slots . . -.. °-,° snot Ilr Top(TVD) Btm(TVD) Dens SLEEVE,5,508 - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (el- Type Comment 5,712.0 5,772.0 5,296.6 5,350.3 T-3,2P-434 1/1/2004 6.0 IPERF 2.5"HSD PJ,DP;60 deg phase, random orientation lir NIPPLE,5,524 5,780.0 5,784.0 5,357.5 5,361.1 T-3,2P-434 1/1/2004 6.0 IPERF 2.5"HSD PJ,DP;60 deg phase, 0 random orientation 5,790.0 5,794.0 5,366.4 5,370.0 T-3,2P-434 1/1/2004 6.0 IPERF 2.5"HSD PJ,DP;60 deg phase, LOCATOR, random orientation 5,537 . I / Notes: General&Safety End Date Annotation 7/27/2009 NOTE:ZONES NOT LOADED INTO WELLVIEW YET 7/28/2009 NOTE:WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR 11/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY, _u 5,538 PRODUCTION, • ' 26-5,711 IPERF, 5,712-5,772 IPERF, 5,780-5,784 Mandrel Details IPERF, Top Depth Top Port 5,790-5,794 S... (TVD) Inc! OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) (% Make Model (in) Sery Type Type (In) (psi) Run Date Corn... 1 5,459.1 5,070.0 26.04 CAMCO KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/7/2005 FISH,5,882 LINER, 5,525-6,025" ' TD,6,030 Hunt, Jennifer L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 26, 2013 12:39 PM To: NSK Fieldwide Operations Supt Cc: Hunt, Jennifer L (DOA) Subject: RE: Meltwater SSSV Testing I missed that one... thanks.Transposed with 2P-419 PTD too. Here is updated corrected wells and PTD's. So a total of six wells. Well PTD 2P-447 203-154 2P-419 204-017 2P-434 203-153 2P-427 202-018 2P-420 201-182 2P-429 201-102 Guy Schwartz SCANNED FEB 2 $0 Z014 Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSupt@ conocophillips.com] Sent: Wednesday, June 26, 2013 12:30 PM To: Schwartz, Guy L (DOA) Subject: RE: Meltwater SSSV Testing Guy, We also have well 2P-447 as a WAG injector. I don't have the PTD number handy, but I do have the API number— 501032046800. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent N2072(a�ConocoPhillips.com 907-659-7042 Pager 659-7000 x604 From: Schwartz, Guy L(DOA) [mailto:guy.schwartzPalaska.gov] Sent: Wednesday, June 26, 2013 10:59 AM To: NSK Fieldwide Operations Supt Cc: Regg, James B (DOA); Ferguson, Victoria L (DOA); Hunt, Jennifer L (DOA) Subject: [EXTERNAL]RE: Meltwater SSSV Testing Larry, 1 After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ (gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if water is again available for injection on Meltwater the status can be reverted back to WAGIN. The wells in our database that need to have status changed from WAGIN to GINJ are: Well PTD 2P-419 203-154 2P-434 203-153 2P-427 202-018 2P-420 201-182 2P-429 201-102 We will change status in our database today... Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSupt(aconocophillips.com] Sent: Tuesday, June 25, 2013 4:35 PM To: Schwartz, Guy L(DOA) Subject: Meltwater SSSV Testing Guy, We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period. We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or report SSSV testing for DS-2P during the July pad SVS testing. I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent N2072ConocoPhillips.com 907-659-7042 Pager 659-7000 x604 2 . . Hunt, Jennifer L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 26, 2013 11:26 AM To: Hunt, Jennifer L (DOA) Subject: meltwater wells status change WAGIN to GINJ Put this in comments for 5 Meltwater wells: Well status change to GINJ: No injection water available on Meltwater pad for foreseeable future. Well needs to have SSSV tested every 6 months. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, August 10, 2010 Jim Regg ; ~ P.I. Supervisor I ~2~Cp ~'1'~~C? SUBJECT: Mechanical Integrity Tests 7 l CONOCOPHILLIPS ALASKA INC 2P-434 FROM: BOb Noble KUPARUK RIV U MELT 2P-434 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~rS~ Comm Well Name: KUPARUK RIV U MELT 2P-434 API Well Number: 50-103-20467-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100809172500 Permit Number: 203-153-0 Inspection Date: 8/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 2P-434 ~ Type Irij. N' TVD 5129 ~ IA 5 ~ 2390 2290 2280 ' P.T.D zo31s3o~'TypeTest ~ SPT i Test psi 'i -~---~-_L 2390 OA 100 ~ 101 - 101 101 -- Interval aYRTST p~ P Tubing 1625 1625 1625 1625 Notes: ti~iu1, ~~q1U~ -(~~~ /SG+~~s~ ~. ~ ~ -Y' .'~ Tuesday, August ] 0, 2010 Page 1 of 1 • 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.brooks~a~ska.gov; tan.maunder~alaska.genr; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2P 08/08/10 Colee /Coleman - AES Robert Noble Packer Pretest Initial 15 Min. 30 Min. Well 2P-419 T In'. G TVD 5,202' Tu ' 3,700 3,700 3,700 3,700 Interval 4 P.T.D. 2040170 T test P Test 1500 2,716 3,300 3,260 3,260 P/F P Notes: OA 291 335 338 336 Well 2P-420 T fn . G TVD 5,428' Tuts 3,050 3,050 Interval 4 P.T.D. 2011820 T test P Test 1500 1,850 1,769 P/F F Notes: Pumped 13bbls. With no pressure increase. OA 291 275 We11 2P-427 T In'. G TVD 5,455 T 3,100 3,100 3,100 3,100 Interval 4 P.T.D. 2020180 T test P Test 1500 - 1,925 2,600 2,520 2,520 P/F P Notes: OA 675 676 676 676 We11 2P-429 T In'. N TVD 5,218' T 910 910 910 910 Interval 4 P.T.D. 2011020 T test P Test 1500 435 1,820 1,770 1,760 P/F P Notes: OA 310 442 349 339 We11 2P-434 T In'. N TVD 5,129' T 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2031530 T test P Test 1500 5 2,390 2,290 2,280 P/F P Notes: OA 100 t Oi 101 101 We11 2P-447 T In'. G TVD 5,226' T 3,500 3,500 3,500 3,500 Interval 4 P.T.D. 2031540 T test P Test 1500 240 1,840 1,810 1,810 PiF P Notes: OA 1175 1176 1195 1201 Well T In". TVD Tubi Interval P.T.D. T test Test C P/F Notes: OA Well T In". TVD Tu ' Interval P.T.D. T test Test P/F Notes: OA ~ ~, TYPE INJ Codes TYPE TEST Codes ` }<ta'4.,~ ~ ?~ `-? i..~ 14 / ~ [ ~9 D =Drilling Waste M =Annulus Monitorir-g G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test ~~i to INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2P Pad 08-08-10.x1s • • 5rs~~n~~ ~~ n~ ~~~>~~w~ ~ ,.w..M...~o~,~ ALASFiA OII. Ai`D GA5 333 W. 7th AVENUE, SUITE 100 CO1~T5IiRQA'1`IO1~T COMl-IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Specialist ConocoPhillips Alaska Inc. PO Box 100360 ; f, } ~,; ~~4 r ,. Anchorage AK 99510 - ~ ~~u~ ~~ ~ I.~ ~~ Re: Kuparuk River Field, Meltwater Oil Pool, 2P-434 Sundry Number: 309-027 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Comrriission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair ~- DATED this day of February, 2009 Encl. • Cor~oco~Phillips January 26, 2009 Robert Christensen / Darrell Humphrey Production Engineering Specialist Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 .lAN .~ 7 20(~ Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Alaska Oii & Gas Cons. Ga~~nd~~';.~;~ Anchorage Dear Mr. Maunder, ConocoPhillips Alaska, Inc requests approval to convert Meltwater We112P-434 (PTD 203-1530) from WAG Injection Service to Oil Production Service. ~ Enclosed you will find 10-403 Application for Sundry Approval. If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, Robert D. Christensen • Attachments ~/~ .~~ • STATE OF ALASKA ~ ~~~~ ~ 0 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION `~" ~A~ ~ ~ ~~Q~ ,~,`~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2so Al~k~ Oii & Gas ~f~r3~.~f}~r~if~t~~.Sir~~~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Wai~1i CI10~~ .Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time F~ctension ^ WAG to Oil Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 203-153 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20467-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ~ 2P-434 9. Property Designation: 10. KB Elevation (tt): 11. Field/Pool(s): ADL 373112 - RKB 252' Kuparuk River Field / Meltwater Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (tt): Total Depth TVD (tt): Effective Depth MD (ft): Effective Depth TVD (tt): Plugs (measured): Junk (measured): 6030' - 5582' 5926' 5489' Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 16" 108' 108' SURFACE 2169' 9-5/8" 2421' 2356' PRODUCTION 5459' 7" 5711' 5296' LINER 501' 3-1 /2" 6030' 5582' Perforation Depth MD (tt): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: Tubing MD (tt): 5712-5772; 5780-5784; 5790-5794 5297-5350; 5358-5361; 5366-5370 3-1 /2" L-80 5575' Packers and SSSV Type: Packers and SSSV MD (tt) Packer =BAKER ZXP LINER TOP ISOLATION PACKER Packer = 5525' SSSV =Nipple SSSV = 500 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 8, 2009 Oil '^ • Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Name; R bent D. Christensen Title: Production Engineering Specialist Signature m~ -- ---_ Phone: 659-7535 Date Dj -~ (o --Q Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness _ a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~^ \ ^ ~~ `~~ ~ ~'^' ~ ~`~'d Other: t ~ •~ rl~~t . Subsequent Form Required: ~r~ t ~, ~ ~~` ~~~~~~~~ APPROVED BY ~ ~ 3 Approved by: COMMISSIONER ; THE COMMISSION . Date: 1 Form 10-403 Revised 06/2008' ~~; ~ `~ ~ ~ ~ ~ '~ ("'~ L /S9 ~' ~~'~/1. /J~~rr~,iryDuplicate 2P-434 DESCRIPTION SUMMARY U OF PROPOSAL ConocoPhillips Alaska, Inc. Meltwater Well 2P-434 (PTD 2031530) Sundry Notice 10-403 Request January 26, 2009 ConocoPhillips Alaska Inc. requests approval to convert Meltwater Well 2P-434 from WAG Injection Service ~ to Oil Production Service. The purpose of this conversion is to reduce the Meltwater Oil Pool Bermuda reservoir pressure in support of a Coil Tubing Drilling development program planned for Q4 2009. 2P-434 is currently operating with an Outer Annulus pressure waiver due to OA charging from formation. Last MITIA was performed on 08/18/06 (passed). Annulus trends and recorded bleeds do not indicate charging is from an internal source. IA x OA communication does not appear to exist at this time. TheTubing/Casing annulus is isolated via ZXP Liner Packer with HR profile (5450' and / 5129' tvd). The top of Bermuda T3 sand was found at 5708' and / 5293' tvd. ~-~ KUP ~ 2P-434 ~01'I000PI'11~~IP 5 ~ well Attributes AI,1~~, 7. 1~ 1 Wellbore API/UWI Held Name Well Sblus Inclination (°) MD (RKB) Total Depth IRKS) 501032046700 MELTWATER INJ 28.19 4,183.83 6,030.0 ... - Comment SSSV: NIPPLE H23 Ippm) 0 Dab 7/1/2008 Annobtbn Last WO: End Data KB13rd IRI Rig Release Data 79 12/5/2003 33 w•n coon -zP- en srzooe n w v AM . m•tlc- tual Annotation Depth IRNBI End Data A nnotation End Date Last Tag: 5,813.0 6/5/2008 R ev Reason: TAG SLM 6/13/2008 Casio Strin s Casing Description OD Ilnl ID Iln) Top IftKB) Set Oaplh (RKB) Set Depth (TVD) (RKB) Wt Ilbsml Drade Top Threatl CONDUCTOR 16 15.062 0.0 108.0 108.0 62.50 H-00 WELDED HANGER, z3 SURFACE 9518 8.697 0.0 2,421.0 2,356.1 40.00 L-80 BTC PRODUCTION 7 6.151 0.0 5,711.0 5,295.7 26.00 L-80 BTCMD corvoucroR LINER 31/2 2.992 5,529.0 6,030.0 9.30 L-80 SLHT . 708 Tubin Strln s TuOing Descrl ption OD Iln) ID Iln) Top (RKB) Sat Depth (RKB) Set DepM (TVD) (RKB) Wt (lb•Rt) Orotle Top Threatl NIPPLE. soo TUBING 3 1/2 2.992 0.0 5,575.0 5,174.1 9.30 L-80 EUE8rdMOD Other In Hole All Jewel : Tubin Run 8 Retrlelrable, Fish etc. Top (RNeI Dascrlptlon Com ent m Run Dab ID (in) suRfncE. z azl 23.0 HANGER 3.5" FMC GEN V TUBING HANGER 12/5/2003 3.500 , 500.0 NIPPLE CAMCO'DS' LANDING NO GO NIPPLE 12/5/2003 2.875 5,459.0 GAS LIFT CAMCOIKBG2-9/1/DMYIBTAN// Comment: STA 1 11/1/2005 2.900 5,508.0 SLEEVES BAKER CMU SLIDING SLEEVE- CLOSED 1182005 1215/2003 2.810 5,524.0 NIPPLE CAMCO'D' NIPPLE NOGO 12/52003 2.750 GAS uFr S.d59 5,525.0 PACKER BAKER ZXP LINER TOP ISOLATION PACKER 12/5/2003 5.000 5,537.0 LOCATOR BAKER G22 LOCATOR SEAL ASSEMBLY 12/5/2003 3.000 5,538.0 SEAL BAKER80-40 SEAL ASSEMBLY 12/5/2003 3.000 SLEEVE C 5,544.0 NIPPLE RS PACKOFF SEAL NIPPLE 12IS2003 4.250 . sloe - + ~ ~ 5,546.0 HANGER BAKER SxT' FLEXLOCK LINER HANGER 12/52003 5.000 5,556.0 SBE BAKER 80-00 SEAL BORE EXTENSION 12/52003 4.000 5,574.0 BUSHING XO BUSHING 12/52003 3.500 NIPPLE, 5,524 5'575'0 TTL 12/42003 2'992 I- PACKER, 5,525 -7 5,882.0 FISH FISH TOOL SAVER BROKE AFTER FIRING 3RD GUN LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5' 1/1/2004 I I 6,023.0 SHOE 12/5/2003 3.500 Perforations Top (RKB) Btm (RKB) rap IrvDI IRKB) Btm IrvD1 (RKB) Type Zone sn°e oen. (°hOt~~~ Dab Comment LOCATOR, s.sT7 5,712.0 5,772.0 5,296.6 5,350.3 IPERF 6.0 1/12004 2.5" HSD PJ, DP; 60 deg phase, rdrldom orientation SEAL. 5,538 5,780.0 5,784.0 5,357.5 5,361.1 IPERF 6.0 1/12004 2.5" HSD PJ, DP; 60 deg phase, random odentation 5,790.0 5,794.0 5,366.4 5,370.0 IPERF 6.0 1/12004 2.5" HSD PJ, DP; 60 deg phase, random orientaton Notes: General 8 Safe NIPPLE, 5,500 End Data Annotation 6/142004 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR HANGER, 5,506 COUPLING. 5,555 SBE. 5,558 BUSHING, 5.571 TTL, 5,575 PRODUCTION, 5 711 IPERF. 5,712-5.772 IPERF. 5,780-5.761 IPERF, 5,790-5,790 FISH, 5,862 SHOE. 6.023 LINER, 6,1730 TD, 6030 ~ ~ - ~, MICROFILMED 03/01 /2008 DO NOT PLACE ..,`._., {. "'' 4 - ~;.. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc '-"",-=", ~ Conoc~hillips Alaska RE'CEf\JED J\JL {} 5 2006 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 & ~ci 33 Ccmm1s$ion .~nch~rage June 06, 2006 ------.,~.- *"-....,... Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 n '1 ZGOR ~ANNED JUL 'i ' . - ... \5 3 ~07J 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 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, Royfi1l404B, 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 fonn 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 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. ~ :;¿¡o Perry Klein ConocoPhillips Problem Well Supervisor (" (.. .s ~",,-d. d ~ o6/~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 Royfill404B inhibitor/ Name PTD# of cement pu mped cement off date RG2041 vol vol. sealant date ft bbls ft gal qal 5/19/2006 2P-406 ~22 4 0.0 -4_ na 5] 17.1 5/19/2006 2P-415a 201-226 5.5 0.0 5.5 na 7.1 30.9 5/19/2006 2P41't-· 201-069 7.5 0.7 2.5 51-112006 S-~7 -9' 5/1812006 2P-419 204-017 1 0.0 1 na 6.7 0 5/18/2006 c2P;420 -201-182 3.5 ŒO 3~5 na 7.1 17.3 - 5/1812006 2P-422a 202-067 13.5 2.3 2.5 5/1/2006 7.1 10.7 5/18/2006 2P.:424a· _ 204-009 4;5 0.0 4.5 na 5~7 17.6 511812006 2P-427 202-018 10 1.6 2.5 5/1/2006 7.1 13.7 5/18/2006 2P-429 'c 201-102- - 2 0.0 2 na 3.8 5.7 5/1812006 2P-431 202-053 13 1.9 2.5 5/1/2006 7.1 10.1 5/18/2006 2P..432 202-091 8.5 0.9 2.5 S/1/2006 5~7 13.8 5/1812006 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 " -204-032 . 3.5 0.0 3.5 na 8.7 11.4 5/18/2006 " 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 5118/2006 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 5/112006 "7.1 6.5 . 5/18/2006 ) Conoc~illips Alaska r'" ..1:: UN .2 ,¡: \ \,.' i !]ij~ ·~~G·)~) C:jJ¡IfiJ'$. AJ1Jth¡Dn¡!~[~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 aos - /53 June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUN 2 7 200B 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, Royfi1l404B, 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 315\ 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 ) :J 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 t~5' , 1 : . :~'5.:\.'~!' 13.5 .:'4~5: ""; 10 'I .....2'..... .... 13 ",8~5>' ...... 14 :.5>" , 15 ""'~'3-Jf:" .. 2.5 . .:tS· 3 '. :.1:0'. :. .:::;·'¡::2PL4œ·. 2P-415 f:/i2P.~'7 ':';.:': 2P-419 ~.'~' !~:2'P*DÐ~ " ':'.~' 2P-422 :':·::~P.~4;<·;: : 2P-427 .···:.iYl1::::': 2P-431 '. >2t-«t2~:, '~> 2P-434 ,"·:':2~æ:''''·:·:"" 2P-441 . ,··2PfQß~.'· 2P-447 .,:2R~:: 2P-449 ... . . "2P~'i:. pumped bbls .0;0··..· 0.0 Ó~7. . 0.0 ", . :~·.o:ô': 2.3 ·."~O..': · 1.6 '..Œ~l·· 1.9 :O~9.· . 2.0 .' ·'O~.O· 2.0 ':. . oj) :.. . · 0.0 '··0.0 . 0.0 ~1 cement ft ;" ..4." 5.5 '.,' ',,2~5 1 .... . ::''.":3.5,':'.-: 2.5 .' "." ,".,4L:5':. 2.5 . .":. .::t:: ':: 2.5 . . ,. : '..' ". '::~.2'£5:.:... . . ',; 2.5 ·:~;;5:·. . '... 2.5 . . ·)3~5 2.5 .. ::.1';5' "., 3 ',2.5'·:· . Kuparuk Field June 6,2006 off date . å,a na ". ::',·',::5/112006. na '. ':riå¡::: 5/1/2006 . ." 'na: 5/1/2006 '.':.' ,;:Iia;:\,' 5/1/2006 :'.' 511'12006.: :'. ~:;~'. 5/1/2006 .. . . :.>nâ:·..::···· 5/1/2006 ..... '.: hâ; na : tlà . na . . 51.1/2006·' . RG2041 vol J qal ·5.:7. 7.1 .> ..'i5'~.7··· 6.7 ··'c:,·'7A·.' 7.1 . . 5::'",: 7.1 ".' 3~8~·· . . , 7.1 ,·5.;7,.: 5.7 " :":5'::.1'-:'. . .: 7.1 ,·8~7 '.. 9.5 ·,9.5. . 5.7 ··.7.t· Royfill404B vol. Qal I '" 1"7'.t 30.9 , .' ·>'9'. :. o . ' '1::7.3,,' 10.7 ." '1'7~6;" 13.7 ..5~:7 . 10.1 "'. '13~'8:' 6.2 '··:2fé.· . ' 13.1 . . '·11:.4 o o 11.5 . '6~5 . Corrosion inhibitor/ sealant date 5/19/2006 , :". '5/10912096 ': 5/19/2006 . ,.., . ':'=l\f;ð~~tu\~:.;: ,- " '"Yr~.~~Q; ".~ 5/18/2006 . ·····:.511~·::..~ 5/18/2006 " ,~.: ::51:t8l2ØO$;:·,:. 5/18/2006 . , .,.. .:~tt8120f¡.r:.'!-: 5/18/2006 ...t::ì-ia'Ìd~" :::. : ¡. .'i:If:.;~~~,.. /';.',' 5/18/2006 .::5l:~;1.:~:.:, 5/18/2006 ," '.:51:1812006·:::",' 5/18/2006 ····,511~2QØ&:,·:· , 5/31/2006 . . .511:8/2006 .'. '. llib DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031530 Well Name/No. KUPARUK RIV U MELT 2P-434 Operator CONOCOPHILLlPS ALASKA INC Sf2~ API No. 50-103-20467-00-00 MD 6030 ,..,..- TVD 5582 ,- Completion Date 1/1/2004 ,- Completion Status WAGIN Current Status WAGIN (UIC Y )~ REQUIRED INFORMATION ~--- Mud Log No Samples No Directiona~y Yes -~-,_. DATA INFORMATION Types Electric or Other Logs Run: GR/ReslDen/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ !J%' Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ---- Injection Profile 5 Blu 1 5595 5755 Case 9/28/2005 Injection Profile SPINITEMP/PRESS/GRAD 10 16 Sep 2005 ~ Directional Survey 0 6030 1/23/2004 b' Cement Evaluation 5 Col 4842 5510 Case 1/30/2004 Ultrasonic Imaging Tool w/Cement Bond Log ~C ZFfo L. ,~ 12452 I nd uction/Resistivity 108 6030 Open 3/16/2004 Multiple Propagation Resistivity - Gamma Ray - RWD Ji:Ó C Pds 12452 I nd uction/Resistivity 108 6030 Open 3/16/2004 Multiple Propagation Resistivity - Gamma Ray - RWD ~ I nd uction/Resistivity TV/~ 25 Blu 108 6030 Open 3/16/2004 Multiple Propagation Resistivity - Gamma Ray - RWD . ~ C ;¡:f'" t.., ') 12452 Neutron 2 108 6030 Open 3/16/2004 Caliper Corrected Neutron, Optimezed Rotational Density - RWD ,.€D C Pds 12452 Neutron 2 108 6030 Open 3/16/2004 Caliper Corrected Neutron, Optimezed Rotational ~ Density - RWD Neutron f\Þ 25 Blu 2 108 6030 Open 3/16/2004 Caliper Corrected Neutron, Optimezed Rotational Density - RWD ~ C ;U "-, ~ 12452 Density 2 108 6030 Open 3/16/2004 Caliper Corrected Neutron, Optimezed Rotational Density - RWD ~ C Pds 12452 Density 25 2 108 6030 Open 3/16/2004 Caliper Corrected Neutron, Optimezed Rotational Density - RWD DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permitto Drill 2031530 Well Name/No. KUPARUK RIV U MELT 2P-434 Operator CONOCOPHILLlPS ALASKA INC ~ 6030 TVD 5582 Completion Date 1/1/2004 Completion Status WAGIN Current Status WAGIN Density 'JVc>---- 25 Blu 2 108 6030 Open 3/16/2004 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMA1l0N Well Cored? Y I(t) Daily History Received? <§}/ N (ÐN Chips Received? ~ Formation Tops Analysis Y II" Received? Comments: Compliance Reviewed By: ~. Date: API No. 50-103-20467-00-00 UIC Y (!) 30.,..- .~ ~ . . . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test r7 ¿:¡ II{ 14'(Db -Email to:Tom_Maunder@admin:state.ak.u-s;Scl)~¡:¡ecken-stei~@;d~in.-stat;~k:~s; J~-=-R-;99@;¡~~:~tcrt;.;~lk(-+------ -- ------ OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRU 12P 11/08/05 Bakke - HES ~D3-15~ Packer Depth Pretest Initial 15 Min. 30 Min. Well2P-434 I Type Inj. I W TVD I 5,141' Tubing 1800 1800 1800 1800 Interval 0 P.TD. 2031530 Type test P Test psi 1500 Casing 2200 3000 2875 2800 P/F P Notes: MITIA after dual check OV replaced with DV OA 1300 1350 1350 1325 weill I Type Inj. I I TVD I Tubing Interval P.TD. Type test Test psi Casing P/F Notes: OA weill I Type ,nj·1 I TVD I Tubing Interval I P.TD. Type test T est psi Casing P/F Notes: OA weill I Type Inj·1 I TVD I Tubing Interval PTD. Type test Test psi Casing P/F Notes: OA weill I Type Inj. I TVD I Tubing Interval 1 P.TD. Type test Test psi Casing P/F Notes: OA well I Type Inj. I TVD I Tubing Interval PTD. Type test Test psi Casing P/F Notes: OA well I Type Inj. I TVD I Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: OA Test Details: TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form Revised: 06/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 2P-43411-08-05.xls \, . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2P-434 Contains the following: ±r I~L\5a 1 LDWG Compact Disc a (Includes Graphic Image files) I LDWG lister summary 1 blue line - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log 1 blueline - CCN-ORD TVD Log LAC Job#: 582953 Sent By: Glen Borel Received By~)~ ~ ~.-~~jV' . 803 -/53 "ill BAKER HUGHES Anchorage GEOScience Center Date: Mar 15, 2004 Date: 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 RECEIVED . , .1 # tV'" J ,'. '''I: .j. :'" . I () ~~Uv¿ f'~13~kH Œ! ¡~; Gas Cons, Commi~lon i "'!"'~ ""'-196 d",:~~L,~~,gIJH,;I~ ~ .--.-----------,--.--..---------_.._---.--. I: 1:Ø'I:./.!'.I5Ii·joo-,,)¡Ð!l.TlTJiOOI; I , ' ~.. , .-. ¡ -"-"""--"---'0 -'" -'" .... .... _.' -'':! ---- , ..~"." v·,c-,',.,'-""-, i ...... .... .... -',' "^'" ",."... ,-. ".. ,,,;,<~,,,,.,,, , .-; :' '" -~.:.i .. MEMORANDUM . TO: TURU: Jim Regg 'K0ð1 z,1 )'OID4- P.I. Supervisor l FROM: Chuck Scheve Petroleum Inspector API Well Numbe 50-103-20467-00-00 NON-CONFIDENTIAL Insp N mitCS040217184223 Packer Depth Pretest Initial Well: 2P-434 Type Inj. G TVD 5129 IA 1160 2540 ~Jl530 TypeTest SPT Test psi 1282.25 OA 565 705 Interval Initial Test PIF Tubing 2370 2370 Notes: Pretest pressures were observed and found stable. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SAL T WATER INJ. N=NOT INJECTING Wednesday, February 18,2004 Type Test M=Annulus Monitoring P=Standard Pressure Test R=lnternal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 18,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-434 KUPARUK RIV U JlÆELT 2P-434 Src: Inspector Inspection Date: 2/17/2004 15 Min. 30 Min. 45 Min. 60 Min. 2470 2455 670 660 2370 2370 Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Workover O~Other (describe in notes) Page I of! TUBING (()'5575, 00:3.500, 102.992) SURFACE -- (()'2421, 00:9.625. Wt40.o0) OOUCTION (()'5711, 007.000, Wt26.00) SLEEVE-C (5508-5509, 004.500) NIP (5524-5525, 004.500) LOCATOR (5537-5538, 005.000) NIP (5544-5546, 005.500) COUPLING (5555-5555, 005570) BUSH ING (5574-5575, 005.000) 2P-434 API: 501032046700 SSSV Type: NIPPLE Annular Fluid: Reference Log: 28' RKB Last Tarr 5904 Last Tag Date: 12/25/2003 Casing String. ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION LINER Tubing . TUBING . Size 3.500 Perforations Summary Interval TVD 5712 - 5772 5712 - 5772 KRU Well Type: Oriç¡ Completion: Last W/O: Ref Log Date: TO: Max Hole An¡¡le: SVC 6025 ftKB o deq @ Angle @ TS: deg @ Anqle @ TO: deg @ Rev Reason: PERFS Last Update: 1/3/2004 Wt 62.50 40.00 26.00 9.30 Grade H-40 L-80 L-80 L-80 Size Top 16.000 0 9.625 0 7.000 0 3.500 5524 Bottom 108 2421 5711 6025 TVD 108 2421 5711 6025 5780 - 5784 5780 - 5784 5790 - 5794 5790 - 5794 Zone Status Ft SPF Date Type 60 6 111/2004 IPERF 4 6 1/1/2004 IPERF 4 6 1/1/2004 IPERF Gas Uft Mandrels/Valves 81 I MD I TVD I Man I Man Type I V Mfr 1 5459 5459 C:~~O KBG-2-9 Other (plugs, equip., etc.) . JEWELRY Depth TVD Type 23 23 HANGER 500 500 NIP 5508 5508 SLEEVE-C 5524 5524 NIP 5537 5537 LOCATOR 5538 5538 SEAL 5575 5575 TTL Other (plu;ls, equip., etc.) - LINER JEWELRY Depth TVD Type 5525 5525 PACKER 5544 5544 NIP 5546 5546 HANGER 5555 5555 COUPLING 5556 5556 SBE 5574 5574 BUSHING 6023 6023 SHOE Thread EUE8rdMOD 2P-434 Thread WELDED BTC BTCMD SLHT Comment 2.5" HSD pj, DP; 60 deg phase, random orientation 2.5" HSD pj, DP; 60 deg phase, random orlenlation 2.5" HSD pj, DP; 60 deg phase, random orientation I V Type I V OD I Latch I Port I TRO I ~:t~ I C~~t OMY 1.0 BTM 0.000 I 0 12/25/2003 Description 3.5" FMC GEN V TUBING HANGER CAMCO 'OS' LANDING NIPPLE NO GO BAKER CMU SLIDING SLEEVE CAMCO '0' NIPPLE NOGO BAKER G-22 LOCATOR SEAL ASSEMBLY BAKER 80-40 SEAL ASSEMBLY Description BAKER ZXP LINER TOP ISOLATION PACKER RS PACKOFF SEAL NIPPLE BAKER 5x7" FLEXLOCK LINER HANGER 5" TKC COUPLING BAKER 80-40 SEAL BORE EXTENSION XO BUSHING ID 3.500 2.875 2.810 2.750 3.000 3.000 2.992 ID 5.000 4.250 5.000 4.380 4.000 3.500 3.500 Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING String Type: Surface Casing Hole TVD: 2,356.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 3.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Manufacturer: FMC Hanger Model: Actual TMD Set: 2,421.28 (ft) Page 1 of 1 ConocoPhillips Alaska Casing Report Report #: Start: Spud Date: 11/24/2003 Report Date: 11/25/2003 End: 12/5/2003 1 11/23/2003 -- General Information 1 56 1 2 1 1.52 2,303.79 1.50 84.77 1.70 Kelly Bushing 224.00 (ft) (ft) (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: . 12.250 (in) (ft) (ft) 28.00 (ft) 2,421.0 (ft) 83,000 (Ibs) 26.10 (0) 2.00 (days) .'.,,_.,,-"..,... Casing Flange I Wellhead Model: Gen V Packoff Model: .-..--- . ..---........... Top Hub/Flange: 11.000 (in) I 5,000 (psi) BTM Hub/Flange:11.000 (in) I 5,000 (psi) ----- Drift (in) Integral Casing Detail, Threads JTS Length Top MU Torq. THD Manufacturer (ft) (ft) (ft-Ibf) Model Condo Max OD Min ID Compo Name (in) (in) Item ,,' Size Weight Grade (in.) (Ib/ft) Casing Hanger 9.625 40.00 L-80 Casing 9.625 40.00 L-80 Float Collar 9.625 Casing 9.625 40.00 L-80 Float Shoe 9.625 8.679 BTC 8.679 BTC 8.679 BTC --' Accessory Manufacturer Bowspring Centralizer _-----,_,.._JWEAT~ERF?RD.. 28.00 29.52 2,333.31 2,334.81 2,419.58 2,421.28 Casing Hanger 8.835 9 5/8" 40# L-80 Float Collar 8.835 ~:~:~~~: L-8. Non-Integral Casing Accessories . ,. .....,... Number Spacing (ft) Top (ft) ... 1 ,6~~.0 I Bottom (ft) .2,411:0 I OverColI~.~_ . Interval How Fixed ..---'. 191 Remarks .-.. ---- .....____0..__.- Rig & ran 9-5/8" Float shoe, 2 jts 9-5/8", 40#, L-80, BTC csg, Float collar, 56 jts 9-5/8", 40#, L-80, BTC csg., Placed centralizers 1-5' above shoe on stop collar and 1-5' above float collar on stop collar, and 1 on evert joint from shoe to joint # 18 for a total of 19 centralizers. Casing ran in hole fine with very little trouble, Landed casing with shoe at 2421.39' and float collar at 2333.42' Printed: 2/3/2004 10:31 :39 AM Printed: 2/312004 0:32:19 AM Fluid Loss Pressure: Test Data Thickening Time: Free Water: Fluid Loss: %) (cc) OF) Temperature: Temperature: Temperature: OF) ("F) 'F) Compressive Strength 1: Compressive Strength 2: Temp CF) "F) Pressure (psi) (psi) Slurry Data Fluid Type: Slurry Interval: Water Source: FLUSH (ft) To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Time Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: Wsk) Other Vol:40 () Purpose: SPACER Mix Water: (gal) Foam Job: N Type: Spud Mud Density: 9.3 (ppg) Visc: 47 (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Fluid Type:Mud Stage No: Density: 1 (cp)/14 (lb/100ft2) Gels 10 see: 4 (lb/100fP) Gels 10 min: 5 Bottom Hole Static Temperature: ("~) 9.3 (ppg) Volume: 1~:OO (bbl) - .. n. .. _.. ...__uo_.. Slurry No: 1 of4 To Cementing: 3.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 300 (psi) Top Plug: Bottom Plug: Y Y PV/YP: 25 Mud Data Float Held: Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: 400 (psi) 1 ,100 (psi) 5 (min) Y Ib/100ft2) Ann Flow Alter: N Mixing Method: Tub Density Meas By: Densometer Type: Cement Casing Volume Excess %: Meas. From: 249 Time Circ Prior End Pumping: End Pump Date: Start Mix Cmt: Start Slurry Displ: Start Displ 21:53 23:14 23:14 23:45 11/25/2003 7.00 (bbl/min) 7.00 (bbl/min) Y Returns: Full Total Mud Lost: Cmt Vol to Surf: (bbl) 249.00 (bbl) Rot Time Start: : Rec Time Start:17:30 Time End: : Time End: 23:00 RPM: SPM: Stage No: 1 of 1 Init Torque: Stroke Length: t-Ibf) 15.0 (It) Avg Torque: Drag Up: t-Ibf) 125,000 Clbs) Max Torque: Ibf) Drag Down: 115,000 (lbs) Pipe Movement Cement Co: Surface Casing Dowell Schlumberger Cementer: Kevin Anderson Pipe Movement: Reciprocating .. .n__·_·_·__U .- Cmtd. Csg: Csg Type: Csg Size: Hole Size: TMD Set: Date Set: Prim_ary 12.250 (in) 2,421 (ft) 11/25/2003 Surface Casing 9.625 (in. Cmtd. Csg: Csg Type: sa TMD: sa Date: Cmtd. Csg Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Hole Size: sa TMD: sa Date: sa Type: ( Hole Size: TMD Set: Date Set: Hole Size: Top Set: BTM set: ( ( Cement Job Type: Primary .. . ._.~----- ~~l!~e3=~_Q~ti-º.Ie. _n ___?qu~E:)~~. Ças.i.ng .-- Plug Legal Well Name 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Report #: Start: 1 11/23/2003 Spud Date Report Date End: 11/24/2003 11/25/2003 12/5/2003 . Cementing Report ConocoPh ps Alaska . Page 1 of 3 Test Data Thickening Time: Free Water: Fluid Loss: Fluid Loss Pressure: (%) (cc) (OF) Temperature: Temperature: Temperature: OF) (OF) (OF) Compressive Strength Compressive Strength 2: Printed: Temp F) OF) 2/3/2004 10:32:19 AM Pressure (psi) (psi) Slurry Water Slurry Data Fluid Type: Interval: Source: TAIL Description: LiteCRETE ,400.00 (ftTo: 2,421.00 (ft) Cmt Vol: 89.0 (bbl) Slurry VoI:220 (sk) Time Density: 12.00 (ppg) WaterVol:41.1 (bbl) Class: G Yield: 2.28 Other Vol: 0 ft3/sk) Purpose: TAIL Mix Water: 7.84 (gal) Foam Job: N Stage No: 1 Slurry No: 4 of 4 D53 D79 S001 D124 D46 D65 D44 Concentration .... .._no__._.... 30.00 %BWOC 1.50 %BWOC 1.50 %BWOC 43.10 %BWOC 0.60 %BWOC 0.50 %BWOC 9.00 %BWOW Trade Name Type Additives Units ...-.....---.-.-.-.-. .... Liqui~tÇ<?nc. Units Stage No: 1 Slurry No: 3 of 4 Fluid Loss Pressure: Test Data Thickening Time: Free Water: Fluid Loss: (%) (cc) OF) Temperature: Temperature: Temperature: OF) 'F) 'F) Compressive Strength 1: Compressive Strength 2: Temp "F) "F) Pressure (psi) (psi) Slurry Interval: Water Source: Slurry Data Fluid Type: LEAD f To: ,400.00 ) Time Description: ARCTIC SET Cmt Vol: 404.0 (bbl) Density: 0.70 (ppg) Slurry Vol:530 (sk) Water Vol: 251.5 (bbl) Class: G Yield: 4.28 Other Vol: 0 P/sk) Purpose: PRIMARY Mix Water: 19.93 (gal) Foam Job: N Test Data Thickening Time: Free Water: ('Yo) Fluid Loss: (cc) Fluid Loss Pressure: OF) Temperature: Temperature: Temperature: "F) OF) OF) Stage No: Compressive Strength 1: Compressive Strength 2: 1 Slurry No: 3 of 4 Temp 'F) 'F) Pressure (psi) (psi) Slurry Interval: Water Source: Slurry Data Fluid Type: FLUSH ft To: ft Time Description: MUDPUSH XL Cmt Vol: (bbl) Density: 0.50 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: Other Vol t3/sk) o Purpose: SPACER Mix Water: (gal) Foam Job: N Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Stage No: 1 Slurry No: 2 of 4 Report # Start: 1 11/23/2003 Spud Date: Report Date End: 11/24/2003 11 /25/2003 2/5/2003 . Cementing Report ConocoPhillips Alaska . Page 2 of 3 Printed: 2/3/2004 0:32:19 AM Mix & pump 10 bbls CW10 8.3 ppg at rate of 5.0 bpm @ 95 psi, Shut down, Test lines to 3500 psi, I; 00 to total of 40 bbls, Mix & pump )bls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 3.5 bpi i down and drop btm plug, Mix & pump ~ ¡XS (404.0 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wI additives at ,:1 230 psi, Followed by 220 sxs (89.0 bbh Iii LiteCRETE cmt mixed at 12.0 ppg w/ additives at rate of 5.2 bpm @ 180 psi, Shut jowl I and drop top plug, Displace cmt wI 20 I fresh water, Shut down and turn over to rig pumps and continue to displace w/155.0 bbls 9.3 ppg mud (total of 175.0 bbls to bump p Slowed rate to 3.0 bpm @ 400 psi for 0 bbls of displacement, Bump plug w/11 00 psi, . .~.. 11/25/03, Had good returns thru out until cement to surface, Had 249 bbls good Rig Dowell CW at rate of 7.0 bpm @ 650 psi, r-'Mts held- OK, CIP @ 23:45 hrs cmt returns to surface. last job, Reciprocate csg. rat~ of 6.5 bpm @ . I . , 15' CBL Run: Under Pressure: Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: (psi) Remarks Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: It Log/Survey Evaluation Test For: Cement Found between Shoe and Collar: Pressure: Tool: Open Hole: 't Hrs Before Test: Interpretation Summary Cement Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Found on Tool: (psi) (min) Tool Tool: Press: (ppge) --... Liner Lap: D65 D46 D79 Casing Test ! ; , .-...-.-....----. Shoe Test 0.60 %BWOC 0.60 %BWOC 0.80 %BWOC Liner Top Test Trade Name ------.---........ . . .-- - ._1YP~__ u..___.. Additives ....------...--. C~mqeI""!1@!LC?~_.....J.... . -.... Units .~iquid Cone. Units Stage No: Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING 1 Slurry No: 4 of 4 Report #: Start: 1 11 /23/2003 Spud Date: Report Date End: 11/24/2003 11/25/2003 12/5/2003 . Cementing Report ConocoPh I ps Alaska . Page 3 of 3 I JOB NUMBER I· EVENT CODE 124 HRS PROG TMD I TVD I DFS 2P-434 ODR 561.0 2,426.0 2,360.0 2.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG D. Gladdenl M. Thornton Doyon 141 Meltwater 6,087.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD Nipple up BOPE 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL ND Diverter, NU & Test BOP's, PIU BHA & 5" DP, Drill out 11/25/2003 316,711 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 10030797 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 11/25/2003 2,354.81 24.550 305.810 9.625 (in) @ 2,421.0 (ft) 7.000 (in) @ 5,305.0 (ft) DENSITY(ppg) I 9.30 I)p I IECD IMUD DATAl DAILY COST I 0 I CUM COST i FV I PVNP I' GELS .., ViUHTtlP i FCIT.SOL I OIUWAT .., %SandlMBT I Ph/pM PflMf CI I Ca ¡ H2S 47 25/14 I 415 5.41 I 2/ I 118.0 I 8.51 I BHA NO. I 1 I BHA I HOLE CONDITIONS BIT NO. I 1 BHA WT. BELOW JARS I STRING WT. UP STRING WT. DN I STRING WT. ROT TORQUE / UNITS BHA LENGTH ft-Ibf 1,107.42 ITEM DESCRIPTION NO JTS LENGTH ... O.D. 1.0.' CONN SIZE CONN TYPE 1.00 12.250 27.78 8.000 10.05 8.062 5.70 12.125 0.83 7.750 16.10 8.250 37.86 8.000 1.65 8.125 31.00 6.750 30.98 6.750 29.37 6.750 2.53 8.000 120.92 5.000 30.60 6.250 755.05 5.000 6.00 7.000 5.000 .:..~.. -- .:<:-- ConocoPhillips Alaska : Daily Drilling Report WELL NAME Bit Mud Motor Drill Collar - NonMag Stabilizer - NonMag Crossover - Non Mag Resistivity Tool MWD N MCrossover Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Ghost Reamer Drill Pipe 4 25 BIT/RUN I 11 1 BITS )1 'M' XTYCP1 E I SERIAL NO.' I JETS OR TFA 15038007 10/22/22/22/1 SIZE I MANUF. 12.250 I HC Pélge 1 of 2 I REPT NO. I DATE 3 11/25/2003 I CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 754,264 AUTH. LAST BOP PRES TEST o I LIME I ,ES 2.875 2.875 2.875 2.875 2.875 2.875 3.250 2.875 3.000 2.875 3.000 2.875 4.281 DEPTH IN DATE IN I I-O-D·L-B~G-O-R 108.0 11/24/200~ 1-1-WT-A-E-I-EC-TD BIT/RUN I 11 1 GPM 635 BIT OPERATIONS PRESS I P BIT I HRS I '24Hr DIST I· 24Hr ROP ¡'CUM HRS I CUM DEPTH I CUM ROP 1,800 238 561.0 148.90 11.80 I 2,318.0 I 196.44 RPM 60 I 80 WOB 10 I 20 SURVEY DATA M.D. INCL. AZIMUTH T.V.D; N/S CUM EIW CUM SECTION M.D. INCL. AZIMUTH T.V.D. .. NIS CUM EIW CUM SECTION 1,867.42 19.870 310.060 1,846.96 111.66 -150.22 187.16 2,238.51 24.970 309.360 2,190.05 200.09 -260.07 328.14 1,960.01 20.960 308.270 1,933.73 132.05 -175.26 219.44 2,331.53 24.530 306.480 2,274.53 224.03 -290.78 367.07 2,053.53 22.040 307.820 2,020.74 153.17 -202.26 253.71 2,354.81 24.550 305.810 2,295.70 229.73 -298.59 376.73 2,146.03 23.980 309.480 2,105.88 175.77 -230.48 289.85 NO. 1 2 PUMP I HYDRAULIC DATA STROKE (in) J LINER (In) SPM Q (gpm) 12.000 I 6.000 75 317.26 12.000 6.000 75 317.26 PRESS. (psi) TOTAL Q 1,800 634.52 1,800 634.52 MAKE OF PUMP Emsco Emsco KILL SPM I PRESSURE Printed: 2/3/2004 10:32:55 AM ,ConocoPhillips Alaskà . ... . , , , 'Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 561.0 2,426.0 "',-' WELL NAME 2P-434 'FROM' TO HOURS CODE TROUBLE" >SUB 00:00 06:00 6.00 DRILL P DRLG 06:00 06:45 0.75 DRILL P CIRC 06:45 08:30 1.75 DRILL P TRIP 08:30 09:00 0.50 DRILL P CIRC 09:00 09:15 0.25 DRILL P TRIP 09:15 12:00 2.75 DRILL P PULD 12:00 12:30 0.50 CASE P SFTY 12:30 17:30 5.00 CASE P RUNC 17:30 18:30 1.00 CASE P CIRC 18:30 19:00 0.50 CASE P RURD 19:00 21:00 2.00 CEMENT P CIRC 21:00 21:15 0.25 CEMENT P SFTY 21:15 00:00 2.75 CEMENT P PUMP . Page 2 of 2 ITVD IDFS 2,360.0 2.00 I REPT NO. I DATE 3 11/25/2003 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Drill f/1 ,865' to 2,426' ART = 3.2 hrs AST = 1.2 hrs WOB 10/25K, 80 RPM, 635 gpm @ 1800 psi, UP 11 OK, DN 11 OK, ROT 11 OK, TQ on 5-6K, off 1-2K. SURFAC Pump Hi-vis weighted sweep & circ hole clean w/11 0 RPM & 635 gpm. SURFAC Monitor well, Back ream out of hole f/2,426' to 1,292' wI 80 RPM & 635 gpm. SURFAC Circ hole clean, Blow down top drive. SURFAC Monitor well, POOH on elevators to BHA @ 1,107' SURFAC Lay down Ghost reamer, Stand back HWDP & NMDC's, Drain motor, Break bit, Down load MWD, Lay down remaining BHA. SURFAC Held PJSM with crews on running casing, Held Diverter drill while running casing. SURFAC Clear floor, Rig & run 9.625" 40# BTC csg to 2,421' MD ( ran total 58 jts) - MIU hanger - MU landing jt, UP 125K, DN 115K. SURFAC Circ BU wI Franks tool - Stage pumps up slowly to 6 bpm @ 400 psi. SURFAC RID Frank's circu tool - Blow dn TD - MU DS cmt head SURFAC Circu & Condition mud - Circu @ 6 bpm - Final 6 bpm = 300 psi SURFAC Held PJSM with all crews on up coming cement job. SURFAC Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.0 bpm @ 95 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 3.5 bpm @ 80 psi, Shut down and drop btm plug, Mix & pump 530 sxs (404.0 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wI additives at rate of 6.5 bpm @ 230 psi, Followed by 220 sxs (89.0 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI additives at rate of 5.2 bpm @ 180 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 155.0 bbls 9.3 ppg mud (total of 175.0 bbls to bump plug) at rate of 7.0 bpm @ 650 psi, Slowed rate to 3.0 bpm @ 400 psi for last 10 bbls of displacement, Bump plug w/11 00 psi, Floats held- OK, CIP @ 23:45 hrs 11/25/03, Had good returns thru out job, Reciprocate csg. 15' until cement to surface, Had 249 bbls good cmt returns to surface. 24 HR SUMMARY: Drilled to 2,426', Circ clean, Pump out to 1,292', Circ clean, POOH, Lay down BHA, Rig & run 9-5/8" casing, Circ & condo mud, Cement 9-5/8" casing wI 249 bbls cmt to surface & bumped plug. COMPANY ConocoPhillips Company Doyon Drilling Inc Baker Hughes Inteq Baker Hughes Inteq - D SERVICE ITEM UNITS gals bbls USAGE 1,790 1,480 Fuel Water, Drilling PERSONNEL DATA NO. HOURS ,COMPANY ! 2 Epoch Well Services Inc 31 Doyon Universal Service 3 M-I Drilling Fluids 2 APC - Alaska Petroleum ...-.---.... SERVICE NO. HOURS 4 5 2 2 MATERIALS I CONSUMPTION ON HAND ITEM 15,680 Water, Potable 160 UNITS gals USAGE 3,668 r ON HAND 7,894 RESERVOIR NAME 2P-422 I 12P-434 RESERVOIR AND INTERVAL DATA ZONE I' TOP I' BASE I 1033 2.31700 COMMENTS Printed: 2/3/2004 10:32:55 AM Well Name: Drilling Supervisor: I Type of Test: I Casing Shoe Test LOT/FIT Hole Size: 8-1/2" """ RKB-CHF:I Casinfl Size and Description: Casin: Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight: Estimates for Test: ppg Lbl1 00 Ft2 psi Lbs Lbs 2.1 bbls PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. Date: I I #1 Mud Pump Pumping down I annulus and DP. I Hole Rig: EMW :: Leak-off Pressure + Mud Weight'" 1041 9 6 0.052 x TVD 0.052 x 2356 + . EMW at 2421 Ft-MD (2356 Ft- TVD) == 18.1 ppg 4000 3500 3000 - I.J.I 2500 ex: ::;) VJ 2000 VJ ~ .x- a.. 1500 1000 ~ --e /~ k-- 500· ~ Ai ~.~ O..¡,. -< 0 Barrels .........CASING TEST Comments: Casing Shoe 1Ft-Mol 9-5/8" 40#/Ft L-80 BTC .Pressure Inte:ritvTest Mud Weight: ppg Mud 10 min Gel: Lb/100 Ft2 Rotating Weight: Lbs BlockslTop Drive Weight: Lbs Desired PIT EMW: ppg Estimates for Test: 1029 psi "'" _LEAK-OFF TEST PIT 15 Second Shut-in Pressure, psi 1050 - Lost 1 00 psi during test, held = 97.2% of test pressure. o S 10 1 S 20 2S 30 Shut-In time, Minutes o PIT Point 0.6 bbls ""'I I Volume Input Strokes ... Volume/Stroke Casirïg Test Pumping Shut-in Strks psi Min psi o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Pumped 2.8 Bbls Volume Bled Back Bbls Pressure Integrity Test Pumping Shut-in Strks psi Min psi o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 Bbls/Strk ... Pumped 1.5 Bbls Pump Rate: Strk/min ... Vo ume Bled Back IBbls TMD I TVD I DFS 4,200.0 3,946.0, 4.00 AUTHMD 1 DAILY TANG 6,087.0 0 DAILY 'NT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 8-1/2" hole. 11127/2003 138,281 1 JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 18.11 10030797 LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 1 NEXT CASING LAST BOP PRES TEST 11/27/2003 4,091.00 27.300 306.680 9.625 (in) @ 2,421.0 (ft) 7.000 (in) @ 5,305.0 (ft) 11/26/2003 DENSITY(Ppg) 1 10.00 1 PP I 1 ECD 1 1 MUD DATA I DAILY COST 1 0 I CUM COST I 0 FV I' pvivp I GELS I· WUHTHP \ FCIT.SOL I OIUWAT I %SandlMBT I Ph/pM PflMf CI II Ca I H2S \ LIME I ES 63 28/34 10/13 3.41 2/ I 122.5 9.01 I BHA·NO·I 2 BHA I HOLE BHA WT. BELOW JARS . STRING WT. UP.. STRING WT. DN 13 150 125 BIT OPERATIONS PRESS I P BIT I HRS I 24Hr DIST ! 24Hr ROP ., CUM HRS I CUM DEPTH I' CUM ROP 2,000 231 1 15.90 1,774.0 1 111.57 15.90 1,774.0 111.57 SURVEY DATA T.V.D. N/S CUM E/W CUM SECTION .. M.D. 2,438.77 268.97 -351.92 442.94 2,976.78 2,522.13 292.21 -383.16 481.87 3,068.61 2,606.52 316.03 -415.49 522.02 3,161.85 2,688.96 340.85 -448.77 563.53 3,254.52 2,771.98 366.80 -483.04 606.52 3,347.57 _. ConocoPhillips Alaska ,.. Daily Drilling RE!port 1 JOB NUMBER I EVENT CODE 124 HRS PROG 2P-434 ODR 1,774.0 SUPERVISOR I RIG NAME & NO. I FIELD NAME lacs NO. D. Gladdenl M. Thornton Doyon 141 Meltwater CURRENT STATUS ACCIDENTS LAST 24 HRS.? WELL NAME Drilling 8-1/2" hole @ 4,775' MD 24 HR FORECAST LrrHOLOGY STRING Wt.ROT 135 Bit Mud Motor Stabilizer - Non Mag Crossover - Non Mag Resistivity Tool ORDICCN MAP (Pressure) MWD Crossover - Non Mag Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Sub- Circulating Drill Pipe - Heavy Wgt Ghost Reamer Drill Pipe 27 1.00 32.09 3.70 2.02 16.64 15.50 7.25 30.95 1.30 29.20 29.20 28.53 1.22 30.36 30.60 30.79 1.97 814.82 6.95 BIT / RUN 21 r . -. SIZE I MANUF. 8.500 HC BITS I SERIAL NO. f JETS OR TFA 17101195 16/16/16/16/161 21 I TYPE HCM605 BIT/RUN I 21 2 RPM 80 I 90 GPM I 510 WOB 5/20 M.D. 2,512.46 2,604.46 2,697.92 2,790.22 2,883.71 AZIMUTH 306.880 306.390 306.370 307.040 307.230 INCL. 27.020 26.660 26.030 26.270 27.560 INCL. 25.120 24.950 25.950 27.510 27.240 - 8.500 6.750 8.375 6.250 6.750 6.750 6.750 6.750 6.000 5.000 5.000 5.000 6.438 5.000 6.250 5.000 6.375 5.000 8.500 5.000 AZIMUTH 307.830 307.750 307.580 307.700 307.750 Page 1 of 2 I REPT NO. I DATE 5 11/27/2003 ¡CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 1,024,616 AUTH. ---.. TORQUE / UNITS 6 ft-Ibf BIT NO. 2 ....---.. .-.-. BHA LENGTH 1,114.09 2.813 2.813 2.813 2.813 2.750 2.750 2.813 3.000 2.250 3.000 2.875 3.000 2.750 4.281 _....---- DEPTH.IN DATE IN I I-O"D-L-B-G-O-R 2,426.0 11/26/200~ O-O-NO-A-D-I-NO-TD T.V.D. 2,854.81 2,936.74 3,020.30 3,103.48 3,186.45 NIS CUM E/W CUM SECTION 392.65 -516.70 648.96 418.06 -549.46 690.42 443.34 -582.22 731.80 468.28 -614.56 772.64 494.05 -647.87 814.76 Printed: 2/312004 10:33:25 AM . . .. ConocóPhillips Alaska DailyDrilling Report [JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 1,774.0 4,200.0 ,SURVEY DATA T.V.D. NIS CUM E/W CUM SECTION M.D.. " .. INCL. 3,269.69 520.27 -682.21 857.96 3,812.33 26.630 3,351.17 545.81 -715.49 899.91 3,903.63 26.490 3,434.64 572.10 -749.19 942.65 3,997.96 26.120 3,516.49 597.54 -782.10 984.25 4,091.00 27.300 . WELL NAME 2P-434 M.D. 3,441.35 3,533.00 3,626.77 3,718.59 AZIMUTH 306.980 308.020 307.900 307.510 INCL. 27.300 27.190 27.040 26.840 NO.. . 1 2 , MAKE OF PUMP Emsco Emsco . Page 2 of2 [TVD IDFS 3,946.0 4.00 I REPT NO. I DATE 5 11/27/2003 AZIMUTH T.V.D. NIS CUM E/W CUM SECTION 307.350 3,600.21 623.18 -815.59 1,026.42 306.850 3,681.87 647.80 -848.15 1,067.24 306.600 3,766.44 672.80 -881.65 1,109.04 306.680 3,849.55 697.75 -915.21 1,150.85 PUMP/HYDRAULIC DATA STROKE (in) LINER (in) SPM,·, Q (gpiïir 12.000 6.000 60 253.81 12.000 6.000 60 253.81 PRESS. (psi) TOTÄi.. Q 2,000 507.62 2,000 507.62 KILL SPM /. PRESSURE OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Finish testing 9-5/8" casing to 3500 psi. SURFAC Drill out float collar @ 2,333', Cement & Shoe @ 2,421', Clean out rate hole to 2,426', Drill 20' new hole to 2,446'. SURFAC Pump Hi-vis sweep, Change over to 9.6 ppg LSND mud. SURFAC Rig & perform 18.1 ppg EMW wI 1041 psi, 2,356' TVD, 9.6 ppg mud. INTRM1 Drill f/2,446' to 2,523' WOB 5/20K, 90 RPM, 510 GPM @ 1700 PSI. INTRM1 Circ & Obtain PWD Base line.ECD clean hole base line 10.32 ppg wI 9.6 ppg mud. INTRM1 Drill fl 2,523' to 3,235' ART:: 6.6 hrs, AST:: 0.6 hrs, WOB 5/20K, 90 RPM, 510 GPM @ 1700 PSI, UP 115K, DN 95K, ROT 110K, TO on 2/8K, off 2/3K, Control drilling rate at 150'lhr. to limit ECD's, ECD's ranging from 11.4 to 11.8 ppg, Pumping Hi-vis sweeps every 4 to 5 stands with 50-60% increase in large cuttings on sweeps. DRLG INTRM1 Drill f/3,235' to 4,200' ART:: 8.7 hrs, AST:: 0.6 hrs, WOB 5/15K, 90 RPM, 510 GPM @ 2000 PSI, UP 150K, DN 125K, ROT 135K, TO on 3/8K, off 3/6K, Control drilling rate at 150'/hr. to limit ECD's, ECD's ranging from 11.4 to 11.8 ppg, Pumping Hi-vis sweeps every 3 to 4 stands with 50-60% increase in large cuttings on sweeps. Every third sweep has been WV hi vis sweep. FROM TO HOURS CODE TROUBLE SUB 00:00 00:15 0.25 DRILL P DEOT 00:15 01:30 1.25 DRILL P DRLG 01:30 02:00 0.50 DRILL P CIRC 02:00 02:45 0.75 DRILL P FIT 02:45 03:45 1.00 DRILL P DRLG 03:45 04:00 0.25 DRILL P CIRC 04:00 12:00 8.00 DRILL P DRLG 12:00 00:00 12.00 DRILL P 24 HR SUMMARY: Finish testing 9-5/8" csg. to 3500 psi, Drill out Shoe track & 20' new hole to 2,446', Change over to 9.6 ppg LSND mud, Perform FIT to 18.1 ppg, Drill to 2,523', Obtain PWD Base line, Drill to 4,200' COMPANY -- ConocoPhillips Company Doyon Drilling Inc Baker Hughes Inteq Baker Hughes Inteq - D SERVICE ITEM UNITS gals bbls USAGE 1,260 820 Fuel Water, Drilling PERSONNEL DATA NO. HOURS COMPANY ·v_···.··· 2 Epoch Well Services Inc 31 Doyon Universal Service 3 M-I Drilling Fluids 2 APC - Alaska Petroleum SERVICE . NO. HOURS 4 5 2 2 MATERIALS / CONSUMPTION ON HAND I ITEM 12,960 I· Water, Potable 460 . USAGE 4,117 UNITS gals ON HAND 14,166 RESERVOIR NAME 2P-422 I 12P-434 .. RESERVOIR AND INTERVAL DATA ZONE..' TOP I BASE I 756 2 650 COMMENTS Printed: 2/3/2004 10:33:25 AM GonocoPhillips Alaska Casing Report Page 1 of ~ Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Report #: Start: 2 11/23/2003 Spud Date: 11/24/2003 Report Date: 12/1/2003 End: 12/5/2003 ._~_.-----, General Information ---" -".- String Type: Production Casing Hole TVD: 5,298.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 2.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Kelly Bushing 224.00 (ft) (ft) 132.0 (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 8.500 (in) (ft) (ft) 25.52 (ft) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 5,714.0 (ft) 126,000 (Ibs) 28.19 (0) 8.00 (days) . -----------'.----.,.- -----.. Casing Flange I Wellhead Manufacturer: Hanger Model: FMC UHA Mandrel Model: Packoff Model: GenV UHA Top Hub/Flange: 11.000 (in) 15,000 (psi) BTM Hub/Flange:11.000 (in) I 5,000 (psi) Actual TMD Set: 5,711.00 (ft) --~- .------- ---"-- Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer Model Condo Max OD Min ID Compo Name (in.) (Ib/ft) (in) (ft) (ft) . (ft-Ibf) . (in) (in) Casing Hanger L·80 BTC-MOD 1 1.65 25.52 Casing Hanger CASING 7.000 26.00 L·80 6.151 BTC-MOD 1 40.66 27.17 6.276 7" 26# L-80 Cas Casing - Pup Jt 7.000 26.00 L·80 6.151 BTC-MOD 1 5.28 67.83 6.276 7" 26# L-80 Cas CASING - PUP JT 7.000 26.00 L-80 6.151 BTC-MOD 1 19.66 73.11 6.276 7" 26# L.80_ CASING 7.000 26.00 L-80 6.151 BTC-MOD 138 5,537.29 92.77 6.276 7" 26# L·80 FLOAT COLLAR BTC-MOD 1 1.32 5,630.06 Float Collar CASING 7.000 26.00 L-80 6.151 BTC-MOD 2 78.15 5,631.38 6.276 7" 26# L·80 Cas FLOAT SHOE BTC-MOD 1 1.47 5,709.53 Float Shoe 5,711.00 Non-Integral Casing Accessories Accessory Manufacturer Number Spacing Interval How Fixed (ft) Top (ft) Bottom (ft) Bowspring Centralizer WEATHERFORD 18 SC/ OCs Centering Guides RAY OIL TOOLS 19 Floating Printed: 2/312004 10:32:03 AM ConocoPhillips Alaska Casing Report Page 2 of 2. Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Report #: Start: 2 11/23/2003 Spud Date: 11/24/2003 Report Date: 12/1/2003 End: 12/5/2003 -..'-"" Remarks Rig & ran 7" Float shoe, 2 jts 7",26#, L-80, BTCM csg, Float collar, 138 jts 7",26#, L-80, BTCM csg, Pup jt 19.66' & Pup jt 5.28', 7" ,26# BTCM csg,1 jt 7" ,26# & 7" FMC csg hanger. Placed centralizers 1-5' above shoe on stop collar and 1-5' above float collar on stop collar, and 1 on every joint from shoe to joint # 18 for a total of 19 centralizers. . While running csg, circu and conditioning mud we lost 67 bbls mud. While pumping and displacing cmt we lost 65 bbls. . Printed: 2/3/2004 10:32:03 AM Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: OF) Temperature: Temperature: Temperature: OF) OF) OF) Compressive Strength 1 : Compressive Strength 2: Temp ('F) OF) Printed: 2/3/2004 10:32:37 AM Pressure (psi) (psi) Slurry Data Fluid Type: FLUSH Slurry Interval: 3,830.00 (ftJfo: Water Source: Description: MUDPUSH XL 4,848.00 (ft) Cmt Vol: 40.0 (bbl) Slurry Vol: (sk) Density: 12.50 Water Vol: (bbl) Time (Ppg) Class: Yield: (IP/sk) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Type: Non-Disp. LS Density: 11.3 (ppg) Vise: 53 (slqt) Bottom Hole Circulating Temperature: eF) Displacement Fluid Type:Mud . ,.u -" Stage No: 1 PV/YP: 29 (cp)/19 (lb/100ft>.) Gels 10 see: 7 Bottom Hole Static Temperature: .3 (ppg) Volume: - ...." Density: 11 Slurry No: 1 of 2 212.80 (bbl) -- .-. Ib/1001t2) Gels OF) To Cementing: 4.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 450 (psi) Top Plug Bottom Plug: 2/1/2003 Y Y Mud Data Press Bumped: Press Held: Float Held: 575 (psi) 1.500 (psi) 5 (min) Y Omin: Ann Flow After: Mixing Method: Density Meas By: 10 Ib/100lt2) Densometer N Batch End Pumping: End Pump Date: Type: Volume Excess Meas. From: Time Circ Prior Cement Casing %: 75.00 Start Mix Cmt: Start Slurry Displ Start Displ: 04:30 05:37 05:47 06:50 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: 3.50 (bbl/min) 4.00 (bbllmin) Y Returns: 80% Total Mud Lost: Cmt Vol to Surf: 65.00 (bbl) (bbl) Rot Time Start: : Rec Time Start:00:45 Time End: : Time End: 06:50 RPM: SPM: Stage No: Init Torque: Stroke Length: 1 of 1 Ibl) 15.0 (It) Avg Torque: Drag Up: (It-Ibl) 170 (lbs) Max Torque: Ibf) Drag Down: 120 lIbs) ., n .. Cement Co: Dowell Schlumberger --" --- Pipe Movement Cementer: Don Zierke Cmtd Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) Hole Size: TMD Set: Date Set: 8.500 (in) 5,711 (ft) 12/1/2003 Hole Size: sa TMD: sa Date: sa Type: (ft) Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Pipe Movement: Reciprocating --.'-- .- ." Csg: Production Casing Cmtd. Csg: Cmtd. Plug Date: Plug Type: Drilled Out: Csg: Hole Size: Top Set: BTM set: (It) ) P~!!!1ªr.Y .--.,..".. . ..-.--.--....-... Sg.\!~.l?ze Op",!I}..!::Io1e ---.....-.- Sq,!~~z.:~ Casil).9._.. . ---~.... ..J'lu9.__ legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRilLING Cement Job Type Report # Start: Primary 2 11/23/2003 Spud Date Report Date End: 11/24/2003 12/1/2003 12/5/2003 . Cementing Report GonocoPhillips Alaska . Page 1 of 2 Printed: 2/312004 Turn over to Dowell, Pump 5 bbls fresh water, Test lines to 3500 psi, Pump 40 bbls 12.5 ppg MudPUSH II at rate of 4 bpm @ 410 psi, Shut down drop btm plug, Pump 35.5 bbls (170 sxs) Class G cmt w/.03%B155, 004%D65, 0.2%gpsD47, 2.0%gpsD600G, 2lb/bbl CemNET mixed at 15.8 ppg, Pumped at 4.0 bpm @ 410 to 330 psi, Shut down drop top plug, Displace cmt. w/10 bbls fresh water, followed by 202.8 bbls 11.3+ ppg mud at rate of 3.5 bpm @ 350 to 575 psi, Lost 35 bbls mud displaceing MudPUSH to shoe, Lost 17 bbls mud after MudPUSH rounded shoe, Lost 13 bbls mud after cmt rounded shoe, Bumped plug wI 1500 psi, C.I.P at 06:50 hrs 12/1/03, Reciprocated casing 15' and land just prior to bumping plug, Floats held -OK, No annulas flow after cmt in place, Calculated top of MudPUSH @ 3830', Calculated top of cement @ 4848' 0:32:37 AM Hrs Prior to Log: CBL Run: Under Pressure: Bond Quality: Cet Run: Bond Quality: Temp Survey: Remarks Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (psi) Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful It) Log/Survey Evaluation Test For: Cement Found between Shoe and Collar: (psi) (min) Pressure: Tool: Open Hole: ) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Found on Tool: Interpretation Summary Cement Tool: Tool Press: Shoe Test (ppge) B155 D65 D47 D600G CemNET Casing Test 0.03 %BWOC 0040 %BWOC 2.00 %BWOC Liner Top Test 0.20G P S 2.00G P S -.--. . Trade Naf!1e . -.- Type Slurry No: 2 of 2 Concentration Additives Units .. ... .- . Liquid Conç:. Units Test Data Thickening Time: 4.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) . .- --- -.-...-- Stage No: 1 Temperature: Temperature: Temperature: OF) "F) "F) Compressive Strength' : Compressive Strength 2: Temp OF) OF) Pressure (psi) (psi) Slurry Data Fluid Type: Interval: Source: Slurry Water PRIMARY 4,848.00 (ltjfo: 5,711.00 ft) Description: Cmt Vol: 35.5 (bbl) Slurry Vol:170 (sk) Time Density: 15.80 (ppg) Water Vol: 20.9 (bbl) Class: G Yield: 1.17 Other Vol: 0 '3/sk) Purpose: PRIMARY Mix Water: 5.16 (gal) Foam Job: N Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Stage No: 1 Slurry No: 2 of 2 Report # Start: 2 11/23/2003 Spud Date: Report Date: End: 11/24/2003 12/1/2003 12/5/2003 . Cementing Report ConocoPhillips Alaska . Page 2 of 2 I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD 1 DFS 2P-434 ODR 5,714.0 5,298.0 8.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG D. Gladdenl M. Thornton Doyon 141 Meltwater 6,087.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD TIH P/U 4" DP 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH to 5630', Test csg, CIO to 5714', Drill to 6087' 12/1/2003 300,735 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 18.11 10030797 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 11/29/2003 5,629.86 26.610 306.150 7.000 (in) @ 5,711.0 (ft) 3.500 (in) @ 6,087.0 (ft) 12/1/2003 DENSITY(ppg) I 9.60 I pp I I ECD I I MUD, D~TÄI DAILY ëOST I 0 -----:--CÜM cosT~·---6 FV I PVNP I GELS I WLlHTHP I FêlT.SOL I OILIWAT 1 ·%SandlMBT I Ph/pM.' I PflMf CI. [' Ca , H2S I LIME I ES 50 115/22 I 7/10 4.81 11 I I /12.5 9.2/ / BHA NO. I 3 BHA I HOLE BHA WT. BELOW JARS STRING WT. UP STRING WT. DN BIT OPERATIONS GPM I PRESS I P BIT" I HRS I 24Hr DIST I 24Hr ROP ¡ CUM HRS I CUM DE~H' CUM ROP OPERATIONS SUMMARY PHASE ,-- DESCRIPTION INTRM1 Finish running 7" casing to 5686' at 20 ftIhr (Hole very free), Make up hanger & land casing at 5711'. UP 170K, DN 120K. INTRM1 Cire btm's up & condition mud wI fill up tool at of 1.5 bpm @ 275 psi (Btm's up gas 57 units), Stage pump rate from 1.5 bpm @ 275 psi to 3.0 bpm @ 400 psi, Lost 41 bbls mud while cire. INTRM1 Rig down Franks fill tool, Blow down top drive, Rig up Dowell cement head. INTRM1 Finish conditioning mud for cement job, Mud cheek before = Wt 11.3+, vis 60, PV 32, YP 24 Gels 8/12, After= Wt 11.3+, vis 53, PV 29, YP 19, Gels 7/10, Stage rate from 1.5 bpm @ 275 psi to 3.5 bpm @ 450 psi, Had minor loses- lost total of 26 bbls while eire, Had 97 units gas from shut down Installing cmt head, Hold PJSM with all rig personal for cmt job, Batch mix cement. ~//" --, - . .. .. ..... . . çonocoPhillipS~laska, Daily Drilling Report, WELL NAME Bit FM-2643 1 0.78 6.125 Mud Motor M1-XL 1 30.88 4.750 NM STAB 1 4.58 6.000 MAP/MPR 1 21.44 4.750 SND 1 16.51 4.750 MWD I UPA 1 23.03 4.750 NMCSDP 3 92.78 3.500 XO 3.51 FxHT38 1 2.50 4.875 HWDP 4 122.70 4.000 JARS 1 29.45 4.750 HWDP 25 767.53 4.000 XO HT38xXT39 1 1.74 4.938 4"S135 DP 4.000 BIT/RUN I 31 3 ' BITS -I TYPE I SERIAL N0·1 JETS OR TFA I FM-2643 5012726 15/20/20111 SIZE .1 MANUF. 6.125 SEC BIT / RUN· . WOB RPM FROM TO HOURS CODE TROUBLE! SUB 00:00 00:45 0.75 CASE P RUNC 00:45 03:30 2.75 CEMENT P CIRC 03:30 04:00 0.50 CEMENT P PULD 04:00 05:15 1.25 CEMENT P CIRC . . Page 1 of 2' I REPT NO. I DATE 9 12/1/2003 ¡CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 1 ,753,875 AUTH. . TORQUE I UNITS -I BIT NO. 3 BHA LENGTH 1,113.92 2.375 2.250 2.563 2.563 2.250 2.563 2.500 3.340 DEPTH IN DATE IN I I-O-D-L-B-G-O-R 5, 714.0 12/1/200~ O-O-NO-A-D-I-PN- TD Printed: 2/312004 10:33:58 AM ConocoPhillips Alaska .Daily Drilling.fleport IJOBNUMBER IEVE~Dc~DE 124HRSPROG IT~~714.0 WELL NAME 2P-434 - Page 2 of 2·. ITVD IDFS 5,298.0 8.00 I REPT NO. I DATE 9 12/1/2003 FROM TO·. HOURS 05:15 07:15 2.00 CODE TROUBLE SUB CEMENT P PUMP OPERATIONS SUMMARY PHASE INTRM1 07:15 07:45 0.50 CEMENT P PULD INTRM1 07:45 08:30 0.75 CASE P DEQT INTRM1 08:30 10:00 1.50 CASE P RURD INTRM1 10:00 14:00 4.00 DRILL P PULD INTRM1 14:00 16:00 2.00 WELCTL P NUND INTRM1 16:00 21:00 5.00 WELCTL P BOPE INTRM1 21:00 22:00 1.00 DRILL P PULD INTRM1 22:00 00:00 2.00 DRILL P PULD INTRM1 DESCRIPTION Turn over to Dowell, Pump 5 bbls fresh water, Test lines to 3500 psi, Pump 40 bbls 12.5 ppg MudPUSH II at rate of 4 bpm @ 410 psi, Shut down drop btm plug, Pump 35.5 bbls (170 sxs) Class G cmt wI .03%B155, 0.4%D65, 0.2%gpsD47, 2.0%gpsD600G, 21b/bbl CemNET mixed at 15.8 ppg, Pumped at 4.0 bpm @ 410 to 330 psi, Shut down drop top plug, Displace cmt. w/1 0 bbls fresh water, followed by 202.8 bbls 11.3+ ppg mud at rate of 3.5 bpm @ 350 to 575 psi, Lost 35 bbls mud displaceing MudPUSH to shoe, Lost 17 bbls mud after MudPUSH rounded shoe, Lost 13 bbls mud after cmt rounded shoe, Bumped plug wI 1500 psi, C.I.P at 06:50 hrs 12/1/03, Reciprocated casing 15' and land just prior to bumping plug, Floats held -OK, No annulas flow after cmt in place, Calculated top of MudPUSH @ 3830', Calculated top of cement @ 4848'. Rig down Dowell cement head, Lay down landing joint. Set 7" packoff & test to 5000 psi f/1 0 min. Change top 7" rams back to 3-1/2" x 6", Change bails, Rig down all casing equip., Clear rig floor. Lay down excess 5" drill pipe from derrick except 18 stands for next well. Change saver sub from 5" to 4", Change btm pipe rams to 4". Rig & test BOPE to 250 psi low & 5000 psi high, Test waived by AOGCC John Crisp, Rig down test equip., Set wear bushing. Pick up 21 joints 4" drill pipe and stand back in derrick. PJSM, Make up 6-1/8" BHA 24 HR SUMMARY: Finish running 7" csg to 5711', Circ & cond mud, Cmt 7" csg, Set & test 7" pack off, Lay down 5" D.P., Test BOPE, Pick up 21 jts. 4" D.P., Pick up 6-1/8" BHA. COMPANY ConocoPhillips Company Doyon Drilling Inc Baker Hughes Inteq Baker Hughes Inteq - D SERVICE PERSONNEL DATA SERVICE NO~, 2 31 3 2 HOURS COMPANY Epoch Well Services Inc Doyon Universal Service M-I Drilling Fluids APC - Alaska Petroleum NO. HOURS 4 5 2 2 ITEM USAGE 1 ,439 650 MATERIALS /..Ç.9NSUMPTION ON HAND ITEM 7,011 Water, Potable 730 ON HAND 5,184 UNITS gals bbls Fuel Water, Drilling UNITS gals USAGE 4,890 RESERVOIR NAME 2P-422 [2P-434 RESERVOIR AND INTERVAL DATA ZONE I TOP I BASE I 419 1 850 COMMENTS Printed: 2/3/2004 10:33:58 AM I Volume Input Volume/Stroke Pump Rate: I 0.10051 Bbls/Strk I . 7.01 Strk/min I· Strokes I· Casin~ Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Strks psi Min psi Strks psi Min psi 0 0 0 3575 0 0 0 855 2 80 1 3575 2 195 0.25 845 4 377 2 3550 4 323 0.5 835 6 632 3 3520 6 431 1 83. 8 902 4 3520 8 538 1.5 82 10 1096 5 3520 10 668 2 825 12 1314 6 3500 12 752 2.5 821 14 1541 7 3500 14 800 3 806 16 1798 8 3500 16 840 3.5 797 18 2068 9 3500 18 890 4 797 20 2374 10 3500 20 950 4.5 795 22 2700 15 3480 22 1028 5 795 24 2945 20 3480 24 1080 5.5 794 26 3235 25 3475 26 1160 6 793 28 3568 30 3475 28 1215 6.5 790 30 1250 7 780 ;.~.~. 1* 7.5 777 34 1280 8 775 36 1211 8.5 773 40 1199 9 773 44 1172 9.5 773 48 1121 10 77. 52 1080 56 1059 60 1030 64 1008 66 1001 PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. Well Name: 2P-434 I Rig: Doyon 141 Date: I 12/5/2003 Drilling Supervisor: Mike Thornton pump used: I #1 Mud Pump I. Type of Test: I Annulus Leak Off Test for Disposal Adequacy 1.1 Pumping down 1 annulus and DP. I. Hole Size: 18-1/2" l"'l Casing Shoe Depth II Hole Depth RKB-CHF: 25.51Ft 2,421 1Ft-MOl 2,3561 Ft-TVD 2,446IFt-MD I 2,378IFt-TVD CasinQ Size and Description: 19-5/8" 40#/Ft L-80 BTC r .1 ChanQes for Annular AdeQuacv Test Pressure Inte~ritvTest )uter casing shoe test results 18.0 in comments Mud Weight: 11.3 ppg Description references outer 9.6 casing string. Inner casing 00: 7.0 In. ;ize is that drilled below outer 9 casing. ¡timated TOC for Hole Depth. 4,848 Enter inner casing 00 at right 7 Desired PIT EMW: Estimates for Test: 18.0 ppg 821 psi 0.2 bbls I... 1...\ EMW = Leak-off Pressure + Mud Weight = 752 11 3 0.052 x TVD 0.052 x 2356 + . EMW at 2421 Ft-MD (2356 Ft-TVD) = 17.4 PIT 15 Second Shut-in Pressure, psi 845 4000· : Lost 100 psi during test, held : 97.2% of test pressure. ····W..\ ,. .& 3500· / j 3000· w 2500· ~ :::> CI) CI) w ~ Q.. 2000· 1500· 1000~_ '~' t 500 o o 1 ..- _. ":'....a..:......._ _ ""- -1- - -- , - - iw.., I I I I 7 2 3 Barrels 4 5 6 o 5 10 15 20 25 Shut-In time, Minutes o PIT Point --'-CASING TEST _LEAK-OFF TEST Comments: I, 30 Volume Pumped 2.8 Bbls Volume Bled Back I Bbls Volume Pumped 6.6 Bbls Voume Bled Back Itsbls . . ." .. , ' ConocoÞhillips'Alaska pailyDrilling'Repört Page 1 of 1 I JOB NUMBER I EVENT CODE 124 HRS PROG 2P-434 ODR SUPERVISOR RIG NAME & NO. I FIELD NAME I OCS NO. F. Herbert! M. Thornton Doyon 141 Meltwater CURRENT STATUS ACCIDENTS LAST 24 HRS.? Released Rig at 12:00 hrs 12/5/2003 24 HR FORECAST Released Rig at 12:00 hrs 12/5/2003 I JAR HRS OF SERVICE I BHA HRS SINCE INSP INC AZIM I LAST CASING 25.720 306.780 3.500 (in) @ WELL NAME LITHOLOGY LAST SURVEY: DATE 12/2/2003 TMD 5,949.41 FROM TO HOUR!; CODE TROUBLE SUB 00:00 01:30 1.50 CMPL TN P DEQT 01:30 02:30 1.00 CMPL TN P PULD 02:30 03:30 1.00 CMPL TN P FRZP 03:30 04:30 1.00 CMPL TN P NUND 04:30 07:00 2.50 CMPL TN P NUND 07:00 08:00 1.00 CMPL TN P FRZP 08:00 09:00 1.00 CMPL TN P RURD 09:00 10:00 1.00 CMPL TN P RURD 10:00 12:00 2.00 CMPL TN P RURD TMD I TVD I DFS 6,030.0 5,582.0 12.00 AUTHMD DAILYTANG 6,087.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 12/4/2003 225,470 I LEAKOFF AFE 12.61 10030797 ¡NEXT CASING 6,025.0 (ft) (in) @ (ft) LAST BOP PRES TEST 12/1/2003 I REPT NO. I DATE 13 12/5/2003 ¡CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 2,407,394 AUTH. OPERATIONS SUMMARY I ' I PHASE DESCRIPTION CMPL TN Rig & Preesure test tubing to 3500 psi f/30 min.- OK, Bleed tubing press. down to 1500 psi, Pressure test 7" x 3-1/2" annulas to 3500 psi f/30 min.- OK, Bleed off tubing preesure & Shear out DCK-3 valve. CMPL TN Lay down landing joint, Break out pump in sub, Set 2 way check in tubing hanger. CMPL TN Rig & perform Injectivity test on 9-5/8" x 7" annulas, 752 psi, 11.3 ppg mud, 2356' TVD= 17.4 EMW, Flush annulas with 200 bbls fresh water followed by 60 bbls diesel to freeze protect. CMPL TN Nipple down BOPE, Change out Saver sub on top drive. CMPL TN Nipple up Tree, Test adapter void to 5000 psi f/1 0 min., Test tree to 250 low & 5000 psi high. CMPL TN Pull 2 way check, Pump 50 bbls diesel down 3-1/2"x 7" annulas at rate of 2 bpm @ 1475 psi, Put tubing and annulas in communication and let U-tube. CMPL TN Finish changing out saver sub, Grabbers, Pipe guide on top drive. CMPL TN Install SPV, Rig down circ hoses. CMPL TN Remove double annulas valve, Install Blind flanges wI valves, Suck out cellar, Remove and roll up hoses, Remove containment. Release Rig at 12:00 hrs 12/5/2003. 24 HR SUMMARY: Test tubing and annulas to 3500 psi f/30 min. each, Shear out DCK-3 valve, UD landing jt. & pump in sub, Set 2 way check, Rig & perform injectivity test on 9-518"x 7" annulas & freeze protect same, NID BOP, NIU Tree, Freeze protect well, Release rig. COMPANY ConocoPhillips Company Doyon Drilling Inc Baker Hughes Inteq Saker Hughes Inteq - D SERVICE ITEM UNITS gals bbls USAGE 1,700 290 Fuel Water, Drilling 'M~__' PERSO~NEL DATA NO. HOURS COMPANY 2 Epoch Well Services Inc 31 Doyon Universal Service 3 M-I Drilling Fluids 2 APC - Alaska Petroleum SERVICE NO. HOURS 4 5 2 2 MATERIALS I CONSUMPTION ON HAND I ITEM 5,170 ¡Water, Potable 60 UNITS gals USAGE 5,087 ON HAND 15,654 RESERVOIR NAME 2P-422 2P-434 RESERVOIR AND,INTERVAL DATA ZONE" TOP BASE I '-3:~--~~ 2P-434 2P-434 COMMENTS Printed: 2/312004 10:34:37 AM Scblumbepgep NO. 3100 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 01/27/04 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color )<{)'-/ "053 2A-04 10709682 INJECTION PROFILE 12/27/03 1 J9,5.~ 2T-28 10709867 STATIC SURVEY 01/15/04 1 )'B"LJ' F- 2A-04 10709691 RST 01/19/04 1 ,~. );;J'd-- 2K-01 10696828 LDL 01114/04 1 9«)' J3Lt 10-140 10696827 LDL 01/13/04 1 '-¿)1'-\\ 3H-03 10709688 PRODUCTION PROFILE 01/16/04 1 ~D3'- \5~ 2P-447 10696819 SCMT 01/04/04 1 ~'"1S3 2P-434 10709667 USIT/CBL 12/02/03 1 5)O?ì'-C~i \ 2P-432 10696818 PERF RECORD & SBHP 01/03104 1 ~~'-. "'. -",-".. SIGNED: . ~ \u /\,{\.-~\'") '- C) û'1 :t..... f"~, Kuparuk CD . . RE~['V[D J/\N 2) C 2004 A.\aß~.aOi\ & Gas Cons. Comm. Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. þ,or,horage DATE: --.--......... <:::... ~, c· \ ") ~ '¡--..~" .~ . ConocóP'hillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 22,2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-434 (APD # 203-153) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-434. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, ~r. 0~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RE(~ JAN 2' 8 2004 Alaska Oil 8. Gas Anchor&{ß o q , G , ~, A , . STATE OF ALASKA .' ALA OIL AND GAS CONSERVATION COM' ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U GINJ D 2. Operator Name: WINJ D WDSPL D Plugged D Abandoned D 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: 957' FNL, 1855' FWL, Sec. 17, T8N, R7E, UM At Top Productive Horizon: 184' FSL, 365' FWL, Sec. 8, T8N, R7E, UM Total Depth: 270' FSL, 253' FWL, Sec. 8, T8N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 443815 I y- TPI: x- 442330 y- Total Depth: x- 442218 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res/Den/Neu 22. CASING SIZE 16" 9.625" WT. PER FT. 62.5# 40# 26# 9.2# GRADE B L-80 L-80 L-80 7" 3.5" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2421' Surface 5711' 5524' 6025' Zone-4 Zone- 4 Zone- 4 5868921 5870073 5870159' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 5712'-5772' MD 5780'-5784' MD 5790'-5794' MD 5297'-5350' TVD 5358'-5361' TVD 5367'-5370' TVD 26. Date First Injection January 6, 2004 Date of Test Hours Tested NIA Flow Tubing Casing Pressure press. 27. psi PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) WAG Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL 6 spf 6 spf 6 spf 24-Hour Rate -> Suspended D WAG 0 1b. Well Class: 20AAC 25.110 Development D Exploratory D Other Service 0 Stratigraphic Test D 5. Date Comp., ~. ',;¡..:;6t/.. 12. Permit to Drill Number: or Aband.: .. nM')we, l. 'i[';OS /,Þ 203-1531 6. Date Spudded: 13. API Number: November 24,2003 50-103-20467-00 7. Date TD Reached: 14. Well Name and Number: December 2, 2003 8. KB Elevation (It): 28' RKB 9. Plug Back Depth (MD + TVD): 5926' MD I 5489' TVD 10. Total Depth (MD + TVD): 6030' MD I 5582' TVD . 2P-434 15. FieldlPool(s): Kuparuk River Field Meltwater Oil Pool 16. Property Designation: ADL 373112 11. Depth where SSSV set: Landing Nipple @ 500' 19. Water Depth, if Offshore: NIA feet MSL 17. Land Use Permit: ALK 32092 20. Thickness of Permafrost: 1354' MD HOLE SIZE CEMENTING RECORD 90sxASI AMOUNT PULLED 42" 12.25" 530 sx AS Lite, 220 sx LiteCrete 170 sx Class G 120 sx Class G 8.5" 6.125" 24. TUBING RECORD DEPTH SET (MD) 5575' PACKER SET (MD) 5556' SIZE 3.5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A WATER-BBL CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) not available GAS-MCF WATER-BBL CORE DATA RCC 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". ~~,~i.... ~ Form 10-407 Revised 2/2003 fE80 lûù't NONE r··~·····"----·-' f 'GO~{.1PLLT~ON ì \1 1 í," DI~TE il ' ð ! -tLj!.-~-.. - I 1"'., ~"'.,-"-n I', .. \I.!<,j '''It:u i 'O¡ .. ~ 1-. .-.--.....-. ; ~....,~..,,~-....~....'_.,--_.......-., J,fI Ala~,1 CONTINUED ON REVERSE SIDE l,~ Submit in duplicate OR\G\NAL 28. GEOLOGIC MARKER. 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-434 T3 T2 5708' 5867' 5293' 5436' NIA RECEI JAN 2 8 200' Alaska Oil & Gag 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed Na~ __ R. :flpmas _ Signature l ~ t ~ . Title: f'iUf'e Kuparuk Team Leader '2...'~--6-B }C) Date t ("L(, (0 .., Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 OR (~I , '" ..... .. Page 1 of 6 ConocoPhillips Alaska Operations Summary Report Date 2P-434 2P-434 ROT - DRILLING Doyon Doyon 141 From - To ' Hours I Code . I 4.00 MOVE Sub Code Phase DMOB MOVE Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/23/2003 08:00 - 12:00 12:00 - 15:30 15:30 - 17:30 17:30 - 22:30 3.50 MOVE 2.00 MOVE 5.00 MOVE MOB MOVE RURD MOVE RURD MOVE 22:30 - 00:00 1.50 MOVE SFTY MOVE 11/24/2003 00:00 - 02: 15 2.25 RIGMNT RSRV RIGUP 02:15 - 02:45 0.50 WELCTL OTHR RIGUP 02:45 - 05:45 3.00 DRILL PULD SURFAC 05:45 - 06:00 0.25 DRILL OTHR SURFAC 06:00 - 00:00 18.00 DRILL DRLG SURFAC 11/25/2003 00:00 - 06:00 6.00 DRILL DRLG SURFAC 06:00 - 06:45 0.75 DRILL CIRC SURFAC 06:45 - 08:30 1.75 DRILL TRIP SURFAC 08:30 - 09:00 0.50 DRILL CIRC SURFAC 09:00 - 09: 15 0.25 DRILL TRIP SURFAC 09:15 - 12:00 2.75 DRILL PULD SURFAC 12:00 - 12:30 0.50 CASE SFTY SURFAC 12:30 - 17:30 5.00 CASE RUNC SURFAC 17:30 - 18:30 1.00 CASE CIRC SURFAC 18:30 - 19:00 0.50 CASE RURD SURFAC 19:00 - 21 :00 2.00 CEMENTCIRC SURFAC 21:00 - 21:15 0.25 CEMENT SFTY SURFAC 21 :15 - 00:00 2.75 CEMENT PUMP SURFAC Start: Rig Release: Rig Number: Spud Date: 11/24/2003 End: 1V5/2003 Group: 11/23/2003 12/5/2003 141 Description of Operations Rig down and moved off 2P-432, prepared 2P-434 pad and set in matting boards, set in divertor spool, 21 1/4" divertor, knifevalve and 16" divertor line, set in wellhead Spot sub over well and set in rig complex's, rock washer and pipe shed Hooked up service loops, mud lines and berms around rig Fin. NU divertor system, mixed spud mud and started changing out saver sub on top drive to 5" DP. Accepted Rig at 17:30 Hrs, 11/23/03 Held Pre-Spud meeting at camp with both crews, service company personnel. Fin changing over top drive saver sub to 5" DP and mixing spud mud Performed function test on Diverter and Accumulator unit, good test, NOTE: Chuck Scheeve with AOGCC waived witnessing of test PU & MU 12 1/4" BHA #1, oriented and uploaded MWD Est circ filling hole and pressure tested surface lines to 3,500 psi, ck ok, held divertor drill and pumping of kill wt mud prior to spudding well Spudded well @ 06:00 hrs, drilled 12 1/4" hole per directional plan from 108' to 1,865' MD/1,845' TVD, (1,757') ART 9.1 Hrs, AST 2.7 Hrs, 10-20K wob, 80 rpm's, 150 spm, 630 gpm, off btm press 1,680 psi, on btm 1,800 psi, off btm torque 1 K ft-Ibs, on btm 3K ft-Ibs, rot wt 103K, up wt 101K, dn wt 104K, ave BGG 60 units Drill f/1 ,865' to 2,426' ART = 3.2 hrs AST = 1.2 hrs WOB 10/25K, 80 RPM, 635 gpm @ 1800 psi, UP 110K, DN 110K, ROT 110K, TQ on 5-6K, off 1-2K. Pump Hi-vis weighted sweep & circ hole clean w/11 0 RPM & 635 gpm. Monitor well, Back ream out of hole fl 2,426' to 1,292' wI 80 RPM & 635 gpm. Circ hole clean, Blow down top drive. Monitor well, POOH on elevators to BHA @ 1,107' Lay down Ghost reamer, Stand back HWDP & NMDC's, Drain motor, Break bit, Down load MWD, Lay down remaining BHA. Held PJSM with crews on running casing, Held Diverter drill while running casing. Clear floor, Rig & run 9.625" 40# BTC csg to 2,421' MD ( ran total 58 jts) - MIU hanger - MU landing jt, UP 125K, DN 115K. Circ BU wI Franks tool - Stage pumps up slowly to 6 bpm @ 400 psi. RID Frank's circu tool - Blow dn TD - MU DS cmt head Circu & Condition mud - Circu @ 6 bpm - Final 6 bpm = 300 psi Held PJSM with all crews on up coming cement job. Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.0 bpm @ 95 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 3.5 bpm @ 80 psi, Shut down and drop btm plug, Mix & pump 530 sxs (404.0 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wI additives at rate of 6.5 bpm @ 230 psi, Followed by 220 sxs (89.0 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI additives at rate of 5.2 bpm @ 180 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 155.0 bbls 9.3 ppg mud (total of 175.0 bbls to bump plug) at rate of 7.0 bpm @ 650 psi, Slowed rate to 3.0 bpm @ 400 psi for last 10 bbls of displacement, Bump plug w/11 00 psi, Floats held- OK, CIP @ 23:45 hrs 11/25/03, Had good returns thru out job, Printed: 1/20/2004 2:28:50 PM . . Page 2 of 6 GonocoPhillips Alaska Operations Summary Report Date 2P-434 2P-434 ROT - DRilLING Doyon Doyon 141 ! Sub From-To Hours Code Code Phase I ..____ ._......_. ._n __._ __ ___. _ _"_______ ...____."____ Description of Operations Reciprocate csg. 15' until cement to surface, Had 249 bbls good cmt returns to surface. UD CMT head - UD landing jt. NID Diverter Syst~m Install FMC Gen V 5K well head system - Orient per well plan Set BOP on well head. Install new BOP lifting system NIU BOPE - Change bttm rams to 5' pipe rams. Test BOPE - Test all BOPE & Choke manifold valves 250psi/5000k- Test annular 250 psil 5000k . No failures. AOGCC rep John H. Crisp witnessed test. Pull test plug, Install wear bushing. Pick up 81 jts. 5' drill pipe and stand back in derrick. Cut & Slip drilling line 65'. PJSM on picking up BHA & Loading R.A. sources. Make up 8-1/2' BHA, Program MWD, Load sources. Pick up 36 jts. 5" drill pipe & RIH to 2,225' Circ. btm's up for casing test. Rig & test 9-5/8' casing to 3500 psi for 30 min.- OK Finish testing 9-5/8' casing to 3500 psi. Drill out float collar @ 2,333', Cement & Shoe @ 2,421', Clean out rate hole to 2,426', Drill 20' new hole to 2,446'. Pump Hi-vis sweep, Change over to 9.6 ppg LSND mud. Rig & perform 18.1 ppg EMW wI 1041 psi, 2,356' TVD, 9.6 ppg mud. Drill f/2,446' to 2,523' WOB 5/20K, 90 RPM, 510 GPM @ 1700 PSI. Circ & Obtain PWD Base line.ECD clean hole base line 10.32 ppg wI 9.6 ppg mud. Drill f/ 2,523' to 3,235' ART = 6.6 hrs, AST = 0.6 hrs, WOB 5/20K, 90 RPM, 510 GPM @ 1700 PSI, UP 115K, DN 95K, ROT 110K, TO on 218K, off 213K, Control drilling rate at 150'lhr. to limit ECD's, ECD's ranging from 11.4 to 11.8 ppg, Pumping Hi-vis sweeps every 4 to 5 stands with 50-60% increase in large cuttings on sweeps. 12.00 DRILL DRLG INTRM1 Drill f/3,235' to 4,200' ART= 8.7 hrs, AST= 0.6 hrs, WOB 5/15K, 90 RPM, 510 GPM @ 2000 PSI, UP 150K, DN 125K, ROT 135K, TO on 3/8K, off 3/6K, Control drilling rate at 150'/hr. to limit ECD's, ECD's ranging from 11.4 to 11.8 ppg, Pumping Hi-vis sweeps every 3 to 4 stands with 50-60% increase in large cuttings on sweeps. Every third sweep has been WtJ hi vis sweep. 12.00 DRILL DRLG INTRM1 Drill f/4200' to 5288' ART = 8.0 hrs, AST = 0.8 hrs, WOB 5/20K, 90 RPM, 507 GPM @ 1900 PSI, UP 171K, DN 138K, ROT 153K, TO on 5-9K, off 24-8K, Control drilling rate at 150'/hr. to limit ECD's, ECD's ranging from 11.3 to 11.7 ppg, Pumping Hi-vis sweeps every 3-4 to stands with 25-30% increase in large cuttings on sweeps. Every third sweep is WTI Hi Vis. BGG av 30-35 units. 3.00 DRILL DRLG INTRM1 Drill f/5288' to 5508' ART = 1.75 hrs, AST = 0.6 hrs, WOB 5/20K, 90 RPM, 507 GPM @ 1900 PSI, UP 171K, DN 138K, ROT 153K, TO on 5-9K, off 24-8K, Control drilling rate at 150'/hr. to limit ECD's, ECD's ranging from 11.3 to 11.7 ppg, Pumping Hi-vis sweeps every 3-4 to stands with 25-30% increase in large cuttings on sweeps. Every third sweep is WTI Hi Vis. BGG av 30-35 units. 0.25 WELCTL OBSV INTRM1 Flow check well- Static, Record SPR's. 1.25 DRILL DRLG INTRM1 Drill f/5508' to 5535' ART = .75 hrs AST = .25 hrs, Had 4880 units gas from btm's up, Flow check well- OK. legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/25/2003 21:15 - 00:00 2.75 CEMENT PUMP SURFAC 11/26/2003 00:00 - 00:45 0.75 CEMENTPULD SURFAC 00:45 - 03:00 2.25 WELLSR NUND SURFAC 03:00 - 03:45 0.75 WELLSR NUND SURFAC 03:45 - 04:00 0.25 WELLSR NUND SURFAC 04:00 - 06:00 2.00 RIGMNT RGRP SURFAC 06:00 - 09:00 3.00 WELLSR NUND SURFAC 09:00 - 13:30 4.50 WELLSR SEOT SURFAC 13:30 - 14:00 0.50 WELLSR SEOP SURFAC 14:00 - 17:30 3.50 DRILL PULD SURFAC 17:30 - 18:30 1.00 RIGMNT RSRV SURFAC 18:30 - 18:45 0.25 DRILL SFTY SURFAC 18:45 - 21 :30 2.75 DRILL PULD SURFAC 21 :30 - 23:00 1.50 DRILL TRIP SURFAC 23:00 - 23:15 0.25 DRILL CIRC SURFAC 23:15 - 00:00 0.75 DRILL DEOT SURFAC 11/27/2003 00:00 - 00:15 0.25 DRILL DEOT SURFAC 00:15 - 01:30 1.25 DRILL DRLG SURFAC 01 :30 - 02:00 0.50 DRILL CIRC SURFAC 02:00 - 02:45 0.75 DRILL FIT SURFAC 02:45 - 03:45 1.00 DRILL DRLG INTRM1 03:45 - 04:00 0.25 DRILL CIRC INTRM1 04:00 - 12:00 8.00 DRILL DRLG INTRM1 12:00 - 00:00 11/28/2003 00:00 - 12:00 12:00 - 15:00 15:00 - 15:15 15:15 - 16:30 Start: Rig Release: Rig Number: Spud Date: 11/24/2003 End: 12/5/2003 Group: 11/23/2003 12/5/2003 141 Printed: 1/20/2004 2:28:50 PM . . Page 3 of 6 ConocoPhillíps Alaska Operations Summary Report Make mad pass fl 5535' to 5567' @ 200 ftIhr. Drill f/5567' to 5633' (TVD 5226') ART = .5 hrs AST = .25 hrs, Had connection gas of 4280 units on btm's up. Circ. & pump 2-30 bbl weighted sweeps at rate of 510 gpm @ 1800 psi, String in 10 ppb LCM into mud system, BGG 90 to 150 units, ECD's 11.1 to 11.3 ppg. Slow pump rate to 350 gpm - ECD of 10.0 ppg (PWD tool shut down), Increase rate to 420 gpm - ECD 10.7 ppg (PWD shut down again) hold rate for 5 min., Bring pump rate back up to 510 gpm & circ btm's up- Had 6200 units gas from ECD of 10.0 ppg & gas decreased to 5600 units from ECD of 10.7 ppg, Raise mud weight f/1 0.0 to 10.3 ppg. Shut pump down for 1 min., Circ btm's up- Had 3990 units gas on btm's up, BGG 80 to 100 units. Raise mud weight f/1 0.3 to 10.6 ppg pumping at rate of 480 gpm @ 1700 psi, ECD's 11.3 ppg. No mud loss. Shut pump down for 1 min., Circ btm's up- Had 2100 units gas on btm's up, BGG 60 to 80 units. Raise mud weight f/10.6 to 10.8 ppg pumping at rate of 440 gpm @ 1550 psi, ECD's 11.5 ppg. No mud loss. Finish raising mud weight f/1 0.6 to 10.8 ppg pumping at rate of 440 gpm @ 1550 psi, ECD's 11.5 ppg. No mud loss. Shut down pump f/10 min., Circ btm's up, Had 3400 units gas. Raise mud weight f/1 0.8 to 11.0 ppg, Pumping at rate of 390 gpm @ 1400 psi & 50 RPM, ECD's 11.8 ppg. Shut down pump f/10 min., Circ btm's up, Had 290 units gas. Shut down pump f/30 min., Circ btm's up, Had 540 units gas. Wipe hole 5 stands to 5169', Pulled at 25 ftImin. & RIH at 30 ftImin., Hole took proper fill, No tight hole- Hole in very good shape. Circ. btm's up- Had 1960 units trip gas. Raise mud weight f/11.0 to 11.2 ppg, Pumping at rate of 390 gpm @ 1400 psi & 30 RPM. Wipe hole 10 stands to 4735', Pulled at 25 ftImin. & RIH at 30 ftImin., Hole took proper fill, No tight hole- Hole in very good shape. Circ. btm's up- Had 760 units trip gas, Circ & monitor well. Drill f/5633' to 5714' (5298' TVD) ART = 2.0 hrs, WOB 5/12K, 80 RPM, 420 gpm @ 1700 psi, UP 180K, DN 140K, ROT 158K, TQ 7K. Circ btm's for samples at rate of 340 gpm @ 1200 psi, 80 RPM, Had 522 units gas on btm's up, Add LCM for minor losses +- 20 bph, ECD's 11.8 ppg. Raise mud weight f/11.2 to 11.4 ppg, Pumping at rate of 340 gpm @ 1150 psi & 30 RPM. Record SPR's, Spot 18 bbls of 40 ppb LCM pill on btm, Monitor well- Minor breathing. Wipe hole 15 stands to 4363', Pulled at 35 ftImin. & RIH at 30 ftImin., Gained 5.8 bbls on first 5 stands, then hole took proper fill on next 10 stands, No tight hole- Hole in very good shape. Circ btm's up, Stage pumps up to 300 gpm- hole started taking 60 bph, Slowed pump to 285 gpm with no losses, Trip gas 530 units, then down to 15 units, Lost total of 20 bbls while circ, Spot 25 bbls 40 ppb LCM pill on btm. Note: Lost total of 155 bbls mud in hole. 1.50 DRILL TRIP INTRM1 POOH for 7" casing, Pulling at 35 ftImin., Gained 6.0 bbls on first 5 stands, then hole taking proper fill, No tight hole- Hole in very."good Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-434 2P-434 ROT - DRILLING Doyon Doyon 141 Date Sub From - To Hours Code Code Phase 11/28/2003 16:30 - 17:00 0.50 DRILL CIRC INTRM1 17:00 - 18:00 1.00 DRILL DRLG INTRM1 18:00 - 19:30 1.50 DRILL CIRC INTRM1 19:30 - 20:45 1.25 DRILL CIRC INTRM1 20:45 - 21 :15 0.50 DRILL CIRC INTRM1 21:15 - 22:45 1.50 DRILL CIRC INTRM1 22:45 - 23:15 0.50 DRILL CIRC INTRM1 23:15 - 00:00 0.75 DRILL CIRC INTRM1 11/29/2003 00:00 - 00:45 0.75 DRILL CIRC INTRM1 00:45 - 01 :30 0.75 DRILL CIRC INTRM1 01 :30 - 02:30 1.00 DRILL CIRC INTRM1 02:30 - 03: 15 0.75 DRILL CIRC INTRM1 03:15 - 04:15 1.00 DRILL CIRC INTRM1 04:15 - 05:30 1.25 DRILL WIPR INTRM1 05:30 - 06:00 0.50 DRILL CIRC INTRM1 06:00 - 07:15 1.25 DRILL CIRC INTRM1 07:15 - 09:15 2.00 DRILL WIPR INTRM1 09:15 -11:30 2.25 DRILL CIRC INTRM1 11 :30 - 13:45 2.25 DRILL DRLG INTRM1 13:45 - 16:30 2.75 DRILL CIRC INTRM1 16:30 - 18:00 1.50 DRILL CIRC INTRM1 18:00 - 18:30 0.50 DRILL CIRC INTRM1 18:30 - 21:00 2.50 DRILL WIPR INTRM1 21 :00 - 22:30 1.50 DRILL CIRC INTRM1 22:30 - 00:00 Start: Rig Release: Rig Number: Spud Date: 11/24/2003 End: 12/5/2003 Group: 11/23/2003 12/5/2003 141 Description of Operations Printed: 1/20/2004 2:28:50 PM 'IW'" . Page 4 of 6 ConocoPhillips Alaska Operations Summary Report. shape. Continue to POOH to 4270' at rate of 40 ftImin. (Good fill), Observe well- Static, Pump dry job, Blow down top drive, POOH to BHA at 1114' at rate of 40 ftImin., Observe well- Static. Lay down Ghost reamer, Stand back HWDP & NMDC's, PJSM, Remove RASource, Flush BHA wI fresh water, Lay down remaining BHA. Clear rig floor. Pull wear bushing, Set test plug, Change top pipe rams to 7", Test door seals to 2500 psi. Rig to run 7" casing, Franks fill up tool, Bails, etc. PJSM wI all rig personal on running 7" casing. Run 7",26#, L-80, BTCM casing to 5,330', Running speed f/40-20 ftlhr., Stop and brake circ every 10 joints, Circ btm's up at 2421',3600', Circ. 1 hr. @ 4600',5010',5330', Only circ at 1.5 bpm with +-75% returns, Pipe displacement diminishing as run in hole, Lost total of 87 bbls running casing. Finish running 7" casing to 5686' at 20 ftIhr (Hole very free), Make up hanger & land casing at 5711'. UP 170K, DN 120K. Circ btm's up & condition mud wI fill up tool at of 1.5 bpm @ 275 psi (Btm's up gas 57 units), Stage pump rate from 1.5 bpm @ 275 psi to 3.0 bpm @ 400 psi, Lost 41 bbls mud while circ. Rig down Franks fill tool, Blow down top drive, Rig up Dowell cement head. Finish conditioning mud for cement job, Mud check before = Wt 11.3+, vis 60, PV 32, YP 24 Gels 8/12, After= Wt 11.3+, vis 53, PV 29, YP 19, Gels 7/10, Stage rate from 1.5 bpm @ 275 psi to 3.5 bpm @ 450 psi, Had minor loses- lost total of 26 bbls while eire, Had 97 units gas from shut down Installing cmt head, Hold PJSM with all rig personal for cmt job, Batch mix cement. 2.00 CEMENT PUMP INTRM1 Turn over to Dowell, Pump 5 bbls fresh water, Test lines to 3500 psi, Pump 40 bbls 12.5 ppg MudPUSH II at rate of 4 bpm @ 410 psi, Shut down drop btm plug, Pump 35.5 bbls (170 sxs) Class G cmt wI .03%B155, 0.4%D65, 0.2%gpsD47, 2.0%gpsD600G. 21b/bbl CemNET mixed at 15.8 ppg, Pumped at 4.0 bpm @ 410 to 330 psi, Shut down drop top plug, Displace cmt. w/1 0 bbls fresh water, followed by 202.8 bbls 11.3+ ppg mud at rate of 3.5 bpm @ 350 to 575 psi, Lost 35 bbls mud displaceing MudPUSH to shoe, Lost 17 bbls mud after MudPUSH rounded shoe, Lost 13 bbls mud after cmt rounded shoe, Bumped plug wI 1500 psi, C.I.P at 06:50 hrs 12/1/03, Reciprocated casing 15' and land just prior to bumping plug, Floats held -OK, No annulas flow after cmt in place, Calculated top of MudPUSH @ 3830', Calculated top of cement @ 4848'. Rig down Dowell cement head, Lay down landing joint. Set 7" packoff & test to 5000 psi f/1 0 min. Change top 7" rams back to 3-1/2" x 6", Change bails, Rig down all casing equip., Clear rig floor. Lay down excess 5" drill pipe from derrick except 18 stands for next well. Change saver sub from 5" to 4", Change btm pipe rams to 4". Rig & test BOPE to 250 psi low & 5000 psi high, Test waived by AOGCC John Crisp, Rig down test equip., Set wear bushing. Pick up 21 joints 4" drill pipe and stand back in derrick. PJSM, Make up 6-1/8" BHA Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To I Hours Code Sub Phase I Code 11/29/2003 22:30 - 00:00 1.50 DRILL TRIP INTRM1 11/30/2003 00:00 - 03:00 3.00 DRILL TRIP INTRM1 03:00 - 06:45 3.75 DRILL PULD INTRM1 06:45 - 07:15 0.50 WELCTL EaRP INTRM1 07:15 - 09:45 2.50 CASE RURD INTRM1 09:45 - 10:00 0.25 CASE SFTY INTRM1 10:00 - 00:00 14.00 CASE RUNC INTRM1 12/1/2003 00:00 - 00:45 0.75 CASE RUNC INTRM1 00:45 - 03:30 2.75 CEMENTCIRC INTRM1 03:30 - 04:00 0.50 CEMENT PULD INTRM1 04:00 - 05:15 1.25 CEMENTCIRC INTRM1 05:15 - 07:15 07:15 - 07:45 0.50 CEMENT PULD INTRM1 07:45 - 08:30 0.75 CASE DEaT INTRM1 08:30 - 10:00 1.50 CASE RURD INTRM1 10:00 - 14:00 4.00 DRILL PULD INTRM1 14:00 - 16:00 2.00 WELCTL NUND INTRM1 16:00-21:00 5.00 WELCTL BOPE INTRM1 21 :00 - 22:00 1.00 DRILL PULD INTRM1 22:00 - 00:00 2.00 DRILL PULD INTRM1 Start: Rig Release: Rig Number: Spud Date: 11/24/2003 End: 1V5/2003 Group: 11/23/2003 1 V5/2003 141 Description of Operations Printed: 1/20/2004 2:28:50 PM ..., - Page 5 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2P-434 Common Well Name: 2P-434 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/2/2003 00:00 - 03:00 3.00 DRILL PULD INTRM1 03:00 - 07:30 4.50 DRILL PULD INTRM1 07:30 - 08:45 1.25 DRILL CIRC INTRM1 08:45 - 09:45 1.00 CASE DEOT INTRM1 09:45 - 11 :00 1.25 DRILL DRLG PROD 11 :00 - 11 :30 0.50 DRILL CIRC PROD 11 :30 - 12:00 0.50 DRILL DRLG PROD 12:00 - 12:30 0.50 DRILL CIRC PROD 12:30 - 13:15 0.75 DRILL FIT PROD 13:15 - 14:15 1.00 DRILL CIRC PROD 14:15 - 20:45 6.50 DRILL DRLG PROD 12/3/2003 20:45 - 21:15 0.50 DRILL CIRC PROD 21:15 - 22:15 1.00 DRILL CIRC PROD 22:15 - 23:00 0.75 DRILL CIRC PROD 23:00 - 23:15 0.25 DRILL OBSV PROD 23: 15 - 00:00 0.75 DRILL CIRC PROD 00:00 - 01 :00 1.00 DRILL WIPR PROD 01 :00 - 02:00 1.00 DRILL CIRC PROD 02:00 - 06:00 4.00 DRILL TRIP PROD 06:00 - 09:15 3.25 DRILL PULD PROD 09:15 - 15:00 5.75 LOG ELOG PROD 15:00 - 18:00 3.00 CASE PULR PROD 18:00 - 23:00 5.00 CASE RUNL PROD 23:00 - 00:00 1.00 CASE CIRC PROD 00:00 - 00:45 0.75 CASE CIRC PROD 00:45 - 01 :30 0.75 CASE RUNL PROD 01 :30 - 04:45 3.25 CEMENTCIRC PROD 12/4/2003 04:45 - 05:45 1.00 CEMENT PUMP PROD Start: Rig Release: Rig Number: Spud Date: 11/24/2003 End: 12/5/2003 Group: 11/23/2003 12/5/2003 141 Description of Operations Finish picking up 6-1/8" BHA, Load R.A sources, Program MWD, Pick up 4" HWDP, Surface test MWD. Pick up 4" drill pipe to 5630'. Circ. & change over to 9.6 ppg LSND mud. Rig & test 7" casing to 3500 psi f/30 min.- OK. Drill out Float collar @ 5630', Cmt, Shoe @ 5711', Cmt to 5714'. Observe well- Static, Circ btm's up at rate of 275 gpm @ 1500 psi, Btm's up gas 35 units. Drill f/5714' to 5734' ADT=.2 hrs., WOB 5/1 OK, 65 RPM, 275 gpm @ 1500 psi, UP 125K, DN 100K, ROT 118K, TO 3/5K. Observe well- Static, Circ btm's up at rate of 275 gpm @ 1500 psi, Btm's up gas 390 units. Perform FIT to 12.6 ppg EMW with 800 psi, 9.7 ppg mud, 5295' TVD. Circ btm's up at rate of 300 gpm @ 1600 psi, Btm's up- gas 400 units mud cut to 8.3 ppg, Flow check well- Static, Circ btm's up- gas 165 units mud cut to 8.1 ppg Drill f/5734' to 6030' (5582' TVD) T.D., ADT= 5.0 hrs, WOB 10/15K, 80 RPM, 300 gpm @ 2300 psi, UP 140K, DN 109K, ROT 122K, TO 5K, Mud wt. 9.7 ppg, BGG +- 80 units, Connection gases f/150 to 400 units, Had 4000 units from connection @ 5963' MD, 5522' TVD. Circ & raise mud weight to 10.0 ppg. Shut down pump for 5 min., Circ btm's up- Had 300 units btm's up gas, Pump hi-vis weighted sweep around. Circ & raise mud weight to 10.3 ppg at rate of 300 gpm @ 1900 psi., BGG 35 units. Shut pump off & observe well for 15 min's.- well static. Circ. btm's up, No excess gas- BGG 35 units, No mud loss. Pump out to shoe @ 5711 wI 275 gpm @ 1500 psi & 65 RPM (Hole in very good shape- No tight hole), Observe well, RIH to btm @ 6030'. Circ btm's up wI 300 gpm @ 1900 psi- Trip gas 57 units, Pump Hi-vis sweep around, BGG 35 units, Observe well. Pump out to shoe @ 5711', Observe well, Pump dry job, POOH on elevators at rate of 40-45 ftImin. to BHA at 1113'. Stand back HWDP, Lay down NMDC's, PJSM, Remove R.A. Source, Down load MWD, Lay down remainder of BHA. PJSM, Rig Schlumberger wire line & run USIT log f/5510' to 4842', Rig down Schlumberger. PJSM, Rig & run 3-1/2", 9.3#, L-80 liner, Make up liner hanger UP 40K, DN 40K. RIH wI 3-1/2" liner to 7" shoe to 5647', Run liner at 50 ftImin., Fill pipe every 10 stands. Circ btm's up, Stage rate up to 3.5 bpm @ 500 psi, Btm's up gas 1980 units, No mud lost. Finish circ. btm's up At rate of 3.5 bpm @ 500 psi, Circ gas down to 35 units, Obtain UP wt of 109K, DN 92K, ROT 100K, TO 2500 ftIlb RIH wI liner to btm & tag btm at 6030', Pick up Baker cement head Circ & Condo mud for cement job, Stage rate up f/1.5 bpm to 4 bpm @ 625 psi, Btm's up gas- 137 units, No mud lost, Mud check before= Wt. 105, vis 50, PV 19 YP 23, After= Wt. 10.3+, vis 42, PV 15, YP 15, Obtain UP wt of 118K, DN 106K, ROT 107K, TO 2500 ftIlb, Held PJSM with all rig personal for cement job, Batch mix cement. Switch to Dowell, Pump 10 bbls 8.3 ppg CW1 00, Shut down & test lines to 4500 psi, Pump 10 more bbls CW1 00 at rate of 4.0 bpm @ 570 psi, Printed: 1/20/2004 2:28:50 PM / --, ,., A Page 6 of 6 ConocoPhillips Alaska Operations Summary . Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-434 2P-434 ROT - DRILLING Doyon Doyon 141 Date Sub From - To Hours Code Code Phase --------- ----- 12/4/2003 1.00 CEMENT PUMP PROD 04:45 - 05:45 05:45 - 06:00 0.25 CASE MIT PROD 06:00 - 07:45 1.75 CEMENTCIRC PROD 07:45 - 13:30 5.75 CEMENT TRIP PROD 13:30 - 14:30 1.00 DRILL PULD PROD 14:30 - 15:30 1.00 CMPL TN RURD CMPL TN 15:30 - 21 :00 5.50 CMPL TN RUNT CMPL TN 21 :00 - 22:00 1.00 CMPL TN SOHO CMPL TN 22:00 - 23:00 1.00 CMPL TN CIRC CMPL TN 23:00 - 00:00 1.00 CMPL TN SOHO CMPL TN 12/5/2003 00:00 - 01 :30 1.50 CMPL TN DEQT CMPL TN 01 :30 - 02:30 1.00 CMPL TN PULD CMPL TN 02:30 - 03:30 1.00 CMPL TN FRZP CMPL TN 03:30 - 04:30 1.00 CMPL TN NUND CMPL TN 04:30 - 07:00 2.50 CMPL TN NUND CMPL TN 07:00 - 08:00 1.00 CMPL TN FRZP CMPL TN 08:00 - 09:00 1.00 CMPL TN RURD CMPL TN 09:00 - 10:00 1.00 CMPL TN RURD CMPL TN 10:00 - 12:00 2.00 CMPL TN RURD CMPL TN Start: Rig Release: Rig Number: Spud Date: 11/24/2003 End: 12/5/2003 Group: 11/23/2003 12/5/2003 141 Description of Operations ---...--..-.----- Pump 25 bbls 11.5 ppg MudPUSH at rate of 3.5 bpm @ 600 psi, Pump 25 bbls (120 sxs) Class 'G' cmt mixed at 15.8 ppg wI .03%B155, .40%D65, .20%D47, 2.0%D600G, pumped at rate of 3.5 bpm @ 600 to 200 psi, Shut down, Wash lines to rig floor, Drop plug, Displace cmt wI 8.7 bbls seawater followed by 58.4 bbls 10.3 ppg mud (Note: Seen pressure spike when plug went thru top of liner and continued to pump 3.5 bbls to displace liner), Slowed rate to 2 bpm @ 750 psi for the last 10 bbls, Pumped plug wI 1500 psi, C.I.P at 05:45 hrs 12/4/03, Reciprocated csg. 15' until last 10 bbls of displacement, Had good circ thru out job. Continue to pressure up to 2500 psi to set hanger, Slack off 25K to check that hanger is set- OK, Pressure up to 4000 psi to release from liner, Bleed off & check floats holding- OK (Bleed back 1 bbl), Swith to rig pumps, Pressure drill pipe to 500 psi, Pick up 9' to expose dogs, Slack off 10 K to check dogs exposed- OK, Bleed off all pressure, Slack off 50K and set casing packer, Close Hydrill & pressure annulas to 1000 psi- OK, Bleed off pressure, pressure drill pipe to 500 psi, Pick up 5' until pressure bled off & Pick up an additional 5'. Circ btm's up at rate of 12.5 bpm @ 3000 psi, Had CW100, MudPUSH & 14.2 bbls cmt & cmt contaminated mud return to surface, Continue to circ pipe & hole clean with a total of 3 times btm's up, Swith to Seawater and change hole over to clean seawater. POOH & Lay down 4" drill pipe &Lay down liner running tool. RIH and lay down 4" HWDP. Pull wear bushing, Rig to run 3-1/2" completion string. Pick up completion jewelry, Pick up 3-1/2",9.3#, L-80, EUE 8rd tbg to 5525'. Rig up to circ, Work thru top of liner, Break circ & sting into SBE, Check space out. Displace well with clean seawater at rate of 7.6 bpm @ 930 psi. Make up space out pup & hanger, Land tbg and run in lock down screws. Rig & Preesure test tubing to 3500 psi f/30 min.- OK, Bleed tubing press. down to 1500 psi, Pressure test 7" x 3-1/2" annulas to 3500 psi fl 30 min.- OK, Bleed off tubing preesure & Shear out DCK-3 valve. Lay down landing joint, Break out pump in sub, Set 2 way check in tubing hanger. Rig & perform Injectivity test on 9-5/8" x 7" annulas, 752 psi, 11.3 ppg mud, 2356' TVD= 17.4 EMW, Flush annulas with 200 bbls fresh water followed by 60 bbls diesel to freeze protect. Nipple down BOPE, Change out Saver sub on top drive. Nipple up Tree, Test adapter void to 5000 psi f/1 0 min., Test tree to 250 low & 5000 psi high. Pull 2 way check, Pump 50 bbls diesel down 3-1/2"x 7" annulas at rate of 2 bpm @ 1475 psi, Put tubing and annulas in communication and let U-tube. Finish changing out saver sub, Grabbers, Pipe guide on top drive. Install BPV, Rig down circ hoses. Remove double annulas valve, Install Blind flanges wI valves, Suck out cellar, Remove and roll up hoses, Remove containment. Release Rig at 12:00 hrs 12/5/2003. Printed: 1/20/2004 2:28:50 PM Date 12/21/03 12/23/03 12/25/03 01/01/04 01/04/04 01/05/04 . 2P-434 Event History . Comment TAGGED ICE IN TREE [TAG,-ICE] TAGGED ICE @ 8' WLM [TAG] SET DGLV IN STA # 1 @ 5459' RKB (TEST TBG. AND IA TO 3000 PSI ). TAGGED TD @ 5904' SLM W/22' X 2.5 DUMMY GUN. PERFORATED: 5712'-5772', 5780'-5784', 5790'-5794' WITH 2.5" HSD/POWERJET/DP/6 SPF/60 DEG .- PHASING/RANDOM ORIENTATION -- ****TOOL SAVER BROKE AFTER FIRING 3RD GUN LEAVING THE 20' GUN AND SAFE ADAPTER IN THE HOLE (24.5')**** FOUND ICE IN TBG. @ 1764' SLM (CLEANED UP W/ HOT OIL) DRIFTED TBG. DOWN TO D-NIPPLE @ 5524' SLM. ATTEMPTED TO FISH E-LINE TOOLS ( ONLY RECOVERED WHAT LOOKS LIKE HOSE STUB FROM TOOL SAVER). ATTEMPT FISH PERF GUN, UNSUCCESSFUL. APPARENT FRAYED ElL ON FISH. MEASURE BHP @ 5782' RKB. [PRESSURE DATA] Page 1 of 1 1/21/2004 . ConocoPhillips ~Iaska, Ille;. 2P-434 . KRU SVC 6025 ftKB Odeg@ Bottom 108 2421 5711 6025 TVD 108 2421 5711 6025 - I OOUCTION Grade (0-5711, L-80 00:7.000, Interval TVD Zone Status Ft SPF Date Type Wt:26.oo) 5712 - 5772 5712 - 5772 60 6 1/1/2004 IPERF 5780 - 5784 5780 - 5784 4 6 1/1/2004 IPERF 5790 - 5794 5790 - 5794 4 6 1/1/2004 IPERF ~ ¡, i !II L G¡;I$...L.iftM¡;I!'ÌdtQJ$/V¡;I'VQ$ St I MD I TVD I Man I Man Type V Mfr 1 5459 5459 CA~~O KBG-2-9 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 23 23 HANGER 500 500 NIP 5508 5508 SLEEVE-C 5524 5524 NIP 5537 5537 LOCATOR 5538 5538 SEAL 5575 5575 TTL Other (plugs, equip., etc.) - LINER JEWELRY Depth TVD Type 5525 5525 PACKER 5544 5544 NIP 5546 5546 HANGER 5555 5555 COUPLING 5556 5556 SBE 5574 5574 BUSHING 6023 6023 SHOE V Type I!iII API: 501032046700 Well Type: TUBING '" SSSV Type: NIPPLE Orig Completion: (0-5575, Annular Fluid: Last W/O: 00:3.500, Reference Log: 28' RKB Ref Log Date: 10:2.992) Last Tag: 5904 ID: SURFACE Last Taç¡ Date: 12/25/2003 Max Hole Anç¡le: (0-2421, Casing String - ALL STRINGS 00:9.625, Description Size Top Wt:40.oo) CONDUCTOR 16.000 0 SURFACE 9.625 0 PRODUCTION 7.000 0 LINER 3.500 5524 SLEEVE-C (5508-5509, 00:4.500) NIP (5524-5525, 00:4.500) LOCATOR (5537-5538, 00:5.000) NIP (~, 00:5.500) COUPLING (5555-55&5. 00 557C) BUSHIt-J~; \557~5575 00 5 COO) DMY Description 3.5" FMC GEN V TUBING HANGER CAMeO 'DS' LANDING NIPPLE NO GO BAKER CMU SLIDING SLEEVE CAMCO 'D' NIPPLE NOGO BAKER G-22 LOCATOR SEAL ASSEMBLY BAKER 80-40 SEAL ASSEMBLY Description BAKER ZXP LINER TOP ISOLATION PACKER RS PACKOFF SEAL NIPPLE BAKER 5x7" FLEXLOCK LINER HANGER 5" TKC COUPLING BAKER 80-40 SEAL BORE EXTENSION XO BUSHING 2P-434 Angle @ TS: deg @ Angle @ TD: deç¡ @ Rev Reason: PERFS Last Update: 1/3/2004 Wt 62.50 40.00 26.00 9.30 Grade H-40 L-80 L-80 L-80 Thread WELDED BTC BTCMD SLHT Thread EUE8rdMOD Comment 2.5" HSD PJ, DP; 60 deg phase, random orientation 2.5" HSD PJ, DP; 60 deg phase, random orientation 2.5" HSD PJ, DP; 60 deg phase, random orientation TRO Vlv Cmnt 0 ID 3.500 2.875 2.810 2.750 3.000 3.000 2.992 ID 5.000 4.250 5.000 4.380 4.000 3.500 3.500 ConocoPhillips Alas.c.,slot #434 Drill Site 2P, Meltwater,North Slope, Alaska ðð3--)~ -.. SURVEY LlaG Page 1 Wellbore: 434 Wellpath: MWD <0-6030'> Date Printed: 11-Dec-2003 r~i. BAKER HUGHES INTEQ Well bore Name 434 I Created 25-Nov-2003 I Last Revised 8-Dec-2003 Well Name 434 I Government ID I Last Revised 12-SeD-2003 Slot Name slot #434 I Grid NorthinQ 5868921.4465 I Grid EastinQ 443815.4241 I Latitude N70 3 9.1160 I LonQitude W150 26 58.6301 I North 955.98S lEast 1858.71E Ihstallation Name Drill Site 2P I Eastino Northina I Coord Svstern Name I North Alianment 441964.235 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Meltwater I Eastina Northina 441964.238 I Coord Svstern Name I North Alianment 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True RECEIVCD JAN2 3 2004 Alaska Oil & Gas Cons. Commission Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.27 degrees Bottom hole distance is 2020.89 Feet on azimuth 307.35 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated '=K~D\~~ """ ConocoPhillips AlasAc.,slot #434 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 2 Well bore: 434 Well path: MWD <0-6030'> Date Printed: 11-Dec-2003 "~i. BAKER HUGHES INTEQ Well path· (GridliRjport MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing rdeQ/100ftl Sectionrftl 0.0<;' 0.00 0.0<;' O.OQ 0.001\, O.OOF O.OC 0.0<;' 44381504; 5868921A~ 1 08.0( 0.00 O.OQ 108.0C, 0.001\, O.OOF O.OQ 0.0<;' 44381504; 5868921A~ 206.92 0.59 248.1:; 206.92, 0.19S OA7W 0.60 0.26 443814.9~ 5868921.21 301.81; 0.37 277.6!;, 301.81; 0.3351 1.23W 0.34 0.7/3¡ 443814.1t 5868921.1; 390.7( 0.57 270.8( 390.6!;, 0.2951 1.961/1{ 0.2~ 1.3e, 443813A~ 5868921.1" 480.9:; 0.63 294.0:; 480.9¿' 0.08S 2.86W 0.28 2.23 443812.5" 5868921.3! 572.9" 0.7'- 290A!;, 572.9( 0.331\, 3.86W 0.11 3.27 443811.5' 5868921.8· 663 A!;, 0.70 286041; 663.41; 0.691\, 4.92W 0.06 4.33 443810.5( 5868922.1' 755.1' 0.72 286.57 755.0E 1.011\. 6.01W 0.02 5AC 443809.4: 5868922.5( 844.8€ 0.92 292.3~ 844.8L 10441\, 7.22W 0.24 6.62 443808.2; 5868922.9' 935.67 4.31 308.9~ 935.5" 3.871\, 10.55V1 3.7~ 10.7¿ 443804.9' 5868925.3! 1025.21 6.69 311.7~ 1024.7~ 9.461\. 17.06V1 2.67 19.3' 44379804: 5868931.0: 1124.6: 6.37 312.9( 1123.4¡ 17.061\, 25A2V1 0.3~ 30.51; 443790.1 ~ 5868938.6! 1217.3~ 6.22 306.4( 1215.6; 23.551\, 33.23V1 0.7& 40.7' 443782.3' 5868945.2' 1309.81 6.95 303.5£ 1307A~ 29.611\. 41.93V1. 0.86 51.3(, 443773. 7~ 5868951.31 1403.1' 9.23 301.a¿" 1399.8( 36.671\, 52.99V1 20461 64.3~ 443762.7' 5868958.5' 1496.0( 12.661 304.2( 1490.9~ 46.331\, 67.74V1 3.n 81.91; 443748.0- 5868968.2" 1588.6~ 15.05 30704:; 1580.9~ 59.351\. 85.691/\ 2.71 104.1:; 443730.11, 5868981.4: 1681.2: 16.661 308.6!;, 1669.9~ 74.951\, 105.6011\ 1.7/3¡ 12904" 443710.3t 5868997.1" 1774.2~ 17.9C. 309041; 1758.S<! 92.381\, 127.0511\ 1.361 157.0~ 443689.0~ 5869014.7~ 1867.4¡ 19.87 310.0(', 1846.9~ 111.671\ 150.22V1 2.13 187.1(', 443666.0! 5869034.2' 1960.0' 20.961 308.27 1933.7: 132.051\ 175.2611\ 1.361 219A¿" 443641.1t 5869054.7" 2053.5: 22.04 307.8" 2020.7¿ 153.171\ 202.2611\ 1.17 253.7' 443614.3; 5869076.0~ 2146.0~ 23.98 309AE 2105.8~ 175.761\ 230.48V1 2.21 289.8£ 443586.2: 5869098.8! 2238.5' 24.97 309.31; 2190.0! 200.091\ 260.0711\ 1.07 328.1¿ 443556.8~ 586912304: 2331.5: 24.52 306.4€ 2274.5: 224.031\ 290.7811\ 1.3& 367.07 443526.3~ 5869147.5! 2354.8' 24.55 305.8' 2295. 7~ 229.731\ 298.59V1 1.20 376.72 443518.5: 5869153.3! 2512.4~ 25.12,. 306.8€ 2438.8( 268.981\ 351.9311\ 0046 442.9~ 443465.5: 5869192.9! 2604.4f 24.9~ 306.3~ 2522.1: 292.211\ 383.1611\ 0.29 481.87 443434A~ 586921604· 2697.9¡ 25.95 306.37 2606.5¡ 316.031\ 41504911\ 1.07 522.0~ 443402.3: 5869240.5( 2790.2¡ 27.51 307.QJ.., 2688.9~ 340.851\ 448.7711\ 1.72- 563.5~ 443369.2: 5869265.51 2883.7' 27.24 307.2:;' 2771.9£ 366.801\ 483.0411\ 0.3Q 606.5" 443335.1 ~ 5869291.71 2976.7~ 27.02,. 307.8:; 2854.8- 392.651\ 516.7011\ 0.38 648.9(', 443301.6t 5869317.81 3068.6- 26.661 307.7!;. 2936.7¿ 418.061\ 549.46V1 0.39 69004" 443269.1' 5869343.5( 3161.8~ 26.0:;' 307.5~ 3020.3( 443.341\ 582.2211\ 0.6/3¡ 731.8( 443236.5~ 5869369.0; 3254.5¡ 26.27 307.7(, 3103.4~ 468.281\ 614.5611\ 0.27 772.51- 443204A~ 5869394.2( 3347.5i 27.561 307.7!;. 3186A~ 494.051\ 647.8711\ 1.3~ 814.71; 443171.21, 5869420.2; 3441.3~ 27.3C, 306.9~ 3269.6~ 520.271\ 682.2111\ 0047 857.91; 443137.1' 5869446.6! 3533.7~ 27.19 308.0~ 3351.8. 546.021\ 715.76V1 0.53 900.2£ 443103.71 5869472.6" 3626.7i 27.04 307.9( 3434.51- 572.101\ 749.1911\ 0.17 942.6~ 443070.5~ 5869499.0( 3718.5~ 26.84 307.5- 3516.4~ 597.541\ 782.1011\ 0.2~ 984.2~ 443037.8~ 5869524.6 3812.3: 26.62, 307.3£ 3600.2- 623.171\ 815.5911\ 0.24 1026.4. 443004.5~ 5869550.5( 3903.6: 26049 306.8~ 3681.81 647.801\ 848.1511\ 0.29 1067.2¿ 442972.11 5869575.4: 3997.9f 26.12 306.6( 3766.4<! 672.801\ 881.6511\ 0.41 1109.Q¿ 442938.8< 5869600.6t 4091.0~ 27.3C 306.6E 3849.5~ 697.751\ 915.21V1 1.27 1150.8~ 442905.41, 5869625.8( 4183.8: 28.19 307 .3~ 3931.7( 723.771\ 949.7211\ 1.01 1194.0~ 442871.11 5869652.1 : 4276.6( 27.64 307.2C, 4013.6£ 750.071\ 984.2811\ 0.6<;' 1237.5( 442836.8t 5869678.61 4369.3~ 27.3(, 306.6£ 4095.9~ 775.761\ 1018.4711\ 0.46 1280.2~ 442802.8' 5869704.6: 4462.4( 26.77 305.57 4178.8~ 800.701\ 1052.6511\ 0.761 132?5i 442768.8' 5869729.8· 4555.5¡ 26.81 306.3( 4261.9Æ 825.331\ 1086.6311\ 0.361 1364.5: 442735.0; 5869754.61 4647.8~ 26.5C 308.7C, 4344.5~ 850.541\ 1119.5011\ 1.21 1405.9( 442702.3~ 5869780.1/ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.27 degrees Bottom hole distance is 2020.89 Feet on azimuth 307.35 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .. ConocoPhillips AlasAc.,slot #434 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 3 Well bore: 434 Wellpath: MWD <0-6030'> Date Printed: 11-Dec-2003 "~i. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing IdeQ/100ftl Sectionlftl 4740.4i 25.9Q 308.8~ 4427.6( 876.151\ 1151.36\0\ 0.6~ 1446.8; 442670.6" 5869805.91 4833.6t 26.6Ç. 308.5!;, 4511.1~ 901.931\ 1183.52\0\ 0.77 1488.0¡ 442638.7~ 5869832.0( 4926.5i 27.72, 307.74 4593.8l 928.121\ 1216.89\0\ 1.28 1530.4~ 442605.5< 5869858.4: 5019.4¡ 27.3~ 307.9~ 4676. H 954.481\ 1250.80\0\ O.4Q 1573.3~ 442571.8; 5869885.0: 5111.8t 26.67 308.1( 4758.5' 980.371\ 1283.88\0\ 0.77 1615.31 442538.9' 5869911.11 5205.1i 25.99 308.9' 4842.1l 1006.13f\ 1316.27\0\ 0.82- 1656.7~ 442506.7' 5869937.1~ 5297.7¡ 26.04 307.9~ 4925.3' 1031.37f\ 1348.06\0\ 0.44 1697.3-< 442475.1' 5869962.6; 5391 .O~ 26.42- 307.9' 5009.0' 1056.72f\ 1380.58\0\ 0.41 1738.5( 442442.8' 5869988.2: 5484.0C 26.10 306.5E, 5092.3~ 1081.62f\ 1413.331/\ 0.72 1779.7' 442410.2! 5870013.31 5574.7~ 26.3:.' 306.2, 5173.81 1105.42f\ 1445.61\0\ 0.31 1819.8' 442378.1 t 5870037.3! 5629.8t 26.61 306.1 ~ 5223.1 ~ 1119.91 f\ 1465.42\0\ 0.51 1844.3( 442358.4t 5870052.0: 5797 .8~ 26.42 307.5E 5373.4~ 1164.88f\ 1525.421/\ 0.39 1919.3, 442298.7! 5870097.4: 5887.Oi 25.9& 307.1 ~ 5453.5' 1188.79f\ 1556.74\0\ 0.5:.' 1958.7~ 442267.6t 5870121.51 5949.4' 25.7" 306. 7~ 5509.6' 1205.13f\ 1578.45\0\ 0.4~ 1985.9' 442246.01 5870138.0' 6030.0( 25.72 306.78 5582.2~ 1226.07f\ 1606.471/\ 0.00 2020.8~ 442218.2~ 5870159.2· All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.27 degrees Bottom hole distance is 2020.89 Feet on azimuth 307.35 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocoPhillips AlasAc.,slot #434 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 4 Well bore: 434 Well path: MWD <0-6030'> Date Printed: 11-Dec-2003 r'¡. BAKER HUGHES INTEQ Comments MDrftl ITVorftl J Northrftl I Eastlftl I Comment 6030.od 5582.2 1226.07t-~ 1606.47WProiected Data - NO SURVEY Hole·.Sections Diameter Start Start finl Morftl TVorftl 121/< 108.0(, 8 1/" 2426.0( 6 1/S 5714.0( Start Northrftl 108.0(, 0.001\, 2360.3~ 247.221\ 5298.3~ 1142.291\ Start End End End Start Wellbore Eastlftl Morftl TVorftl Northrftl Eastlftl O.OOE 2426.0( 2360.3~ 247.221\ 322.6211\434 322.6211\ 5714.0( 5298.3~ 1142.291\ 1495.6611\ 434 1495.6611\ 6030.0( 5582.2~ 1226.071\ 1606.4711\434 Càsinas Name Top Top Top Morftl TVDrftl Northrftl O.OC. 0.00 0.001\, O.oc, 0.00 0.001\, 0.0c. 0.00 0.00f\. 5546.4" 5148.3~ 1097.981\ Top Shoe Shoe Eastlftl MDrftl TVorftl O.OOF 108.0( O.OOE; 2421.0( O.OOF 5711.0( 1435.4711\ 6025.0( 108.0C, 2355.8~ 5295.7' 5577.7" Shoe Shoe Wellbore Northrftl Eastlftl 0.00f\. O.OOF 434 245.98[\, 320.9311\ 434 1141.491\ 1494.5911\ 434 1224.771\ 1604.7311\434 16" Conductor 9 5/8" Casinq 7" Casino 5" x 3 1/2" Liner All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.27 degrees Bottom hole distance is 2020.89 Feet on azimuth 307.35 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Re: 2P-434 (203-153): Cementing and bond logs . . Subject: Rc: 2P-434 (203-153): Cementing and bond logs From: Thomas Maunder <tom_maunder~&admil1.statc.ak.us> Datc: Tue, 09 Dee 2003 14:23:52 -0900 To: "I-layden, Philip" <Philip.l-Iayden(q)eonocophillips.eom> CC: "Jackson, Darron B." <darron.bjackson(@col1ocophillips.com> Philip and Darron, I concur with the assessment of the USIT log on 2P-434. The character change defining the TOC is pretty evident at 5140'. Running the log after drilling did give you the opportunity to see nearly all the casing, so I am surprised that the log didn't go somewhat deeper. I understand not wanting to run out into the open hole, but I thought you might have gone "closer". Based on the quality of the cement in the lower logged intervals, it is reasonable to presume that similar or better quality is in the deeper intervals. Isolation bet\t.een the Cairn and Bermuda is denmnstrated. It will not be necessary to run a cement quality log in the 3-1/2" liner. Tom Maunder, PE AOGCC þ~~ \ "). (<;. - 0 ';> Hayden, Philip wrote: Tom, We ran the USIT log after drilling out and on to TD but before running the 3 1/2" liner. Attached is an electronic copy of the USIT log. Our assessment of the bond log quality is that the cement coverage is adequate with good bond to 5140 ft MD approximately. Philip -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 08, 2003 2:16 PM To: Hayden, Philip Cc: Jackson, Darron B. Subject: Re: 2P-434: Cementing and bond logs Philip and Darron, Operationally what you describe regarding the cementing operations should be acceptable. I presume that the bond log was run prior 10f3 12/9120032:28 PM Re: 2P-434 (203-153): Cementing and bond logs . . to drilling out. Is that correct?? What was your assessment of the bond quality in the interval that could be logged. You can email me the bond log if you wish and have the e-copy. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, We are currently preparing to move off 2P-434 to got to 2P-447 so I would like to bring you up to speed on events on this last well and our proposed plan forward. The attached file contains a schematic as it is today. Note that we have placed the shoe of the 7" casing into the very top of the Bermuda interval. The cement job was a success; pumped 35.5 bbls of 15.8 ppg Gasblok slurry, lost 13 bbls of fluid after the cement had rounded the shoe. We ran a USIT log on the 7" and found the TOC to be 5140 ft MD - approximately 330 ft MD above the top of the Cairn interval where we had our first indication of pressured gas (presumed MI at this point in time) . We successfully drilled the reservoir interval with a 6 1/8" bit. Ran and cemented our 3 1/2" liner with 25 bbls of 15.8 ppg Gasblok slurry with no observed losses. After setting the liner hanger packer we circulated out approximately 14 bbls of cement and cement contaminated mud from the liner top. After having successfully cemented both the 7" casing and 3 1/2" liner and verified that success with the USIT log in the 7" and the cement circulated from the liner top in the 3 1/2" we would like to forego the running of a bond log in the 3 1/2" liner as we feel we have adequately proven the confinement of the injection zone. Of course we have the 7" USIT log available for your convenience should you wish to review it. Regards Philip «2P-434 12-05-2003.ppt» 2 of3 12/9120032:28 PM · . 2P-434 12/05/03 16" @ 108' MD I TVD - J 9 5/8" @ 2421' MD / 2356' TVD TOC @ 5140' MD a; _ Top Cairn @ 5470 ' MD 3 ~" Liner Top @ 5525' MD Top Bermuda @ 5710' MD Approximately 7" @ 5711' MD I 5295' TVD 3 ~" @ 6025' MD I 5578' TVD n .... , { ! , , , , , , , I . lli1 !Æ !Æ~ - !Æ . / / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field 2P-434 ConocoPhillips (Alaska), Inc. Pennit No: 203-153 Surface Location: 957' FNL, 1855' FWL, Sec. 17, T8N, R7E, UM Bottomhole Location: 286' FSL, 228' FWL, Sec. 8, T8N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). t:re1Y, ~~ Rand:2edriCh Commissioner BY ORDER OF THE COMMISSION DATED this..f. day of September, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section Conoc~hillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com September 2, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permits to Drill, Meltwater Injectors, 2P-434 and 2P-447 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for onshore injection wells 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 both of these wells. The expected spud dates are as follows: 2P-434 November 24, 2003 2P-447 January, 2004 If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, \<.~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ORIGINAL 1a. Type of Work: Drill0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: It . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 RedrillU 11 b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 957' FNL: 1855' FWL: Sec. 17, T8N, R7E, UM . Top of Productive Horizon: 191' FSL, 352' FWL, Sec. 8, T8N, R7E, UM Total Depth: . 286' FSL, 228' FWL, Sec. 8, T8N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 443815 16. Deviated wells: Kickoff depth: 900' 18. Casing Program Size Hole 42" 12.25" 8.5" 8.5" Casing 16" 9.625" 5.5" 3.5" 19 Total Depth MD (It): Casing Structu ral Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat D y- 5868921 Zone- ft. Maximum Hole Angle: 26.94° AifŠ ExploratoryU Development Oil U Multiple Zone D Service 0 . Development Gas D Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 2P-434 6. Proposed Depth: 12. Field/Pool(s): MD: 6087' TVD: 5621' Kuparuk River Field 7. Property Designation: L 32092) 8. Land Use Permit: ,p> ADL 373112 9. Acres in Property: 5760 10. KB Elevation 4 252' AMSL feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 1854 psig Setting Depth Weight 62.5# 40# 15.5# 9.3# Specifications Top Bottom Grade Coupling Length MD TVD MD TVD H-40 Weld 80 28' 28' 108' 108' L-80 BTC 2401 28' 28' 2429 2360 L-80 BTCM 5277 28' 28' 5305 4924 L-80 EUE8RDM 782 5305 4924 6087 5621 PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Meltwater Oil Pool 13. Approximate Spud Date: 11/24/2003 14. Distance to Nearest Property: 5471 @ Target 15. Distance to Nearest Well within Pool: 2P-432, 37.16 I Max. Surface Pressure: 1254 psig Quantity of Cement c. f. or sacks (including stage data) 90 sx ArticCRETE (preinstalled) 526 sx ASLite & 220 sx LiteCrete 295 sx Class G (Included above) (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD Length Size ¡rerfOration Depth TVD (ft): Drilling Program0 Timev. Depth PlotU Seabed Report D Drilling Fluid Program 0 Date: BOP SketchU Diverter Sketch D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name R. Thomas ~~~ Commission Use Only Permit to Drill I API Number: ~ /. I Permit Approval Number: ,2Q.6 - /53 50- / D:3 .. 2.l) '''/b 7· lù Date: Conditions of approval: Samples required DYes ~o Hydrogen sulfide measures DYes WNO Signature Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 Contact Philip Hayden 265-6481 Title Kuparuk Drilling Team Leader Phone -4:, ')6?3 ~ð Date ~ (,lo·J PreDared bv Sharon Al/suD-Drake Mud log required Directional survey required Isee cover letter for other requirements DYes ß[ No ~Yes D No Date: ~/ryO] Other: \'\ \"\ ~ <:J.L""'-C1S'\.\- Cy'-.)C.\\~ì \c~ ~50a~.;1. t-^-.\ "\~~Ñ'o. \Sa~ ~'>~ p ~ ÆP ~ BY ORDER OF Approved by: ~ J~. 0 --- ~1l)iN AHtOMMISSION Form 10-401 Revised 3/2003. tJ Submit in duplicate e A_. . ation for Permit to Drill, Well 2P-434 .., Revision No.O Saved: 29-Aug-03 Permit It - Meltwater Well #2P-434 Application for Permit to Drill Document MoximizE Well Vatu ~ 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. Dri II i ng 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 ...................................................................................5 Requirements of 20 AAC 25.005(c)(7) .. ....... ....... .... ....... ............ ................... ............... ....... ................... 5 8. Dri II i ng FI u id Program .................... ........... ................ ............... ............. ............. ....... .................... .... 6 Requirements of 20 AAC 25.005(c)(8) .......... ............. ..... ........ ............. ............ ......... ....................... ...... 6 Surface Hole Mud Program (extended bentonite) ..................................................................................6 Production Hole Mud Program (LSND) .... ..... ........... ..... ............... ..... ..... ............... .... ....... ......... ..... ........ 6 9. Abnormally Pressured Formation Information ......................................................6 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................6 10. Seism ic Analysis ............. ............ ........... ... .... ......................... ......... ............ .............. ................. ............ 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................7 12. Evidence of Bonding ............................................................................................... 7 2P-434 PERMIT IT. doc Page 1 of 8 Printed: 29-Aug-03 I 51 e ~ation for Permit to Drill, Well 2P-434 . Revision No.O Saved: 29-Aug-03 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 7 13. Proposed Drilling Program ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments .......... ............. ....... ............... ....... ................... ........... ............... ...... ...... 8 Attachment 1 Directional Plan (13 pages) .............................................................................................. 8 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 8 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 8 Attachment 4 Well Schematics (1 page) ................................................................................................ 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b/ For a well with multiple well branches, each branch must similarly be identified by a unique name 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-434. 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 already on file with the commission and identified in the application: (2) a plat identifying the propetty and the propetty'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. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National OCeanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective fonnation and at total depth; Location at Surface NGS Coordinates Northings: 5,868,921 Eastings: 443,815 957' FNL, 1855' FWL, Section 17, TaN, R7E, UM I RKB Elevation I 252' AMSL Pad Elevation 224' AMSL Location at Top of Productive Interval (Bermuda Sand) NGS Coordinates Northings: 5,870,080 191' FSL, 352' FWL, Section 8, T8N, R7E, UM Eastings: 442,317 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 5,742 5,314 5,062 Location at Total Depth NGS Coordinates Northings: 5,870,176 Eastings: 442,193 286' FSL, 228' FWL, Section 8, T8N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6,087 5,621 5,369 and ~ r 2P-434 PERMIT IT. doc Page 2 of 8 Printed: 29-Aug-03 e ~ation for Permit to Drill, Well 2P-434 . Revision No.O Saved: 29-Aug-03 (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect 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 wellbore, including all adjacent wellbores within 200 feet of any portion of the propos-ed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (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 applicabon for a Permit to DJiIl must be accompanied by each of the following item~ except far an item already an file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.03~ 20 AAC 25.03(i or 20 AAC 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-434. 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 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: (4) information on dlil/ing hazard~ including (A) the maximum downhole pressure that may be encountered, criteria used to determine it; and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Bermuda sands in the 2P-434 area vary from 0.27 to 0.34 psi/ft, ". or 5.2 to 6.5 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 1254 psi, calculated as follows: MPSP =(5452 ft)(0.34 - 0.11 psi/ft) = 1254 psi . (B) data on potential gas zones; Due to the presence of high annular pressures on some of the Meltwater wells (2P-431, 451 & 438) there is the risk of encountering a pressured shallow zone. This interval may be encountered through the C-80 and C-37 formations. 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 1245 / Well Surface Pressure 1600 1380 879 Fluid Level 2387 2160 895 C-80 Equivalent Gradient (ppg) 13.85 12.23 9.83 Surface Pressure 1260 940 820 08/22/2003 Fluid C-80 C-80 Equivalent Level Pressure Gradient (ppg) 1822 1473 11.66 2281 1074 8.53 682 1244 9.83 2P-431 2P-451 2P-438 2P-434 PERMIT IT.doc Page 3 of 8 Printed: 29-Aug-03 e ~ation for Permit to Drill, Well 2P-434 ,. Revision No.O Saved: 29-Aug-03 Using the latest annular pressures available the highest pressure that would be expected is approximately v 1480 psi at 2435 ft lVD or 11.7 ppg EMW. Most of the previously drilled Meltwater wells 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. Further annular bleeds are planned to take place before spud in order to reduce further the potential maximum pressure that could be encountered in the C-80 and C-37 intervals. 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 tests, as required under 20 MC 25. 030(f}; 2P-434 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 Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 MC 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 lineI'¡ pre- pelforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm CsglTbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 Cemented to surface with 90 sx ArticCRETE 95/8 12 V4 40 L-80 BTC 2401 28 / 28 2429 / 2360 Cement to Surface with 526 sx ASLite Lead, 220 sx LiteCRETE Tail 51/2 8 V2 15.5 L-80 BTCM 5277 28 / 28 5305 / 4924 Cement Top planned @ 3 V2 81/2 9.3 L-80 EUE8RD 782 5305/ 4924 6087/5621 5005' MD / Mod 4657' lVD. Cemented w/ 295 sx Class G 2P-434 PERMIT IT.doc Page 4 of 8 Printed: 29-Aug-03 e ~ation for Permit to Drill, Well 2P-434 ,., Revision No.O Saved: 29-Aug-03 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: (7) a diagram and description of the dlverter system as required by 20 AAC 25. 035, unless this requirement Is waived by the commission under 20 AAC 25.035(h)(2); A 21 %", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2P-434. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 2P-434 PERMIT IT.doc Page 50t8 Printed: 29-Aug-03 e 1A;ation for Permit to Drill, Well 2P-434 .. Revision No.O Saved: 30-Aug-03 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 flle with the commission and identifled in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Suñace Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.6 ~9.2 Funnel Viscosity 250 250 (seconds) Yield Point 35-45 35-45 (cP) pH 9-9.5 9-9.5 API Filtrate 6 6 (cc / 30 min)) Chlorides (mg/I) <600 <600 *9.6 ppg if hydrates are encountered Production Hole Mud Program (LSND) 95/8" Casing Shoe to TD Initial Value Final Value 9.6 9.6 22-28 10-15 9-9.5 9-9.5 4-6 4 Density (ppg) Yield Point (cP) pH API Filtrate (cc/30min)) HTHP @ 15cf (cc)) <12 <12 Base of Permafrost to 9 5/8" Casing Point Initial Value Final Value ~9.2* 9.6 150-200 55-65 30-35 12-15 9-9.5 4-6 <600 9-9.5 4-6 <600 I Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 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 identifled in the application: (9) for an exploratory or strati.qraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 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 ¡tem~ except for an Item already on file with the commission and identifìed in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a),· Not applicable: Application is not for an exploratory or stratigraphic test well. 2P-434 PERMIT IT. doc Page 6 of 8 Printed: 30-Aug-03 e ~ation for Permit to Drill, Well 2P-434 ... Revision No.O Saved: 29-Aug-03 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 structure, jack-up ri{b 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 a/1 item already 0/1 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 following 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 V4" 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 2429' MD / 2360' 1VD as per directional plan. Run MWD tools as required for directional monitoring and L~ tools 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. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutêš 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 V2" X 3 V2" casing point at 6087 MD / 5621' 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. ~t2/~6"5 40/;<0/ þé)l// /¥G'K.. ~7> 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 11. Freeze protect well with diesel by pumping into tubing, taking returns from annulus 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). 14. Run cement bond log and perforate. Rig down wire line unit. 2P-434 PERMIT IT. doc Page 70t8 Printed: 29-Aug-03 e ~ation for Permit to Drill, Well 2P-434 . Revision No.O Saved: 29-Aug-03 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 Identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator li7tends to request authorization under 20 MC 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 v' 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-434 for annular disposal of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 Directional Plan (13 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) 2P-434 PERMIT IT. doc Page 8 of 8 Printed: 29-Aug-03 e e Structure: Drill Site 2P ConocoPhillips Alaska, Inc. Well: 434 ./ ConocoPhillips Created by bmichael For: P Hayden Date plotted: 27-Au9-2003 Plot Reference is 2P-434 Versfon #9.8. Coordinates ore in feet reference slot #434_ True Vertical Deplhs or-e reference RKB (Doyon 141). JNTEQ ""-_..~_...,..--------,-- 350 - 0 - 350 - 700 - 1050 - 1400 - ,.-.., 1750 - +- Q) Q) '1- 2100 - ........... ..c +- Q.. Q) 2450 - £::) 0 2800 - Ü +- .... Q) > 3150- Q) :::¡ .... 3500 - l- I V 3850 - 4200 - Field: Meltwater 1Iii. .... i RKB Elevation: 252' KOP . 2.00 n 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 P 10.00 Bose ermafrost 12.00 14.00 16.00 18.00 20.00 22.00 Base West Sak 24.00 26.00 EDC 9 5/8 CSG c8b C50 C40 C37 TANGENT ANGLE 4550- 26.94 DEG Location : North Slope, Alaska ---~ --"---"--'~-'---'-----'"-'--~---"------'--"------'- 307.27 AZIMUTH 1894' (TO TARGET) ***Plane of Proposal*** T7 4900- 5 1/2 X 3 1/2 XO T4.1 (Top Cairn) 5250 - 5600 - 5950 350 2P-434 Top Berm Tgl 22 Jul 03 o 350 700 1050 1400 1750 2100 2450 2800 3150 T3 (Top Bermuda) T2 (Base Bermuda) C3~ (Top Albian) TO, Csg PL Vertical Section (feet) -> Azimuth 307.39 with reference 0.00 N, 0.00 E from slot #434 Created by bmichael ConocoPhillips Alaska, Inc. Well : 434 ¥ ConocoPhillips For: P Hayden Date plotted; 27 -Aug-2003 Plot Reference is 2P-434 Version #9.B. Coordinates ore in feet reference slot #434. Vertícol Depths are reference RKB (Doyon Structure : Drill Site 2P Field : Meltwater Location : North Slope, Alaska ... .... INTEQ <- West (teet) 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 o I TD LOCATION: I 286' FSL. 228' FWL SEC. 8, T8N, R7E C35 (Top Albian) T2 (Base Bermuda) T3 (Top Bermuda) 2P-434 Top Berm Tgt 22 Jul 03 (Top Cairn) I TARGET LOCATION: I 191' FSL, 352' FWL SEC. 8, T8N, R7E 307.27 AZIMUTH 1894' (TO TARGET) "'Plane of Proposal»> ~ TRUE CSG Base Permofros I SURFACE LOCATION: I . 957' FNL, 1855' FWL SEC. 17, T8N, R7E 100 OP - 1300 - 1200 - 1100 - 1000 - 900 - 800 ^ I - 700 Z 0 , -+ - 600 :::r ......... -h (J) - 500 (J) -+ "--'" - 400 - 300 - 200 - 100 - 0 - 100 e e ConocoPhillips Alaska, Inc. ~ Crected by bmíchoel For: P Hoyden Structure: Drill Site 2P Well : 434 ConocoPhillips Dote plotted: 27 -Aug-2003 Plol Reference is 2P-434 Version #9.B. Field : Meltwater Location : North Slope, Alaska Coordinates ore in feet reference 5101 #434. Vertical Depths ore reference RKB (Doyon .. "U INTEQ ==== PROF~LE COMMENT DATA ==== e ----- Point ----- MO Inc Oir NO North East V. Sect Oe9/1OO KOP 900.00 0.00 307.27 900.00 0.00 0.00 0.00 0.00 Base Permafrost 1353.90 9.08 307.27 1352.00 21.73 -28.55 35.88 2.00 Base West Sak 1977.21 21.54 307.27 1952.00 121.21 -159.27 200.15 2.00 EOC 2246.83 26.94 307.27 2197.76 188.23 -247.32 310.80 2.00 9 5/8 CSG 2428.81 26.94 307.27 2360.00 238.16 -312.92 393.24 0.00 C80 2512.94 26.94 307.27 2435.00 261.24 -343.25 431 .35 0.00 C50 3153.43 26.94 307.27 3006.00 436.96 -574.13 721.50 0.00 C40 3430.48 26.94 307.27 3253.00 512.97 -674.00 847.00 0.00 e C37 3593.13 26.94 307.27 3398.00 557.59 -732.63 920.68 0.00 T7 4630.70 26.94 307.27 4323.00 842.25 -1106.65 1390.70 0.00 5 1/2 X 3 1/2 XO 5304.50 26.94 307.27 4923.70 1027.10 -1349.54 1695.94 0.00 T4.1 (Top Cairn) 5504.50 26.94 307.27 5102.00 1081.97 -1421.64 1786.54 0.00 13 (Top Bermuda) 5742.29 26.94 307.27 5314.00 1147.21 -1507.36 1894.26 0.00 T2 (Base Bermuda) 5897.09 26.94 307.27 5452.00 1189.68 -1563.16 1964.38 0.00 C35 (Top Albian) 5940.83 26.94 307.27 5491.00 1201.68 -1578.93 1984.20 0.00 TD, Csq Pt. .6087.09 26.94 307.27 5621 .39 . 1241.81 -1631.65 2050.45 0.00 ConocoPhillips Alaska, Inc. Creoted by bmÎcho,"1 For: P Hayden Dote piotte-d ; 27--Aug-2003 Plot Reference is 2P-434 Version 11-9.8. Structure : Drill Site 2P Well : 434 .~. ConocoPhillips Field : Meltwater Location : North Slope, ('...oordinoles ore În feet reference slot 1/434-_ True Vertical Depths .;:we referençe RKB (Doyon INTEQ TRUE NORTH <::r 350 10 340 20 300 3 30 o 40 310 50 60 290 70 280 80 270 2 90 260 100 250 110 240 120 2 220 210 190 180 \ \ 160 170 \ 150 ® Normal Plane Travelling Cyli nder Feet All depths shown ore Measured depths on Reference Well ConocoP For: P Hoyden Dote plotted: 27 -Aug-2003 Plot Reference IS 2P~434 Version #9.8. Coordinates are in feet reference S!01 #434. s Alaska, Inc. Field : Meltwater Structure : Drill Site 2P Location : North Slope, True Vertìcol Depths ore RKB (DoYOr1 INTEQ 680 640 600 560 520 480 440 400 ~ '0' "" 3000 "- "- "- "- "- "- ". 2800 "- "- "- "- "- "- "- ,,2600 "- "- "- "- "- "- ~". 800 1600 1400 < - West (feet) 360 320 280 Well : 434 240 200 160 120 80 'IJwr/ ConocoPhillips 40 "- "- "- "- "- "- '< 2200 "- "- "- "- "- "- " 2000 "- "- "- "- "-0 1800 "- "- "- "- "" 1 600 "- "- " 1400 '. 1200 "-" 1200 " 200 000 800 ·,.200 &1 200 o í 1 I 1200 I 1400 1000 &1 40 80 800 120 - 440 400 - 360 320 - 280 - 240 ^ - 200 I z 0 , 160 -+ ;:y ,........, ...... 120 (IJ (IJ -+ '--./ - 80 40 - 0 - 40 - 80 120 Created by bmichaei For: P Hayden D01e plotted: 27 -Awg-2003 PlOt Reference is 2P-434 Version #9.8. CQordinates ore in feet reference slot #434. verticol Depth$ are reference RKB (Doyon Bill ~ø INTEQ s Alaska, Inc. ConocoP ~/ ConocoPhillips Well : 434 Structure : Drill Site 2P Location : North Slope, Field : Meltwater <- West (feet) 200 300 500 400 600 700 900 800 1000 1100 1300 1200 1400 1500 1600 1900 1800 1700 2000 2200 2100 1700 - 1600 - 1500 - 1400 - 1300 - 1200 - 1100 ^ I 1000 Z 0 ..., -+- ::J - 900 ,...-.... -+, CD CD - BOO -+- '---"' - 700 - 600 500 - 400 - 300 200 ~..... 5600 " " " 5400 " " ..... 5200 " " ..... 5000 " " ..... 4600 " " ..... 4500 " " ..... 4400 " " ..... 4200 " " ..... 4000 " " ..... 3600 " " ..... 3600 " " ..... 3400 " "" 3200 " " " 3000 " " " 2600 " " ".2600 " " ~400 ~ ~ 3600 '~ 3400 , ~,3200 ,3000 2400 >,2200 .,,2000 '~ e e ConocoPhillips Alaska, Inc. Drill Site 2P 434 slot #434 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-434 Version #9.B prop4525 Date printed Date created Last revised 27-Aug-2003 25-Feb-2001 25-Aug-2003 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.116,w150 26 58.630 Slot Grid coordinates are N 5868921.445: E 443815.428 . Slot local coordinates are 955.98 S 1858.71 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,434 Your ref 2P-434 Version #9.B Meltwater,North Slope, Alaska Last revised : 25-Aug-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 RDINA T E S DegllOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 307.27 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 307.27 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 307.27 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 307.27 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 307.27 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 307.27 600.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 307.27 700.00 0.00 N 0.00 E 0.00 0.00 800.00 0.00 307.27 800.00 0.00 N 0.00 E 0.00 0.00 - 900.00 0.00 307.27 900.00 0.00 N 0.00 E 0.00 0.00 KOP 1000.00 2.00 307.27 999.98 1.06 N 1.39 W 2.00 1. 75 1100.00 4.00 307.27 1099.84 4.23 N 5.55 W 2.00 6.98 1200.00 6.00 307.27 1199.45 9.50 N 12.49 W 2.00 15.69 1300.00 8.00 307.27 1298.70 16.88 N 22.19 W 2.00 27.88 1353.90 9.08 307.27 1352.00 21.73 N 28.55 W 2.00 35.88 Base Permafrost 1400.00 10.00 307.27 1397.47 26.36 N 34.63 W 2.00 43.52 1500.00 12.00 307.27 1495.62 37.91 N 49.82 W 2.00 62.60 1600.00 14.00 307.27 1593.06 51. 54 N 67.72 W 2.00 85.10 1700.00 16.00 307.27 1689.64 67.21 N 88.31 W 2.00 110.98 1800.00 18.00 307.27 1785.27 84.92 N 111. 57 W 2.00 140.21 1900.00 20.00 307.27 1879.82 104.63 N 137.48 W 2.00 172.77 1977.21 21. 54 307.27 1952.00 121. 21 N 159.27 W 2.00 200.15 Base West Sak 2000.00 22.00 307.27 1973.17 126.34 N 166.00 W 2.00 208.60 2100.00 24.00 307.27 2065.21 150.00 N 197.09 W 2.00 247.67 2200.00 26.00 307.27 2155.84 175.59 N 230.71 W 2.00 289.93 2246.83 26.94 307.27 2197.76 188.23 N 247.32 W 2.00 310.80 EOC 2428.81 26.94 307.27 2360.00 238.16 N 312.92 W 0.00 393.24 9 5/8" CSG 2500.00 26.94 307.27 2423.47 257.69 N 338.59 W 0.00 425.49 2512.94 26.94 307.27 2435.00 261. 24 N 343.25 W 0.00 431.35 C80 , 3000.00 26.94 307.27 2869.22 394.86 N 518.82 W 0.00 651. 99 3153.43 26.94 307.27 3006.00 436.96 N 574.13 W 0.00 721.50 C50 3430.48 26.94 307.27 3253.00 512.97 N 674.00 W 0.00 847.00 C40 3500.00 26.94 307.27 3314.97 532.04 N 699.06 W 0.00 878.50 3593.13 26.94 307.27 3398.00 557.59 N 732.63 W 0.00 920.68 C37 . 4000.00 26.94 307.27 3760.73 669.21 N 879.30 W 0.00 1105.00 4500.00 26.94 307.27 4206.48 806.39 N 1059.54 W 0.00 1331. 50 4630.70 26.94 307.27 4323.00 842.25 N 1106.65 W 0.00 1390.70 T7 5000.00 26.94 307.27 4652.24 943.56 N 1239.78 W 0.00 1558.00 5304.50 26.94 307.27 4923.70 1027.10 N 1349.54 W 0.00 1695.94 5 1/2" X 3 1/2" XO 5500.00 26.94 307.27 5097.99 1080.74 N 1420.02 W 0.00 1784.50 5504.50 26.94 307.27 5102.00 1081. 97 N 1421. 64 W 0.00 1786.54 T4.1 (Top Cairn) 5742.29 26.94 307.27 5314.00 1147.21 N 1507.36 W 0.00 1894.26 2P-434 Top Berm Tgt 22 Ju1 03 5897.09 26.94 307.27 5452.00 1189.68 N 1563.16 W 0.00 1964.38 T2 (Base Bermuda) 5940.83 26.94 307.27 5491.00 1201. 68 N 1578.93 W 0.00 1984.20 C35 (Top Albian) 6000.00 26.94 307.27 5543.75 1217.91 N 1600.26 W 0.00 2011.00 6087.09 26.94 307.27 5621. 39 "" 1241. 81 N 1631. 65 W 0.00 2050.45 TD, Csg Pt. All data is in feet unless otherwise stated. Coordinates from slot #434 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 2050.45 on azimuth 307.27 degrees from wellhead. Total Dogleg for wellpath is 26.94 degrees. Vertical section is from wellhead on azimuth 307.27 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e ConocoPhillips Alaska, Inc. Drill Site 2P,434 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-434 Version #9.B Last revised : 25-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 900.00 900.00 0.00 N 0.00 E KOP 1353.90 1352.00 21. 73 N 28.55 W Base Permafrost 1977.21 1952.00 121.21 N 159.27 W Base West Sak 2246.83 2197.76 188.23 N 247.32 W EOC 2428.81 2360.00 238.16 N 312.92 W 9 5/8" CSG 2512.94 2435.00 261.24 N 343.25 W C80 3153.43 3006.00 436.96 N 574.13 W C50 3430.48 3253.00 512.97 N 674.00 W C40 3593.13 3398.00 557.59 N 732.63 W C37 4630.70 4323.00 842.25 N 1106.65 W T7 5304.50 4923.70 1027.10 N 1349.54 W 5 1/2" X 3 1/2" XO 5504.50 5102.00 1081. 97 N 1421. 64 W T4.1 (Top Cairn) 5742.29 5314.00 1147.21 N 1507.36 W 2P-434 Top Berm Tgt 22 Jul 03 5897.09 5452.00 1189.68 N 1563.16 W T2 (Base Bermuda) 5940.83 5491. 00 1201.68 N 1578.93 W C35 (Top Albian) 6087.09 5621.39 1241.81 N 1631.65 W TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 2428.81 6087.09 2360.00 5621. 39 238.16N 1241. 81N 312.92W 1631. 65W 9 5/8" CSG 3 1/2" CSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2P-434 Top Berm Tgt 442317.000,5870080.000,999.00 5314.00 1147.21N 1507.36W 22-Feb-2001 e e ConocoPhillips Alaska, Inc. Drill Site 2P 434 slot #434 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our re f License 2P-434 Version #9.B prop4525 Date printed Date created Last revised 27-Aug-2003 25-Feb-2001 25-Aug-2003 Field is centred on 441964.235,5869891. 466.999. OOOOO,N Structure is centred on 441964.235,5869891. 466,999.00000, N Slot location is n70 3 9.116,w150 26 58.630 Slot Grid coordinates are N 5868921.445, E 443815.428 Slot local coordinates are 955.98 S 1858.71 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,434 Your ref 2P-434 Version H.B Meltwater,North Slope, Alaska Last revised : 25-Aug-2003 Measured Inclin Az imu th True Vert R E C TAN GULAR G RID C o 0 R D S G E 0 G RAP H I C Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C 0 o R DIN A T E S 0.00 0.00 0.00 0.00 O.OON O.OOE 443815.43 5868921.44 n70 09.12 w150 26 58.63 100.00 0.00 307.27 100.00 O.OON O.OOE 443815.43 5868921.44 n70 09.12 w150 26 58.63 200.00 0.00 307.27 200.00 O.OON O.OOE 443815.43 5868921. 44 n70 09.12 w150 26 58.63 300.00 0.00 307.27 300.00 O.OON O.OOE 443815.43 5868921. 44 n70 09.12 w150 26 58.63 400.00 0.00 307.27 400.00 O.OON O.OOE 443815.43 5868921.44 n70 09.12 w150 26 58.63 500.00 0.00 307.27 500.00 O.OON O.OOE 443815.43 5868921.44 n70 3 09.12 w150 26 58.63 600.00 0.00 307.27 600.00 O.OON O.OOE 443815.43 5868921.44 n70 3 09.12 w150 26 58.63 700.00 0.00 307.27 700.00 O.OON O.OOE 443815.43 5868921.44 n70 3 09.12 w150 26 58.63 800.00 0.00 307.27 800.00 O.OON O.OOE 443815.43 5868921.44 n70 3 09.12 w150 26 58.63 900.00 0.00 307.27 900.00 O.OON O.OOE 443815.43 5868921.44 n70 3 09.12 w150 26 58.63 1000.00 2.00 307.27 999.98 1. 06N 1.39W 443814.05 5868922.51 n70 09.13 w150 26 58.67 1100.00 4.00 307.27 1099.84 4.23N 5.55W 443809.91 5868925.71 n70 09.16 w150 26 58.79 1200.00 6.00 307 .27 1199.45 9.50N 12.49W 443803.01 5868931. 04 n70 09.21 w150 26 58.99 1300.00 8.00 307 .27 1298.70 16.88N 22.19W 443793.37 5868938.50 n70 09.28 w150 26 59.27 1353.90 9.08 307 .27 1352.00 21. 73N 28.55W 443787.04 5868943.39 n70 09.33 w150 26 59.45 1400.00 10.00 307.27 1397.47 26.36N 34.63W 443781. 00 5868948.06 n70 09.38 w150 26 59.63 1500.00 12.00 307.27 1495.62 37.91N 49.82W 443765.91 5868959.73 n70 09.49 w150 27 00.06 1600.00 14.00 307.27 1593.06 51. 54N 67 .72W 443748.11 5868973.49 n70 09.62 w150 27 00.58 1700.00 16.00 307.27 1689.64 67.21N 88.31W 443727.64 5868989.32 n70 09.78 w150 27 01.17 1800.00 18.00 307.27 1785.27 84.92N 111.57W 443704.51 5869007.20 n70 09.95 w150 27 01. 84 1900.00 20.00 307.27 1879.82 104.63N 137.48W 443678.76 5869027.11 n70 10.15 w150 27 02.59 1977.21 21. 54 307.27 1952.00 121.21N 159.27W 443657.10 5869043.86 n70 10.31 w150 27 03.22 2000.00 22.00 307.27 1973.17 126.34N 166.00W 443650.42 5869049.03 n70 10.36 w150 27 03.41 2100.00 24.00 307.27 2065.21 150.00N 197.09W 443619.51 5869072.93 n70 10.59 w150 27 04.31 2200.00 26.00 307.27 2155.84 175.59N 230.71W 443586.08 5869098.77 n70 10.84 w150 27 05.27 2246.83 26.94 307.27 2197.76 188.23N 247.32W 443569.57 5869111. 54 n70 10.97 w150 27 05.75 2428.81 26.94 307.27 2360.00 238.16N 312.92W 443504.36 5869161. 96 n70 11.46 w150 27 07.64 2500.00 26.94 307.27 2423.47 257.69N 338.59W 443478.85 5869181. 68 n70 11. 65 w150 27 08.38 2512.94 26.94 307.27 2435.00 261.24N 343.25W 443474.21 5869185.27 n70 11.69 w150 27 08.52 3000.00 26.94 307.27 2869.22 394.86N 518.82W 443299.68 5869320.21 n70 13 .00 w150 27 13 .57 3153.43 26.94 307.27 3006.00 436.96N 574.13W 443244.70 5869362.72 n70 13.41 w150 27 15.17 3430.48 26.94 307.27 3253.00 512.97N 674.00W 443145.42 5869439.48 n70 14.16 w150 27 18.04 3500.00 26.94 307.27 3314.97 532.04N 699.06W 443120.51 5869458.74 n70 14.35 w150 27 18.76 3593.13 26.94 307.27 3398.00 557.59N 732.63W 443087.13 5869484.55 n70 14.60 w150 27 19.73 4000.00 26.94 307.27 3760.73 669.21N 879.30W 442941. 34 5869597.28 n70 15.70 w150 27 23.96 4500.00 26.94 307.27 4206.48 806.39N 1059.54W 442762.17 5869735.81 n70 17.05 w150 27 29.15 4630.70 26.94 307.27 4323.00 842.25N 1106.65W 442715.33 5869772.02 n70 17.40 w150 27 30.51 5000.00 26.94 307.27 4652.24 943.56N 1239.78W 442582.99 5869874.34 n70 18.40 w150 27 34.34 5304.50 26.94 307.27 4923.70 1027.10N 1349.54W 442473.88 5869958.70 n70 19.22 w150 27 37.50 5500.00 26.94 307.27 5097.99 1080.74N 1420.02W 442403.82 5870012.87 n70 19.75 w150 27 39.53 5504.50 26.94 307.27 5102.00 1081. 97N 1421. 64W 442402.21 5870014.11 n70 19.76 w150 27 39.58 5742.29 26.94 307.27 5314.00 1147.21N 1507.36W 442317.00 5870080.00 n70 20.40 w150 27 42.05 5897.09 26.94 307.27 5452.00 1189.68N 1563.16W 442261.53 5870122.89 n70 20.82 w150 27 43.66 5940.83 26.94 307.27 5491.00 1201. 68N 1578.93W 442245.85 5870135.01 n70 20.94 w150 27 44.11 6000.00 26.94 307.27 5543.75 1217.91N 1600.26W 442224.65 5870151.40 n70 21.10 w150 27 44.73 6087.09 26.94 307.27 5621. 39 1241.81N 1631. 65W 442193.45 5870175.53 n70 21.33 w150 27 45.63 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #:434 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 2050.45 on azimuth 307.27 degrees from wellhead. Total Dogleg for wellpath is 26.94 degrees. Vertical section is from wellhead on azimuth 307.27 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e e ConocoPhillips Alaska lIne. Drill Site 2P,434 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-434 Version #9.S Last revised : 25-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Conunent - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - - ---- - - - - - -- - - - - - - - - - - - - - -- - -- - --- --- -- - - - - - -- 900.00 900.00 O.OON O.OOE KOP 1353.90 1352.00 21.73N 28.55W Base Permafrost 1977.21 1952.00 121. 21N 159.27W Base Wes t Sak 2246.83 2197.76 188.23N 247.32W EOC 2428.81 2360.00 238.16N 312.92W 9 5/8" CSG 2512.94 2435.00 261.24N 343.25W C80 3153.43 3006.00 436.96N 574.13W C50 3430.48 3253.00 512.97N 674.00W C40 3593.13 3398.00 557.59N 732.63W C37 4630.70 4323.00 842.25N 1106.65W T7 5304.50 4923.70 1027.10N 1349.54W 5 1/2" X 3 1/2" XO 5504.50 5102.00 1081. 97N 1421. 64W T4.1 (Top Cairn) 5742.29 5314.00 1147.21N 1507.36W 2P-434 Top Berm Tgt 22 Jul 03 5897.09 5452.00 1189.68N 1563.16W T2 (Base Bermuda) 5940.83 5491.00 1201. 68N 1578.93W C35 (Top Albian) 6087.09 5621.39 1241. 81N 1631. 65W TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords . Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 2428.81 2360.00 O.OOE 6087.09 5621.39 238.16N 1241. 81N 312.92W 9 5/8" CSG 1631. 65W 3 1/2" CSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 2P-434 Top Berm Tgt 442317.000,5870080.000,999.00 5314.00 1147.21N 1507.36W 22-Feb-2001 Company: Field: Reference Site: Reference Well: Reference Wellpath: -taker Hughes IncorporaA Anticollision Report ConocoPhillips Alaska, Inc. Meltwater 2P Pad 434 2P-434 Vers#9b NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 6087.09 ft Maximum Radius: 5280.00 ft Survey Program for Definitive Wellpath Date: 8/12/2003 Validated: No Planned From To Survey ft ft 0.00 6087.09 Planned: 2P-434 Vers#9b V14 Summary < ----- OlTsel Wellpalh Sitc Wcll 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad Meltwater North#1 Meltwater South #1 MWN#2 MWN#2 406 414 415 415 416 417 419 420 422 422 424 427 429 431 432 438 441 443 445 447 448 448 448 449 451 MWN#1 MWS#1 MWN#2 MWN#2 - - ..... --.> Wcllpath 2P-406 Vers#2.A V2 Pia 2P-414 Vers#3a V1 Plan 2P-415 VO 2P-415A VO 2P-416 Version#O.A VO 2P-417 VO 2P-419 Vers#3.A V1 Pia 2P-420 VO 2P-422 V7 422A VO 2P-424 Vers#3.a V1 Pia 2P-427 VO 2P-429 VO 2P-431 V1 2P-432 Version#4.b V7 2P-438 VO 2P-441 VO 2P-443 Vers#3 V1 Plan: 2P-445 Vers#4 VO Plan: 2P-447 Vers#8b V2 Plan 2P-448 V2 2P-448A VO 2P-448PB1 VO 2P-449 Vers#6.b V1 Pia 2P-451 VO MWN#1 VO MWS#1 VO MWN#2 VO MWN#2A VO Datc: 8/27/2003 Time: 13:26:18 I'al:c: Co-ordinatc(:'Œ) I{dcrcllcc: Well: 434, True North \"l'rlical (T\"Il) l{dcl'cllce: Doyon 141 (0Id2) 252.0 Version: Toolcode MWD+SAG Refcrcllce :\1U ft 474.99 599.98 299.95 299.95 499.98 993.02 374.96 994.20 499.58 499.58 449.93 748.05 549.66 624.32 998.33 424.99 1002.74 399.98 474.99 474.99 424.99 424.99 424.99 374.99 325.00 932.33 5377.61 orrscl :\m ft 475.00 600.00 300.00 300.00 500.00 1000.00 375.00 1000.00 500.00 500.00 450.00 750.00 550.00 625.00 1000.00 425.00 1000.00 400.00 475.00 475.00 425.00 425.00 425.00 375.00 325.00 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Tool Name MWD + Sag correction Ctr-Or :'\io-Go nisl'allcc Area ft ft 560.95 8.93 401.13 11.67 380.50 4.90 380.50 4.90 360.86 9.36 343.67 18.06 301.20 6.55 284.05 17.38 242.57 8.91 242.57 8.91 201.31 8.08 142.12 14.50 104.52 10.10 59.82 11.22 37.16 20.02 81.39 7.43 138.76 17.62 180.62 7.24 220.67 9.04 260.42 8.89 281.99 7.67 281.99 7.67 281.99 7.67 300.63 6.82 340.37 5.50 "lIo\\-ablc I)c,·iatioll ft 552.01 389.45 375.61 375.61 351.50 325.62 294.65 266.67 233.66 233.66 193.23 127.62 94.42 48.60 17.14 73.96 121.14 173.39 211.63 251.53 274.32 274.32 274.32 293.82 334.87 975.00 4046.92 16.81 4030.11 7600.00 2612.66 159.46 2453.21 . ........- Warnin!: Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: Major Risk Pass: Major Risk e e MEL TW A TER - DRILLING HAZARDS SUMMARY 12 IA" Open Hole & 9 5/8" Surface Casin2 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 / 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 TO 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 Vi' Production Casin2 Interval I 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 / 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 9/112003 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 8/28/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD I I I: I I < Base of Permafrost at 1,353 ft. MD (1,352 ft. TVD) < Top of Tail at 1,400 ft. MD < 95/8", 40.0#, L-80 grade BTC, AB Modified in 12 1/4" OH TD at 2,429 ft. MD (2,360 ft. TVD) Mark of Schlumberger .. 2P-434 .........."""..""·c·ë·ñïc'Ã'õ..E·..·..P'relim inarŸ""J'õ'b Design " 95/8" Surface Casing UlblPRep Preliminary Job Design based on limited Input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 450% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 47' below base of permafrost.) Lead Slurry (minimum pump time 206 min.) ArcticSet III Lite @ 10.7 ppg, -4.28 ft3fsk 0.7632 ft31ft x (108') x 1.00 (no excess) = 0.3132 ft31ft x (1353' - 108') x 5.50 (450% excess) = 0.3132 ft3fft x (1400' - 1353~ x 1.45 (45% excess) = 82.4 ft3 + 2144.6 ft3+ 21.3 ft = 2248.3 ft3 f 4.28 ft3fsk = Round up to 526 sks 82.4 ft3 2144.6 ft3 21.3 ft3 2248.3 ft3 525.3 sks Have 410 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 149 min.) LiteCRETE @ 12.0 ppg - 2.28 ft3/sk 3 0.3132 ft 1ft x (2429' -1400') x 1.45 (45% excess) = 0.4257 ft3fft x 80' (Shoe Joint) = 467.3 ft3 + 34.1 ft3 = 501.4 ft31 2.28 ft3/sk = Round up to 220 sks 467.3 ft3 34.1 ft3 501.4 ft3 219.9 sks BHST = 58°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.6"Ff100 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 6 40 6.7 24.7 Drop bottom plug 4.0 28.7 Lead Slurry 7 401 57.3 86.0 Tail Slurry 5 89 17.8 103.8 Drop Top Plug 4.0 107.8 Water 5 20 4.0 111.8 XO to rig pump 4.0 115.8 Displacement 7 145 20.7 136.5 Bump Plug 3 13.1 4.4 140.9 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-20, Ty? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 9/4/2003 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 2,429 ft. MD < 51/2",15.5#, L-80 grade BTC, AB Modified in 8 112" OH < Top ofTail at 5,005 ft. MD < X-over at 5,305 ft. MD < Top of Caim Fm. at 5,505 ft. MD < 3 1/2", 9.3#, L-80 grade EUE, 8rd Modified in 8112" OH TD at 6,087 ft. MD (5,621 ft. TVD) Mark of Schlumberger e 2P-434 CemCADE" Preliminary Job Design 51/2" x 31/2" Production Casing ! Schlumberger 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 300' above casing X-over. Tail Slurry (minimum thickening time 134 min.) LiteCRETE wI Class G, 0167, 0046, 0065, per lab testing 3 @ 12.5 ppg, 1.94 ft Isk 0.2291 ft3/ft x 300' x 1.75 (75% excess) = 0.3272 ft31ft x (6087' - 5305') x 1.75 (75% excess) = 0.0488 ft31ft x 60' (Shoe Joint) = 120.3 ft3 + 447.8 ft3 + 2.9 ft3 = 571.0 ft3/1.94 ft3/sk = Round up to 295 sks 120.3 ft3 447.8 ft3 2.9 ft3 571.0 ft3 294.3 sks BHST = 143°F, Estimated BHCT = 122°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 50 10.0 22.0 Drop Bottom Plug 5.0 27.0 MudPUSH II 6 30 5.0 32.0 Tail Slurry 7 102 14.6 46.6 Drop Top Plug 5.0 51.6 Displacement 8 118 14.8 66.4 Bump Plug 3 15 5.0 71.4 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 22-25, Ty ? 37-40 Centralizers: Recommend 1 per joint on 5-1/2" section and 1-1/2 per joint on the 3-1/2 section to aid in mud removal Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 8/28/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (90?) 265-6205 Mobile: (90?) 229-6266 email: martin13@slb.com , r . I !Ii'. Previous Csg. ; , ~ < 95/8", 40.0#, L-80 grade BTC, AB Modified at 2,429 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 8 1/2" OH < Top ofTail at 5,005 ft. MD < 3 1/2", 9.3# -80 grade EUE, Brd odified in 8 11 ' OH Mark of Schlumberger .. 2P-434 CemCADE" Preliminary Job Design 5 1/2" x 3 1/2" Production Casing 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 casing X-over. (minimum thickening time 134 min.) wI Class G + 053, 0600, 0135, 0800, DO @ jÞKp ,1.94 ft3/sk \;;) 3 O. 1ft x 300' x 1.75 (75% excess) = 0.3272 ft3/ft x (6087' - 5305') x 1.75 (75% e 0.0488 ft3/ft x 60' (Shoe Joint) = 120.3 ft3 + 447.8 ft3 + 2.9 ft3 = 571.0 ft3/1.94 ft3/sk = Round up to 295 sks 120.3 ft3 447.8 ft3 2.9 ft3 571.0 ft3 294.3 sks BHST = 143°F, Estimated BHC = 122°F. (BHST calculated using a gr lent of 2.6°F/1 00 ft. below the permafrost) S¢\"'-~~~ c; I \ ~ PUMP SCHED Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) 100 5 10 2.0 2.0 st lines 10.0 12.0 CW100 5 50 10.0 22.0 Drop ottom Plug 5.0 27.0 MudPUSH II 6 30 5.0 32.0 Tail Slurry 7 102 14.6 46.6 Drop Top Plug 5.0 51.6 Displacement 8 118 14.8 66.4 Bump Plug 3 15 5.0 71.4 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 22-25, Ty ? 37-40 Centralizers: Recommend 1 per joint on 5-1/2" section and 1-1/2 per joint on the 3-1/2 section to aid in mud removal e Meltwater 2P-434 Injector Proposed Completion Schematic 3-1/2" Completion String e 11i¡.. r ~ ~ f ~ r ~ ~ '- ~ '- 3 14" FMC Gen 5 Tubing Hanger, 3 14" L-80 EUE8RD Mod pin down I ~ ~ I ~ '- ~ ~ ~ '- 3 14" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required ~ I ~ I '- I ~ ~ '- 3 14" 9.3# L-80 EUE8RD Mod Tubing to Surface I ~ I '- J I I I '- I ---- ~ I ~ '- ~ '- 3 14" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 14" x 6' L-80 handling pups ~ I '- ~ '- 30" x 16" 62.6# I E '- ~ '- installed above and below, EUE8RD Mod, set at +1- 500' MD ~ '- ~ '- @ +1- 108' MD I ~ '- I ~ ~ ~ I (Insulated) ~ I '- E I I ~ I ~ ~ I ~ 3 Y2" 9.3# L-80 EUE8RD Mod tubing to landing nipple ~ ~ '- ~ ! ~ '- '- Depths are I '- '- I ~ I '- based on I '- '- ~ '- '- Doyon 141 I ~ '- '- ~ I '- '- RKB ~ ~ '- '- ~ ~ '- '- ~ ~ '- ~ ~ ~ '- ~ I I ~ ~ I ~ I ~ i ~ '- I '- '- ~ ~ ~ '- ~ I ~ '- I I ~ '- ~ Surface csg. ~ I '- ~ ..,..¡¡¡¡¡ ~ '- ~ 95/8" 40.0# L-80 BTC ~ '- +1- 2429' MD I 2360' TVD I '- I '- I '- I '- I ~ ~ " '- I '- 3 W' x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear ~ I I '- (casing to tubing differential), 314" x 6' L-80 handling pups installed above and I I below, EUE8RD Mod I '- I I I '- ~ '- ~ ~ I I I ~ '- '- 3 Y2" Baker 'CMU' sliding sleeve wI 2.813" Cameo DS profile, ~ I EUE8RD Mod box x pin. 3 Y2" x 6' L-80 EUE8RD Mod handling pup ~ I I '- installed above ~ '- I I 314" Cameo 'D' nipple wI 2.75" No-Go profile. 314" x 16' L-80 EUE8RD Mod I I I ... I spacaeout pup installed above, 3 Y2" x 6' handling pup installed below ~ '- '- I I '- 5 Y2" 15.5# L-80 BTCM I E '- I x 1.....- .. ~ +- 3 Y2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 Y2" L-80 3 Y2" 9.3# L-80 EUE8RD Mod ~ FIIJB I EUE8RD Mod box up, 3 W' x 6' L-80 EUE8RD Mod handling pup installed on top crossover at +1- 5305' MD I ~ ~/ 4924' TVD ~ Baker Seal Bore Extension, 5 W' BTCM x 3 14" EUE8RD Mod r SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) Future Perforations Production csg 5 14" 15.5# L-80 BTCM x 3 Y2" 9.3# L-80 EUE8RD Mod +1- 6087' MD 15621' TVD ... ~ 08/27103 o o o -0 ED ~ ..., N \ ~ 150 2!3CO¿~ 150 22 OOW . GI\~~¡C:I.""",,, 4 J4 "'''-. . .;,:~¡".~.1~2·'11'7 ···""7···1.'····;· ¡;;~~.., ..~ ._"'--~'~;:"". / ' } '\ \ ~::::~.~..::-......... ---. .. ..c...--.,.;;t h ,I \ \ "'... ---..~. ·"P--4 "0 /~ il, \ .......~, :.Ji..c..._ .,/ '.\1..... ........... I . \ ... ....' \ \ .\ --.....,...... ~ I , If: II ~\ '-.-. // r \ '\ \'\ .......-. ,1/ I 1\ \ \ l \ , 2P-4 I 5.6, ....--...--. ......-......---... ........"............... -..-..(- 2P'-4 15 e I /' .I ¡ . I i . .t 2P·-4.38 / \ \ ", i. l \, \ \ to ::F....\¡ \ -....J . . 2P"'- 4 31 ..(' o o z -440 ,000 I Feel I 1 o 1,000 21000 J,OOO 4.000 ...~-~...~......~"-_......._~~ .. '. .';.:"'~"" ~.,: .",;~,¿:,,;i.~:. '. ::',';;.;.:,,"'!:;:·~"";;i:'£~;,Jò,::ài~.>';~:,I.!',(¡..,~,'i:.'.¡';'.iI., .; ,'~ . '.' . ... ....:¡^¡~,:. ,,' _~, ,... :,;':''',¡,. ".:.~:..:..~ J..; .........~'~.~.;'.,...~~~..¡..;., ,r',.,,·~'..:~,¡·..~ _,... ...._.~,.;."'.;¡.i;:.þ>'~...,..."..:, f...":,,,,'~'.,,~... '_" '..,.~';;'~.~:~.... :', :,.J..... " .'. S. K. ALLSUP-DRAKE CONOCOPHILLlPS 711 G STREET - A T01530 ANCHORAGE AK 99501 1058 ~2-14/311 Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars 200WhlteCIay Cent&rDr., Newark.' DE 19711 MEMO e .:0 ~ . .00 ..... .....: 2 .80000.... 27 257"· .058 e e e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/P ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME j!R.u ;zr>-cf3Ý 2-03---155 CHECK WHAT APPLIES Rev: 07/10/02 C\jody\templates PTD# ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing weB -' Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals througb target zones. ~ I"'--, ~~ v\>~ Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date Appr SFD Date 9/3/2003 35 36 37 38 39 YenT]it C<!n be issued wfo hydr9gen_ s_ulfide measu(es _D_ata_ presented on_ pote_ntial pverpres_sure _zones _Seismic_analysis of shaJlow gas_zpoes Seabed wndjtiPn survey off-sh9(e) Contact nam_elpJ1oneJor (if weekly progress_reports [exploratpry 9nlyt Yes Yes NA NA NA ad_dresse_dJn the Drilling Hazards Summary. Uf\lDERF'RESSURED:_ expected pressul'e in 6ermuda reseJ\loir is 5.2~ 6.5 ppg EMW, I-iigh annula( pressul'es in_2P43t expeGtedJs 11 .1 ppgEMW._ 4518. 438 denote some_ rIsk pf shallow, high_ pressul'e. Operato( rates risk_as Jow to moderate._ Potential and miti9ation measures are Geology Date TEM 9/4/2003 e&t~ Appr 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Meçha_nicalCPndition pf wells wiJhin ~OR verified (for_s_ervice well only) Is presence of H2S gas_ prob_able Choke manifold complies wI API RF'-53 (May 84) Work will PCCU( withputoperationsbutdoWJ1 B0PEs,d9they meet B0PEpress ra_ting approp(iate; Jest to Jpu_t psig in_comments) Itdivecter required, does it meet reguJations Drilliog fluid program sGhematic_& equip listadequate regulation !fa re-ddlt Adequate well bore separation proposed bas a_ 10~'t03 for abandonment been approved AdequateJankageor re_serye pit Surface CMT v9f adequ_atE çirc_ul ~ Ly tie-tn J"!' '''"' _v known -Productiye bori;!:o"-s C, _Casing designs adequaJe fp( T~ B _&_ permafr9st _CMT v_of adequate ,~ _CMT will GOYer_aU I~nn ~tring to_surf csg_ casing_proteGts all known_ USDWs _cond_ucto( 8. surtcsg Yes NA Yes No_ Yes Yes Yes NA Yes Yes Yes Yes Yes Yes Yes No_ NA Highes_t There_ are 00 wells within a 1 l4 mile radius 9f 2F'-434at the top 9f the productiveJoter:val._ Some_locaJizedsballow p(essures have beeo seen 90 3 wells, CalcuJaJedMASF' 1254 psi 3500 psi _appropriate, Maximum expecUormation pressure aUD6.5 EMW, MW plaon_ed 9.6ppg. Nearest well PPCo usually_ test to 5000 psi. (2P-45Hhas ç~8_0EMW ptM. prpximity analysis perf9rme_d_and travelin9_cylinderplot prepared. Rig isequippe_dwitb steel pits. No_ reseJ'.(e_pitplanoed, Waste_to approved annulus or_disposal well, ~nnular disp_osal may be propo_sed. All aquifers exempted 40 CfR 147_.102 (b)(3) Engineering _C9nductor st(ing_provided Appr ~ 12 13 14 15 16 17 ACMP FJndjng 9f Consistencyh_as bee_n Jssued_ for tbis pmlect # (putlO# AJI wellswithin_1l4_mile_area_of review ideotified (Fp( service w_ell only) _ _ Pre-produ_ced injector; duratJoRof pre-produGtioo less_ than_ 3 months (For Date 9/3/2003 2 3 4 5 6 7 8 9 10 11 _Can permit Well J 5-day wait located within area and_strata authorized by_lojectipo Orde( be approved before in_cpmments) (For Permit Permit admioist(atiye_approvaJ _Qpe(ator only affected party Qper_ator basapprppriate bond in Jorce conservaJion order _Sufficient If deviated is weJlbore plaUnclu_ded Well Well Well acreageayailable in_drilling unit located prpper _distance_ from driJling uoitb9uodary_ ocated pmper _distance from other wells Unique well name and oumb_er JQcated in a_ d_efined pool PTD#: 2031530 Administration _ser:vice well only) can be issued without can be issued without leas_e_number _appropriate Company CONOCOPHILLlPS ALASKA Permit fee attaçhed KUPARUK RIVER, MELTWATER OIL Field & Pool NC 490140 Initial ClasslType Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes No NA ~I021 f\lon_e Per _C_O_ 456, 10-acrespacing, Well Name: KUPARUK RIV U MELT SER I PEND GeoArea 890 2P-434 Unit 11160 Program SER On/Off Shore On Well bore seg Annular Disposal o o 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. **** REEL HEADER **** LDWG 04/03/15 AWS 01 **** TAPE HEADER **** LDWG 04/03/15 01 *** LIS COMMENT RECORD *** . LA }~ . !!!!!!!!!!!!!!!!!!! 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 1 1 C. WONG D. GLADDEN MWD RUN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # ~~~,,\ ~ OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 2P-434 501032046700 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 15-MAR-04 MWD RUN 2 2 E. AGUIRRE M. THORNTON MWD RUN 17 8N 7E 252.00 224.00 CASING SIZE (IN) 16.000 9.625 7.000 MWDRUN 3 3 STURDIVANT F. HERBERT MWD RUN DRILLERS DEPTH (FT) 108.0 2421. 0 5711. 0 6030.0 303~IS0 } ~ c..( ç À... RECEiVED l~~) ~l () 1"'1",,<> ·1"} ~ f"'^ml"\):"-iAn (';I:'!:)lA:,1 :;ì,\A) !;¡d~IIJ\' REMARKS: Tape Subfile: 1 . . PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 03' 18.521" LONG: W150 DEG 27' 52.172" LOG MEASURED FROM D.F. AT 252.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a Multiple Propagation Resistivity (MPR) and Gamma Ray with Near Bit Inclination services from 108 - 2428 feet MD (108 - 2362 TVD). (2) Baker Hughes INTEQ run 2 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD) , Caliper Corrected Neutron (CCN) , along with DCP (Drill Collar Pressure) and MPR Resistivity services from 2428 - 5714 feet MD (2362 - 5298 TVD). (3) Baker Hughes INTEQ run 3 utilized the slimhole Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD) , Caliper Corrected Neutron (CCN) , along with Annular Pressure and MPR Resistivity services from 5714 - 6030 feet MD (5298 - 5582 TVD). (4) 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. (5) The bulk density measurement was adversely effected by occurances of BHA stick-slip. Large stick-slip events often result in poor data quality with anomalous Delta Rho measurements which in turn drive anomalous bulk density measurements. Stick-slip episodes were more common when the BHI was sliding (BDSI). REMARKS: (1) Depth of 9 5/8" Casing Shoe - Logger: 2425 feet MD (2359 TVD) Depth of 9 5/8" Casing Shoe - Driller: 2421 feet MD (2356 TVD) (2) The interval from 2374 to 2425 feet MD (2313 - 2359 TVD) was not logged due to the presence of the 9 5/8" casing. (3) Depth of 7" Casing Shoe - Logger: 5711 feet MD (5296 TVD) Depth of 7" Casing Shoe - Driller: 5711 feet MD (5296 TVD) (4) The interval from 5667 to 5711 feet MD (5256 - 5296 TVD) was not logged due to the presence of the 7" casing. (5) The interval from 5987 to 6030 feet MD (5543 - 5582 TVD) was not logged due to sensor-bit offset at TD. $ 97 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** . . 1024 *** 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 227.0 STOP DEPTH 6030.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 227.0 2381.0 5654.0 MERGE BASE 2381.0 5654.0 6030.0 # 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-434_5.xtf 150 ConocoPhillips Alaska 2P-434 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP GRAM RPD RPM RPS RPX BDCM DRHM DPEM NPCKSM ROPS 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 . . FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 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 12 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 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 611 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 227.000000 6030.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 660 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** . !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!1!!!! 1!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 1 .2500 START DEPTH 227.0 STOP DEPTH 2381.0 # 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 MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # 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): # REMARKS: BIT RUN 1 (MWD Run 1). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) 25-NOV-03 MSB 18655 8.25 MPR MEMORY 2428.0 227.0 2381.0 o .6 24.6 TOOL NUMBER DHA 7113 MPR 8017 SRIG 5269 12.250 108.0 Spud 9.00 .0 .0 200 .0 .000 .000 .000 .000 86.0 .0 .0 .0 .00 .000 .0 o . . RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) 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-434.xtf 150 ConocoPhillips Alaska 2P-434 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 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 12 Curves: . Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 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 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 . Total Data Records: 454 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 227.000000 2381.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 553 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 2381.0 STOP DEPTH 5654.0 # 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): 29-NOV-03 MSB 18655 6.75 TC MEMORY 5714.0 2381. 0 . 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): # . 5654.0 o 24.6 28.2 TOOL NUMBER DAS 1728 CCN 71630 ORD 12103 MPR 6245 SRIG 92230 8.500 2421.0 LSND 10.45 .0 .0 200 .0 .000 .000 .000 .000 112.0 .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) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) 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) $ REMARKS: # . *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-434.xtf 150 ConocoPhillips Alaska 2P-434 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 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 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 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: 14 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 16 Curves: . Name Tool Code Samples Units Size Length 1 2 3 4 5 6 7 8 9 10 68 68 68 68 68 68 68 68 68 68 4 4 4 4 4 4 4 4 4 4 1 1 1 1 1 1 1 1 1 1 GAPI OHMM OHMM OHMM OHMM OHMM OHMM OHMM OHMM G/C3 GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH BDCM MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 4 4 4 4 4 4 4 4 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 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 936 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2381.000000 5654.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1046 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 . log header data for each bit run in separate files. 3 .2500 START DEPTH 5654.0 STOP DEPTH 6030.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 02-DEC-03 MSB 18655 4.75 SDN MEMORY 6030.0 5654.0 5987.0 o 25.7 26.4 TOOL NUMBER . . DIR CCN ORD MPR GRAM $ DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY DAS 1542 CCN 45227 ORD 45227 MPR 1033 SRIG 60365 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 5711.0 # 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: LSND 9.80 .0 .0 200 .0 .000 .000 .000 .000 107.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Sandstone .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 3) . 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 (GICC) DRHM - DENSITY CORRECTION (GICC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) 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 2p-434.xtf 150 ConocoPhillips Alaska . . WN FN COUN STAT 2P-434 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 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 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 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: 14 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 16 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 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 , . . . Total Data Records: 108 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5654.000000 6030.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 218 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/03/15 01 **** REEL TRAILER **** LDWG 04/03/15 AWS 01 Tape Subfile: 6 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes