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202-053
2025-0715_Location_Clear_KRU_2P-431_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-431 Conoco Phillips Alaska LLC. PTD 2020530; Sundry 324-624 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-431 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 6 feet 9 inches 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 14:01:36 -08'00' 2025-0715_Location_Clear_KRU_2P-431_ksj Page 2 of 2 Surface Abandonment Inspection – KRU 2P-431 (PTD 2020530) 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 120' 7-5/8" L-80 2381' 5.5" L-80 5388' 3.5" L-80 5809' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, (included above)8.5" TUBING RECORD 320 sx Class G w/ GasBlok8.5" 8826' MD 3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/2/2025 202-053 / 324-624 50-103-20417-00-00 KRU 2P-431 ADL0373112, ADL0389058 943' FNL, 1914' FWL, Sec. 17, T8N, R7E, UM 2464' FSL, 1516' FWL, Sec. 20, T8N, R7E, UM ALK 4998 3/28/2002 9685' MD/ 5823' TVD Surface/ Surface P.O. Box 100360, Anchorage, AK 99510-0360 443874 5868935 2356' FNL, 1526' FWL, Sec. 20, T8N, R7E, UM 9. Ref Elevations: KB: WT. PER FT.GRADE 4/7/2002 CEMENTING RECORD 5862245 1390' MD / 1351' TVD SETTING DEPTH TVD 5861785 TOP HOLE SIZE AMOUNT PULLED 254' AMSL 443458 443433 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 N/A PACKER SET (MD/TVD) 42" 9.875' 29.6 bbls AS I 30'365 sx AS III Lite, 229 sx LiteCrete 9.3# 30' 8828' 2988'30' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 37-2512' 140 bbl 15.8 PTA Cement/ est. 20 bbl returns to surf. Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 2512-3039' 7144' (SW TOC) -8727' Abandoned 9290-9300' MD and 5624-5629' TVD (below cement plug) Gas-Oil Ratio:Choke Size: 31 bbls 15.8 ppg Class G Cement Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 21 bbl 15.8 ppg Cement w 150# Bridge Maker II LCM 8828' SIZE DEPTH SET (MD) 9655' 26' 5388' 62.5# 29.7# 120' 26' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:16 pm, Mar 03, 2025 Abandoned 2/2/2025 JSB RBDMS JSB 030625 xGVTL 7/30/2025 DSR-4/7/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1390' 1351' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations, Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Digital Signature with Date:Contact Email: shane.germann@conocophillips.com Contact Phone:(907) 263-4597 Senior 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 N/A - Abandoned N/A- Abandoned Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location:Date: 2025.03.03 13:08:02-09'00' Foxit PDF Editor Version: 13.0.0 g Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,144.0 2P-431 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&Ad AOGCC Inpsector Bob Noble witnessed, 6'-9" below OG. 2P-431 2/1/2025 mouser Notes: General & Safety Annotation End Date Last Mod By NOTE: P&Ad PULLED SHORE CAN & BACKFILLED EXCAVATION N. STEP: FINAL SITE CLEARANCE (afterSnow Season) 2/2/2025 pproven NOTE: P&Ad AOGCC Inpsector Bob Noble witnessed, 6'-9" below OG 2/1/2025 mouser NOTE: WAIVERED WELL CHARGING OA FROM FORMATION. WAIVER EXPIRES 5/16/15. 1/8/2015 hipshkf NOTE: FOUND LEAK IN MANDREL # 5 @ 8705' 12/7/2012 ninam NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM 9/19/2008 lmosbor 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 36.8 120.0 120.0 62.30 H-40 WELDED SURFACE 7 5/8 6.87 36.7 2,988.2 2,380.9 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @8807' 5 1/2 4.95 3,039.0 9,655.6 5,808.9 15.50 L-80 BTC MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 44.3 Set Depth … 2,512.4 Set Depth … 2,138.4 String Max No… 3 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Top (ftKB) 3,223.0 Set Depth … 8,826.5 Set Depth … 5,386.9 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,253.0 3,045.4 57.04 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,489.9 3,667.3 59.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,409.8 4,147.7 58.55 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,459.8 4,173.6 58.85 SLEEVE-C 4.500 Sliding Sleeve w/DS PROFILE (CLOSED) BAKER CMU 2.813 6,463.7 4,175.7 58.88 OVERSIZED TBG 4.530 SPECIAL 4.53" OD CUT TUBING , OAL= 12', FOR JET PUMP 2.992 6,475.8 4,181.9 58.97 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,514.0 4,201.5 59.25 LOCATOR 4.560 GBH-22 LOCATOR BAKER 3.000 6,514.9 4,202.0 59.26 SEAL 4.000 SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR BAKER 3.000 8,813.7 5,380.3 59.49 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 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) 36.7 36.7 0.00 MARKER PLATE 1/4" x 30" Marker plate @6' 9" Below OG 2/1/2025 0.000 3,043.0 2,408.9 59.40 CUT MSC run on rig @ 3043' 12/31/2024 4.950 3,048.0 2,411.4 59.42 CIBP Modle A Premium Bridge Plug 12/31/2024 0.000 3,223.0 2,499.6 60.06 CUT JET CUT AT 3223' RKB 9/17/2024 2.992 8,723.0 5,334.5 59.82 TUBING PUNCH 4.5' TUBING PUNCH. 18 HOLES. 8/5/2024 2.992 9,254.3 5,606.4 60.61 CIBP CIBP W/ MOE = 9255' PDC, OAL = 1.376' 6/28/2024 0.000 9,291.0 5,624.5 60.24 CIBP CIBP W/ MOE = 9260' PDC, OAL = 1.376' (MOVED DOWNHOLE FROM ORIGINAL SET DEPTH) 3/20/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,290.0 9,300.0 5,624.0 5,629.0 T-3, 2P-431 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60° ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,290.0 9,300.0 1 FRAC 4/20/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 36.7 3,005.0 36.7 2,389.5 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 67000 Drag up (lbs): 75000 Time started reciprocating: 11:30Time stopped reciprocating: 17:15Annular flow after cement job (Y/N): NPressure before cementing (psi): 450Hours circulated between stages: 3.25Bbls cmt to surf: 143Method used to measure density: meter/scalMethod used for mixing cement in this stage: displacemeReturns (pct): 100Time cementing mixing started: 16:17 3/31/2002 9,203.0 9,254.3 5,581.0 5,606.4 Cement Plug Dump Bail Cement Plug 7/2/2024 7,144.0 8,727.5 4,516.8 5,336.8 Cement Plug PUMPED 31 Bbls OF 15.8 PPG CLASS G CMT 9/8/2024 2P-431, 2/25/2025 3:32:28 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @8807'; 3,039.0-9,655.6 IPERF; 9,290.0-9,300.0 FRAC; 9,290.0 CIBP; 9,291.0 CIBP; 9,254.3 Cement Plug; 9,203.0 ftKB GAS LIFT; 8,813.6 TUBING PUNCH; 8,723.0 Cement Plug; 7,144.0 ftKB GAS LIFT; 6,409.8 GAS LIFT; 5,489.9 GAS LIFT; 4,253.0 CUT; 3,223.0 CIBP; 3,048.0 CUT; 3,043.0 SURFACE; 36.7-2,988.2 Plug – Plug Back / Abandonment Plug; 2,512.0 ftKB Cement Casing; 36.7 ftKB CONDUCTOR; 36.8-120.0 MARKER PLATE; 36.7 Plug – Plug Back / Abandonment Plug; 36.7 ftKB KUP PROD KB-Grd (ft) 30.00 RR Date 4/10/2002 Other Elev… 2P-431 ... TD Act Btm (ftKB) 9,685.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032041700 Wellbore Status PROD Max Angle & MD Incl (°) 62.23 MD (ftKB) 5,091.99 WELLNAME WELLBORE2P-431 Annotation Last WO: End DateH2S (ppm) 20 Date 11/23/2015 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,512.0 3,039.0 2,138.2 2,406.8 Plug – Plug Back / Abandonment Plug Pumped 21 bbls of 15.8# Cement with 150# of Bridge Maker II LCM. Laid in balanced plug to calculated TOC of 2,691'. 1/11/2025 36.8 2,512.0 36.8 2,138.2 Plug – Plug Back / Abandonment Plug Pumped 140 bbls of 15.8# PTA cement. Est. 20 bbls good 15.8# returns to surface. 1/13/2025 2P-431, 2/25/2025 3:32:28 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @8807'; 3,039.0-9,655.6 IPERF; 9,290.0-9,300.0 FRAC; 9,290.0 CIBP; 9,291.0 CIBP; 9,254.3 Cement Plug; 9,203.0 ftKB GAS LIFT; 8,813.6 TUBING PUNCH; 8,723.0 Cement Plug; 7,144.0 ftKB GAS LIFT; 6,409.8 GAS LIFT; 5,489.9 GAS LIFT; 4,253.0 CUT; 3,223.0 CIBP; 3,048.0 CUT; 3,043.0 SURFACE; 36.7-2,988.2 Plug – Plug Back / Abandonment Plug; 2,512.0 ftKB Cement Casing; 36.7 ftKB CONDUCTOR; 36.8-120.0 MARKER PLATE; 36.7 Plug – Plug Back / Abandonment Plug; 36.7 ftKB KUP PROD 2P-431 ... WELLNAME WELLBORE2P-431 Plug #4 – Surface TOC 25' RKB BOC @ ±2512' RKB C80 @ 3080' KB Production Casing Cement: 62 bbls of 15.8# Class G Cement Calculated TOC @ 6,460' KB 2P-431 Well Final P&A Schematic Conductor: 16" Conductor 120' KB 1 2 4 7 6Production Casing: 5.5" x 3.5" @ 8,807' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 9,655.6’ KB T-3 Peforations: @ 9,290' – 9,300' KB (10') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,988.2' KB (2381' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 8,826.5' KB 8 /ƚĞŵĞƉƚŚͲƚŽƉƐ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϰϴΖ ϯ ϯϯΖWĂƚĐŚ ϴ͕ϲϴϱΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ ^WƌŽĨŝůĞ;ĐůŽƐĞĚͿ ϴϳϱϰ͘ϱ ϱ ^ƉĞĐŝĂůϰ͘ϱϯΗKĐƵƚƚƵďŝŶŐ͕ K>сϭϮΖĨŽƌũĞƚƉƵŵƉ ϴ͕ϳϱϴ͘ϰϬ ϲ ĂŵĐŽEŝƉƉůĞ ϴ͕ϳϳϬ͘ϱΖ ϳ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϴϬϴ͘ϳΖ ϴ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJ^ƚĂďďĞĚ ŝŶƚŽϯ͘ϱΗWƌŽĚƵĐƚŝŽŶ^'^Z ϴ͕ϴϬϵ͘ϲΖ 5 Plug #1 – Reservoir TOC ±9203' RKB Plug #2 – Intermediate TOC ±7144' RKB BOC @ ±8727' RKB C80 @ 3080' KB Plug #3 – Surface Shoe TOC 2512' RKB (2138' TVD) BOC @ ±3048' RKB DTTMSTART JOBTYP SUMMARYOPS 12/30/2024 RECOMPLETION MIRU. Kill well. RIG ACCEPT 18:00 Circulate 12/31/2024 RECOMPLETION Tested BOP Pulled 3 1/2" tubing, 101 Jts, 1 GLM, 1 3.51' cut joint. RIH w/ CIBP and Set @ 3048' Top of plug, Trip out for multi string cutter. Cut 5 1/2" casing @ 3043', no PSI wrap around on OA. R/U attempt to circ, pressure broke over @ 373 PSI, pumped 1 Bbls. Pressure fell to 300 PSI and held. P/U re cut 5 1/2" CSG #@ 2977'. 1/1/2025 RECOMPLETION Continue cutting 5 1/2" CS @ 2977'. No PSI wrap around. R/U attempt to circ, pressure broke over @ 373 PSI, pumped .5 Bbls. Pressure fell to 300 PSI and held. POOH F/ 2977' T/ 11'. L/D BHA #2 MSC, inspect cutter blades, good wear pattern. Suck out BOP stack. M/U pack of pulling tool, BOLDS and pull pack off. M/U landing joint. Pull hanger off seat & ~25' 5 1/2" CSG @ 310K over. Attempt to circ @ 1 BPM, pressured up T/ 300 PSI. B/D TD. Continue working 5 1/2" CSG T/ 312K over. Pipe parted below hanger. L/D landing joint & hanger. Perform post jarring derrick inspection. Call out Yellow Jacket E-line. R/U E-Line. Run CBL, log F/ 3000' T/ 600'. Log showed heavy bonding T/ 2750'. M/U BHA #4 spear w/ pack off. L/D BHA #4 in shed. M/U BHA #3 MSC T/ 11'. RIH T/ 193'. Change out bad hoses on TD. RIH T/ 2081''. Circ gas & freeze protect out of hole to tiger tank. OWFF. RIH F/ 2081' T/ 2363'. 1/2/2025 RECOMPLETION Cont. RIH T/ 2710'. Cut 5 1/2" CSG @ 2710. OWFF. POOH, L/D BHA #3. M/U BHA #4 spear w/ pack off. RIH had trouble getting grapple into 5 1/2" fish neck. POOH, L/D BHA #4. M/U BHA #5 MSC. RIH cut 10' off top of 5 1/2" fish to leave clean fish top. POOH, L/D BHA #5 & 10'L 5 1/2" fish. M/U BHA #6 spear w/ pack off. RIH engage fish top @ 40'. Pull 5 1/2" CSG up 20'. PUW increased T/ 300K no pipe movement. Release spear & L/D. M/U BHA #7 MSC, RIH re-cut 5 1/2" @ 2703'. POOH, L/D BHA #7. Inspect cutter, 2 missing blades. Remaining blade showed wear pattern. M/U BHA #8 spear w/ pack off. RIH engage fish top @ 20'. Worked PUW T/ 300K no movement. Release spear, POOH & L/D. M/U BHA #9 MSC. RIH & cut 5 1/2" @ 1910'. POOH, L/D BHA #9. Inspect cutter, blades showed good pattern. M/U BHA #10 spear w/ pack off. RIH engage fish top @ 20'. Worked PUW T/ 300K no movement. Release spear, POOH & L/D. M/U BHA #11 MSC. RIH, cut 5 1/2" CSG @ 908'. POOH, L/D BHA #11. Blades showed good wear pattern. M/U BHA #12 spear w/ pack off. Engage fish top, pull 5 1/2" clean from cut @ 908' T/ 884'. Circ STS, Release spear & L/D BHA #12. 1/3/2025 RECOMPLETION L/D 5 1/2" CSG from 884' T/ surface. Set test plug in CSG head. Perform post BOPE usage test 250/2500 PSI. Pull test plug. M/U BHA #13. MSC, Trip in. Cut 5 1/2 @ 1550. TOOH. M/U BHA #14. Fishing BHA W/Jars accelerator, and collars. Engage 5 1/2 @ 908. Work down to 916. PUH 100K. Fish came free. Circ BU 2 BPM @ 110 PSI. OWFF. POOH, L/D BHA #14 & 5 1/2" fish, 14 full joints & 2 cut joints. M/U BHA #15 spear w/ pack off, jars & DC's. RIH engage fish top # 1550', swallow T/ 1558'. Attempt to pull free. Hit jars 5 times @ 100K over, jars not responding correctly. Staged straight pull F/ 220K-370K over, no pipe movement. Release spear. POOH, L/D BHA #15. M/U BHA #16 MSC. RIH T/ 2140'. Locate collar @ 2156'. RIH & cut 5 1/2" CSG @ 2166'. POOH T/ 1720'. 1/4/2025 RECOMPLETION RIH locate collar @ 1735'. RIH cut 5 1/2" CSG @ 1750'. POOH, L/D BHA #16. M/U BHA #17 spear w/ pack off, jars & DC's. RIH engage fish @ 1550', P/U pipe free 3K additional string weight. Circ STS. POOH, L/D BHA #17 & 5 1/2" fish, 12.1 cut joint, 4 full joints & 17.31 cut joint. M/U BHA #18 spear w/ pack off & jars & DC’s. RIH engage fish top @ 1750’. P/U pipe free 7K additional string weight. Circ STS. POOH L/D BHA #18 & 5 1/2" fish, 25.60' cut joint, 9 full joints &17.31' cut joint. M/U BHA #19 spear w/ pack off & jars & DC’s. RIH engage fish top @ 2166’. Pull/Jar on fish, 60 jar hits @ 100K over no pipe movement, release from fish. Post jarring Derrick inspection, POOH L/D BHA #19. M/U BHA #20 MSC. RIH T/ 481' 1/5/2025 RECOMPLETION Continue RIH, locate collar @ 2541'. Cut 5 1/2" CSG @ 2550'. POOH & locate collar @ 2372'. Cut 5 1/2" CSG @ 2360'. POOH, L/D BHA #20. M/U BHA #21 spear. RIH engage fish @ 2166'. Pull/Jar fish free. Jar @ 100K over 6 times. Pull free @ 300K. Circ STS, gas & cement returns. POOH, L/D BHA #21 & 5 1/2" CSG fish, 33.82' cut joint, 3 full joints & 33.32' cut joint.. M/U BHA #22 spear. RIH engage fish @ 2360'. Pull/jar fish free. Jar @ 100K over 9 times. Pull free @ 225K. Circ STS, gas and cement returns. POOH, L/D BHA #22 & 5 1/2" CSG fish, 10.62' cut joint, 4 full joints & 10/79' cut joint. Troubleshoot & repairing IBOP. 1/6/2025 RECOMPLETION Complete repair on IBOP. M/U BHA #23, spear w/ drilling jars. RIH, RIH, engage fish @ 2550'. Pull@ 100K over 1 time. Straight pull T/ 357KL. Pipe free. Circ STS. POOH, L/D BHA #23 5 1/2" fish, 32.55' cut joint, 2 full joints & 14.29' cut joint. M/U BHA #24, short catch spear w/ drilling jars. RIH, engage fish @ 2703'. P/U pipe free. Circ STS. POOH, L/D BHA #24 & 5 1/2" fish, 4.02' cut joint. M/U BHA #25. RIH engage fish @ 2707. Hit jars 1 time @ 75K over. Straight pull 250K, Pipe moving. Dragging up hole 50-100K over. POOH T/ 2565'. Establish circulation. Pump 15 Bbls hi-vis sweep around. Wash in hole T/ 2650'. Divert returns to open top tank. 2P-431 Final Plug and Abandon Summary of Operations 1/7/2025 RECOMPLETION Continue circ contaminated fluid out T/ open top tank. OWFF. Open up. Wash in hole F/ 2650' T/ 2700', clean. OWFF. POOH F/ 2700 T/ 340'. L/D BHA #25. Remove spear. L/D 5 1/2" CSG fish, 30.25' cut joint, 5 full joints, 29.70' cut joint. M/U BHA #26 spear w/ drilling jars. RIH engage fish @ 2978'. Stage jar hits up T/ 100K over. Stage straight pull up T/ 340K over, hit jars 100 times, no pipe movement. Attempt to work right hand torque down to release spear. Jar down on spear. Set down 20K. Rotate 40 RPM to stall. PU and released from fish. Circ BU. Perform post-jarring derrick inspection. 1/8/2025 RECOMPLETION Complete post jarring derrick inspection. OWFF. TOOH w/ BHA #26 F/ top of fish @ 2,978'. L/D BHA #26. Inspect. Recovered spear intact. Found deep scarring on top of spear No-Go. MU BHA #27 (6 3/4" Drift/Dress off). TIH w/ BHA #27 to 2914'. Slip & cut drill line. RIH tag top of fish @ 2979'. Mill T/ 2981', displace to vis 9.8# while milling. Circ BUS. POOH, L/D BHA #27. M/U BHA #28, MSC, RIH, cut 5 1/2" CSG @ 3011'. POOH, L/D BHA #28 (MSC). MU BHA #29 (Spear). TIH w/ Spear and engage fish top @ 2,981'. Rotate slowly to enter stub. No-Go @ 2,987'. Set 20K down. Warm up jars. 1/9/2025 RECOMPLETION Hit 7 jar licks pulling 75K over. Saw 2' of movement. Hit one more jar lick. Pulled 175K over (250K total) and fish came free. PUH to 2,925'. Circ BU. OWFF. Perform post jarring derrick inspection. TOOH w/ BHA #29 (Spear) + fish. L/D spear and fish. Found buckled 5 1/2" collar on fish. Top of fish to buckled collar = 10.92'. Fish OAL = 33.75'. MU BHA #30 (Spear). TIH to surface casing shoe. Wash down to 5 1/2" stub @ 3,011' in open hole. Circ BUS. Engage fish @ 3011'. P/U 10K over. Drag up inside shoe. Circ BUS. POOH, L/D BHA #30. No fish. Inspect grapple, formation behind grapple. M/U BHA #31, spear no pack off. RIH. Wash into open hole & engage fish @ 3011'. Hit jars @ 75K over 1 time, spear slipped off. Attempt to reengage, no joy. POOH, L/D BHA #31. Inspect spear, no grapple. M/U BHA #32 spear w/ extension. RIH. Wash into open hole & engage fish @ 3011'. Cont. TIH to no-go @ 3,024'. Set 25K down. Engage spear. Hit 30 jar licks up @ 75K over (150K total) with straight pulls to 350K. Hit 5 jar licks down. Est. +/- 1' of movement. Continue working fish. 1/10/2025 RECOMPLETION Cont. working fish. Hit 20 additional jar licks pulling 75K over with straight pulls to 350K. 50 hits total. Establish circulation. 1 BPM @ 320 psi. Release from fish to confirm not key seated. Re-engage fish and continue working to free fish. Continue jarring on fish. Hit25 jar licks @ 95K over, pulling to 370K. Perform top drive and derrick inspection. Release from fish, reengage fish. Hit jars @ 100K over, stage straight pull T/ 415K over. No pipe movement. Release from fish. POOH, L/D BHA #32. M/U BHA #33 (Packer mill w/ boot baskets). RIH, wash & ream F/ 2971' T/ fish top @ 3015'. Mill T/ 3,039' (51' below SC shoe), pumping hi vis pill around every 5' milled. Circ BU @ 5 BPM. Swap hole over to neat 9.8# brine. PUH into cased hole. Rotate up through tight spot @ 2,951'. 1/11/2025 RECOMPLETION Wash down and tag @ 3,039' to confirm. P/U into cased hole. Finish Circ out. OWFF. TOOH w/ BHA #33 (Pilot Mill). Saw 25K over pull @ 2,921'. Pump OOH F/ 2,914'. Seeing 10-15K over pulls (dragging metal debris above mill). Cont. pumping OOH. L/D BHA #33. Good wear pattern of mill. Jet BOP stack. L/D boot baskets - full of metal. Clean and clear rig floor. Prep floor to run 3 1/2" Tubing. Run 3 1/2" Tubing to SCS shoe. Wash down to 3,036'. RU HAL cementers. Flood and PT lines. Batch up cement (cement wet @ 15:34). Pump 22.5 bbls of 10# spacer ahead. Drop Foam Ball. Pump 21 bbls of 15.8# Cement w/ LCM. Drop Foam Ball. Pump 5.7 bbls 10# spacer behind. Displace balanced plub w/ 14.5 bbls of 9.8# brine. R/D cement manifold. Pull 3 1/2" cement string to safety. (rack back 7 stands). Cement in place @ 18:15. Circ out @ 5 BPM/120 psi. SD pumps. WOC for 29 hours (500 psi + 3 hrs). L/D 7 stands and collars. Kick out YJ tools. 1/12/2025 RECOMPLETION Continue to WOC until 23:30. Clean up rig floor and pipe shed. Clean up Draw Works. L/D 3 stands of Tubing. Perform rig maintenance while WOC. At 23:30, screw in TD. Obtain parameters. TIH to 2,442'. 1/13/2025 RECOMPLETION Wash down single. Start seeing green cement @ 2,509', Find hard TOC tag @ 2,512'. Set 6K down. PUH. Repeat tag. Mark pipe. P/U 5' off tag and Circ STS. SD Pumps. PUH. L/D single. P/U testing equipment. PT cement plug to 1,500 PSI for 30-min. Chart. Passed. Bleed off. Space out. M/U and Land hanger. RILDS. Pump STB down Tubing, taking returns to cuttings tank. OWFF. Jet BOP stack. Drain stack. Perform BMW. N/D BOP. N/U adaptor spool & tree. PT hanger void T/ 5000 PSI for 10 Min. R/U HES & circ equipment. PT cement line T/ 3000 PSI. HES pump 20 Bbls fresh water spacer w/ surf. wash. Pumped 140 bbls 15.8 PPG PTA cement. Good 15.8# at surface. Est. 20 bbls cement returns to cuttings tank. SD pumps. Close IA and Wing valve. Flush lines w/ Rinse aid and blowdown hardline. R/D cellar hoses and hardline. Obtain final pressures. Clean and clear cellar. Release rig @ 00:00. Prep for rig move to 2P-429. 1/20/2025 ACQUIRE DATA (P&A) DDT-T TO 0 PSI (PASSED), DDT-IA X OA TO 0 PSI (PASSED) 1/26/2025 ACQUIRE DATA (P&A) REMOVE TREE, IA AND OA VALVES (COMPLETE) TOC @ SF. NEXT STEP CUT/REMOVE WELLHEAD AND CELLAR. 1/27/2025 ACQUIRE DATA (P&A) PREP IN PROGRESS. CUT/ REMOVED 6’-9.5" OF WELLHEAD/CONDUCTOR. ***NEXT STEP- REMOVE CELLAR BOX BEGIN EXCAVATING TO 14' FOR SHORE CAN INSTALL.*** 1/28/2025 ACQUIRE DATA (P&A) PREP IN PROGRESS, REMOVE CELLAR (COMPLETE) ***NEXT STEP- BEGIN EXCAVATING TO 14' FOR SHORE CAN INSTALL.*** 1/29/2025 ACQUIRE DATA (P&A) PREP- BEGAN EXCAVATION, TD OF 14' TO SET SHORE CAN FOR WELL STUB REMOVAL. OBTAINED 6'. ***NEXT STEP: EXCAVATE TO 14' SET SHORE CAN, CUT AND REMOVE MINIMUM OF 5' 3" MORE OF WELL STUB TO MEET 4' BELOW OG REQUIREMENT.*** 1/30/2025 ACQUIRE DATA (P&A) PREP - IN PROGRESS. EXCAVATED TO 14' SET SHORE CAN, BACKFILLED AROUND SHORE CAN. ***NEXT STEP- CUT/REMOVE MORE OF THE WELL STUB AND PREP REMAINING WELL STUB FOR MARKER PLATE.*** 1/31/2025 ACQUIRE DATA (P&A) IN PROGRESS- CUT AND REMOVED ADDITIONAL 92" (7'- 8") OF WELL STUB. COMBINED WITH ORIGINAL 6'-9" (81") OF WELLHEAD REMOVED, ESTIMATED 81" OR 6'-9" BELOW OG. PREPARED REMAINING WELL STUB FOR MARKER PLATE WELD. ***NEXT STEP: AOGCC SCHEDULED TO VERIFY TOC AND MARKER PLATE INFORMATION . WELD MARKER PLATE, PULL SHORE CAN BACKFILL EXCAVATION FOR FINAL SITE CLEARANCE.*** 2/1/2025 ACQUIRE DATA (P&A) AOGCC INSPECTOR BOB NOBLE VERIFIED MARKER PLATE INFORMATION AND TOC. AGREED MARKER PLATE IS 6' 9" BELOW OG. WELDED MARKER PLATE. RDMO PRIOR TO PULLING SHORE CAN, FOR NORDIC 3 CEMENT JOB.. ***NEXT STEP: PULL SHORE CAN AND BACKFILL FOR FINAL SITE CLEARANCE.*** 2/2/2025 ACQUIRE DATA (P&A) COMPLETE- PULLED SHORE CAN AND BACKFILLED EXCAVATION. NEXT STEP: FINAL SITE CLEARANCE (AFTER SNOW SEASON) Page 1/17 2P-431 Report Printed: 2/25/2025 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) 12/30/2024 06:00 12/30/2024 18:00 12.00 MIRU, MOVE MOB P RDMO F/2P-432 T/P2 -431 Due to wind blowing chill factor -65 Set mats for pulling off well, Spot mats and herculite around new well, pull rig on well and center/level. Take on 9.8 Brine R/U hard lines test lines t/2500psi Rig Accept 18:00 0.0 0.0 12/30/2024 18:00 12/30/2024 20:30 2.50 MIRU, WELCTL KLWL P Start pumping down tubing taking returnes through choke manifold. pump 35 bbl deep clean pill and chase with 107 bbls 9.8 ppg NaCl. ICP 445 psi/FCP 612psi. Shut down No flow monitor well 30 mins All good Blow down all lines. 0.0 0.0 12/30/2024 20:30 12/31/2024 00:00 3.50 MIRU, WELCTL NUND P Pull tree off and inspect hanger threads. NU BOP stack. 0.0 0.0 12/31/2024 00:00 12/31/2024 00:30 0.50 MIRU, WELCTL NUND P Continue N/U BOP. 0.0 0.0 12/31/2024 00:30 12/31/2024 07:00 6.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 2 7/8" and 5 1/2"", UVBR's, w/ 2 7/8" donut test joints. Test blinds rams. No Test LPR 7" 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 = 2950 PSI, after closure = 1700 PSI, 200 PSI attained = 25 sec, full recovery attained =115 sec. UVBR's = 4 sec Annular = 20 sec. Simulated blinds = 5 sec. HCR choke & kill = 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. AOGCC witness waived by Sean Sullivan 0.0 0.0 12/31/2024 07:00 12/31/2024 08:30 1.50 COMPZN, RPCOMP THGR P M/U 3 1/2" EUE landing Jt BOLDS Pull Hanger t/foor Up Wt 55K L/D same Monitor well 30 mins 3,223.0 3,183.0 12/31/2024 08:30 12/31/2024 11:30 3.00 COMPZN, RPCOMP PULL P Cont L/D 3 1/2" Eue Tubing F/ 3183', PUW=55K. L/D 101 joints & 3,51' cut joint. 1 GLM. 1 X nipple 3,183.0 0.0 12/31/2024 11:30 12/31/2024 12:00 0.50 COMPZN, RPCOMP CLEN P Clean & clean RF. 0.0 0.0 12/31/2024 12:00 12/31/2024 12:30 0.50 COMPZN, RPCOMP RURD P R/U 2 7/8" handling equipment. 0.0 0.0 12/31/2024 12:30 12/31/2024 12:42 0.20 COMPZN, RPCOMP BHAH P M/U BHA #1 CIPB T/ 10.74 0.0 10.7 12/31/2024 12:42 12/31/2024 13:42 1.00 COMPZN, RPCOMP TRIP P Trip in hole 2 7/8" DP with CIBP 10.7 1,700.0 12/31/2024 13:42 12/31/2024 14:12 0.50 COMPZN, RPCOMP SVRG P Service rig top drive 1,700.0 1,700.0 12/31/2024 14:12 12/31/2024 14:42 0.50 COMPZN, RPCOMP TRIP P Con Continue in hole. 43 stands and single, PUW=58K. SOW-54K 1,700.0 3,044.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 2/17 2P-431 Report Printed: 2/25/2025 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) 12/31/2024 14:42 12/31/2024 15:12 0.50 COMPZN, RPCOMP MPSP P KU, Get on depth 3049. Top of plug @ 3048 Drop 5/8" ball. Pump on .5 BPM. See tool shift at 1700 PSI. Hole 2000 PSI 5 min. P/U to neutral weight. Pressure up to shear tool @ 2360 PSI. P/U off plug 55K. Bleed off drill pipe. Set back down @ 3048'. Set down10K, Plug is set. 3,044.0 3,048.0 12/31/2024 15:12 12/31/2024 15:30 0.30 COMPZN, RPCOMP RURD P PUH, Kelly down, Blow down top drive. Prep for trip out 3,048.0 3,022.0 12/31/2024 15:30 12/31/2024 16:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 3048/ T/ 10', PUW=55K. 3,022.0 10.0 12/31/2024 16:30 12/31/2024 17:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 CIPB setting tool. 10.0 0.0 12/31/2024 17:00 12/31/2024 17:30 0.50 COMPZN, RPCOMP PRTS P PT CIBP T/ 1000 PSI for 10 Min. R/D testing equipment. 0.0 0.0 12/31/2024 17:30 12/31/2024 18:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 MSC T/ 11'. 0.0 11.0 12/31/2024 18:00 12/31/2024 20:00 2.00 COMPZN, RPCOMP TRIP P RIH F/ 11' T/ 2990', SOW=55K. 11.0 2,990.0 12/31/2024 20:00 12/31/2024 22:00 2.00 COMPZN, RPCOMP SLPC P Slip & cut 66' of drill line. 2,990.0 2,990.0 12/31/2024 22:00 12/31/2024 22:30 0.50 COMPZN, RPCOMP TRIP P Circ @ 1 BPM, 370 PSI. RIH F/ 2990' T/ 3048', tag CIBP, could not locate any collars. P/U T/ 3039', circ 1.5 BPM, 500 PSI. RIH tag plug top @ 3048'. No collar located. PUW=55K, SOW=52K. 2,990.0 3,048.0 12/31/2024 22:30 12/31/2024 23:00 0.50 COMPZN, RPCOMP CPBO P P/U T/ 3043'. Cut 5 1/2" CSG @ 2043'. Pump @ 2 BPM, 1180 PSI. Rot @ 80 RPM, 1,5K Free Tq. ROT=55K. Tq 1.7K-3K. Fell off to free Tq. No PSI wrap around up OA. Gas migrating inside 5 1/2" CSG. 3,048.0 3,043.0 12/31/2024 23:00 12/31/2024 23:30 0.50 COMPZN, RPCOMP CIRC P POOH T/ 3020'. B/D TD. M/U TIW valve. Close UPR. Attempt to circ through cut. Pressured up, pressure broke over @ 373 PSI. Pump 1 Bbls. Shut off pumps pressure stabilized @ 300 PSI. No fluid movement up OA. Bleed off OA. Open LPR. B/D OA circ manifold. 3,043.0 3,020.0 12/31/2024 23:30 12/31/2024 23:45 0.25 COMPZN, RPCOMP TRIP P P/U T/ 2972'. Circ @ 1.5 BPM, 480 PSI. RIH F/ 2972' T/ 2983', could not locate any collars. PUW=55K, SOW=52K. 3,020.0 2,983.0 12/31/2024 23:45 1/1/2025 00:00 0.25 COMPZN, RPCOMP CPBO P P/U T/ 2977', Cut 5 1/2" CSG @ 2 BPM, 1180 PSI. Rot @ 80 RPM, 1,5K Free Tq. ROT=55K. Tq 1.7K-3K. Fell off to free Tq. No PSI wrap around up OA. Gas migrating inside 5 1/2" CSG. 2,983.0 2,977.0 1/1/2025 00:00 1/1/2025 00:15 0.25 COMPZN, RPCOMP CPBO P Continue to Cut 5 1/2" CSG @ 2 BPM, 1180 PSI. Rot @ 80 RPM, 1,5K Free Tq. ROT=55K. Tq 1.7K-3K. Fell off to free Tq. No PSI wrap around up OA. Gas migrating inside 5 1/2" CSG. 2,977.0 2,977.0 1/1/2025 00:15 1/1/2025 01:00 0.75 COMPZN, RPCOMP CIRC P POOH T/ 2957'. B/D TD. M/U TIW valve. Close UPR. Attempt to circ through cut. Pressured up, pressure broke over @ 373 PSI. Pump .5 Bbls. Shut off pumps pressure stabilized @ 300 PSI. No fluid movement up OA. Bleed off OA. Open LPR. B/D OA circ manifold. 2,977.0 2,957.0 1/1/2025 01:00 1/1/2025 02:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2957' T/ 11'. PUW=56K. 2,957.0 11.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 3/17 2P-431 Report Printed: 2/25/2025 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) 1/1/2025 02:00 1/1/2025 02:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #2 MSC. Inspect cutter blades, good wear pattern. 11.0 0.0 1/1/2025 02:30 1/1/2025 03:00 0.50 COMPZN, RPCOMP WWSP P Suck out BOP stack. M/U pack off pulling tool. BOLDS. Pull 11" x 5 1/2" pack off & L/D on RF. 0.0 0.0 1/1/2025 03:00 1/1/2025 03:30 0.50 COMPZN, RPCOMP RURD T Clean up damaged starting thread on landing joint. 0.0 0.0 1/1/2025 03:30 1/1/2025 04:00 0.50 COMPZN, RPCOMP RURD P M/U landing joint to hanger. K/U on landing joint. 0.0 2,977.0 1/1/2025 04:00 1/1/2025 04:45 0.75 COMPZN, RPCOMP PULL P Pull 5 1/2" CSG. Pulled ~25' @ 310K over. Attempt to circ, 1 BPM, pressure climbed to 300 PSI no fluid movement in stack. 2,977.0 2,977.0 1/1/2025 04:45 1/1/2025 05:00 0.25 COMPZN, RPCOMP RURD P B/D TD. 2,977.0 2,977.0 1/1/2025 05:00 1/1/2025 05:30 0.50 COMPZN, RPCOMP PULL P Continue T/ pull 5 1/2" CSG working PUW T/ 312K over blocks. Pipe parted at connection below hanger. 2,977.0 2,977.0 1/1/2025 05:30 1/1/2025 06:00 0.50 COMPZN, RPCOMP RURD P Lay down landing joint 2,977.0 0.0 1/1/2025 06:00 1/1/2025 11:00 5.00 COMPZN, RPCOMP SFTY P Post jarring inspection on derrick & TD. Straighten out wraps of drill line on drum. Replace weight indicator load cell. Trouble shoot pig tail wiring 0.0 0.0 1/1/2025 11:00 1/1/2025 12:30 1.50 COMPZN, RPCOMP ELNE P PJSM with YJOS eline. MIRU E-line for CBL . 0.0 0.0 1/1/2025 12:30 1/1/2025 16:30 4.00 COMPZN, RPCOMP ELOG P RIH for cement bond log. Log from 3000' T/ 600'. Log showed significant bonding up T/ 2750'. R/D E-line. 0.0 0.0 1/1/2025 16:30 1/1/2025 17:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #4 M/U spear w/ pack off. L/D in shed. 0.0 0.0 1/1/2025 17:30 1/1/2025 18:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #3 MSC T/ 11'. 0.0 11.0 1/1/2025 18:00 1/1/2025 18:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 11' T/ 193'. 11.0 193.0 1/1/2025 18:30 1/1/2025 19:00 0.50 COMPZN, RPCOMP SVRG P Servicce rig. Replace bad hydraulic hoses on TD. 193.0 193.0 1/1/2025 19:00 1/1/2025 20:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 193' T/ 2081'. PUW=45K, SOW=45K. Retrun flow rate increeased. Gas bubling in stack. 193.0 2,081.0 1/1/2025 20:00 1/1/2025 23:00 3.00 COMPZN, RPCOMP CIRC P Stabbed TIW valve & SI. Close UPR. Open HCR choke. Recoerd pressure. 20 PSI on CSG. R/U circ hose T/ TIW. Open super choke, taking returns out to tiger tank, pumping @ 1 BPM, 375 PSI. Pumped total of 100 Bbls. 100 Bbls reteruned. Shut down pumps. 2,081.0 2,081.0 1/1/2025 23:00 1/1/2025 23:45 0.75 COMPZN, RPCOMP OWFF P OWFF, verify no flow. Open UPR & TIW. R/D, B/D circ equipment & tiger tank line. 2,081.0 2,081.0 1/1/2025 23:45 1/2/2025 00:00 0.25 COMPZN, RPCOMP TRIP P RIH F/ 2081' T/ 2363'. PUW=50K, SOW=50K. 2,081.0 2,363.0 1/2/2025 00:00 1/2/2025 00:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 2363' T/ 2703'. PUW=55K, SOW=50K 2,363.0 2,703.0 1/2/2025 00:30 1/2/2025 01:00 0.50 COMPZN, RPCOMP CPBO P Obtain parameters. Rot @ 80 RPM, 1.8K Free Tq. ROT=54K. Cut 5 1/2" CSG @ 2703'. Pump @ 2 BPM, 1280 PSI. Tq= 1.8-2.4K. 2,703.0 2,703.0 1/2/2025 01:00 1/2/2025 02:15 1.25 COMPZN, RPCOMP TRIP P OWFF - no flow. B/D TD. POOH F/ 2703' T/ 11' PUW=55K. 2,703.0 11.0 1/2/2025 02:15 1/2/2025 02:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 MSC. Marginal wear pattern on cutter blades. Does not appear blades fully extended. 11.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 4/17 2P-431 Report Printed: 2/25/2025 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) 1/2/2025 02:45 1/2/2025 03:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 spear w/ pack off. RIH had trouble getting grapple into 5 1/2" fish top. POOH L/D BHA #4. 0.0 0.0 1/2/2025 03:15 1/2/2025 03:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #5 MSC. Dress w/ good blades. RIH T/ 40' 0.0 40.0 1/2/2025 03:45 1/2/2025 04:00 0.25 COMPZN, RPCOMP CPBO P Obtain parameters. Rot @ 80 RPM, 1.1K Free Tq. ROT=33K. Cut 5 1/2" CSG @ 40'. Pump @ 1.5 BPM, 1480 PSI. Tq= 1.1-1.5K. 40.0 40.0 1/2/2025 04:00 1/2/2025 04:30 0.50 COMPZN, RPCOMP BHAH P POOH, L/D BHA #5 MSC & 10'L 5 1/2" CSG cut. Top of fish swedged down. 40.0 0.0 1/2/2025 04:30 1/2/2025 05:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6 spear w/ pack off. RIH & engage fish top @ 40'. 0.0 40.0 1/2/2025 05:00 1/2/2025 05:30 0.50 COMPZN, RPCOMP FISH P Pull 5 1/2" CSG up 20'. PUW increased to 300K. No pipe movement. Release spear & L/D. 40.0 0.0 1/2/2025 05:30 1/2/2025 06:30 1.00 COMPZN, RPCOMP BHAH P C/O cutter blade pins, Clear and clean rig floor M/U cutter, M/U BHA #7 MSC 0.0 6.0 1/2/2025 06:30 1/2/2025 08:00 1.50 COMPZN, RPCOMP TRIP P TIH BHA #7 to 2709, Pull single off stand 29 6.0 2,708.0 1/2/2025 08:00 1/2/2025 10:30 2.50 COMPZN, RPCOMP CPBO P KU, Break circulation. Attempt to locate cut 2660 to 2720. Tag at 2672, 2705. space out knives @ 2708. Make cut @ 2708' Hit torque stop at 3500 Lb/Ft. Stall. popped free before could get top drive shut down. Back lash string. Broke loose below saver sub at X-O. B/O XO. Blow down top drive. OWFF 2,708.0 2,708.0 1/2/2025 10:30 1/2/2025 11:18 0.80 COMPZN, RPCOMP TRIP P Trip out of hole BHA #7, PUW=55K 2,708.0 10.1 1/2/2025 11:18 1/2/2025 11:30 0.20 COMPZN, RPCOMP BHAH P Lay down BHA # 7 cutter. Two cutter blades lost in hole. 3" X 1.5" X 1" 10.1 0.0 1/2/2025 11:30 1/2/2025 13:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA #8 Spear. Latch 5 1/2" casing @ 20'. Work pipe up to 300K. Attempt circulation. No rise if static fluid level. No returns 0.0 20.0 1/2/2025 13:00 1/2/2025 13:06 0.10 COMPZN, RPCOMP BHAH P Lay down BHA # 8 Spear 20.0 0.0 1/2/2025 13:06 1/2/2025 13:36 0.50 COMPZN, RPCOMP OWFF P Observe well for flow. Consult town. Discuss options for plan forward 0.0 0.0 1/2/2025 13:36 1/2/2025 15:30 1.90 COMPZN, RPCOMP TRIP P M/U BHA # 9, MSC tool, Trip in well 20 stands & single. Torque every connection 0.0 1,892.0 1/2/2025 15:30 1/2/2025 16:30 1.00 COMPZN, RPCOMP CPBO P Kelly up. Attempt to locate collars 1892 to 1905. Bobble @ 1904. Make cut at 1910. PUW=47K, RIW=47K, FT=1289 LB/FT. 2 BPM @ 1210 PSI. Set off low level gas alarm. Shipped returns to cuttings box 1,892.0 1,910.0 1/2/2025 16:30 1/2/2025 16:48 0.30 COMPZN, RPCOMP CPBO P Never observed torque increase, . Pick up single. attempt to locate cut. Locate collar 1947' 1,910.0 1,947.0 1/2/2025 16:48 1/2/2025 17:48 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1947' T/ 11'. PUW=47K. 1,947.0 11.0 1/2/2025 17:48 1/2/2025 18:18 0.50 COMPZN, RPCOMP BHAH P L/D BHA #9. Inspect cutter blades. Good wear pattern on blades, Mobilize new cutter T/ RF. 11.0 0.0 1/2/2025 18:18 1/2/2025 18:48 0.50 COMPZN, RPCOMP BHAH P M/U BHA #10 spear w/ pack off. RIH engage 5 1/2" fish top @ ~20'. 0.0 20.0 1/2/2025 18:48 1/2/2025 19:00 0.20 COMPZN, RPCOMP FISH P Pull on 5 1/2" CSG fish. Work PUW F/ 100K T/ 300K, no pipe movement. POOH, L/D BHA #10. 20.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 5/17 2P-431 Report Printed: 2/25/2025 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) 1/2/2025 19:00 1/2/2025 19:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #11 MSC T/ 11'. 0.0 11.0 1/2/2025 19:45 1/2/2025 20:15 0.50 COMPZN, RPCOMP TRIP P RIH F/ 11' T/ 921'. PUW=40K, SOW=40K. 11.0 921.0 1/2/2025 20:15 1/2/2025 20:30 0.25 COMPZN, RPCOMP CIRC P P/U T/ 889'. Circ @ 1 BPM, 255 PSI. RIH locate collar @ 918'. P/U T/ 908' 921.0 908.0 1/2/2025 20:30 1/2/2025 21:00 0.50 COMPZN, RPCOMP CPBO P Rot @ 80 RPM, 1.1K Free Tq. Cut 5 1/2" CSG @ 908'. Pump @ 2 BPM, 880 PSI. 1.1-1.6K Tq. P/U T/ 898'. Circ 1 BPM, 250 PSI, locate cut @ 908 w/ mule shoe below cutter. 908.0 908.0 1/2/2025 21:00 1/2/2025 21:15 0.25 COMPZN, RPCOMP OWFF P B/D TD. OWFF - no flow. 908.0 889.0 1/2/2025 21:15 1/2/2025 21:45 0.50 COMPZN, RPCOMP TRIP P POOH F/ 889' T/ 11'. PUW=40K. 889.0 11.0 1/2/2025 21:45 1/2/2025 22:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #11. Inspect cutter. Good wear pattern on blades. 11.0 0.0 1/2/2025 22:00 1/2/2025 22:15 0.25 COMPZN, RPCOMP BHAH P M/U BHA #12 spear w/ pack off. RIH engage fish top. Pull 5 1/2" CSG from cut @ 908' T/ 884'. Clean pick up. PUW=48K. 908.0 884.0 1/2/2025 22:15 1/2/2025 22:45 0.50 COMPZN, RPCOMP CIRC P Circ STS @ 3 BPM, 155 PSI. 884.0 884.0 1/2/2025 22:45 1/2/2025 23:00 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow. 884.0 884.0 1/2/2025 23:00 1/3/2025 00:00 1.00 COMPZN, RPCOMP BHAH P Remove spear from CSG. L/D BHA #12 & cut joint. 884.0 884.0 1/3/2025 00:00 1/3/2025 00:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. Prep for L/D 5 1/2" CSG. 884.0 884.0 1/3/2025 00:30 1/3/2025 01:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Work on 5 1/2" elevators. 884.0 884.0 1/3/2025 01:00 1/3/2025 02:00 1.00 COMPZN, RPCOMP PULL P L/D 5 1/2" CSG F/ 884' T/ surface. L/D 35.08' cut joint, 19 full joints & 33.66' cut joint. Lower cut was rough. 884.0 0.0 1/3/2025 02:00 1/3/2025 02:15 0.25 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 1/3/2025 02:15 1/3/2025 02:30 0.25 COMPZN, RPCOMP WWWH P Jet BOP stack. 0.0 0.0 1/3/2025 02:30 1/3/2025 03:00 0.50 COMPZN, RPCOMP MPSP P Set test plug in CSG head. 0.0 0.0 1/3/2025 03:00 1/3/2025 03:30 0.50 COMPZN, RPCOMP RURD P R/U 2 7/8" test joint & testing equipment. Fill stack w/ fresh water. 0.0 0.0 1/3/2025 03:30 1/3/2025 04:00 0.50 COMPZN, RPCOMP BOPE P Post usage BOPE test. 2 7/8" UPR. HCR choke & kill 250/2500 PSI for 5 Min each. 0.0 0.0 1/3/2025 04:00 1/3/2025 05:00 1.00 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Pull test plug. 0.0 0.0 1/3/2025 05:00 1/3/2025 05:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA # 13 MSC tool, 0.0 10.1 1/3/2025 05:30 1/3/2025 06:00 0.50 COMPZN, RPCOMP TRIP P RIH F/ 10' T/ 481'. 10.1 481.0 1/3/2025 06:00 1/3/2025 06:30 0.50 COMPZN, RPCOMP RGRP T Replace compensator hose on top drive 481.0 481.0 1/3/2025 06:30 1/3/2025 07:00 0.50 COMPZN, RPCOMP TRIP P Continue in well to 1610 481.0 1,610.0 1/3/2025 07:00 1/3/2025 08:30 1.50 COMPZN, RPCOMP CPBO P Lay down single on stand 17, KU, 1 BPM @ 284 PSI. Locate collar @ 1558. Slack off, PUH to 1550', Make cut. 2 BPM @ 984 PSI, 40 RPM, F- torque=1200Lb/Ft, 1,610.0 1,550.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 6/17 2P-431 Report Printed: 2/25/2025 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) 1/3/2025 08:30 1/3/2025 09:00 0.50 COMPZN, RPCOMP OWFF P OWFF, 30 min, Lay down single, Break off X-O, Make up stand 17. Blow down top drive. Well is static 1,550.0 1,516.0 1/3/2025 09:00 1/3/2025 09:30 0.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=45K 1,516.0 10.4 1/3/2025 09:30 1/3/2025 10:00 0.50 COMPZN, RPCOMP BHAH P Lay down MSC, Pull used cutters. Good wear pattern 10.4 0.0 1/3/2025 10:00 1/3/2025 10:30 0.50 COMPZN, RPCOMP RURD P Swap out pipe handleing equipment 2 7/8" to 3 1/2". Pre3p for BHA #15 Spear run with jars & collars 0.0 0.0 1/3/2025 10:30 1/3/2025 11:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA #14. Spears, jars, acelorator, and collars 0.0 230.0 1/3/2025 11:00 1/3/2025 12:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole to 908 see spear go into 5 1/2 Tubing to 916' Tap down twice. PUH to 100K. Fish came free 230.0 916.0 1/3/2025 12:00 1/3/2025 12:30 0.50 COMPZN, RPCOMP CIRC P PUH , Circulate 2 BPM @ 110 PSI, 916.0 916.0 1/3/2025 12:30 1/3/2025 13:00 0.50 COMPZN, RPCOMP OWFF P OWFF, well is static 916.0 916.0 1/3/2025 13:00 1/3/2025 13:30 0.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=55K 916.0 230.2 1/3/2025 13:30 1/3/2025 14:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA # 14 to spear 230.0 0.0 1/3/2025 14:00 1/3/2025 15:00 1.00 COMPZN, RPCOMP RURD P Chage out pipe hadleing equipment to 5 1/2, 642.0 0.0 1/3/2025 15:00 1/3/2025 15:30 0.50 COMPZN, RPCOMP PULL P Lay down 5 1/2" completion 908 to 1550, 14 Jts & 2 cut joints, 30.92 & 10.0 0.0 0.0 1/3/2025 15:30 1/3/2025 16:30 1.00 COMPZN, RPCOMP RURD P Reconfigure pipe handleing pipe handleing equipment to 3 1/2 DP 0.0 0.0 1/3/2025 16:30 1/3/2025 17:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #15, spear w/ pack off, jars & DC's T/ 230'. 0.0 230.0 1/3/2025 17:00 1/3/2025 17:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 230' T/ 1530'. PUW=55K, SOW=55K. 230.0 1,530.0 1/3/2025 17:30 1/3/2025 19:30 2.00 COMPZN, RPCOMP FISH P RIH fully engage 5 1/2" CSG stub down T/ 1558'. Warm up jars. Beat down on CSG. Hit jars @ 100K over, working straight pull up F/ 220K T/ 370K over. Hit jars 5 times. Jars not functioning properly. Release spear. P/U 1527'. PUW=55K. 1,530.0 1,530.0 1/3/2025 19:30 1/3/2025 20:15 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1527' T/ 230', PUW=55K. 1,530.0 230.0 1/3/2025 20:15 1/3/2025 21:00 0.75 COMPZN, RPCOMP BHAH P L/D BHA #15. Rack back DC's. L/D accelerator, jars & bumpers sub F/ 230' T/ surface. PUW=43K. 230.0 0.0 1/3/2025 21:00 1/3/2025 21:30 0.50 COMPZN, RPCOMP RURD P Swap handling equipment T/ 2 7/8" 0.0 0.0 1/3/2025 21:30 1/3/2025 21:45 0.25 COMPZN, RPCOMP BHAH P M/U BHA #16 MSC T/ 11' 0.0 11.0 1/3/2025 21:45 1/3/2025 23:00 1.25 COMPZN, RPCOMP TRIP P RIH F/ 11' T/ 2140', PUW=50K, SOW=50K 11.0 2,140.0 1/3/2025 23:00 1/3/2025 23:15 0.25 COMPZN, RPCOMP CIRC P Circ @ 1.8 BPM, 640 PSI. RIH locate collar @ 2156'. Kill pump. RIH T/ 2166' 2,140.0 2,166.0 1/3/2025 23:15 1/3/2025 23:30 0.25 COMPZN, RPCOMP CPBO P Rot @ 80 RPM, 1.2K Free Tq. Pump @ 2 BPM, 825 PSI. Cut 5 1/2" CSG @ 2166'. ROT=50K. 1.2-2.2K Tq, Tq fell off. P/U T/ 2164'. Kill Rot. Circ @ 1.5 BPM, RIH locate cut @ 2166'. 2,166.0 2,166.0 1/3/2025 23:30 1/3/2025 23:45 0.25 COMPZN, RPCOMP OWFF P P/U T/ 2140'. OWFF. B/D TD. 2,166.0 2,140.0 1/3/2025 23:45 1/4/2025 00:00 0.25 COMPZN, RPCOMP TRIP P POOH F/ 2140 T/ 1720', PUW=50K. 2,140.0 1,720.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 7/17 2P-431 Report Printed: 2/25/2025 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) 1/4/2025 00:00 1/4/2025 00:15 0.25 COMPZN, RPCOMP CIRC P Circ @ 1.5 BPM, 377 PSI. RIH locate collar @ 1735'. Kill pump. RIH T/ 1750' 1,720.0 1,750.0 1/4/2025 00:15 1/4/2025 00:30 0.25 COMPZN, RPCOMP CPBO P Rot @ 80 RPM, 1.1K Free Tq. Pump @ 2 BPM, 800 PSI. Cut 5 1/2" CSG @ 1750'. ROT=50K. 1.1-1.6K Tq, Tq fell off. P/U T/ 1748'. Kill Rot. Circ @ 1 BPM, RIH locate cut @ 1750'. 1,750.0 1,750.0 1/4/2025 00:30 1/4/2025 00:45 0.25 COMPZN, RPCOMP OWFF P P/U T/ 1733'. OWFF. B/D TD. 1,750.0 1,733.0 1/4/2025 00:45 1/4/2025 01:15 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1733' T/ 11'. PUW=49K. 1,733.0 11.0 1/4/2025 01:15 1/4/2025 01:30 0.25 COMPZN, RPCOMP BHAH P L/D BHA #16. Cutter blades showed good wear pattern. 11.0 0.0 1/4/2025 01:30 1/4/2025 02:15 0.75 COMPZN, RPCOMP RURD P Change handling equipment T/ DP. Mobilize tools for BHA #15. 0.0 0.0 1/4/2025 02:15 1/4/2025 03:00 0.75 COMPZN, RPCOMP BHAH P M/U BHA #17 spear w/ pack off, jars & DC's T/ 230'. SOW=45K. 0.0 230.0 1/4/2025 03:00 1/4/2025 03:30 0.50 COMPZN, RPCOMP SFTY P Crew change out. Welcome back meeting. 230.0 230.0 1/4/2025 03:30 1/4/2025 04:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 230'. Engage fish top @ 1550', swallow T/ 1558'. PUW=59K, SOW=57K. 230.0 1,550.0 1/4/2025 04:30 1/4/2025 04:45 0.25 COMPZN, RPCOMP FISH P P/U pipe free PUW=62K. Rack back stand T/ 1727' 1,550.0 1,727.0 1/4/2025 04:45 1/4/2025 06:00 1.25 COMPZN, RPCOMP CIRC P Circ STS @ 3 BPM, 210 PSI. OWFF, Blow down TD 1,727.0 1,727.0 1/4/2025 06:00 1/4/2025 06:30 0.50 COMPZN, RPCOMP SVRG P Service Rig, Top drive & draw works 0.0 0.0 1/4/2025 06:30 1/4/2025 07:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1727' T/ 430' PUW=62K. 1,727.0 430.0 1/4/2025 07:00 1/4/2025 07:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #17 F/ 430' T/ 200'. PUW 48K. 430.0 200.0 1/4/2025 07:30 1/4/2025 08:00 0.50 COMPZN, RPCOMP RURD P C/O handling equipment for 5 1/2" CSG. 200.0 200.0 1/4/2025 08:00 1/4/2025 08:30 0.50 COMPZN, RPCOMP PULL P L/D 5 1/2" CSG fish. 12.1 cut joint, 4 full joints & 17.31 cut joint. 200.0 0.0 1/4/2025 08:30 1/4/2025 09:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. C/O handling equipment 0.0 0.0 1/4/2025 09:00 1/4/2025 09:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #18 spear w/ pack off, jars & DC's T/ 230'. SOW=45K. 0.0 230.0 1/4/2025 09:30 1/4/2025 10:00 0.50 COMPZN, RPCOMP TRIP P Trip in hole to 1713', KU, PUW=69K, SOW=59K 230.0 1,713.0 1/4/2025 10:00 1/4/2025 10:30 0.50 COMPZN, RPCOMP FISH P KU, PUW=69K, SOW=59K, Sting into fish 1750 to 1758', PUH 7K over pull. Fish free. Lay down single. Screw in. Circ BU 1,713.0 1,710.0 1/4/2025 10:30 1/4/2025 11:30 1.00 COMPZN, RPCOMP CIRC P Circ BU 3 BPM 210 PSI. No gas. clean returns OWFF 2,165.0 2,165.0 1/4/2025 11:30 1/4/2025 12:00 0.50 COMPZN, RPCOMP TRIP P TOOH, PUW=45K 2,165.0 230.0 1/4/2025 12:00 1/4/2025 12:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 18, Lay down cut joint 25.60 230.0 0.0 1/4/2025 12:30 1/4/2025 13:00 0.50 COMPZN, RPCOMP RURD P C/O floor equipment 0.0 0.0 1/4/2025 13:00 1/4/2025 13:30 0.50 COMPZN, RPCOMP PULL P Lay down 9 Jts 5 1/2 casing, 10.50' cut joint 0.0 0.0 1/4/2025 13:30 1/4/2025 14:00 0.50 COMPZN, RPCOMP RURD P Clean floor, Rig up to run DP 0.0 0.0 1/4/2025 14:00 1/4/2025 14:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #19 Spear 0.0 230.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 8/17 2P-431 Report Printed: 2/25/2025 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) 1/4/2025 14:30 1/4/2025 15:00 0.50 COMPZN, RPCOMP TRIP P Trip in well. 3 1/2DP. KU 230.0 2,113.0 1/4/2025 15:00 1/4/2025 16:45 1.75 COMPZN, RPCOMP JAR P Obtain parameters, PUW=66K RIW=63K No Go on fish @ 2177, PUH to 50 over @ 110K. Work jars up T/ 100K over. Stage straight pull up F/ 100K T/ 320K over., 60 jar hits. No pipe movement. 2,113.0 2,177.0 1/4/2025 16:45 1/4/2025 18:00 1.25 COMPZN, RPCOMP SFTY P Post jarring derrick inspection. Replace broken tie wire on top drive bolts. 2,177.0 2,177.0 1/4/2025 18:00 1/4/2025 18:30 0.50 COMPZN, RPCOMP OWFF P Release spear from fish. Rack back stand T/ 2108'. OWFF. 2,177.0 2,108.0 1/4/2025 18:30 1/4/2025 21:30 3.00 COMPZN, RPCOMP RGRP T Rig repair. Adjust bail clamps. 2,108.0 2,108.0 1/4/2025 21:30 1/4/2025 22:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2106' T/ 230'. PUW=66K 2,108.0 230.0 1/4/2025 22:30 1/4/2025 23:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #19 230.0 0.0 1/4/2025 23:00 1/4/2025 23:30 0.50 COMPZN, RPCOMP RURD P C/O handling equipment T/ 2 7/8". 0.0 0.0 1/4/2025 23:30 1/4/2025 23:45 0.25 COMPZN, RPCOMP BHAH P M/U BHA #20 MSC T/ 11' 0.0 11.0 1/4/2025 23:45 1/5/2025 00:00 0.25 COMPZN, RPCOMP TRIP P RIH F/ 11' T/481, SOW=35K. 11.0 481.0 1/5/2025 00:00 1/5/2025 01:30 1.50 COMPZN, RPCOMP TRIP P RIH F/ 481' T/2530', SOW=60K 481.0 2,530.0 1/5/2025 01:30 1/5/2025 01:45 0.25 COMPZN, RPCOMP CIRC P Circ @ 1 BPM, 480 PSI. RIH locate collar @ 2541'. RIH T/ 2550' 2,530.0 2,550.0 1/5/2025 01:45 1/5/2025 02:00 0.25 COMPZN, RPCOMP CPBO P Cut 5 1/2" CSG @ 2550', Rot @ 80 RPM, 1.2K Free Tq. ROT=53K. Pump @ 2 BPM, 940 PSI. T1.2-1.6K Tq. P/U T/ 2548. Kill rotary, pump @ 1 BPM, 450 PSI. RIH locate cut @ 2551'. 2,550.0 2,550.0 1/5/2025 02:00 1/5/2025 02:15 0.25 COMPZN, RPCOMP OWFF P L/D working single T/ 2548'. OWFF. B/D TD. 2,550.0 2,548.0 1/5/2025 02:15 1/5/2025 02:30 0.25 COMPZN, RPCOMP TRIP P POOH F/ 2548' T/ 2358', PUW=55K. 2,548.0 2,358.0 1/5/2025 02:30 1/5/2025 02:45 0.25 COMPZN, RPCOMP CIRC P Circ @ 1 BPM, 480 PSI. RIH locate collar @2372'. P/U T/ 2360' 2,358.0 2,360.0 1/5/2025 02:45 1/5/2025 03:00 0.25 COMPZN, RPCOMP CPBO P Cut 5 1/2" CSG @ 2360', Rot @ 80 RPM, 1.2K Free Tq. ROT=53K. Pump @ 2.5 BPM, 1120PSI. 1.2-1.7K Tq. P/U T/ 2548. Kill rotary, pump @ 1 BPM, 450 PSI. RIH locate cut @ 2360'. 2,360.0 2,360.0 1/5/2025 03:00 1/5/2025 03:15 0.25 COMPZN, RPCOMP OWFF P L.D working single.. OWFF. B/D TD. 2,360.0 2,360.0 1/5/2025 03:15 1/5/2025 04:15 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2360' T/ 11'. 2,360.0 11.0 1/5/2025 04:15 1/5/2025 04:30 0.25 COMPZN, RPCOMP BHAH P L/D BHA #20. 11.0 0.0 1/5/2025 04:30 1/5/2025 05:00 0.50 COMPZN, RPCOMP RURD P C/O handling equipment T/ 3 1/2" 0.0 0.0 1/5/2025 05:00 1/5/2025 06:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #21 spear with new grapple, 0.0 230.0 1/5/2025 06:00 1/5/2025 07:00 1.00 COMPZN, RPCOMP TRIP P Trip in well 230 to 2116. KU, PUW=65K, SOW=63K 230.0 2,116.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 9/17 2P-431 Report Printed: 2/25/2025 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) 1/5/2025 07:00 1/5/2025 08:30 1.50 COMPZN, RPCOMP FISH P Sting into fish 2165', No Go @ 2177. 'P/U 110K. Fish moving ~15' up started pulling hard. Pulled up to 110K.. Worked back down. Recip 15'. Attempt to circulate. No Go. Broke out TD and blow down. KU., Started jarring 100K over woth straight pulls after fire. X6. Fish pulled free at 300K. PUH to 2120. Recip back to bottom and back up to 2117 clean. Run back to bottom 2170 2,116.0 2,177.0 1/5/2025 08:30 1/5/2025 10:30 2.00 COMPZN, RPCOMP CIRC P Pump 15 BBl hi vis sweep Circ S X S. 3.5 BPM @ 354 PSI get slug of gas at BU. Send to cuttings box. See some cement at hi vis sweep. Pump 135 BBls. Shut down. Still light gas breaking out at surface. Pump 100 BBls. OWFF 2,177.0 2,177.0 1/5/2025 10:30 1/5/2025 11:30 1.00 COMPZN, RPCOMP TRIP P Break out TD and blow down, Trip out of well, PUW=66K 2,177.0 230.0 1/5/2025 11:30 1/5/2025 12:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #21, Lay down spear w/32.82' cut joint 230.0 0.0 1/5/2025 12:30 1/5/2025 13:00 0.50 COMPZN, RPCOMP RURD P Change out pipe handling equipment 0.0 0.0 1/5/2025 13:00 1/5/2025 13:30 0.50 COMPZN, RPCOMP PULL P Recoce 3 Jts 5 1/2" casing, 33.32' cut joint 0.0 0.0 1/5/2025 13:30 1/5/2025 14:00 0.50 COMPZN, RPCOMP RURD P Change out pipe handling equipment 0.0 0.0 1/5/2025 14:00 1/5/2025 14:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA # 22, fishing package with spear 0.0 230.0 1/5/2025 14:30 1/5/2025 15:30 1.00 COMPZN, RPCOMP TRIP P Trip in well 230.0 2,302.0 1/5/2025 15:30 1/5/2025 16:15 0.75 COMPZN, RPCOMP FISH P KU. PUW=64K. SOW=45K RIH to No Go @ 2373. PUH to 100K. Jars fire. Pull to 120. Jar. Jar 7 times. Move fish on straight pull to 200K 8 feet. RIH Jar 2 more times. Pull free @ 225K. PUH to 2300. Break circulation. Reciprocate back down to 2371. PUH to 2367 2,302.0 2,367.0 1/5/2025 16:15 1/5/2025 17:15 1.00 COMPZN, RPCOMP CIRC P Circ @ 3 BPM, 265 PSI. PSI dropped, Slight gas at surface at initial BU, Send returns to cutting box. Return dropped off then returned. Some cement/fill in sweep. Rack back stand T/ 2295'. PUW=70K. B/D TD. 2,295.0 2,295.0 1/5/2025 17:15 1/5/2025 19:30 2.25 COMPZN, RPCOMP SFTY P OWFF on trip tank - No flow. Perform post jarring derrick inspection. Crew change out. 2,295.0 2,295.0 1/5/2025 19:30 1/5/2025 20:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2295' T/ 230', PUW=68K 2,295.0 430.0 1/5/2025 20:30 1/5/2025 21:15 0.75 COMPZN, RPCOMP BHAH P L/D BHA #22. PUW=40K, Lay down spear w/ 10.62' cut joint 430.0 200.0 1/5/2025 21:15 1/5/2025 21:30 0.25 COMPZN, RPCOMP RURD P C/O handling equipment T/ 5 1/2", 200.0 200.0 1/5/2025 21:30 1/5/2025 22:00 0.50 COMPZN, RPCOMP PULL P L/D 5 1/2" CSG fish 4 full joints & 10.79' cut joint. 200.0 0.0 1/5/2025 22:00 1/5/2025 23:00 1.00 COMPZN, RPCOMP SVRG P Service rig. Troubleshoot IBOP. Load drilling jars into pipe shed for next BHA. 0.0 0.0 1/5/2025 23:00 1/6/2025 00:00 1.00 COMPZN, RPCOMP RGRP T Replace actuator sprockets on IBOP. 0.0 0.0 1/6/2025 00:00 1/6/2025 02:00 2.00 COMPZN, RPCOMP RGRP T Replace actuator sprockets on IBOP. 0.0 0.0 1/6/2025 02:00 1/6/2025 02:30 0.50 COMPZN, RPCOMP SVRG P Service rig, grease TD. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 10/17 2P-431 Report Printed: 2/25/2025 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) 1/6/2025 02:30 1/6/2025 04:15 1.75 COMPZN, RPCOMP BHAH P M/U BHA #23, spear w/ drilling jars T/ 250', SOW=40K 0.0 250.0 1/6/2025 04:15 1/6/2025 05:00 0.75 COMPZN, RPCOMP TRIP P RIH F/ 250' T/ 2536', SOW=63K 250.0 2,536.0 1/6/2025 05:00 1/6/2025 07:00 2.00 COMPZN, RPCOMP FISH P P/U Single, KU. Sting into fish, NoGo @ 2563, Jar on fosh100K over Straight pull to 375K 2,536.0 2,563.0 1/6/2025 07:00 1/6/2025 08:00 1.00 COMPZN, RPCOMP CIRC P Break Circulation, 3 BPM @ 320 PSI. Pump S X S. Get gas at surface. S/D pump 2,563.0 2,563.0 1/6/2025 08:00 1/6/2025 09:30 1.50 COMPZN, RPCOMP OWFF P OWFF, Static, Perform derrick inspection 2,563.0 2,563.0 1/6/2025 09:30 1/6/2025 10:00 0.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=45K 2,563.0 230.0 1/6/2025 10:00 1/6/2025 10:30 0.50 COMPZN, RPCOMP BHAH P L/D intensifier, Rack back two stands of collars, Bumper sub and jars, spear, and 32.55' cut joint 230.0 0.0 1/6/2025 10:30 1/6/2025 11:00 0.50 COMPZN, RPCOMP RUNL P C/O pipe handling equipment 0.0 0.0 1/6/2025 11:00 1/6/2025 11:30 0.50 COMPZN, RPCOMP PULL P Pull two joints, 14'29' cut joint 0.0 0.0 1/6/2025 11:30 1/6/2025 12:00 0.50 COMPZN, RPCOMP RURD P Change out pipe handling equipment 0.0 0.0 1/6/2025 12:00 1/6/2025 13:00 1.00 COMPZN, RPCOMP BHAH P P/U Spear, Release upper cut joint. P/U BHA #24 0.0 246.6 1/6/2025 13:00 1/6/2025 14:00 1.00 COMPZN, RPCOMP TRIP P RIH BHA # 24 F/246 T/2708, KU Jt 27. RIW=64K, PUW=70K, Bring pumps on 2 BPM @ 111 PSI. RIH to no go @ 2712. No PSI increase 246.6 2,712.0 1/6/2025 14:00 1/6/2025 16:00 2.00 COMPZN, RPCOMP TRIP P Blow down top drive. TOOH from 2708. Hole not taking proper fill stop @ 1844. Observe well. Light gas at surface. Well went static. Continue out of well 2,712.0 246.0 1/6/2025 16:00 1/6/2025 17:30 1.50 COMPZN, RPCOMP BHAH P Lay down intensifier, Rack back collars, Remove fish from spear, Fish OAL=4.02' 246.0 0.0 1/6/2025 17:30 1/6/2025 18:30 1.00 COMPZN, RPCOMP BHAH P Clear and clean floor. Check spear 0.0 0.0 1/6/2025 18:30 1/6/2025 19:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA # 25 0.0 340.9 1/6/2025 19:30 1/6/2025 20:00 0.50 COMPZN, RPCOMP TRIP P Trip in well, BHA #25 to 2657 340.9 715.0 1/6/2025 20:00 1/6/2025 20:30 0.50 COMPZN, RPCOMP SVRG P Inspect / lubricate draw works 715.0 715.0 1/6/2025 20:30 1/6/2025 21:30 1.00 COMPZN, RPCOMP TRIP P Continue in well 715.0 2,657.0 1/6/2025 21:30 1/6/2025 22:30 1.00 COMPZN, RPCOMP FISH P KU Joint 2657, PUW=70K, SOW=65K. NoGo @2720. TOF=2711. P/U 100K Sat down to 2720. Pull up 50 over. Jars fire. Set back down. Gained 1 foot. PUH 75K Jars fired. Moving up hole pull 250K @ 2700 Popped free. Gain at trip tank, No gas at surface. Space out @ 2686. Break off. Blow down top drive. POOH F/ 2686' T/ 2565'. PUW=75K. 2,711.0 2,565.0 1/6/2025 22:30 1/6/2025 23:00 0.50 COMPZN, RPCOMP CIRC P Circ @ 1 BPM, 70 PSI, 2 BPM, 250 PSI, 3 BPM, 325 PSI. Pump 15 Bbls hi vis sweep. Reciprocated pipe back down T 2650'. 2,565.0 2,650.0 1/6/2025 23:00 1/7/2025 00:00 1.00 COMPZN, RPCOMP CIRC P Divert returns to open to tank. Circ 3 BPM, 425 PSI. Gas decreased. Still getting contaminated milky fluid back. 2,650.0 2,650.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 11/17 2P-431 Report Printed: 2/25/2025 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) 1/7/2025 00:00 1/7/2025 00:15 0.25 COMPZN, RPCOMP CIRC P Circ contaminated fluid out to open top tank. 2,650.0 2,650.0 1/7/2025 00:15 1/7/2025 00:30 0.25 COMPZN, RPCOMP OWFF P Verify no PSI under UPR. Open rams. B/D choke and hard line T/ tanks. 2,650.0 2,650.0 1/7/2025 00:30 1/7/2025 00:45 0.25 COMPZN, RPCOMP WASH P Wash in hole @ 3 BPM, 290 PSI F/ 2650' T/ 2700'. P/U T/ 2650'. 2,650.0 2,650.0 1/7/2025 00:45 1/7/2025 01:00 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow. B/D TD. 2,650.0 2,650.0 1/7/2025 01:00 1/7/2025 01:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 2650' T/ 1623 PUW=75K. 2,650.0 1,623.0 1/7/2025 01:30 1/7/2025 02:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Replace cotter pins in slips w/ roll pins. 1,623.0 1,623.0 1/7/2025 02:00 1/7/2025 02:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1623 T/ 340'. PUW=60K. 1,623.0 340.0 1/7/2025 02:30 1/7/2025 03:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #25 T/ 340 T/ fish, PUW=48K. Remove spear from fish. 340.0 0.0 1/7/2025 03:00 1/7/2025 03:30 0.50 COMPZN, RPCOMP RURD P C/O handling equipment T/ 5 1/2" 0.0 0.0 1/7/2025 03:30 1/7/2025 04:30 1.00 COMPZN, RPCOMP PULL P L/D spear, 5 1/2" CSG fish, 30.25' cut joint, 5 full joints, 29.70' cut joint. 0.0 0.0 1/7/2025 04:30 1/7/2025 05:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 1/7/2025 05:00 1/7/2025 06:00 1.00 COMPZN, RPCOMP RURD P C/O handling equipment T/ 3 1/2". Crew change out. 0.0 0.0 1/7/2025 06:00 1/7/2025 07:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #26 spear w/ drilling jars. Install new grapple in spear. T/ 340' 0.0 340.0 1/7/2025 07:00 1/7/2025 08:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 340' engage fish top @ 2978'. PUW=75K, SOW=65K. 340.0 2,978.0 1/7/2025 08:00 1/7/2025 11:00 3.00 COMPZN, RPCOMP FISH P Warm up jars. Stage jar hits up T/ 100K over. Work straight pull T/ 300K over. Hit jars 100 times. No pipe movement. 2,978.0 2,978.0 1/7/2025 11:00 1/7/2025 12:00 1.00 COMPZN, RPCOMP SFTY P Perform post jarring derrick inspection. No deficiencies. 2,978.0 2,978.0 1/7/2025 12:00 1/7/2025 12:30 0.50 COMPZN, RPCOMP FISH P Stage straight pull up T/ 340K over, no pipe movement. Release spear. P/U T/ xxx'. PUW=75K. 2,978.0 2,978.0 1/7/2025 12:30 1/7/2025 18:30 6.00 COMPZN, RPCOMP FISH P Attempt to work right hand torque down to release spear. Continue to work to free spear from fish. Unable. 2,978.0 2,978.0 1/7/2025 18:30 1/7/2025 22:45 4.25 COMPZN, RPCOMP FISH P Mobilize additional fishing tools from Deadhorse. Continue to work pipe to release from fish. Continue jarring up and working right hand torque into spear to release. Jarred down on fish top. Set 20K down. Set torque limit to 10K. Rotate 40 RPM. Stalled out. PU and came free from fish. 2,978.0 2,978.0 1/7/2025 22:45 1/7/2025 23:30 0.75 COMPZN, RPCOMP CIRC P Circ until returns cleaned up (153 bbls). Some gas back. Kicked dirty fluid out to cuttings tank. Pump Rate = 3 BPM @ 360 psi. 2,978.0 2,978.0 1/7/2025 23:30 1/8/2025 00:00 0.50 COMPZN, RPCOMP SFTY P Perform post jarring derrick inspection. 2,978.0 2,978.0 1/8/2025 00:00 1/8/2025 01:00 1.00 COMPZN, RPCOMP SFTY P Finish post jarring derrick inspection. Grease crown. OWFF during inspection. 2,978.0 2,978.0 1/8/2025 01:00 1/8/2025 02:45 1.75 COMPZN, RPCOMP TRIP P TOOH F/ top of fish @ 2,978', racking back 3 1/2" DP. PUW = 75K. TOOH at reduced speed (30 FPM). BHA catching on collars during TOOH to approx. 2,000'. TOOH clean from 2,000'. 2,978.0 340.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 12/17 2P-431 Report Printed: 2/25/2025 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) 1/8/2025 02:45 1/8/2025 03:45 1.00 COMPZN, RPCOMP BHAH P L/D BHA #26 (Spear w/ Drilling Jars). Inspect. Recovered spear intact. Nothing LIH. Found deep scarring on top of No-Go (junk or debris on top of No-Go). Made decision to run dress off mill to clear casing of potential debris. 340.0 0.0 1/8/2025 03:45 1/8/2025 05:45 2.00 COMPZN, RPCOMP RURD P Drain Stack. Look for potential debris in BOP stack. Function test blinds. Load Yellow Jacket Tools. Crew change out. 0.0 0.0 1/8/2025 05:45 1/8/2025 06:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #27 (6 3/4" Drift/Dress off Mill). T/ 337'. SOW=45K. 0.0 337.0 1/8/2025 06:15 1/8/2025 07:30 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #27 to 2914, PUW=74K, SOW=65K.'. 337.0 2,914.0 1/8/2025 07:30 1/8/2025 09:30 2.00 COMPZN, RPCOMP SLPC P Slip and cut 60' of drill line. 2,914.0 2,914.0 1/8/2025 09:30 1/8/2025 10:30 1.00 COMPZN, RPCOMP MILL P RIH, took 10K @ 2947. Worked through. Obtain parameters: Circ # 3 BPM, 230 PSI, Rot@ 90 RPM, 2K Free Tq. ROT=72K. Tag fish top @ 2979'. Mill T/ 2981. WOB=5K, Tq=3-4K. Displace over T/ vis 9.8# while milling. 2,914.0 2,981.0 1/8/2025 10:30 1/8/2025 11:00 0.50 COMPZN, RPCOMP CIRC P Circ BUS. 4 BPM, 315 PSI. 2,981.0 2,981.0 1/8/2025 11:00 1/8/2025 11:30 0.50 COMPZN, RPCOMP OWFF P P/U T/ 2926'. OWFF; B/D TD. 2,981.0 2,926.0 1/8/2025 11:30 1/8/2025 13:00 1.50 COMPZN, RPCOMP TRIP P POOH F/ 2926'. Pulled 10K over @ 2947' S/O pulled clean. Pulled 10K over @ 2903'. K/U Rot through @ 30 RPM. Resume pulling on hook T/ 337'. PUW=74K. 2,926.0 337.0 1/8/2025 13:00 1/8/2025 13:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #27 F/ 337' T/ surface. PUW=47'. Inspect packer mill. Good wear pattern. Metal debris imbedded in water course on mill. 337.0 0.0 1/8/2025 13:45 1/8/2025 14:15 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 1/8/2025 14:15 1/8/2025 14:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #28 MSC T/ 105' 0.0 105.0 1/8/2025 14:45 1/8/2025 16:45 2.00 COMPZN, RPCOMP TRIP P RIH F/ 105' T/ 3011'. PUW=74K, SOW=63 105.0 3,011.0 1/8/2025 16:45 1/8/2025 17:15 0.50 COMPZN, RPCOMP CUTP P Cut 5 1/2" CSG @ 3011';. Rot @ 80 RPM, 1.8K Free Tq. Circ @ 3 BPM, 1300 PSI. ROT=66K. Tq=3.5K, fell off. 3,011.0 3,011.0 1/8/2025 17:15 1/8/2025 17:30 0.25 COMPZN, RPCOMP OWFF P P/U T/ 2976', OWFF. B/D TD. 3,011.0 2,976.0 1/8/2025 17:30 1/8/2025 19:30 2.00 COMPZN, RPCOMP TRIP P Crew C/O. TOOH w/ BHA #28 (MSC). 2,976.0 105.0 1/8/2025 19:30 1/8/2025 20:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #28. Inspect cutter blades. Clean rig floor. 105.0 0.0 1/8/2025 20:30 1/8/2025 22:00 1.50 COMPZN, RPCOMP BHAH P MU BHA #29 (Spear) 0.0 339.0 1/8/2025 22:00 1/8/2025 23:45 1.75 COMPZN, RPCOMP TRIP P TIH w/ BHA #29 (Spear) to top of fish @ 2,981'. 339.0 2,981.0 1/8/2025 23:45 1/9/2025 00:00 0.25 COMPZN, RPCOMP FISH P Obtain parameters. PUW = 75K. SOW = 65K. Set down 10K at top of fish. Mark pipe. PUH. TIH rotating slowly to the left @ 10 RPM / 1.8k ft-lbs torque. Enter 5 1/2"stub @ 2,981'. See 5K bobbles from 2,983' to 2,987'. Set 20K down. Est. 6.5' swallow to no-go. Warm up jars. 2,981.0 2,987.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 13/17 2P-431 Report Printed: 2/25/2025 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) 1/9/2025 00:00 1/9/2025 00:30 0.50 COMPZN, RPCOMP FISH P Warm up jars. Hit 7 jar licks pulling 75K over. Saw 2' of movement. Hit one more jar lick, pulled 175K over (250K total) and fish came free. 2,981.0 2,987.0 1/9/2025 00:30 1/9/2025 01:30 1.00 COMPZN, RPCOMP CIRC P PUH fish inside SC shoe to 2,925'. Circ 157 bbls @ 3 BPM / 230 psi, until returns cleaned up. SD Pumps. BD Top Drive. 2,987.0 2,925.0 1/9/2025 01:30 1/9/2025 02:00 0.50 COMPZN, RPCOMP OWFF P OWFF. Perform post-jarring derrick inspection during monitor. 2,925.0 2,925.0 1/9/2025 02:00 1/9/2025 03:15 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #29 (Spear) and 5 1/2" casing fish T/ cut @ 3,011'. PUW = 75K 2,925.0 339.0 1/9/2025 03:15 1/9/2025 04:30 1.25 COMPZN, RPCOMP BHAH P L/D BHA #29 and casing fish. Found 5 1/2" collar on fish buckled/damaged. Damaged collar pulled from estimated 4' below surface casing shoe. Length from dressed off fish top (2,981') to buckled collar = 10.92'. Fish OAL = 33.75'. 339.0 0.0 1/9/2025 04:30 1/9/2025 06:30 2.00 COMPZN, RPCOMP BHAH P MU BHA #30 (Spear, no pack-off). Crew C/O. SOW=45K. 0.0 337.0 1/9/2025 06:30 1/9/2025 07:30 1.00 COMPZN, RPCOMP TRIP P TIH T/ 2931. PUW=76, SOW=65K 337.0 2,931.0 1/9/2025 07:30 1/9/2025 08:00 0.50 COMPZN, RPCOMP WASH P Screw in TD. Obtain parameters. Pump @ 3 BPM, 220 PSI. Wash down through SC shoe @ 2,988' to top of fish in open hole @ 3,011'. Washing in hole @ 3 BPM, 220-440 PSI, WOB=10-25K. 2,931.0 3,011.0 1/9/2025 08:00 1/9/2025 08:30 0.50 COMPZN, RPCOMP CIRC P Circ BUS @ 4.5 BPM, 400 PSI. Recip up into shoe. Back T/ fish top & back up into shoe. Sandy returns at shakers. 3,011.0 3,011.0 1/9/2025 08:30 1/9/2025 09:00 0.50 COMPZN, RPCOMP FISH P Engage fish top @ 3011', swallow T/ 3015'. Set 30K down. Circ 3 BPM, 200 PSI. Entered fish, Circ 1 BPM, 70 PSI. P/U of fish, 10K over pipe free. Pull up into shoe T/ 2950'. 3,011.0 2,950.0 1/9/2025 09:00 1/9/2025 09:45 0.75 COMPZN, RPCOMP CIRC P Circ BUS @ 4.5 BPM, 244 PSI. Sandy returns at shakers. 2,950.0 2,950.0 1/9/2025 09:45 1/9/2025 10:00 0.25 COMPZN, RPCOMP OWFF P P/U T/ 2931'. OWFF. B/D TD. 2,950.0 2,931.0 1/9/2025 10:00 1/9/2025 10:45 0.75 COMPZN, RPCOMP TRIP P POOH F/ 2931' T/ 337'. PUW=76K. 2,931.0 337.0 1/9/2025 10:45 1/9/2025 12:00 1.25 COMPZN, RPCOMP BHAH P L/D BHA #30. PUW=45K. No fish. Break down grapple clean & inspect. . Formation behind grapple. Re intall grapple. 337.0 0.0 1/9/2025 12:00 1/9/2025 12:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 1/9/2025 12:30 1/9/2025 13:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #31, spear no pack off. T/ 337'. SOW=45K. 0.0 337.0 1/9/2025 13:00 1/9/2025 14:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 337' T/ 2980'. PUW=76K, SOW=65K.. 337.0 2,980.0 1/9/2025 14:00 1/9/2025 15:15 1.25 COMPZN, RPCOMP FISH P Wash into fiish top @ 3011', pump @ 3 BPM, 265 PSI. Engage fish. P/U hit jars @ 75K over 1 time. Slipped off. Attempt to reengage no joy. 2,980.0 3,011.0 1/9/2025 15:15 1/9/2025 15:30 0.25 COMPZN, RPCOMP OWFF P P/U T/ 2926', OWFF. B/D TD. 3,011.0 2,926.0 1/9/2025 15:30 1/9/2025 16:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2926' T/ 337', PUW=76K. 2,926.0 337.0 1/9/2025 16:30 1/9/2025 17:15 0.75 COMPZN, RPCOMP BHAH P L/D BHA #31, PUW=45K. No gapple on spear. 337.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 14/17 2P-431 Report Printed: 2/25/2025 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) 1/9/2025 17:15 1/9/2025 19:30 2.25 COMPZN, RPCOMP BHAH P MU BHA #32 (Spear w/ new grapple and extension). Crew C/O. Blowdown lines to tanks to confirm clear. Replace Drill Collar with damaged thread w/ new. Adjust BHA. 0.0 339.0 1/9/2025 19:30 1/9/2025 22:00 2.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #32 to SC shoe @ 2,933'. Kelly up. PUW = 75K. SOW = 65K. Wash down to fish top @ 3,011'. 3.5 BPM @ 255 psi. See 100 psi pressure indicator @ 3,015'. SD pumps. Cont. TIH to fully no-go @ 3,024'. Set 20K down. Set in slips. PU working joint. 339.0 3,024.0 1/9/2025 22:00 1/10/2025 00:00 2.00 COMPZN, RPCOMP FISH P PU 10K to confirm spear is engaged. Set 25K down to confirm fully no-go'd. Warm up jars. Hit 30 jar licks pulling 75K over with straight pulls to 350K. Hit 5 jar licks down. Est. +/- 1' of movement during jarring up. Continue working fish. 3,024.0 3,024.0 1/10/2025 00:00 1/10/2025 05:00 5.00 COMPZN, RPCOMP FISH P Continue working fish. Break out working joint. MU pup. Hit 20 jar licks up pulling 75K over with straight pulls to 350K. Attempt to establish circulation. Circulate @ 1 BPM / 320 psi. Jar while circulating, No movement. Release and re-engage fish after 50 hits. Continue working to free fish from open hole. Hit25 jar licks @ 95K over, pulling to 370K. 3,024.0 3,024.0 1/10/2025 05:00 1/10/2025 06:15 1.25 COMPZN, RPCOMP SFTY P Perform top drive and derrick inspection. Crew C/O. 3,024.0 3,024.0 1/10/2025 06:15 1/10/2025 07:30 1.25 COMPZN, RPCOMP FISH P Release F/ fish. P/U inside shoe T/ 2872'. RIH, reengage fish @ 3011'. Hit jars @ 100K. Stage straight pull up F/ 385K T/ 415K. No pipe movement. Release F/ fish. P/U T/ 2982'. 3,024.0 2,982.0 1/10/2025 07:30 1/10/2025 08:00 0.50 COMPZN, RPCOMP SFTY P Perform derrick inspection. 2,982.0 2,982.0 1/10/2025 08:00 1/10/2025 08:15 0.25 COMPZN, RPCOMP OWFF P OWFF. B/D TD. 2,982.0 2,982.0 1/10/2025 08:15 1/10/2025 09:00 0.75 COMPZN, RPCOMP TRIP P POOH F/ 2982' T/ 339'. PUW=75K 2,982.0 339.0 1/10/2025 09:00 1/10/2025 09:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #32. PUW=45K. 339.0 0.0 1/10/2025 09:45 1/10/2025 10:45 1.00 COMPZN, RPCOMP CLEN P Clean & clear RF. Load next BHA. 0.0 0.0 1/10/2025 10:45 1/10/2025 12:00 1.25 COMPZN, RPCOMP BHAH P M/U BHA #33 (Packer mill w/ boot baskets) T/ 339'. SOW=47K. 0.0 339.0 1/10/2025 12:00 1/10/2025 13:15 1.25 COMPZN, RPCOMP TRIP P RIH F/ 339' T/ 1971'. PUW=75K, SOW=64K. 339.0 1,971.0 1/10/2025 13:15 1/10/2025 22:15 9.00 COMPZN, RPCOMP MILL P K/U circ @ 3 BPM, 200, PSI, Staging up T/ 5 BPM, 660 PSI. Rot @ 90-110 RPM, 1.9K Free Tq. ROT=71K. Wash & ream down T/ CSG stub @ 3015'. Mill F/ 3015' T/ 3,039' (51' below surface casing shoe). 10K WOB. Tq=2-4K. Pumping 10 Bbls hi-vis pill around every 5' milled. 1,971.0 3,039.0 1/10/2025 22:15 1/11/2025 00:00 1.75 COMPZN, RPCOMP CIRC P Circulate BU @ 5 BPM / 582 psi, reciprocating stand in open hole. Flow % = 11.9. SD pumps. Vac Truck not keeping up at cuttings tank. Blowdown. Rack back 2 stands (pull up into cased hole). Rotate up through tight spot @ 2,951' (10K overpull). Suck out cuttings tank. Transfer fluid in pits. 3,039.0 2,941.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 15/17 2P-431 Report Printed: 2/25/2025 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) 1/11/2025 00:00 1/11/2025 01:00 1.00 COMPZN, RPCOMP CIRC P Finish fluid transfers. Circ. out until see clean 9.8# returns. TIH and tag top of 5 1/2" stump @ 3,039'. P/U into cased hole after BU. SD pumps. 2,941.0 2,921.0 1/11/2025 01:00 1/11/2025 01:15 0.25 COMPZN, RPCOMP OWFF P OWFF. 2,921.0 2,921.0 1/11/2025 01:15 1/11/2025 07:15 6.00 COMPZN, RPCOMP PMPO P TOOH w/ BHA #33 (6 3/4" Pilot Mill). PUW=75K. See 25K over pull @ 2,921' (likely dragging debris above mill). Pump out of hole @ 2.5 BPM / 170 psi. See 15K over pull @ 2,553'. Cont. to see 10-20K over pulls when POOH w/o pumping. Continue pumping OOH. T/ 339' 2,921.0 339.0 1/11/2025 07:15 1/11/2025 09:15 2.00 COMPZN, RPCOMP BHAH P L/D BHA #33. L/D collars. Inspect mill good wear pattern. 339.0 0.0 1/11/2025 09:15 1/11/2025 09:45 0.50 COMPZN, RPCOMP WWWH P Jet BOP stack. B/D TD. Blow air through all ports on stack. 0.0 0.0 1/11/2025 09:45 1/11/2025 10:15 0.50 COMPZN, RPCOMP BHAH P Break down boot baskets - full of metal. 0.0 0.0 1/11/2025 10:15 1/11/2025 10:45 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 1/11/2025 10:45 1/11/2025 11:15 0.50 COMPZN, RPCOMP RURD P C/O handling equipment for 3 1/2" tubing. 0.0 0.0 1/11/2025 11:15 1/11/2025 11:30 0.25 COMPZN, RPCOMP SFTY P Verify joint count. PJSM w/ rig crew on running 3 1/2" EUE tubing. 0.0 0.0 1/11/2025 11:30 1/11/2025 14:15 2.75 COMPZN, RPCOMP PUTB P Run 3 1/2", 9.3#, L-80, EUE-M Tubing to 2964'. PUW=53K, SOW=50K M/U Tq = 2150 Ft/lbs. 0.0 2,964.0 1/11/2025 14:15 1/11/2025 14:45 0.50 COMPZN, RPCOMP WASH P Wash in hole F/ 2964' T/ 3036' @ 3 BPM, 70 PSI. 2,964.0 3,036.0 1/11/2025 14:45 1/11/2025 15:00 0.25 COMPZN, RPCOMP RURD P R/U HES cementers & circ equipment. Mix spacer. 3,036.0 3,036.0 1/11/2025 15:00 1/11/2025 15:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ HES cementers & rig crew on pumping balance plug. 3,036.0 3,036.0 1/11/2025 15:15 1/11/2025 15:30 0.25 COMPZN, RPCOMP PRTS P Flood lines w/ 5 Bbls 9.8# brine # 3 BPM, 165 PSI. Shut in. PT cement lines T/ 2500 PSI. B/D cement line. 3,036.0 3,036.0 1/11/2025 15:30 1/11/2025 17:00 1.50 COMPZN, RPCOMP CMNT P Batch up cement. Cement wet @ 15:34 Hrs. Pump 22.5 Bbls 10 PPG Spacer w/ Surf wash @ 2.5 BPM, 100 PSI. Close UPR. Drop 4" foam ball. Open up rams. Pump 21 Bbls 15.8 PPG PTA cement w/ 150 lbs Bridge Maker II LCM @ 2.4 BPM, 240 PSI. Close UPR. Drop 4" foam ball. Open up rams. Pump 5.7 Bbls spacer @ 2.4 BPM, 80 PSI. Displace w/ 14.5 Bbls 9.8 PPG brine @ 3.5 BPM, 240 PSI. 3,036.0 3,036.0 1/11/2025 17:00 1/11/2025 17:15 0.25 COMPZN, RPCOMP RURD P B/D, R/D cement line. 3,036.0 3,036.0 1/11/2025 17:15 1/11/2025 18:15 1.00 COMPZN, RPCOMP TRIP P POOH F/ 3036' T/2333' (approx. 300' above calculated TOC). PUW=54K. Cement in place @ 18:15. 3,036.0 2,333.0 1/11/2025 18:15 1/11/2025 19:15 1.00 COMPZN, RPCOMP CIRC P Circ. out spacer and clean up well above TOC. 5 BPM @ 120 psi. SD pumps. Blowdown. 2,333.0 2,333.0 1/11/2025 19:15 1/11/2025 23:15 4.00 COMPZN, RPCOMP WOC P Wait on Cement (29 hours after cement in place, until 23:30 on 1/12). 2,333.0 2,333.0 1/11/2025 23:15 1/12/2025 00:00 0.75 COMPZN, RPCOMP CIRC P Pump 20 bbl tubing volume to confirm clear. L/D 7 stand of tubing and DC's. 2,333.0 2,333.0 1/12/2025 00:00 1/12/2025 23:30 23.50 COMPZN, RPCOMP WOC P Continue to WOC until 23:30 on 1/12. (approx. 29 hours after cement in place). 2,333.0 2,333.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 16/17 2P-431 Report Printed: 2/25/2025 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) 1/12/2025 23:30 1/13/2025 00:00 0.50 COMPZN, RPCOMP WASH P Screw in TD. Obtain parameters. PUW = 49K. SOW = 48K. TIH to 2,442'. 2,333.0 2,442.0 1/13/2025 00:00 1/13/2025 00:45 0.75 COMPZN, RPCOMP WASH P Wash down through green cement @ 2,509' (2 BPM @ 84 psi). Set 6K down @ 2,512'. Confirm tag with AOGG rep (Brian Bixby). Tag @ 2,512' (2,138' TVD). Calculated to be 243' TVD above surface casing shoe. 2,442.0 2,512.0 1/13/2025 00:45 1/13/2025 01:15 0.50 COMPZN, RPCOMP RURD P RU PT equipment w/ isolation valves and sensator. Monitor IA and OA pressures at gauges. 2,512.0 2,511.0 1/13/2025 01:15 1/13/2025 02:00 0.75 COMPZN, RPCOMP CIRC P Circ STS (approx. 120 bbls) @ 4 BPM / 185 psi to ensure clean fluids all the way around for testing. SD pumps. 2,511.0 2,511.0 1/13/2025 02:00 1/13/2025 03:15 1.25 COMPZN, RPCOMP PRTS P Pressure up to 1,000 psi and monitor for 10-min. Pressure up to 1,500 psi for 30- min. Chart. First chart found bad sensator. Replaced sensator with new. Initial = 1800 psi. 15-min = 1,700 psi. 30-min = 1,680. Pass. Bleed off. 2,511.0 2,511.0 1/13/2025 03:15 1/13/2025 04:00 0.75 COMPZN, RPCOMP HOSO P Mark pipe. L/D partial joint #81 (29.6') , full joint #80 (31.4'), full joint #79. Calculate space out pups needed. Load 8.20' and 8.32' pup for 14' space out. 2,511.0 2,429.0 1/13/2025 04:00 1/13/2025 05:45 1.75 COMPZN, RPCOMP THGR P MU space out pups (8.20', 8.32'), last full joint #79, tubing hanger, and 3 1/2" landing joint. Land Hanger. RILDS. Bottom of 3 1/2" Tubing @ 2,498' (14' space out above TOC @ 2,512'). PT hanger void to 5,000 psi for 10-min. 2,429.0 2,498.0 1/13/2025 05:45 1/13/2025 06:15 0.50 COMPZN, RPCOMP RURD P R/U tank manifold T/ IA. Offload extra 3 1/2" Tubing and 5 1/2" casing from pipe shed. 0.0 0.0 1/13/2025 06:15 1/13/2025 06:45 0.50 COMPZN, RPCOMP CIRC P Circ STB down TBG @ 3 BPM 135 PSI; Taking returns to cuttings tank to confirm tubing is clear after landing hanger. B/D hardline. B/O and L/D landing joint. 0.0 0.0 1/13/2025 06:45 1/13/2025 07:30 0.75 COMPZN, RPCOMP WWWH P Jet stack. Drain stack. 0.0 0.0 1/13/2025 07:30 1/13/2025 15:00 7.50 COMPZN, RPCOMP OTHR P Perform BWM. C/O UPR, due to wear. C/O door seal on blind rams. 0.0 0.0 1/13/2025 15:00 1/13/2025 15:45 0.75 COMPZN, WHDBOP NUND P ND BOP. NU Tbg head adapter and old tree. 0.0 0.0 1/13/2025 15:45 1/13/2025 17:45 2.00 COMPZN, WHDBOP NUND P NU Tbg head adapter and old tree. 0.0 0.0 1/13/2025 17:45 1/13/2025 18:15 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 10 Min. Crew change out. 0.0 0.0 1/13/2025 18:15 1/13/2025 19:45 1.50 DEMOB, MOVE RURD P R/U HES & circulation equipment to Tubing and IA with washup/blowdown tees/tie-ins. Distribute rinse ait to tanks. 0.0 0.0 1/13/2025 19:45 1/13/2025 20:00 0.25 DEMOB, MOVE SFTY P PJSM w/ HES & rig crew on cementing T/ surface. 0.0 0.0 1/13/2025 20:00 1/13/2025 20:15 0.25 DEMOB, MOVE PRTS P Fill lines. PT cement T/ 2500 PSI. 0.0 0.0 1/13/2025 20:15 1/13/2025 21:30 1.25 DEMOB, MOVE CMNT P Batch up cement. Cement wet @ 20:22 Hrs. HES pump 20 Bbls spacer w/ Surf wash @ 2.5 BPM. 270 PSI. Pump 140 Bbls 15.8 PPG PTA cement @ 3 BPM, 140 PSI. Good 15.8 PPG cement returns at surface @ 120 bbls away. SD pumps. Est. 20 bbls cement returns to cuttings tank. Close IA and wing valve on tree. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 Page 17/17 2P-431 Report Printed: 2/25/2025 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) 1/13/2025 21:30 1/14/2025 00:00 2.50 DEMOB, MOVE RURD P Flush surface hardline w/ rinsate to tanks to clear cement. Blowdown surface lines. RD Halliburton Cementers. RD cellar hoses and hardline. Obtain Final Pressues (T/I/O) = 0 / 0 / 0 psi. Clean and clear cellar. Rig Release @ 00:00. Prep for rig move to 2P-429. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/14/2025 2025-0201_Surface_Abandon_KRU_2P-431_bn Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2/3/2025 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-431 ConocoPhillips Alaska, Inc. PTD 2020530; Sundry 324-624 2/1/2025: I traveled to CPA’s KRU 2P-431 to inspect the cut-off on well KRU 2P-431. When I arrived, I met with CPA’s representative Roger Mouser. I discussed with him the requirements of the AOGCC. I inspected the marker plate; it is 16 inches x ¼-inch thick, the proper size for the outer most string of pipe. It also had all the proper markings on it as required by AOGCC regulation. We then confirmed the depth of the cut-off pipe. It was found to be 6 feet 9 inches below tundra grade. All the strings of pipe were found to have good hard cement. I instructed Roger it was ok to proceed with welding the plate on the outer most casing and backfill the well. Attachments: Photos 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.07 16:28:47 -09'00' 2025-0201_Surface_Abandon_KRU_2P-431_bn Page 2 of 2 Surface Abandonment – KRU 2P-431 (PTD 2020530) Photos by AOGCC Inspector B. Noble 2/1/2025 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: 9685 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: P&A: XXX Conductor: 16 O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 7 5/8 O.D. Shoe@ 2988 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 3 1/2x5/ 1/2 O.D. Shoe@ 9656 Feet Csg Cut@ 3039 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2 O.D. Tail@ 8826 Feet Tbg Cut@ 3223 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 3048 ft 2512 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1800 1700 1680 IA 1800 1700 1680 OA 1800 1700 1680 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Tagged top of cement at 2512 ft; set 6K lbs on it with tubing string. January 13, 2025 Brian Bixby Well Bore Plug & Abandonment KRU 2P-431 ConocoPhillips Alaska Inc. PTD 2020530; Sundry 324-624 none Test Data: P Casing Removal: Tyson Wiese Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0113_Plug_Verification_KRU_2P-431_bb 9 9 9 99 9 999 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.31 16:10:30 -09'00' 1 Gluyas, Gavin R (OGC) From:Rixse, Melvin G (OGC) Sent:Monday, January 13, 2025 9:03 AM To:Klem, Adam Cc:Coberly, Jonathan; Hobbs, Greg S; Nezaticky, Peter; Company Man, Nordic 3; Germann, Shane; Loepp, Victoria T (OGC) Subject:20250113 0900 PTD 202-053 KRU 2P-431 surface casing shoe P&A plug tag Sundry 324-624 Adam, Surface casing shoe plug integrity data received. Thank you. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, January 13, 2025 7:50 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Company Man, Nordic 3 <Nordic3.CompanyMan@conocophillips.com>; Germann, Shane <Shane.Germann@conocophillips.com> Subject: 2P-431 surface casing shoe P&A plug tag Victoria/Mel, Our official tag depth on 2P-431 is 2512’ RKB (2138’ TVD), 179’ RKB above our target of 2691' RKB. This is 240' TVD above the surface casing shoe. The Tag was witnessed by AOGCC field representative and 10K was set down to confirm TOC. Pressure test to 1500psi for 30 minutes was successful per AOGCC field representative. We plan on progressing with the final surface to surface abandonment plug, accounting for the higher cement depth, as per the approved Sundry. Please let me know if you have any questions or disagree with this plan. Feel free to call as well. 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. 2 Thanks, Adam Klem 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): 9685'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-4597 Senior CTD/RWO Engineer KRU 2P-431 5823' 7144' 4517' 7144', 9203',9254', 9291' 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): 8810' MD and 5378' TVD N/A Shane Germann STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 202-053 P.O. Box 100360, Anchorage, AK 99510 50-103-20417-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned TVD Burst 8826' MD 120' 2381' 120' 2988' 5809'9656' 16" 7-5/8" 90' 2958' 9290-9300' 9630' 5624-5629' 3-1/2" x 5-1/2" Perforation Depth TVD (ft): 12/14/2024 3-1/2" Packer: Baker Seal Assembly 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): 624 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: 2024.10.31 13:16:22-08'00' Foxit PDF Editor Version: 13.0.0 324-624 By Grace Christianson at 8:47 am, Nov 01, 2024 DSR-11/6/24 June 30, 2025 X SFD 11/6/2024 BOP test to 2500 psig Annular preventer test to 2500 psig See attached "Conditions of Approval"10-407 XX VTL 11/27/2024 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.29 09:54:40 -09'00'11/29/24 RBDMS JSB 112924 KRU 2P-4ϯϭ Abandonment Conditions of ƉƉƌŽǀĂů͗ ϭ͘ ǀĂriance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata. 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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It has no known tubing or IA integrity issues. This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for the Willow development project in 2026. This well was suspended via reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately execute final abandonment. Well Data Meltwater Formation: x Reservoir pressure 8/9/2020 = 1046 psi @ 5624’ TVD x MASP = 484 psi C-80 Formation: x OAP = 46 psi (11/24/22) (fluid packed with diesel) x MASP = 624 psi Intermediate plug TOC = 7144’ MD Tubing cut depth = 3223’ MD Well Name Previous plug tag depth (RKB) PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-431 7144' Pass 9/15/2024 0 psi 50 psi 125 psi 9/17/2024 Production Casing Cement: 62 bbls of 15.8# Class G Cement Calculated TOC @ 6,460' KB 2P-431 Well Suspension Schematic Conductor: 16" Conductor 120' KB 1 2 4 7 6Production Casing: 5.5" x 3.5" @ 8,807' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 9,655.6’ KB T-3 Peforations: @ 9,290' – 9,300' KB (10') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,988.2' KB (2381' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 8,826.5' KB 8 /ƚĞŵĞƉƚŚͲƚŽƉƐ;<Ϳ ϭ dϭdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂŵĐŽ^EŝƉƉůĞ ϱϬϵ͘ϱΖ ϯ ϯϯΖWĂƚĐŚ ϴ͕ϲϴϱΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ ^WƌŽĨŝůĞ;ĐůŽƐĞĚͿ ϴϳϱϰ͘ϱ ϱ ^ƉĞĐŝĂůϰ͘ϱϯΗKĐƵƚƚƵďŝŶŐ͕ K>сϭϮΖĨŽƌũĞƚƉƵŵƉ ϴ͕ϳϱϴ͘ϰϬ ϲ ĂŵĐŽEŝƉƉůĞ ϴ͕ϳϳϬ͘ϱΖ ϳ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϴϬϴ͘ϳΖ ϴ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJ^ƚĂďďĞĚ ŝŶƚŽϯ͘ϱΗWƌŽĚƵĐƚŝŽŶ^'^Z ϴ͕ϴϬϵ͘ϲΖ 5 Plug #1 – Reservoir TOC ±9203' RKB Plug #2 – Intermediate TOC ±7144' RKB BOC @ ±8727' RKB C80 @ 3080' KBC80 @ 3080' KB Surface Casing Plugs – Rig Date: 10-28-2024 Prepared by: Shane Germann Estimated Start Date: 12-14-2024 MIRU 1. MIRU on 2P-431. 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 18 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 5-1/2” casing is between 150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư- rig remediation. C80 @ 3080' KB Production Casing Cement: 62 bbls of 15.8# Class G Cement Calculated TOC @ 6,460' KB 2P-431 Well Surface Shoe Cement Schematic Conductor: 16" Conductor 120' KB 1 2 4 7 6Production Casing: 5.5" x 3.5" @ 8,807' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 9,655.6’ KB T-3 Peforations: @ 9,290' – 9,300' KB (10') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,988.2' KB (2381' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 8,826.5' KB 8 /ƚĞŵ ĞƉƚŚͲƚŽƉƐ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϵϬΖ ϯ ϯϯΖWĂƚĐŚ ϴ͕ϲϴϱΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ^ WƌŽĨŝůĞ;ĐůŽƐĞĚͿ ϴϳϱϰ͘ϱ ϱ ^ƉĞĐŝĂůϰ͘ϱϯΗKĐƵƚƚƵďŝŶŐ͕K> сϭϮΖĨŽƌũĞƚƉƵŵƉ ϴ͕ϳϱϴ͘ϰϬ ϲ ĂŵĐŽEŝƉƉůĞ ϴ͕ϳϳϬ͘ϱΖ ϳ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϴϬϴ͘ϳΖ ϴ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJ^ƚĂďďĞĚŝŶƚŽ ϯ͘ϱΗWƌŽĚƵĐƚŝŽŶ^'^Z ϴ͕ϴϬϵ͘ϲΖ 5 Plug #1 – Reservoir TOC ±9203' RKB Plug #2 – Intermediate TOC ±7144' RKB BOC @ ±8727' RKB C80 @ 3080' KB Plug #3 – Surface Shoe TOC 2691' RKB (2231' TVD) BOC @ ±3090' RKB Base of 5.5” Casing 350'-400' 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 3040 3090 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing Stub Included in BBL/FT calc 2988 3040 Open Hole 6.75 0.04426 2.3 2691 2988 Surface Casing 6.87 0.04585 13.6 17.8 Total Volume of Plug Surface Casing 23 2691 Surface Casing 6.87 0.04026 107.4 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-431 c. PTD #: 202-053 d. API #: 50-103-20417-00-00 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 Plug #4 – Surface TOC 25' RKB BOC @ ±2691' RKB C80 @ 3080' KB Production Casing Cement: 62 bbls of 15.8# Class G Cement Calculated TOC @ 6,460' KB 2P-431 Well Final P&A Schematic Conductor: 16" Conductor 120' KB 1 2 4 7 6Production Casing: 5.5" x 3.5" @ 8,807' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 9,655.6’ KB T-3 Peforations: @ 9,290' – 9,300' KB (10') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,988.2' KB (2381' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 8,826.5' KB 8 /ƚĞŵ ĞƉƚŚͲƚŽƉƐ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϵϬΖ ϯ ϯϯΖWĂƚĐŚ ϴ͕ϲϴϱΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ^ WƌŽĨŝůĞ;ĐůŽƐĞĚͿ ϴϳϱϰ͘ϱ ϱ ^ƉĞĐŝĂůϰ͘ϱϯΗKĐƵƚƚƵďŝŶŐ͕K> сϭϮΖĨŽƌũĞƚƉƵŵƉ ϴ͕ϳϱϴ͘ϰϬ ϲ ĂŵĐŽEŝƉƉůĞ ϴ͕ϳϳϬ͘ϱΖ ϳ ĂŬĞƌ',ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϴϬϴ͘ϳΖ ϴ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJ^ƚĂďďĞĚŝŶƚŽ ϯ͘ϱΗWƌŽĚƵĐƚŝŽŶ^'^Z ϴ͕ϴϬϵ͘ϲΖ 5 Plug #1 – Reservoir TOC ±9203' RKB Plug #2 – Intermediate TOC ±7144' RKB BOC @ ±8727' RKB C80 @ 3080' KB Plug #3 – Surface Shoe TOC 2691' RKB (2231' TVD) BOC @ ±3090' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,144.0 2P-431 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-431 9/17/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL CHARGING OA FROM FORMATION. WAIVER EXPIRES 5/16/15. 1/8/2015 hipshkf NOTE: FOUND LEAK IN MANDREL # 5 @ 8705' 12/7/2012 ninam NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM 9/19/2008 lmosbor 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 30.0 120.0 120.0 62.30 H-40 WELDED SURFACE 7 5/8 6.87 30.1 2,988.2 2,380.9 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @8807' 5 1/2 4.95 25.6 9,655.6 5,809.0 15.50 L-80 BTC MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 8,826.5 Set Depth … 5,386.9 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) 25.6 25.6 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500 509.5 509.4 3.73 NIPPLE 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,613.8 2,190.9 58.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,908.3 3,387.7 61.44 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,547.7 4,218.7 59.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,784.6 4,862.2 58.67 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,704.5 5,325.3 59.89 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,754.5 5,350.4 59.70 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/DS PROFILE (CLOSED) BAKER CMU 2.813 8,758.4 5,352.4 59.69 OVERSIZED TBG 4.530 SPECIAL 4.53" OD CUT TUBING , OAL= 12', FOR JET PUMP 2.992 8,770.5 5,358.5 59.65 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 8,808.7 5,377.9 59.51 LOCATOR 4.560 BAKER GBH-22 LOCATOR BAKER 3.000 8,809.6 5,378.3 59.50 SEAL 4.000 BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,223.0 2,499.6 60.06 CUT JET CUT AT 3223' RKB 9/17/2024 2.992 8,723.0 5,334.5 59.82 TUBING PUNCH 4.5' TUBING PUNCH. 18 HOLES. 8/5/2024 2.992 9,254.3 5,606.4 60.61 CIBP CIBP W/ MOE = 9255' PDC, OAL = 1.376' 6/28/2024 0.000 9,291.0 5,624.5 60.24 CIBP CIBP W/ MOE = 9260' PDC, OAL = 1.376' (MOVED DOWNHOLE FROM ORIGINAL SET DEPTH) 3/20/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.8 2,190.9 58.61 1 GAS LIFT SOV INT 1 0.0 8/1/2024 2K. CSG Shear 0.000 4,908.3 3,387.7 61.44 2 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 6,547.7 4,218.7 59.60 3 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 7,784.6 4,862.2 58.67 4 GAS LIFT DMY INT 1 0.0 8/1/2024 0.000 8,704.5 5,325.3 59.89 5 GAS LIFT DMY INT 1 0.0 1/19/2013 Ext Pkg 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,290.0 9,300.0 5,624.0 5,629.0 T-3, 2P-431 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,290.0 9,300.0 1 FRAC 4/20/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,203.0 9,254.3 5,581.0 5,606.4 Cement Plug Dump Bail Cement Plug 7/2/2024 7,144.0 8,727.5 4,516.8 5,336.8 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT 9/8/2024 2P-431, 9/17/2024 7:03:10 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @8807'; 25.6-9,655.6 FLOAT SHOE; 9,655.0-9,655.6 FLOAT COLLAR; 9,560.4- 9,561.0 FRAC; 9,290.0 IPERF; 9,290.0-9,300.0 CIBP; 9,291.0 CIBP; 9,254.3 Cement Plug; 9,203.0 ftKB SEAL; 8,809.6 CSR w/XO; 8,807.5-8,828.5 LOCATOR; 8,808.7 NIPPLE; 8,770.5 OVERSIZED TBG; 8,758.4 SLEEVE-C; 8,754.5 TUBING PUNCH; 8,723.0 GAS LIFT; 8,704.5 GAS LIFT; 7,784.6 Cement Plug; 7,144.0 ftKB GAS LIFT; 6,547.7 GAS LIFT; 4,908.3 CUT; 3,223.0 SURFACE; 30.1-2,988.2 FLOAT SHOE; 2,986.7-2,988.2 FLOAT COLLAR; 2,900.1- 2,901.5 GAS LIFT; 2,613.8 PORT COLLAR; 989.0-991.4 NIPPLE; 509.5 CONDUCTOR; 30.0-120.0 HANGER; 30.1-32.3 HANGER; 25.7 HANGER; 25.6-28.1 KUP PROD KB-Grd (ft) 30.00 RR Date 4/10/2002 Other Elev… 2P-431 ... TD Act Btm (ftKB) 9,685.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032041700 Wellbore Status PROD Max Angle & MD Incl (°) 62.23 MD (ftKB) 5,091.99 WELLNAME WELLBORE2P-431 Annotation Last WO: End DateH2S (ppm) 20 Date 11/23/2015 Comment SSSV: NIPPLE ϮWͲϰϯϭϵĂůĐƵůĂƚĞĚWdKΛϲϰϲϬ͛Z<^^ŚŽĞΛϮϵϴϴ͛Z</WΛϯϬϵϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϲϵϭ͛Z<WƵƚΛϯϬϰϬ͛Z<ϴϬdŽƉΛϯϬϴϬ͛Z<ϴϬĂƐĞΛϱϬϱϬ͛Z< 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 120' 7-5/8" L-80 2381' 5.5" L-80 5388' 3.5" L-80 5809' 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 8828' SIZE DEPTH SET (MD) 9655' 26' 5388' 62.5# 29.7# 120' 26' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 7144' (SW TOC) -8727' 31 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 9290-9300' MD and 5624-5629' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 42" 9.875' 29.6 bbls AS I 30'365 sx AS III Lite, 229 sx LiteCrete 9.3# 30' 8828' 2988'30' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 4/7/2002 CEMENTING RECORD 5862245 1390' MD / 1351' TVD SETTING DEPTH TVD 5861785 TOP HOLE SIZE AMOUNT PULLED 254' AMSL 443458 443433 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- Suspended N/A 50-103-20417-00-00 KRU 2P-431 ADL0373112, ADL0389058 943' FNL, 1914' FWL, Sec. 17, T8N, R7E, UM 2464' FSL, 1516' FWL, Sec. 20, T8N, R7E, UM ALK 4998 3/28/2002 9685' MD/ 5823' TVD 7144' MD / 4517' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443874 5868935 2356' FNL, 1526' FWL, Sec. 20, T8N, R7E, UM 9. Ref Elevations: KB: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 9/17/2024 202-053 / 324-406 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, (included above)8.5" TUBING RECORD 320 sx Class G w/ GasBlok8.5" 8826' MD 3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 12:10 pm, Oct 02, 2024 Suspended 9/17/2024 JSB RBDMS JSB 100924 xGDSR-10/14/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1390' 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: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.10.02 09:24:56-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,144.0 2P-431 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-431 9/17/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL CHARGING OA FROM FORMATION. WAIVER EXPIRES 5/16/15. 1/8/2015 hipshkf NOTE: FOUND LEAK IN MANDREL # 5 @ 8705' 12/7/2012 ninam NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM 9/19/2008 lmosbor 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 30.0 120.0 120.0 62.30 H-40 WELDED SURFACE 7 5/8 6.87 30.1 2,988.2 2,380.9 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @8807' 5 1/2 4.95 25.6 9,655.6 5,809.0 15.50 L-80 BTC MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 8,826.5 Set Depth … 5,386.9 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) 25.6 25.6 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500 509.5 509.4 3.73 NIPPLE 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,613.8 2,190.9 58.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,908.3 3,387.7 61.44 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,547.7 4,218.7 59.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,784.6 4,862.2 58.67 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,704.5 5,325.3 59.89 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,754.5 5,350.4 59.70 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/DS PROFILE (CLOSED) BAKER CMU 2.813 8,758.4 5,352.4 59.69 OVERSIZED TBG 4.530 SPECIAL 4.53" OD CUT TUBING , OAL= 12', FOR JET PUMP 2.992 8,770.5 5,358.5 59.65 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 8,808.7 5,377.9 59.51 LOCATOR 4.560 BAKER GBH-22 LOCATOR BAKER 3.000 8,809.6 5,378.3 59.50 SEAL 4.000 BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,223.0 2,499.6 60.06 CUT JET CUT AT 3223' RKB 9/17/2024 2.992 8,723.0 5,334.5 59.82 TUBING PUNCH 4.5' TUBING PUNCH. 18 HOLES. 8/5/2024 2.992 9,254.3 5,606.4 60.61 CIBP CIBP W/ MOE = 9255' PDC, OAL = 1.376' 6/28/2024 0.000 9,291.0 5,624.5 60.24 CIBP CIBP W/ MOE = 9260' PDC, OAL = 1.376' (MOVED DOWNHOLE FROM ORIGINAL SET DEPTH) 3/20/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.8 2,190.9 58.61 1 GAS LIFT SOV INT 1 0.0 8/1/2024 2K. CSG Shear 0.000 4,908.3 3,387.7 61.44 2 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 6,547.7 4,218.7 59.60 3 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 7,784.6 4,862.2 58.67 4 GAS LIFT DMY INT 1 0.0 8/1/2024 0.000 8,704.5 5,325.3 59.89 5 GAS LIFT DMY INT 1 0.0 1/19/2013 Ext Pkg 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,290.0 9,300.0 5,624.0 5,629.0 T-3, 2P-431 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,290.0 9,300.0 1 FRAC 4/20/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,203.0 9,254.3 5,581.0 5,606.4 Cement Plug Dump Bail Cement Plug 7/2/2024 7,144.0 8,727.5 4,516.8 5,336.8 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT 9/8/2024 2P-431, 10/2/2024 7:42:21 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @8807'; 25.6-9,655.6 FRAC; 9,290.0 IPERF; 9,290.0-9,300.0 CIBP; 9,291.0 CIBP; 9,254.3 Cement Plug; 9,203.0 ftKB TUBING PUNCH; 8,723.0 GAS LIFT; 8,704.5 GAS LIFT; 7,784.6 Cement Plug; 7,144.0 ftKB GAS LIFT; 6,547.7 GAS LIFT; 4,908.3 CUT; 3,223.0 SURFACE; 30.1-2,988.2 GAS LIFT; 2,613.8 NIPPLE; 509.5 CONDUCTOR; 30.0-120.0 KUP PROD KB-Grd (ft) 30.00 RR Date 4/10/2002 Other Elev… 2P-431 ... TD Act Btm (ftKB) 9,685.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032041700 Wellbore Status PROD Max Angle & MD Incl (°) 62.23 MD (ftKB) 5,091.99 WELLNAME WELLBORE2P-431 Annotation Last WO: End DateH2S (ppm) 20 Date 11/23/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 8/5/2024 ACQUIRE DATA RAN TUBING PUNCH. PUNCH INTERVAL: 8723' - 8727.5' WITH 4.5', 18 SHOT TUBING PUNCHES. LRS PRESSURED UP TUBING TO CONFIRM GOOD COMMUNICATION. READY FOR INTERMEDIATE CEMENT PLUG. 8/31/2024 ACQUIRE DATA (P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASSED) T PPPOT (PASSED), FUNCTION TEST ALL IC LDS (COMPLETE), IC POT (PASSED) IC PPPOT (PASSED), 9/8/2024 SUPPORT OTHER OPERATIONS PUMP INTERMEDIATE BALANCED CEMENT PLUG.PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT & DISPLACED CEMENT w/63 BBLS OF 9.8 PPG. PLACING TOC IN TBG & IA @ ~7210' MD. JOB COMPLETE. 9/10/2024 SUPPORT OTHER OPERATIONS ATTEMPT TO SHEAR SOV/ FREEZE PROTECT TxIA SOV DID NOT SHEAR (SEE LOG) 9/10/2024 SUPPORT OTHER OPERATIONS REATTEMPT TO SHEAR SOV . SOV SHEARED AT 2500 PSI. PUMPED 60 BBLS DSL INTO IA TAKING RETURNS UP TBG TO OPEN TOP. (SEE LOG) JOB COMPLETE 9/15/2024 SUPPORT OTHER OPERATIONS DRIFT w/ 5' X 2-1/2'' DD BAILER (ball) TAG TOC @ 7144' RKB (RECOVER 1/2 CUP UNCURED CEMENT), LRS PERFORM MIT COMBO TO 1750 PSI STATE WITNESS (SULLY) (PASS), READY FOR TUBING CUT 9/17/2024 SUPPORT OTHER OPERATIONS CUT 3.5" TUBING AT 3223' RKB WITH 2.5" JET CUTTER. JOB COMPLETE, READY FOR RIG 2P-431 Intermediate Suspend Summary of Operations ORIGINATED TRANSMITTAL DATE: 9/19/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5064 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 5064 2P-431 50103204170000 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 202-053 T39575 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.19 10:06:42 -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 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 2P-431 50-103-20417-00-00 202-053 Kuparuk River WL Puncher FINAL FIELD 5-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): 9685'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/22/2024 3-1/2" Packer: Baker Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2958' 9290-9300' 9630' 5624-5629' 3-1/2" x 5-1/2" Perforation Depth TVD (ft): 120' 2988' 5809'9656' 16" 7-5/8" 90' 8826' MD 120' 2381' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 202-053 P.O. Box 100360, Anchorage, AK 99510 50-103-20417-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8810' MD and 5378' 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 Senior Well Interventions Engineer KRU 2P-431 5823' 9203' 5581' 484 9254', 9291' 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 documentLocation: Date: 2024.07.15 16:15:55-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-406 By Grace Christianson at 7:37 am, Jul 16, 2024 SFD 7/16/2024 DSR-7/16/24 Suspend 10-407 VTL 7/17/2024 X X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.17 14:23:37 -08'00'07/17/24 RBDMS JSB 072324 Procedure Wireline & Pumping 1. Punch tubing at ±8710’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±190 bbls 9.8 brine c. ±31 bbls cement d. ±63 bbls 9.8 brine displacement e. Pump methanol across tree and valves for freeze protect 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 7210’ MD 1. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 4. Cut tubing at ±3230’ RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 8710 3.5" 9.3# 2.99" 0.0087 8710 75.6 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 8710 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 8710 103.7 84.0 from punch depth Tubing Cement 7210 8710 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 7210 8710 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 2P-431 Intermediate Plug Date: 4/30/24 Prepared by: Katherine O’Connor (214-684-7400) Network Number: Background & Objecve 2P-431 was a producer shut-in in late 2020. 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 has been suspended with a reservoir plug; the objective of this procedure is to install an intermediate plug, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 8/9/2020 = 1046 psi at 5624’ TVD MASP = 484 psi Last tag 9272’ RKB on 8/9/2020 with BHP gauges History of paraffin Hole in tubing in mandrel at 8705’ KB. LLR 2.72 gpm @ 1700 psi Ensure there are no live valves before pumping cement 2P-431 Well Schematic Conductor: 16" Conductor 120' KB Production Casing Cement: 62 bbls of 15.8# Class G Cement Calculated TOC @ 6,460' KB 1 2 4 7 6 Production Casing: 5.5" x 3.5" @ 8,807' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 9,655.6’ KB T-3 Peforations: @ 9,290' – 9,300' KB (10') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,988.2' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 8,826.5' KB 8 Item Depth - tops (KB) 1 CT1A Tubing Hanger 25.6' 2 Camco DS Nipple 509.5' 4 Baker CMU Sliding Sleeve w/ DS Profile (closed)8754.5 5 Special 4.53" OD cut tubing, OAL = 12' for jet pump 8,758.40 6 Camco D Nipple 8,770.5' 7 Baker GBH-22 Locator 8,808.7' 8 Baker Seal Assembly Stabbed into 3.5" Production CSG CSR 8,809.6' 5 Plug #2 – Intermediate TOC ±7210' RKB BOC @ ±8710' RKB Plug #1 – Reservoir TOC ±9203' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,294.0 2P-431 3/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Noted DB cement plug 2P-431 7/4/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL CHARGING OA FROM FORMATION. WAIVER EXPIRES 5/16/15. 1/8/2015 hipshkf NOTE: FOUND LEAK IN MANDREL # 5 @ 8705' 12/7/2012 ninam NOTE: View Schematic w/ Alaska Schematic9.0 11/22/2010 ninam NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM 9/19/2008 lmosbor 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 30.0 120.0 120.0 62.30 H-40 WELDED SURFACE 7 5/8 6.87 30.1 2,988.2 2,380.9 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @8807' 5 1/2 4.95 25.6 9,655.6 5,809.0 15.50 L-80 BTC MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 8,826.5 Set Depth … 5,386.9 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) 25.6 25.6 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500 509.5 509.4 3.73 NIPPLE 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,613.8 2,190.9 58.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,908.3 3,387.7 61.44 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,547.7 4,218.7 59.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,784.6 4,862.2 58.67 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,704.5 5,325.3 59.89 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,754.5 5,350.4 59.70 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/DS PROFILE (CLOSED) BAKER CMU 2.813 8,758.4 5,352.4 59.69 OVERSIZED TBG 4.530 SPECIAL 4.53" OD CUT TUBING , OAL= 12', FOR JET PUMP 2.992 8,770.5 5,358.5 59.65 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 8,808.7 5,377.9 59.51 LOCATOR 4.560 BAKER GBH-22 LOCATOR BAKER 3.000 8,809.6 5,378.3 59.50 SEAL 4.000 BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,254.3 5,606.4 60.61 CIBP CIBP W/ MOE = 9255' PDC, OAL = 1.376' 6/28/2024 0.000 9,291.0 5,624.5 60.24 CIBP CIBP W/ MOE = 9260' PDC, OAL = 1.376' (MOVED DOWNHOLE FROM ORIGINAL SET DEPTH) 3/20/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.8 2,190.9 58.61 1 GAS LIFT GLV INT 1 1,666.0 4/23/2018 0.156 4,908.3 3,387.7 61.44 2 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 6,547.7 4,218.7 59.60 3 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 7,784.6 4,862.2 58.67 4 GAS LIFT OPEN 1 3/17/2024 Open Pocke t 8,704.5 5,325.3 59.89 5 GAS LIFT DMY INT 1 0.0 1/19/2013 Ext Pkg 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,290.0 9,300.0 5,624.0 5,629.0 T-3, 2P-431 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,290.0 9,300.0 1 FRAC 4/20/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,203.0 9,254.3 5,581.0 5,606.4 Cement Plug Dump Bail Cement Plug 7/2/2024 2P-431, 7/15/2024 3:01:08 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @8807'; 25.6-9,655.6 IPERF; 9,290.0-9,300.0 FRAC; 9,290.0 CIBP; 9,291.0 CIBP; 9,254.3 Cement Plug; 9,203.0 ftKB GAS LIFT; 8,704.5 GAS LIFT; 7,784.6 GAS LIFT; 6,547.7 GAS LIFT; 4,908.3 SURFACE; 30.1-2,988.2 GAS LIFT; 2,613.8 NIPPLE; 509.5 CONDUCTOR; 30.0-120.0 KUP PROD KB-Grd (ft) 30.00 RR Date 4/10/2002 Other Elev… 2P-431 ... TD Act Btm (ftKB) 9,685.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032041700 Wellbore Status PROD Max Angle & MD Incl (°) 62.23 MD (ftKB) 5,091.99 WELLNAME WELLBORE2P-431 Annotation Last WO: End DateH2S (ppm) 20 Date 11/23/2015 Comment SSSV: NIPPLE 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:9,685 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface:7-5/8"O.D. Shoe@ 2,988 Feet Csg Cut@ Feet Intermediate:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Production:5-1/2"x3-1/2"O.D. Shoe@ 9,656 Feet Csg Cut@ Feet Liner:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 8,826 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 9,254 ft MD 9,203 ft MD 9.6 ppg KWF Wireline tag Initial 15 min 30 min 45 min Result Tubing 1780 1730 1726 IA 1780 1730 1726 OA 100 110 110 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 of the 1st cmt plug for 2P-431. 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 9,203 ft MD and returned a good cement sample. E-line rigged down and started rigging up on the next well while LRS rigged up for combination MIT TxIA. MIT was performed with no noticable losses to the plug or to the OA. July 12, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-431 ConocoPhillips Alaska Inc. PTD 2020530; Sundry 323-481 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0712_Plug_Verification_KRU_2P-431_ss 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:9,685 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface:7-5/8"O.D. Shoe@ 2,988 Feet Csg Cut@ Feet Intermediate:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Production:5-1/2" x 3-1/2"O.D. Shoe@ 9,656 Feet Csg Cut@ Feet Liner:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 8,826 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 8,710 ft 7,122 ft 9.6 ppg Wireline tag Initial 15 min 30 min 45 min Result CMIT TxIA Tubing 1865 1750 1720 IA 1835 1720 1710 OA 103 103 104 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Travel to KRU 2P pad for tag and test of the intermediate balanced plug. Tag was good at 7,122 ft MD and the bailer returned with a good cement sample. Passing CMIT TxIA July 12, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-431 ConocoPhillips Alaska Inc. PTD 2020530; Sundry 323-481 none Test Data: P Casing Removal: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0915_Plug_Verification_KRU_2P-431_ss ORIGINATED TRANSMITTAL DATE: 7/1/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4900 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 4900 2P-431 50103204170000 Plug Setting Record 28-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 202-053 T39097 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.01 11:40:10 -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 ORIGINATED TRANSMITTAL DATE: 6/26/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4731 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 4731 2P-431 501032041700 Set Plug 20-Mar-2024 RECIPIENTS Conoco Phillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 0 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 0 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 202-053 T39054 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 15:13:55 -08'00' DNR DIGITAL FILES PRINTS CD'S 0 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 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): 9685'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Well Interventions Engineer KRU 2P-431 5823' 9272' 5615' None N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8685' MD and 5315' TVD 8715' MD and 5330' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 202-053 P.O. Box 100360, Anchorage, AK 99510 50-103-20417-00-00 Kuparuk River Field Meltwater Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst 8826' MD 120' 2381' 120' 2988' 5809'9656' 16" 7-5/8" 90' 2958' 9290-9300' 9630' 5624-5629' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 9/20/2023 3-1/2" Packer: WFD ER Patch Packer Packer: WFD ER Patch 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 By Grace Christianson at 11:22 am, Aug 25, 2023 323-481 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.08.24 12:51:41-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 10-407 December 31, 2024 SFD SFD 9/7/2023 DSR-8/28/23 Suspend SFD VTL 10/3/2023 X X *&:JLC 10/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.03 11:26:54 -08'00' RBDMS JSB 100323 2P-431 Suspension Date WriƩen: 21 Aug 2023 ExecuƟon Date: Sept 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & ObjecƟve 2P-431 was a producer shut-in in late 2020. 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 8/9/2020 = 1046 psi at 5624’ TVD MASP = 484 psi Last tag 9272’ RKB on 8/9/2020 with BHP gauges History of paraffin Procedure Wireline & Pumping 1. Pull patch set from 8685’ – 8715’ KB 2. Tag TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 3. Fluid pack tubing with KWF and freeze protect 4. Set CIBP @ ±9,260’ RKB (must be set within 50’ of the top of perforations) 5. Perform CMIT-TxIA to 1500 psi, record results 6. Dump bail at least 30’ of cement on top of CIBP 7. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 8. RIH and tag TOC, approx. 9,230’ RKB (MUST BE AOGCC WITNESSED) 9. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 10. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,272.0 2P-431 8/9/2020 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag 2P-431 8/9/2020 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL CHARGING OA FROM FORMATION. WAIVER EXPIRES 5/16/15. 1/8/2015 hipshkf NOTE: FOUND LEAK IN MANDREL # 5 @ 8705' 12/7/2012 ninam NOTE: View Schematic w/ Alaska Schematic9.0 11/22/2010 ninam NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM 9/19/2008 lmosbor 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 30.0 120.0 120.0 62.30 H-40 WELDED SURFACE 7 5/8 6.87 30.1 2,988.2 2,380.9 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @8807' 5 1/2 4.95 25.6 9,655.6 5,809.0 15.50 L-80 BTC MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.6 Set Depth … 8,826.5 Set Depth … 5,386.9 String Ma… 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) 25.6 25.6 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500 509.5 509.4 3.73 NIPPLE 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,613.8 2,190.9 58.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,908.3 3,387.7 61.44 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,547.7 4,218.7 59.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,784.6 4,862.2 58.67 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,704.5 5,325.3 59.89 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,754.5 5,350.4 59.70 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/DS PROFILE (CLOSED) BAKER CMU 2.813 8,758.4 5,352.4 59.69 OVERSIZED TBG 4.530 SPECIAL 4.53" OD CUT TUBING , OAL= 12', FOR JET PUMP 2.992 8,770.5 5,358.5 59.65 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 8,808.7 5,377.9 59.51 LOCATOR 4.560 BAKER GBH-22 LOCATOR BAKER 3.000 8,809.6 5,378.3 59.50 SEAL 4.000 BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,685.0 5,315.5 59.92 PACKER UPPER WEATHERFORD ER PACKER 1/19/2013 1.750 8,687.8 5,316.9 59.93 PATCH PATCH SPACER PIPE, SNAP LATCH ASSEMBLY 1/19/2013 1.750 8,715.0 5,330.5 59.85 PACKER LOWER WEATHERFORD ER PACKER 1/4/2013 1.750 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.8 2,190.9 58.61 1 GAS LIFT GLV INT 1 1,666.0 4/23/2018 0.156 4,908.3 3,387.7 61.44 2 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 6,547.7 4,218.7 59.60 3 GAS LIFT DMY INT 1 0.0 4/10/2002 0.000 7,784.6 4,862.2 58.67 4 GAS LIFT OV INT 1 0.0 4/23/2018 0.313 8,704.5 5,325.3 59.89 5 GAS LIFT DMY INT 1 0.0 1/19/2013 Ext Pkg 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,290.0 9,300.0 5,624.0 5,629.0 T-3, 2P-431 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,290.0 9,300.0 1 FRAC 4/20/2002 0.0 0.00 0.00 2P-431, 8/24/2023 12:34:13 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @8807'; 25.6-9,655.6 IPERF; 9,290.0-9,300.0 FRAC; 9,290.0 PACKER; 8,715.0 GAS LIFT; 8,704.5 PATCH; 8,687.8 PACKER; 8,685.0 GAS LIFT; 7,784.6 GAS LIFT; 6,547.7 GAS LIFT; 4,908.3 SURFACE; 30.1-2,988.2 GAS LIFT; 2,613.8 NIPPLE; 509.5 CONDUCTOR; 30.0-120.0 KUP PROD KB-Grd (ft) 30.00 RR Date 4/10/2002 Other Elev… 2P-431 ... TD Act Btm (ftKB) 9,685.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032041700 Wellbore Status PROD Max Angle & MD Incl (°) 62.23 MD (ftKB) 5,091.99 WELLNAME WELLBORE2P-431 Annotation Last WO: End DateH2S (ppm) 20 Date 11/23/2015 Comment SSSV: NIPPLE • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, October 15, 2015 3:49 PM To: NSK Problem Well Supv Subject: RE: Request to allow Meltwater injector 2P-447 (PTD 203-154 AIO 21A.006) and producer 2P-431 (PTD 202-053 AIO 21A.002 Amended)to remain online 10-10-15 Kelly, I am in the process of a new AA for the injector 2P-447 which will probably be A10 21B.001. AIO 21A.002 language and intent was to obtain the understanding integral to the updating of the AIO. Now we have A10 21B in place with an annual injection report detailing all injection and pressure activities including producer data where necessary—I believe there is no need for an AA for the producer 2P-431. A10 21A.002 has already been cancelled by AIO 21B. Production should fall under the sustained casing pressure requirements under the conservation order and not the AIO. You have previously notified us of the > 1000 psi so as long as the 45%is not being exceeded you should be OK under regular producer reporting requirements. Let me know if I am missing something or you feel you need the AA(or waiver etc.)for 2P-431 for any reason. Thanks and Regards, ( hrMPQ( a 't A f04- AP-41 I Chris Wallace /1c repo . Af(I(,cabO Sr. Petroleum Engineer +e 4es .rcl Alaska Oil and Gas Conservation Commission G b41.333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) g1� (907)276-7542(fax) schga �p MAY 0 2 chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wallace, Chris D (DOA) Sent: Saturday, October 10, 2015 10:52 PM To: NSK Problem Well Supv Subject: RE: Request to allow Meltwater injector 2P-447 (PTD 203-154 AIO 21A.006) and producer 2P-431 (PTD 202- 053 AIO 21A.002 Amended) to remain online 10-10-15 Kelly, AIO 21B did cancel the old orders but it was not our intent to change the current operation of the wells. Please get back with me within the mentioned 14 days with the criteria that you see in conflict and we will work this out. Thanks Chris 1 • Original message From: NSK Problem Well Supv<n1617@conocophillips.com> Date: 10/10/2015 2:20 PM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace(a,alaska.gov> Subject: Request to allow Meltwater injector 2P-447 (PTD 203-154 AIO 21A.006) and producer 2P-431 (PTD 202-053 AIO 21A.002 Amended)to remain online 10-10-15 Chris, The AA's of two Meltwater wells, injector 2P-447 (PTD 203-154 AIO 21A.006)and producer 2P-431 (PTD 202-053 A10 21A.002 Amended),expired when the new Meltwater Area Injection Order AIO 21B was issued on 10/08/15. CPAI requests that these wells be allowed to remain on line while new applications are assessed and submitted if deemed appropriate. The wells will be operated as set out in their expired AA's for a period not to exceed 14 days. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 2 • • Al0 13 .0o2. Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Saturday, October 10, 2015 10:52 PM To: NSK Problem Well Supv Subject: RE: Request to allow Meltwater injector 2P-447 (PTD 203-154 A10 21A.006) and producer 2P-431 (PTD 202-053 AIO 21A.002 Amended)to remain online 10-10-15 Kelly, AIO 21B did cancel the old orders but it was not our intent to change the current operation of the wells. Please get back with me within the mentioned 14 days with the criteria that you see in conflict and we will work this out. Thanks Chris Original message From: NSK Problem Well Supv<n1617(aconocophillips.com> Date: 10/10/2015 2:20 PM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace(aalaska.gov> Subject: Request to allow Meltwater injector 2P-447 (PTD 203-154 AIO 21A.006) and producer 2P-431 (PTD 202-053 AIO 21A.002 Amended) to remain online 10-10-15 Chris, The AA's of two Meltwater wells, injector 2P-447 (PTD 203-154 AIO 21A.006) and producer 2P-431 (PTD 202-053 AIO 21A.002 Amended),expired when the new Meltwater Area Injection Order AIO 21B was issued on 10/08/15. CPAI requests that these wells be allowed to remain on line while new applications are assessed and submitted if deemed appropriate. The wells will be operated as set out in their expired AA's for a period not to exceed 14 days. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907)659-7000 pgr 909 1 I mage 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. dO:l- O.s 3 'Well History File Identifier Organizing (dolle) RESCAN 0 Two-Sided 0 Rescan Needed DIGITAL DATA OVERSIZED (Scannable) 0 Color items: 0 Diskettes, No. 0 Maps: Other items scannable by large scanner vi' Grayscale items: 0 Other, Norrype 0 0 Poor Quality Originals: Other: OVERSIZED (Non-Scannable) 0 NOTES: 0 Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERY~INDY 0 Other DATES:~5þ~1 VV1:D BY: BEVERLY ROBIN VINCENT SHERYL8WINDY DATE,) ~Si)lt'sl 3 X 30 = 1 (') + . = TOTAL PAGES c¡or;;- ,~ VINCENT SHERy9rNDY DATES á'5!ðq/SI Vì1 P ~;f I vnfJ Project Proofing ",. Scanning Preparation BY: BEVERLY ROBIN Stage 1 ) . q J ÚJV~ D CUJ'~ ttddtvJ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: / YES NO ./7/tJt, MP Production Scanning PAGE COUNT FROM SCANNED FILE: BY: BEVERLY ROBIN VINCENT SHERY~INDY DATE:~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAl. ATTENTION IS REOUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ¡- ReScanned (inl.fÍ1'idu;ll p.)~r It.p(~r;f,ll ,7t10/Hion} V:,)j nill:J wmp!I~I()(J) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked Idolle) 12/10/02Rev3NOTScanned.wpd 4), \ I%% s9 THE STATE Alaska Oil and Gas tt Of 1 1 1sKA l l servation issi te- 110F GOVERNOR SEAN PARNELL 333 West Seventh Avenue FALA`�lP Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 lrl Tom Nenahlo SCANNED Drill Site Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 � ± "-- © �3 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P-431 Sundry Number: 313-554 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. F rster Q� Chair, Commissioner DATED this ?7- day of November, 2013. Encl. STATE OF ALASKA L RECEIVED � A to OIL AND GAS CONSERVATION COMNOION 't'N P OCT O, APPLICATION FOR SUNDRY APPROVALS ��• 3 20 AAC 25.280 1.Type of Request: Abandon fl Plug for Redrill r Perf orate New Fbol r Repair w ell r Change Ap}r tbedQ ` Suspend r Plug Perforations r Perforate f Pull Tubing r Time Extension fl Operational Shutdown r Re-enter Susp.Well r Stimulate fl Alter casing r Other:Request for Annular Flow rq 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 1; 202-053 3.Address: 6.API Number: Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20417-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p 2P-431 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 389058 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): 9685 5823 9530' 5746' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 90 16 120' 120' SURFACE 2958 7.625 2988' 2381' PRODUCTION 9630 5.5 x 3.5 9656' 5809' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9290'-9300' 5624'-5629' 3.5 L-80 8827 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-UPPER WEATHERFORD ER PACKER MD=8685 TVD=5315 PACKER-LOWER WEATHERFORD ER PACKER MD=8715 TVD=5331 NIPPLE-CAMCO DS NIPPLE MD=510 TVD=509 12.Attachments: Description Summary of Proposal F,1 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory fl Stratigraphic fl Development , Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/1/2013 Oil Gas r WDSPL fl Suspended 16.Verbal Approval: Date: VVINJ r GINJ f WAG r Abandoned r Commission Representative: GSTOR r SPLUG f 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Nenahlo @ 265-6934 Email: Thomas.L.Nenahlo(c�conocoohillips.corr Printed Name To e hlo Title: Drill Site Petroleum Engineer Signature �� °7 r(� Phone:265-6934 Date /0/17I Zo 1 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -- V"j 1—'S S4( Plug Integrity r BOP Test fl Mechanical Integrity Test r Location Clearance RBDMS NOV 1 5 4 Other: Op Q to oister�s-F e, (Jn W'til erns et ki O aUA L A-10 2 1 A.cQ 2 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: i 0 —40 D 4_ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ���8 -Approved application is valid tor 12 months trom the date of approval. Form 10-403(Revised 10/2012) ORIGINAL Submit Form and Attachments in Duplicate z_F 1111113 C4 -4 io/22/203 • • REC;t0itimi lr� OCT 172013 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, 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 Wellbore Schematic • • ConocoPhillips Alaska,Inc. Kuparuk River Unit Meltwater 2P-431 (PTD#202-053) Technical Justification for Administrative Relief Request,AIO 21A,Rule 3 & Sundry Approval for Annular Production Purpose ConocoPhillips Alaska,Inc.(CPAI)requests that the AOGCC approve this Administrative Relief as per Area Injection Order(MO)21A(Amended),Rule 10, for relief from criteria set forth in Rule 3 that limits the Outer Annulus(OA)pressure at surface to no more than 1,000 psi. Specifically,CPAI requests approval for Meltwater well 2P-431's OA pressure to increase to equilibrium pressure,not to exceed 1,800 psi.This request is in support of the 2P-431 OA extended bleed project that is designed to determine if the pressure source is trapped and if it can be de-pressured. To facilitate this 2P-431 OA extended bleed project,CPAI also requests approval of a Sundry 10-403 for annular production. The background and technical justification for these requests are put forth below. Well History and Status Well 2P-431 is a single completion, gas-lifted producer in the Meltwater participating area. This well produces the Bermuda formation. The well was completed in April of 2002 and is currently online, producing approximately 370 BOPD with 0-1%water cut and a gas-oil-ratio(GOR)of 1,500. Currently, a tubing patch is in place at 8685'-8715' MD. This tubing patch was installed after tubing by inner annulus(TxIA)communication was identified in the fall of 2013. Annulus Bleed Project ConocoPhillips Alaska's Meltwater team intends to perform an extended bleed on the outer annulus of 2P-431 to determine if the pressure source is trapped and if the area below the surface casing shoe can be de-pressured. Prior to commencing this extended outer annulus bleed at 2P-431, CPAI would prefer the starting outer annulus pressure to be in equilibrium with the formation at the surface casing shoe. Well 2P-431's outer annulus has required frequent pressure bleeds and/or liquid loading to keep the pressure under the 1,000 psi limit specified in AIO 21A(Amended),Rule 3. Therefore,to ensure an accurate assessment of the initial pressure of the source prior to conducting the extended bleed, it is requested that well 2P-43 l's outer annulus pressure be allowed to rise to an equilibrium pressure. Historically,this equilibrium pressure was approximately 1,560 psig at surface. CPAI estimates the extended outer annulus bleed will require six to eight months to complete. Annulus Bleed Operation The extended outer annulus bleed will require routing the outer annulus to the 2P-431 production well line to enable the outer annulus to flow and thus de-pressure the formation below the surface casing shoe. The routing between the 2P-431 outer annulus and production well line will include the following: • Two manual isolation valves. One will be located on the outer annulus;the other will be located on the production well line. • A pressure control valve that will be set to open at 350 psig. This set pressure is approximately 125 psig greater than the production well line pressure. CPAI Well Integrity Director 10/17/2013 • • • A pressure indicator transmitter on the outer annulus to allow for the continuous monitoring of p g the outer annulus pressure. • An orifice meter to measure flow rate. The orifice will be interchangeable to account for expected flow rate changes. • A check valve to further mitigate the potential of backflow from the production well line to the outer annulus. • Two drain valves,one upstream and one downstream of the pressure control valve. The valve upstream of the pressure control valve can be utilized as a pump-in location for the outer annulus. • The aforementioned outer annulus pressure indicator transmitter,pressure control valve,and orifice flow meter will be linked to CPAI's process control system(SCADA)to allow for continuous monitoring and data capturing of this extended outer annulus bleed. Once the routing between 2P-431 has been constructed,pressure tested, and the instrumentation function tested,the outer annulus will be flowed back to the production well line. Outer annulus fluid samples will be obtained weekly to ensure the flow is characterized. Volumes of fluid produced will be documented. Barrier and Hazard Evaluation Approval to increase the OA pressure on 2P-431 is not expected to affect the production performance of the well. In addition,the primary and secondary barriers between the reservoir and atmosphere(tubing and production casing) should not have an increased risk of a release from this project. Primary barrier:The tubing is the primary barrier to provide zonal isolation and prevent a release from the well. Secondary barrier: The production casing is the secondary barrier to provide zonal isolation and prevent a release from the well. Elevating the surface casing pressure to a not to exceed value of 1,800 psig does increase the operational risk,primarily from the consequences to field personnel should they be exposed to high pressure gas.The surface casing is 9-5/8",36#,J-55 with an internal yield pressure rating of 3520 psi. The maximum requested pressure is 1,800 psig,which is 54%of the book value pressure rating. The expected maximum surface casing pressure(historical)is 1,560 psig,which is 45%of the book value pressure rating.Recent near surface casing inspections indicate only minor corrosion is present and should not be a significant factor at the expected pressure levels of this project.Finally,this well had elevated OA pressures for nearly 10 years without incident, only recently were attempts made to reduce the pressure below 1,000 psig. Safety Valve System:An analysis of the project in terms of safety systems reveals no advantage or reduction of risk if a Low Pressure Pilot(LPP)is incorporated into the wells' Safety Valve System(SVS). The flow from the OA is independent from production from the well, and shutting in the well will have no effect on flow from the OA. Therefore,the pressure control valve on the line from the OA to the well line will be set to close upon indication of low pressure on the well line should there be a loss of pressure on the well line or OA line downstream of the check valve. Administrative Approval Request CPAI requests that the AOGCC approve this Administrative Relief as per Area Injection Order(AIO) 21A(Amended),Rule 10, for relief from criteria set forth in Rule 3 that limits the Outer Annulus(OA) pressure at surface to no more than 1,000 psig. CPAI Well Integrity Director 10/17/2013 2 • Specifically, CPAI requests approval for Meltwater well 2P-431's OA pressure to increase to equilibrium pressure,not to exceed 1,800 psig. The approval is requested for a period of one year from the date of the approval letter. In addition,to facilitate the 2P-431 OA extended bleed project, CPAI requests Sundry 10-403 approval for annular production for a period of one year from the date of the approval letter. CPAI Well Integrity Director 10/17/2013 3 [ 2p-43( • • Pr 262_05 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, March 29, 2013 10:06 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Subject: Report of SCP of OA on 2P -431 (PTD 202 -053) 03 -29 -13 Chris, Jim, Guy te r' Meltwater gaslifted producer 2P -431 (PTD 202 -053) is now demonstrating SCP of the OA�bove 1000psi. The OA pressure had been relatively stable since returning the well to production on 2/1/13 following a retrievable tubing patch installation in January. With the OA pressure nearing 970psi, an initial OA bleed was performed yesterday. Following the initial bleed, the OA pressure displayed a rapid build up rate with the pressure then exceeding 1000psi. Additional bleeding was attempted. Because the OA pressure could not he kept below 1000psi, the well was SI and freeze protected yesterday. Additional bleeding is planned to be performed today with continued monitoring of the pressures. I've attached a 90 day TIO plot as well as a 7 day plot for better resolution. Please let me know if you have any questions. AI ,e ktetC La-s 1; ZsLy Brent Rogers / Kelly Lyons (,Jec.,S r r \c-Li e) , '-' t 1) Problem Wells Supervisor 1 ConocoPhillips Alaska, Inc C -Le "c'< I nc Desk Phone (907) 659 -7224 (;_ SSLLZ' tit -F- Pager (907) 659 -7000 pgr 909 SCANNED .JUL 1 0 2013 KRU 2P -431 PTD 2020530 - 3/29/2013 TIO Pressures Plot — 7 day 1KupLrukSCADA\WD_TREND WELL TRENDS 2P 431 GAS LII- I OIL V/D HOUSE P; T ; TRfLMULT_SCRLE WELLS WLHD CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE OPERATOR NOTES SET CHOKE CHOKE 100. LIFT RATE 0. STATIC PR C -PRIME FTP 229. ROR OIL 27777 ?7 LG CHOKE 0. STATIC P FTT 58. ROR LG 7 ? ? ? ? ?? LG SETPT LG CHOKE IGV /OGV LG ORIF 0.650 LG ORI DP -0. LG SETPT • CASING PRE 489. 1G CPRTME ORTF SZ - -- WEIT STATUS 1500 OFF Ors INVERT OPEN /SI 1350 p i 1500 = • EVENT AT : : ----- -- - : PICK TIME 100( 1200 1000 GENERAL PURPOSE 1500 1050 • EVENT AT 1500. I i t V I I i PICK TIME 900 CREATE WELL Ng NOTE AT 1 PICK TIME O f + - 750 ; ii ORIFICE pir NB -4- _ i li FREEZE 600 PROTECTION PREV WELL 450 . OI NEXT WELL 300 • • Fir VIEW SDL ? 1 0. 150 ` CREATE SDL 0. 0 P i -50. ' VIEW EPDDL n ER SCALE DESC PICK VALUE LATEST TION per CREATE EPDDL 0. MI MN 100. 100. 168.00 HRS 29- MAR -13 10:01 O It FTP 230. 229. [� pr ANNCOM PROBLEMS "Pr FTT 35. 58. 11 I T rF. UMFi Flags: II 'sr CASING P 802. 489. 7nnu TBG: A =7, LIFT RATE 1282. O. MINOR TIME HOUR IA: U! ORIF -DP 75. -0 HOURLY r I` MAJOR TTW DAY OA. OA charging with gas fro: open shoe. IA PRES 802. 490. r• T(`7, TTV 10- MAR -13 15:22:18 L HOUR A OA PRES 939. 1011. KRU 2P -431 PTD 2020530 3/29/2013 TIO Pressures Plot — 90 day `rU ' ''._:` WELL TRENDS 2P 431 GAS LIFT OIL �— WD HousE m- WELLS WLHD CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE OPERATOR NOTES CHOKE CHORE 100. LIFT RATE 0. STATIC PR C -PRIME FTP 230. ROR OIL ? ? ? ? ? ?? LG CHOKE 0. STATIC P FTT 59. ROR LG 7777777 LG SETPT LG CHOKE IGV /OGV LG ORIF 0.650 LG ORI DP -0. LG SETPT • CASING PRE 4Pt LG CPRIME ORTF S7. t WFTT STATU 1500 OFF 1500- _ , INVERT OPEN /SI 80- 1350 I pi EVENT AT 1500. PICK TIME ffw 1200 loon ... 1 - - -- GENERAL PURPOSE 1501! 1050 1111 - I F EVENT AT 1500. PICK TIME I �" 1 - Il - CREATE WELL 900 I� er pi NOTE AT I ____ _ • __ __ 0 I I PICK TIME 0 750 . ORIFICE or 600 in FREEZE I PROTECTION IM PREY WELL FM 450 III NEXT WELL 300 I N VIEW SDL 150 D . - Ii lb J - `i im I marl CREATE SDL 0 ii . ,- III VIEW EPDDL Pil ER SCALE DESC PICK VALUE LATEST O. CREATE EPDDL 0. nom CHOKE O- 100. 2160.0 HRS 29- MAR -13 10:06 P ANNCOM PROBLEMS j OM FTP Er FTT 267. 230. 59. I I I IThrZIMEIE IN Flags: OA: P 1111 illr CASING P 22. 489. r ZOOM TBG: • MN LIFT RATE 0. R. MINOR TIME IA: • ORIF -DP 75. -0. r n- MAJOR TTMT WEEK OA: OA charging with gas from open shoe. al . IA PRES 14. 491. HOURLY r HOUR OA PRES 906. 1012. r PICK TIME 29- DEC -12 10:32:02 STATE OF ALASKA ALA" OIL AND GAS CONSERVATION COMIOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon J Repair w ell E Rug Perforations J °" Perforate f'"' Other l• Install Patch Alter Casing j`"` Pull Tubing f Stimulate - Frac -" Waiver f Time Extension r Change Approved Program EOperat. Shutdown E Stimulate - Other f Re -enter Suspended Well j°'°' 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development f Exploratory f-°" 202 -053 3. Address: 6. API Number: Stratigraphic j Service f' P. O. Box 100360, Anchorage, Alaska 99510 ` 50 103 20417 - 00 7. Property Designation (Lease Number): 9'n 8. Well Name and Number: ADL 389058 4 -3 73 (p., /11. - 2P - 431 9. Logs (List logs and submit electronic and printed data per 20AAC25.07 10. Field /Pool(s): N none Kuparuk River Field / Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 9685 feet Plugs (measured) none true vertical 5823 feet Junk (measured) none Effective Depth measured 9530 feet Packer (measured) 8685, 8715 true vertical 5746 feet (true vertical) 5315, 5331 Casing Length Size MD TVD Burst Collapse CONDUCTOR 90 16 120 120 SURFACE 2958 7.625 2988 2381 -r•,, EIV E PRODUCTION 9630 5.5" x 3.5" 9656 5809 "' EB 1 4 2013 SCANNED WAR 05' c C G Perforation depth: Measured depth: 9290' - 9300' True Vertical Depth: 5624 Tubing (size, grade, MD, and ND) 3.5, L - 80, 8827 MD, 5387 TVD Packers & SSSV (type, MD, and ND) PACKER - UPPER WEATHERFORD ER PACKER @ 8685 MD and 5315 ND PACKER - LOWER WEATHERFORD ER PACKER @ 8715 MD and 5331 ND SSSV - CAMCO DS NIPPLE @ 510 MD and 509 ND 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 333 929 0 -- 241 Subsequent to operation 1088 3347 0 -- 251 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory 1- Development fi • Service E Stratigraphic F 16. Well Status after work: - Oil id' Gas F WDSPL F. Daily Report of Well Operations XXX GSTOR F WINJ F WAG GINJ F SUSP F SPLUG F 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce (cr)_ 265 -6417 Email John .W.Peirceeconocophillips.com Printed Name John Peirce Title Wells Engineer Signature _ s , Phone: 265 -6471 Date 2 /1 3 SUMS FEB 14 2013 4 Vc,r' /774;(/) 1 3 Form 10 -404 Revised 12/2012 Z Submit Original Only 2P -431 Well Work Summary • DATE JOBTYF SUMMARYOPS 10/22/2012 Secure ' CUT WAX, GAUGE TBG TO 2.83 ", DRIFT / TAG FILL @ 9280' SLM, SET CA -2 PLUG @ 8753' SLM, SET AVA CATCHER © 8752' SLM 10/23/2012 Secure ' PULLED OV @ 8704' RKB; CIRC OUT W/ DIESEL; SET DV @ 8704' RKB AND FAILED MIT W/ IA TRACKING. PULLED DV @ 8704' RKB. IN PROGRESS. 10/24/2012 Secure ' SET DV @ 8704' RKB ( TBG x IA CONTINUE TO TRACK ). TAG AVA CATCHER © 8750' SLM. IN PROGRESS. 10/25/2012 Secure' IDENTIFY GLM LEAKING @ 8704' RKB. PULLED DV ( LOWER SET OF PACKING TORN ) AND REPLACED W/ NEW ( T X IA STILL TRACKING ). PULL DV @ 8704' RKB ( LOWER SET OF PACKING TORN W/ SCRAPE MARK ALONG THE SIDE ). RAN POCKET BRUSH AND BRUSH GL POCKET @ 8704' RKB. IN PROGRESS. 10/26/2012 Secure ' RAN DV ( W/ HIGH SEALABILITY PACKING TO 8704' RKB ( STILL LEAKING) PULLED DV AND SET EXTENDED PACKING DV W/ HIGH SEALABILITY PACKING, ( STILL LEAKING ); PERFORM COMBO MIT TxIA TO 2500 PSI, ( PASS) , UNABLE TO ESTABLISH LEAK RATE. IN PROGRESS. 10/27/2012 Secure PERFORMED ARCHER FLOWPOINT LOGGING FROM 8770' RKB TO 2889' RKB. IN PROGRESS 10/28/2012 Secure ' ( ARCHER TOOL DID NOT COLLECT DATA FROM UP LOG ON PREVIOUS DAY ). REPEAT FLOWPOINT UP LOG FROM 8770' RKB TO 2889' RKB ( GOOD DATA ). IN PROGRESS. 10/29/2012 Secure' RAN ARCHER FLOW POINT SURVEY TOOL. LOGGED UP f/ 8770' RKB TO 2889' RKB, WHILE BLEEDING OA PRESSURE CONTINUOUSLY THROUGHOUT; GOOD DATA, RDMO. 11/10/2012 Ann -Cot T -LLRT ESTABLISHED A LLR OF 5.6 GPM 11/14/2012 Ann -Cot LOG 24 ARM MIT FROM 8770' TO SURFACE. READY FOR LDL 11/19/2012 Ann -Cot PERFORMED LDL WITH PDS ULTRASONIC TOOL. FOUND SUSPECTED LEAK AT GLM #5. LEAK AT GLM #5 APPEARS TO HAVE STOPPED LEAKING AS TOOL PASSED THROUGH GLM #5. ADVISED TO PERFORM MIT SINCE THE WELLHEAD PRESSURES WERE NOT MOVING. RESULTS AS FOLLOWS: MIT USING WELLHEAD ANALOG GAUGES INITIAL: T = 2550 PSI; IA= 150 PSI; OA= 900 PSI 15 MINUTEST = 2550 PSI; IA= 150 PSI; OA= 900 PSI 30 MINUTEST = 2550 PSI; IA= 150 PSI; OA= 900 PSI 5 BBLS OF DIESEL PUMPED DOWN TUBING DURING LDL. 10 BBLS METHANOL TO FLOWLINE FOR FREEZE PROTECT 11/27/2012 GLV C/( PULLED DV @ 7785' RKB, REPLACED w/ OV. IN PROGRESS. 11/28/2012 GLV C/( WITH HOLEFINDER IDENTIFIED APPARENT LEAK © GLM @ 8704' RKB. PULLED OV @ 7785' RKB, REPLACED w/ DV. READY FOR LDL. 11/30/2012 Ann -Cot T -LLR ESTABLISHED: 2.72 GPM @ 1700 PSI; 4.1 GPM @ 2500 -2200 PSI; 3.5 GPM @ 2750 PSI. 12/7/2012 Ann -Cot PERFORMED LDL WITH TECWEL ULTRASONIC LEAK DETECTING TOOL. FOUND LEAK IN MANDREL #5 @ 8705'. LEAK IN MANDREL WOULD CLOSE OFF WHENEVER CENTRALIZERS WOULD PASS THROUGH WHILE PUMPING DOWN TUBING. ABLE TO GET A FULL PASS THROUGH MANDREL WHILE IT WAS LEAKING WHEN PUMPING DOWN IA AND TAKING RETURNS TO TUBING. PUMPED 5 BBLS OF DIESEL TO FREEZE PROTECT FLOWLINE 12/11/2012 Ann -Cot PULL CATCHER & 2.75" CA -2 PLUG @ 8770' RKB. BRUSH'n FLUSH PATCH INTERVAL; DRIFT W/ 2.78" X 28' DUMMY PATCH TO D- NIPPLE @ 8770' RKB. READY FOR E -LINE LOWER PACKER. 1/4/2013 Ann -Cot SET WEATHERFORD LOWER ER PACKER AT 8717' USING A BAKER 10 SETTING TOOL. CCL TO MID - ELEMENT LENGTH: 10', CCL STOP DEPTH: 8707'. GOT HUNG UP IN GLM AT 2614' AND 7785', WAS ABLE TO WORK TOOLSTRING DOWN. 1/11/2013 Ann -Cot UNABLE TO CONDUCT CMIT DUE TO GAS IN WELL ( PREPARE WELL FOR CIRC OUT) . SET 3 1/2" ER TEST TOOL @ 8717' RKB. PULLED DV FROM 8705' RKB. IN PROGRESS. 1/12/2013 Ann -Cot LOADED TBG & IA W/ 200 BBLS DIESEL. CMIT TO 2500 PSI PASSED ON 2ND TEST. IN PROGRESS. 1/19/2013 Ann -Cot SET DV @ 8704' RKB. PULLED 3 1/2 ER TEST TOOL @ 8717' RKB. SET 2.74" UPPER WEATHERFORD ER PACKER PATCH ASSEMBLY @ 8685' RKB. ( MIT IA TO 2500 PSI PASS / LOST SHEAR PIN RETAINING RINFR G OM GR) . IN PROGRESS. 1/20/2013 Ann -Cot SET 3 1/2 ER TEST TOOL @ 8685' RKB. JOB POSTPONED DO TO HIGH WINDS. IN PROGRESS. 1/27/2013 Ann -Cot ATTEMPTED MIT - G AND MIT- IA WITH NO SUCCESS. II.OGRESS. 1/28/2013 Ann -Cot MIT- IA TO 2500 PSI, PASSED. ATTEMPTED MIT- TBG, FAILED. WITH HOLEFINDER IDENTIFIED POSSIBLE LEAK IN TBG BETWEEN 2915' AND 3100' SLM. IN PROGRESS. 1/29/2013 Ann -Cot PULLED ER TEST TOOL @ 8685' RKB: SEALS DAMAGED, RECOVERED HALF OF GR PIN RETAINER. DRIFTED WITH BRUSH TO PATCH @ SAME. RE -SET TEST TOOL. IC -POT, T- POT PASSED. MIT- TBG 2500 PSI, PASSED. IN PROGRESS. 1/29/2013 Ann -Cot T -POT (PASSED), T -PPPOT (PASSED) @ 5000 PSI, IC -POT (PASSED), IC -PPPOT (PASSED) @ 3000 PSI 1/31/2013 Ann -Cot REPLACED DV @ 7785' WITH OV, DV © 2614' RKB WITH GLV. TESTED TBG 2500 PSI, GOOD. PULLED ER TEST TOOL @ 8685' RKB. COMPLETE. KUP 2P-431 CanQjj jjj$ W ell Attributes • Max Angle & MD TD , 'MC , . Wel!bore APIIUWI Field Name Well Status Inc1 ( °) MD (ftKB) Act Btm (ftKB) caewc,,,,wmps 501032041700 MELTWATER PROD 62.23 5,091.99 9,685.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "" SSSV: NIPPLE 23 12/11/2012 Last WO: 30.00 4/10/2002 Well Co rq -2P431, 2/1/20136'.34:55 AM Schematic- Actual -: Annotation Depth (ftKB) End Date Annotation Last Mod End Date Last Tag: SLM 9,280.0 10222012 Rev Reason: GLV C/O, SET PATCH osborl 2/1/2013 Casing Strings " s °" - :i 3E ,. 11..11x, - Casing Description String 0 String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd .. CONDUCTOR 16 15.062 30.0 120.0 120.0 62.30 H WELDED HANGER, 26 { (r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd 1 SURFACE 75/8 6.875 30.1 2,988.2 2,380.9 29.70 L BTC - MOD ` -- ' - ''�' �'� Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt.. String ... String Top Thrd 'I PRODUCTION 512 4.950 25.6 9,655.6 5,809.0 15 50 L - 80 BTC MOD 5 5" 1Gt 5" @8807' T Str .�) 1 ..; � '�r in G.. T D on String 0... String ID ... Top (ftK Set Depth (f... Set Depth (TVD) ... St Wt String ... String Top Thrd TUBING 31/2 2.992 2 8,826.5 5,3 �p,�� 9.30 L- EUE -8rd CONDUOTOR,_ � Completion Details 4 ��' .w. z_, g . -.r^ l i9 ,� Top Depth (TVD) Top Intl Top (ftKB) (ftKB) (°) Item Description Comment ID (in) NIPPLE, 510 25.6 25.6 -0.82 HANGER CT1ATUBINGHANGER 3.500 509.5 509.4 3.73 NIPPLE CAMCO DS NIPPLE 2.875 8,754.5 5,350.4 59.70 SLEEVE -C BAKER CMU SLIDING SLEEVE wIDS PROFILE (CLOSED) 2.813 8,758.4 5,352.4 59.69 OVERSIZED SPECIAL 4.53" OD CUT TUBING , OAL =12', FOR JET PUMP 2.992 TBG 8,770.5 5,358.5 59.65 NIPPLE CAMCO D NIPPLE 2.750 1 ,... 11 . 8,808.7 5,378.7 60.19 LOCATOR BAKER GBH -22 LOCATOR 3.000 GAS LIFT, 8,809.6 5,379.1 60.17 SEAL BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR 3.000 2,614 Other Inklole (Wireline retrievable plugs, valves, pumps, fish, etc.) _ , / Top Depth.,... . `. -.\ (TVD) Top Mal 1 i Top (ftKB) (ftKB) ( °) Description y Comment Run Date ID (in) \ 8,685.0 5,315.5 59.96 PACKER UPPER WEATHERFORD ER PACKER 1/19/2013 1.750 8,687.8 5,316.9 59.95 PATCH PATCH SPACER PIPE, SNAP LATCH ASSEMBLY 1/19/2013 1.750 SURFACE, � ■ 8,715.0 5,330.5 59.85 PACKER LOWER WEATHERFORD ER PACKER 1/4/2013 1.750 302,988 ertorations' &Slots h:f Shot at IT Top (TVD) Btm (TVD) Dens Top MKS) BIm(ttKB) (ftKB) (ftKB) Zone Date (eb••• Type Comment GAS LIFT, -. -_. 9,290.0 9,300.0 5,624.1 5,629.1 T - 3, 2P 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60 deg ph 4.968 I . IR Stimulations & Treatments Iti Bottom Min Top Max Btm Top Depth Depth n. Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment GAS LIFT. air 9,290.0 9,300.0 5,624.1 5,629.1 FRAC 4/20/2002 308M# BEHIND PIPE, 10 PPA ON PERFS 6' Notes: General & Safet " ,, " ". End Date Annotation 1 EL 12/30/2003 NOTE: WAIVERED WELL: CHARGING OA 6/14/2004 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR GAS /II V. 9/19/2008 NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM 7.785 ::. 11/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 12/72012 NOTE: FOUND LEAK IN MANDREL # 5 @ 8705' PACKER, 8,685 _ _ _ • • PATCH, 8,688 F . GAS LIFT. I 8.705 I= _ 14f PACKER. 8715 SLEEVE -C. .' 8,755 OVERSIZED TBG, 8,758 NIPPLE. 6771 .`I° LOCATOR, 8,809 tit �._6 SEAL e.e,o ;- ii.x� (ir1 ,.d�,s � Mandrel Details Top Depth Ton Port n P (TVD) Inc! OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Typo (In) (psi) Run Date Com... 1 2,613.8 2,190.9 58.61 CAMCO KBG -2 -9 1 GAS LIFT GLV INT 0.156 1,666.0 1/31/2013 2 4,908.3 3,387.7 61.44 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 4/10/2002 IPERF, 3 6,547.7 4,218.6 59.83 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 4/10/2002 FRAC, 9,2 e•29DS.3DD90 N 1 4 7,784.6 4,862.2 58.67 CAMCO KBG -2 -9 1 GAS LIFT OV INT 0.313 0.0 1/31/2013 5 8,704.5 5,325.3 59.89 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 1/19/2013 EM Pkg PRODUCTION 5.5503.5" ®880T, 269,656 . , TD, 9,685 STATE OF ALASKA AIL OIL AND GAS CONSERVATION GOA/SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell Fi Rug Perforations r Perforate r Other r Set tubing patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' Exploratory r '` 202 - 053 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 4 50- 103 - 20417 -00 --rOd 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0389058 I ADL0373112 % 2P -431 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Y Kuparuk River Field / Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 9685 feet Plugs (measured) None true vertical 5823 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8685, 8688, 8715, 8810 true vertical 0 feet (true vertical) 5315, 5317, 5331, 5378 Casing Length Size MD TVD Burst Collapse CONDUCTOR 90 16 120 120 SURFACE 2958 7.625 2988 2381 PRODUCTION 9630 5.5 x 3.5 9656 5809 RECEIVED SCANNED MAR 052013 FEB 06ZO Perforation depth: Measured depth: 9290 - 9300 AOGCC True Vertical Depth: 5624 -5629 Tubing (size, grade, MD, and TVD) 3.5, L -80, 8809 MD, 5378 TVD Packers & SSSV (type, MD, and TVD) PACKER - UPPER WEATHERFORD ER PACKER @ 8685 MD and 5315 TVD PATCH - PATCH SPACER PIPE, SNAP LATCH ASSEMBLY @ 8688 MD and 5317 TVD PACKER - LOWER WEATHERFORD ER PACKER @ 8715 MD and 5331 TVD SEAL - BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CSG CSR @ 8810 MD and 5378 TVD 12. Stimulation or cement squeeze summary: n/a Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: * Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Kelly Lyons / Brent R s Email n1617 caconocophillips.com Printed Name ,ei 7 Lyons ,/� Title Problem Wells Supervisor Signature �. `-,1 - Phone: 659 -7224 Date 2 -6 -13 Form 10 -404 Revis 10/ e vi-r Submit � '�y Su Original Only 7-1/5 4 ' /7'/ RECEIVED ConocoPhillips FEB 0 8 2011 Alaska /� t � P.O. BOX 100360 AOG CC ANCHORAGE, ALASKA 99510 -0360 February 6, 2013 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2P -431 (PTD 202 -053) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659 -7224 if you have any questions. Sincerely,- Kelly Lyons ConocoPhillips Problem Wells Supervisor Enclosures * • • 2P-431 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/07/12 PERFORMED LDL WITH TECWEL ULTRASONIC LEAK DETECTING TOOL. FOUND LEAK IN MANDREL #5 @ 8705'. LEAK IN MANDREL WOULD CLOSE OFF WHENEVER CENTRALIZERS WOULD PASS THROUGH WHILE PUMPING DOWN TUBING. ABLE TO GET A FULL PASS THROUGH MANDREL WHILE IT WAS LEAKING WHEN PUMPING DOWN IA AND TAKING RETURNS TO TUBING. PUMPED 5 BBLS OF DIESEL TO FREEZE PROTECT FLOWLINE 01/04/13 SET WEATHERFORD LOWER ER PACKER AT 8717' USING A BAKER 10 SETTING TOOL. CCL TO MID - ELEMENT LENGTH: 10', CCL STOP DEPTH: 8707'. GOT HUNG UP IN GLM AT 2614' AND 7785', WAS ABLE TO WORK TOOLSTRING DOWN. 01/12/13 LOADED TBG & IA W/ 200 BBLS DIESEL. CMIT TO 2500 PSI PASSED ON 2ND TEST. IN PROGRESS BEGIN CMIT. INITIAL T /1 /0= 950/975/825. TEST: 2525/2540/927. 15 MIN: 2450/2500/878. 30 MIN: 2450/2475/864. 45 MIN: 2430/2460/864. TEST # 1 FAILED. BEGIN TEST # 2. INITIAL T /I /O= 2430/2460/864. TEST: 2525/2575/852. 15 MIN: 2525/2560/852. 30 MIN: 2525/2550/847. 45 MIN: 2525/2550/841. CMIT PASSED. 01/19/13 SET DV @ 8704' RKB. PULLED 3 1/2 ER TEST TOOL @ 8717' RKB. SET 2.74" UPPER - WEATHERFORD ER PACKER PATCH ASSEMBLY (a, 8685' RKB. ( MIT IA TO 2500 PSI PASS) . IN PROGRESS MITIA passed. Initial T /I /0= 0/0/720. Start MITIA T/I/O= 0/2550/880, 15 min T/I/O= 0/2500/880, 30 min T/I/O= 0/2500/880. Summary !Retrievable tubing patch installed. Patch integrity demonstrated with passing MITIA • • RECEIVED SEP 2 4 2012 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 21, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 N ASR 2 6 2013 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. requests the cancellation of Sundry 10- 403 3.12 -247 for an OA cement shoe on well 2P -431, PTD 202 -053 surface casing cement shoe this work will not be completed. The attached 10 -404 is provided to close the Sundry. Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips ri80MS SEP 2 5 2012 ,(41,4_ Well Integrity Projects Supervisor Enclosures • • SIME [ilF ALASEA SEAN PARNELL, GOVERNOR �T CONSERVATION ALASKA OIL AND GAS 333 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSIO1� ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland WI Project Supervisor © s ConocoPhillips Alaska, Inc. � ` C ) . �� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P -431 Sundry Number: 312 -247 A(ilittp JLJ 8 2010 Dear Ms. Loveland: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 Foerster Chair DATED this b day of July, 2012. Encl. . • • • • ConocoPhillips Alaska P.O. BOX 100360 RECEI VEO ANCHORAGE, ALASKA 99510 -0360 (r , JUL 0 6 2012 July 4, 2012 AOGCC Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2P -431, PTD 202 -053 surface casing cement shoe. ✓ Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, 1 MJ L veland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA qik- - \/// APPLICATION OIL AND GAS CONSERVATION COMMSION t A FOR SUNDRY APPROVALS 4e 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well 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 Alter casing r Other: Pump OA cmt shoe • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r , Exploratory r 202 -053 ' 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20417 -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 r No r 2P-431 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 389058 ALK 4998 Kuparuk River Field / Meltwater Oil Pool • RECEIVED 11. PRESENT WELL CONDITION SUMMARY II Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (mea§ )O G 2 U 12 9685 • 5823 ' 9530' 5746' Casing Length Size MD TVD B40G CONDUCTOR 90 16 115' 115' SURFACE 2988 7.625 2988' 2380' PRODUCTION 8828 5.5" 8828' 5387' Production liner 827 3.5" 9655' 5808' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9290 -9300 5624 -5629 3.5 L -80 8809 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SEAL - BAKER SEAL ASSY STABBED INTO 3.5" PRODUCTION CE MD= 8810 TVD= 5378 SSSV= none No SSSV 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/20/2012 Oil w • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correc t'o the best of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name MJ Loveland Title: WI Proj Supervisor Signature f.���� /Cj C� .---------- Phone: Date l/y r` Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness - /4' „7S Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r 3/42' / Other: Subsequent Form Required: / d AP PROVED BY / Approved by: 6V;141issP4--: COMMISSIONER THE COMMISSION Date: 7 - /6 - (2— h/ Form 10 d.�kD'1 20 . i �y' 1 G 1 N A 7_ L Submit D up lic ate � � • ConocoPhillips Alaska, Inc. Kuparuk Well 2P-431 (PTD 202 -053) SUNDRY NOTICE 10 -403 REQUEST 4/2/12 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Meltwater well 2P -431 (202 -053). A surface casing cement shoe was not pumped at the time of original completion in 2002. The cement shoe is required to isolate the surface casing by production casing annulus, the outer annulus (OA), from downhole formations above the producing zone. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for at minimum —1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi. 5. Submit 10 -404 to AOGCC. I ' NSK Problem Well Supervisor 7/4/2012 KRU 2P-431 (PTD# 202-053) R~ of TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, September 20, 2009 1:32 PM ~e~~c~ ~i ~5~~~ ~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwa , Guy L(DOA) Cc: CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; NSK Well Integrity Proj; NSK Problem Well Supv; Lyons, Kelly A Subject: KRU 2P-431 (PTD# 202-053) Report of TxIA Communication Attachments: 2P-431 Wellbore Schematic.pdf; 2P-431 TIO Plot.pdf -~ Jim/Tom/Guy, Kuparuk (Meltwater) gaslifted produce based upon a failed TIFL on 09/19/09. will troubleshoot and repair if possible. 10/17/09. ~ r 2P-431 (PTD# 202-053) is suspected of having TxIA communication A leakin gaslift valve is the likely source of communication so siickline The well will be added to the SCP report and will be fixed or shut in by Attached is a wellbore schematic and 90 day TIO plot. «2P-431 Wellbore Schematic.pdf» «2P-431 TIO Plot.pdf» ~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supenrisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~~619~~~' i``~ t° `~ ~ 2~~~ ~ 11 /5/2009 Well Name 2P-431 Notes: Annual Waiver Renewal i End Date 10/1/2009 Days 120 Start Date 6/3/2009 1800 1600 1400 1200 1000 .N Q 800 600 400 200 0 Jun-09 aoo ~DGI 70° ~MGI ~ soo ~PW~ a sool~SW~ o aoo~~BLPD~ ~ 300 200 100 0 Jun-09 Annular Communication Surveillance Jul-09 Aug-09 Date Sep-09 P~ ~~Z- G ~ ~ ~o 60 50 . ~ 40 LL ~ d 'a 30 20 10 0 • Jul-09 Aug-09 Sep-09 . , KUP ~ 2P-431 Conc~tcil~illips ~ . ~~ ~~~~,~ 4 ~~ ~..,~. ~ ., , ~~~~ : ~ ~~ ~m : ~ ~ r~ ~ RI~5 5Ft~ IRC. Wellbore APIIUWI Well Status Inel (°) MD (ftK8) Field Name Act Btm (ftKB~ , , 501032041700 MELTWATER PRODUCING 62.23 5,091.99 9,685.0 Comment HYS (ppm) Date Annotation End Date KB-Grd (ft~ Rig Release Data a i~' ~. :af-:. M SSSV: NIPPLE 20 1/13/2009 Last WO: 30.00 4/10/2002 _~ gy~, q~~ -.. ~ AnnoWtion Depth (ftKB) Entl Date Annofation Last Motl By End Date Last Tag: RKB 9,298.0 5/3/2009 Rev Reason: TAG, GW GO tri plwj 5/4/2009 ~ i ~s ~~ ~ 111 ~~tl ~ `~ '~:'=~ ~„r~;~: _ :i o- ~ ,. :.. .~ ~ _ ,- ~F. ~~ ~ c ~,;~~, , ~~.' ~ ~ ~, _ ; ~ s ~ ~r~ ~* - , -~~ , .~_ , .;, .'a SUin91D String OD Set Depth Set Depth (ND) String Wt SMng Casing Description (~n) Qn) 7ap (ftl(B) (fIKB) (kKB) (Ibs/k) Grade g~~ing Top Thrtl CONDUCTOR 1fi 75.062 30.0 120.0 120.0 62.30 H-40 SURFACE 75/8 6.987 29.0 2,988.0 2,380.8 29.70 L-80 BTC-MOD PRODUCTION 51/2 4.950 25.6 8,828.0 5,388.1 'I5.50 L-80 BTC-M&8rd - LINER 31/2 2.992 8,828.0 9,655.0 5,808.6 ~ 9.30 L-80 EUE8rdMod - ~U~It ~~~F~'1 € r~~~~.: i' _ e vrw "`~~ ~ d String O~ String ID Set Depth Set Depth (ND) String Wt String " ~ ' ~~ ~ Tubin908seription (~~) (~n) Top~RKB) (ftKB) (ftK6) (ibsttt) Grode StringTopThrd J ~~ ~ TUBWG 31/2 2.992 25.6 6,803.0 5,378.0 9.30 L-80 EUEBrdMod coNOUCroa, _ TUBING 4.53 2.992 8,758.0 8,770.0 5,3582 120 ,~t}Ifl3`,1T1`~ d8~, f~~$ Bf ._~ r '~'4~7~ ~8 ~~1/.~~$" ~"-~m,: ' ~;r:~*~ = , t°r~2. , '~ ~ - Top Depth ' ~ ~T (T~~) ToP Incl Top (ftKB) (HKB) (°) Description Comment Run Date ID (in) NIPPlE,509 509 508.9 3.71 NIPPLE CAMCO'DS'NIPPLE 4/10/2002 2.875 2,614 2,191.0 58.61 GAS LIFT CAMCO/KBG-2-9/t/DMY/INT/// Comment: STA 1 4/10/2002 2.900 4,908 3,387.6 61.44 GASLIFT CAMCO/KBG2-9/1/DMY/INT///Comment: STA2 4/10Y1002 2.900 -- 6,547 4,2182 59.62 GAS LIFT CAMCO/KBG-2-9/1/DMY/INT/// Comment: STA 3 ~ 4/10/2002 2.900 ~ ~ ~84 861 8 4 58 66 GAS LIFT CAMCO/KBG2-9/1/DMY/INT/N Comment STA 4 4/10/2002 2.900 GHS LIFT, ~ . , . z,si° = 8.704 5,325.0 59.89 GAS LIFT CAMCO/KBG2-9/1/OV/BTM/.313// Comment: STA 5 5/4/2009 2.900 -= 8,754 5,350.2 59.71 SLEEVE-C BAKER CMU SLIDING SLEEVE WITH'DS' PROFILE - 4/10/2002 2.613 CLOSED suaFnce, 8 770 5 3582 59 65 NIPPLE CAMCO'D' NIPPLE 4/10/2002 2.750 2,988 " , , . - ~+ 8,808 5,378.4 60.20 LOCATOR BAKER GBH-22 LOCATOR 4110/2002 3.000 ~~ ~ 8,809 5,378.9 60.18 SEAL ASSY BAKER SEAL ASSEMBLY 4/10/2002 3.000 d ' " „q' I iMk~ :' ~ ~ $ ~ i iFi~~j ~ a ~ = ~ ~ : ~ ` ~ = r# 1 # ;~' ~ ~ ~~; s ~ ; ~ ~~, tir~ 8F ~Lr~ ~, Shot - Top (TVD) Btm (ND) Dens GASLIF7, 4 908 i'~ Top(ftl(B) Btm(ftKB) (ftKB) (RKB) Zone Data (eh~~~ Type Comment , - J~QyO 9,300 5,624.1 5,629.1 4/19/2002 6.0 IPERF 2.5" HSD HJ Chgs; 60 deg ph ,t~ ~FTlY~F~ ~QI1S-~t`i ~~Xi~~ Y,~a„ ~,i~~ - - ' '~ - "~'z.~~, Bottom ` Min Top Max Btm Top Depth Depth ' Depth Depth (ND) (ND) GAS LIFT (ttKB) (ftKB) (/tKB) (nK8) 7ype Date Comment , 6,5y~ 9290.0 9,30 0.0 5,624.1 5,629.1 FRAC 4l20/2002 308M# BEHIND PIPE, 10 PPA ON PERFS ~4~41$:, ~a~3Ci8 ~0. ~~~@ . ~'` ~` ,! °~r~^~'.~ `~ ` -~'^a~='_, _ ~:';;,a~ Entl D ate Annota tion 17J30/2003 NOTE: WAIVERED WELL: CHARGING OA GAS LIFT, 6/~'UZOO4 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR ~ ~~~~ - 9/19/2008 NOTE: GAUGED TUBING TO 2.83" TO 4000' WLM . GFSLIFT, - - 8,70q SLEEVE-C, 8,754 NIPPLE, 8,7)0 )r' PUP.8.7)1 „' .~ IOCATOR ,,,.vyi~ 8.808 y SEAL ASSV, 8,809 PRODUCTION, 8,828 IPERF, 9.290-9.300 FRAC, 9,290 LINER, 9.655 TD, 9,685 ~~ ~ 6 Y~ ~f"> p~; 4~;cu ;,s: e ~ ConocoPhillips Alaska e JUL !'- r" j 11 ;....~ o ru 2006 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,;"¡ ,~ p,m-:hijrage June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 c ,(.j. ;'¡I\ìt.:¡-, ~'\.,;!~~j~: '"-i_·,j~ c; "7 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, 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 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. Sincerely, ("t.-.s~'--¿ á~ C:>6/~ Ö /06 ~ Perry Klein ConocoPhillips Problem Well Supervisor Attachment .....3 go~'-O":) e e ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 5/19/2006 ) ~ ConocoPhiiii ps Alaska 'E:C; E U \\\1 ,'¿~ 't,,: 'ì m~& Gt'A~) G::liIiJ\1~. .~jl~hi\nì:»I~te P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 dD/)¡ -D53 June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AI< 99501 SCANNED JUN 2 'i 2006 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfill 404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05,2006. SchlumbergerWell Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. ¿ Attachment ) ConocoPhillips Alaska Inc. ) Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off X'.\2Þ~øfr:·.. " , 2P-415 ï>U2P~1?7',~, " 2P-419 ~;)¡~~Ð::: .:'~ 2P-422 t'.:'~~4·::·, .; 2P-427 " )~ê~ã':.:'~~'· 2P-431 ,.:;2P.~2:.';",,:. ~ 2P-434 .: ";:iì~8<:"'" 2P-441 ,':2~~;::,:~:'·'", 2P-447 ::2#448:. ;'~.: ' 2P-449 '-, ':,2P~1~" Initial top of cement ft 4' , ' 5.5 t~s'" 1 ',:' ;~(5:":, ' 13.5 :;4~5': " 10 , '; ','2:',,' 13 :,,8;5', 14 ',5" 15 ,'3~5:,," 2.5 ,:1,.,5 " 3 ,>to Kuparuk Field June 6,2006 Vol. of cement Final top of Cement top pumped cement off date bbls ft , ,.(t¡O·, . ",~4: ' 0.0 5.5 :. . ···,'O~,7 ',,". ... '. ·:..·.·2i5·""~· 0.0 1 .': ,:'-,·:'O~O,<:,"'" ':,"::3~:5-. ':',.f:·, . ',œ¡":, ".' 2.3 2.5 . ' .'.: .:"C:f:ö'· /~4~5'." .' 1.6 2.5 , .": . . :,-tlef'.' :,·'2:...... . 1.9 2.5 . '.' ,,:Ø~9 ,_ <~2¿5,~,: 2.0 2.5 .. , .. " . ·:oUf::::. ,.' ·.':'.;;,5::' 2.0 2.5 " .', ··.;:æo " .... ',,: ::3~5:, 0.0 2.5 ·:·O~O',' .;'::..1'~S . 0.0 3 ': . 2,;'1' , :2.5' .ltIa ..' na '5J1'120PQ:. . na 5/1/2006 'ri¡:f\':. ' 5/1/2006 , ::,.,,·;,Oa;'::c,:,> 5/1/2006 . ",·5/1/20Q6. , 5/1/2006 ;,.:'na, 5/1/2006 , .. ',.':na:: ..'." na '. fla ' na , '·'51.112006, : RG2041 voi j qal . :5~:7.·· .' ; 7.1 ",,:5~7' ., 6.7 ,:.;,",7::t:· .' 7.1 , ", 5~'7.,:. 7.1 .' -·,·,3(8: 7.1 ··-P.7:,,:. 5.7 '<:'5~t', " 7.1 ':.:'8.1',:' , " " 9.5 :.:',9.5: ..' . . , 5.7 .' .' ,7;t. Royfill4048 vol. qal _11.1: ' 30.9 ,...,·,','··'9'."..",::' o ',,17~3,,' 10.7 '".' "·l7.~6·'·: 13.7 ....,. .' .'5L7,·:, 10.1 1:3~;8' , 6.2 ; :.21,:;9.' 13.1 :t1.4·· o " ..., . 0 : 11.5 . '6~5· Corrosion inhibitor/ sealant date 5/19/2006 . .' ,;5I1,9~OO'(J': ..', 5/19/2006 . .' J$M;~6r:' ,( 5/18/2006 " '::.. "':5·,¡~"·6~~,'<> , f ,r'J~~~~\ :....... 5/18/2006 ,'.;'. ·,:5/4·81æQ6;~ . ~, 5/18/2006 . ,:'.'·õl18l2oœ'·;;: '::~ 5/18/2006 ; :,',:: ::5l:1.~·;\;:: 5/18/2006 ,:;:,' :::"::>5l18å~/:.~: 5/18/2006 , "··..::5IitaæOœ: ::,...: 5/18/2006 ,! ·,61t8l2øæ':·:,· : 5/31/2006 '''5fffY200S;:, ' e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _ Inserts\Microfilm _ Marker.doc let r'\ tt--. ~~ t\ t\ q ! -, DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020530 Well Name/No. KUPARUK RIV U MELT 2P-431 MD 9685 / ----- ----- lVD 5823,/ Completion Date 4/19/2002 .-- REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Fnnt ~-- ----- ~ciog ~og .~og 1..-1 i þ-og K'og Xog £¡LOg UÆ'D C ! ~- Electr Dataset Number ¡,:Name Gamma Ray . /Casillgc.oUar.lóPåt9[ . ~rforati()n . See Notes i.11699 Induction/Resistivity M. ~ Gaml11aRay fA ~ Gamma Ray 11/ ð Induction/Resistivity ìv Ò L-iS ~rifi(;d[lun Well Cores/Samples Infonnation: ....-tIS Verification Name Interval Start Stop Well Cored? ADDITIONAL INFORMATION Y/~ Chips Received? '-V I N - Analysis Received? - ----- -~ -~------- Comments: ~ Operator CONOCOPHILLlPS ALASKA INC Completion Status 1-01L Samples No Log Log Run Scale Media No 5 BS 1 5 BS 5 BS 2 Blu 25 Blu 25 Blu 25 Blu 25 Blu Sent Received Daily History Received? Formation Tops Current Status 1-01L 5f? t,.J.. d. 2 8 M.ï\A Á..L~ ^- API No. 50-103-20417-00-00 UIC N Directional Survey Yes '" (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received 9200 9430 Open 5/17/2002 9200 9430 Open 5/17/2002 9200 9430 Open 5/17/2002 0 9300 Case 12/10/2002 120 9685 Open 5/9/2003 120 9685 Open 5/9/2003 120 9685 Open 5/9/2003 120 9685 Open 5/9/2003 120 9685 Open 5/9/2003 120 9685 Open 5/9/2003 Sample Set Number Comments (Ý)N (j)N -' Comments Noise Log with Temp and Gradio -.~ DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020530 Well Name/No. KUPARUK RIV U MELT 2P-431 Operator CONOCOPHILLlPS ALASKA INC MD 9685 TVD 5823 Completion Date 4/19/2002 Completion Status 1-01L Current Status 1-01L ---- - - ---- ----- -- - ---"-" ---- }~ Date: Compliance Reviewed By: API No. 50-103-20417..00-00 UIC N IC(~~~~ -' ---- > l .Cé)nQCbPfifIlIPSAlIüÏJq¡'lhC~ dOd - C) s- ~ " ;~ 2P.;.uf' . ' ' T~~~~? :' '/~ API: 501032041700 Well Type: PROD (1XX1W, \" '~ SSSV Type: Nipple Orlg 4/10/2002 00,3.500, .' Completion: ID:2,992) Annular Fluid: Last W/O: Reference Log: Ref Log Date: Last Tag: 9283 TD: 9685 ftKB Last Tag Date: 7/29/2003, Max Hole Angle: 62 de.9 ~ 5092 CaSh1g$trlri,ï'¡;~ALLSTRINGS, ;'" ".-:.;, ',' :', ' ' " Description Size Top Bottom TVD CONDUCTOR 16.000 0 120 120 SURFACE 7.625 0 2988 2381 PRODUCTION 5,500 0 8828 5388 LINER 3,500 8828 9655 5809 Tüblng;Strlng:';;TUBING, ,I ".:,::\:;::-:-, ' '" " ' , " " :~zO~ ,', I T~P I B~:;3m I ~~ I ~~, IG~~e I ~0~;;~Od TÙbln:.~;tg. rl:;t5TP:~~cT1r~rr:~tr~rad.r ' . .. Thr~~d Peiforations'Summary , " ' ", , , ,,,' , " .. Interval TVD Zone Status Ft SPF Date Type Comment 9290 - 9300 5624 - 5629 10 6 4/19/2002 IPERF 2.5" HSD HJ Chgs; 60 deg TUBING (8758-8770, 00:4.530, 10:2.992) PUP (8771-8808, 00:4.560) SEAL (8809-8810, OD:4.500) FRAC (9290-9300) Perf (9290-9300) "~ ,~~:; \ ~, ..: i't;~'. ) KRU 2P-431 Angle @ TS: deg @ Angle @ TD: 60 deg @ 9685 Rev Reason: Tag fill, cut paraffin Last Update: 7/30/2003 ..,' Wt Grade Thread 62.30 H-40 29,70 L-80 BTC-MOD 15.50 L-80 BTC-M&8rd 9.30 L-80 EUE8rdMoc ", ,- ':~~>~ ," I :~,.: <... Type Comment BEHIND PIPE, 10 PPA ON PERFS Interval Date 9290 - 9300 4/20/2002 Gas'Llft' MandrelsNalves St MD TVD Man Man Mfr Type 1 2614 2191 CAMCO KBG-2-9 2 4908 3388 CAMCO KBG-2-9 3 6547 4218 CAMCO KBG-2-9 4 7784 4862 CAMCO KBG-2-9 5 8704 5325 CAMCO KBG-2-9 Othéil Jlugs/equip:"etc;' ,'::\JEWELRY Depth TVD Type 509 509 NIP CAMCO 'OS' NIPPLE 8754 5350 SLEEVE-C BAKER CMU SLIDING SLEEVE WITH 'OS' PROFILE - CLOSED 8770 5358 NIP CAMCO '0' NIPPLE 8771 5359 PUP 8808 5378 LOCATOR BAKER GBH-22 LOCATOR 8809 5378 SEAL BAKER SEAL ASSEMBLY .. , V Mfr V Type V OD Latch Port TRO Date Run 4/10/2002 4/10/2002 4/10/2002 4/10/2002 1/24/2003 , 1, ',:' '.," Vlv Cmnt DMY 1,0 INT 0.000 0 DMY 1.0 INT 0.000 0 DMY 1.0 INT 0.000 0 DMY 1.0 INT 0.000 0 OV 1.0 BTM 0.313 0 '. '. ' " Description ID 2.875 2.813 2.750 2,992 3.000 3,000 -'( .~- ~'::~,~->:.' .-..~>- :, - :.~.-.: - . - .; . : -'-..~': <: i-7 -' .~.:\::~, ..}~~~,: ~-~!~~~~~~:}..~::.,,:,-~~.~"~: - . .;. ~.~. .~.:~. .'-- . ,'CoriQc~Philli~.s:~,las~a . . Casing. Report~., ' .' I - . .. : - - .~. L ,. Legal Well Name: 2P-431 Common Well Name: 2P-431 Event Name: ROT - DRILLING String Type: Surface Casing Hole TVD: 2,389.0 (ft) Ground Level: (ft) Circ Hours: 2.00 (hr) Manufacturer: FMC Hanger Model: Gen V A75 Actual TMD Set: 2,990.06 (ft) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Report #: Start: 1 3/27/2002 General Information Rotary Kelly Bushing 254.00 (ft) (ft) (bbl) 29.70 L-80 6.875 BTC-MOD 1 29.70 L-80 6.750 BTC-MOD 22 6.750 BTC-MOD 1 29.70 L-80 6.750 BTC-MOD 44 6.750 BTC-MOD 1 29.70 L-80 6.750 BTC-MOD 2 BTC-MOD 1 Model: Gen V Packott Model: A-75 Hole Size: Water TMD: Liner Overlap: KB to Cutoff: Casing Flangel\yellheåd. , - - °,-__.. : -- . - I .., ,. . IntegrarCask1g'Cetail' . Item, Size 'Weight" : Gràde - ': Drift. -Threads. JTS . Length (in.) (Ibltt).. .' (in) (ft) . Hanger & 7 5/8" pup Casing Tam Diverter Tool Casing Float Collar 7.625 7.625 7.625 7.625 7.625 7.625 7.625 Casing Float Shoe Ldg Depth - ,,- :':~A'Cþåssóry.' . Bowsprlng Centralizer Bowspring Centralizer 2.20 958.54 2.44 1,908.74 1.34 85.22 1.50 (in) (ft) (ft) 30.08 (ft) .."':~;~S~;~~?;~~~~j1~~;f¡A~!~!~ ~ ii Spud Date: 3/29/2002 Report Date: 3/31/2002 End: - ~_._...:-....;- ::..¡-~_.- -- , -, ~ ~.~- ,. J:i=l"/' -~c_-!'~;§.¡fEr~l Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 3,005.0 (ft) (Ibs) 60.00 (°) 4.00 (days) --' "" . -.'.-'-:.-n~~~~}~~]Š1~~tj~l- c_.: Top Hub/Aange: (in) / (psi) BTM Hub/Range: (in) / (psi) . .001.:"it~~~1.ijj . Moder. ..: -:c~~. M~ØQ' :'fvrtfjlb~{~~è', '. . .. . ". ,~..-(ìñ);. '. '- -fm) ~,:~~::'~ '~2:":':';~¿j::.c. 8.500 6.875 FMC 8.500 6.875 75/8" 29.7# L-8 8.500 6.875 8.500 6.875 7 5/8" 29.7# L-8 8.500 6.875 Weaterford 8.500 6.875 7518" 29.7# L-8 ~ 8.500 Weaterford Top'. MU Torq. THD Manufacturer' (ft) . (ft-Ibf) . 30.08 32.28 990.82 993.26 2,902.00 2,903.34 2,988.56 2,990.06 . " .. Manufacturer . . Nori';lntegral.' Casing Âcce!)sories . " Number Spa9ing ~. (ft) WEATHERFORD WEATHERFORD 1 11 , - - . _. ., - .. . : ~-' >~~::':Hi1tãr;al:'~;, ~.c~; ~. . Top (fír .. .' BOftOñ'1 (ft}.. \;'. 2,978.0 2,384.0 2,978.0 10' above 2,860.0 Roating Printed: 91212003 3: 1 S:S3 PM ') ) Legal Well Name: 2P-431 Common Well Name: 2P-431 Event Name: ROT - DRILLING Report #: Start: Spud Date: 3/29/2002 1 Report Date: 3/31/2002 3/27/2002 End: t~~;;".'~¡'i ìîi:;~~tit~~j:k\ii!:l:i~\1i¡¡~I~r;1i~¡¡t(i:j,r;~;~;il~~r~');i:"~21iJil~~~~~j4i~ì;¡i-¡':-\'}!¡I~i¡;#t¡j¡Ä¡~~t~;';:~~;y~~~\r~?:!~;.;:.Ast,t~~ '~'¡'>ji'''fW~ '1"'~'I,,,,,,),,~j.'";''i¡';;,"''!.<''' ''', i;'1 r" ..'t." ",,-i'l'." "1"ll' ",~ '¡~I ¡ Id,!"", ..'q" "Ii .1.1,..L2>¡,r.lj'" "/"".:1"",.,)", ¡,II'f""il' ,1",,,, (~\:;!,,,,I '1"."",,,¡,l'iiill't&~1'¡'''''''' "',..þ ;,' . ¡""IK" '''''i "'i>': '" ,,' '" '''' ' I"""" ,', I""^ "¡::it.",.,. . ,< "I" ': j:ei I (" I" ¡!,. (¥;l:~If:b:!t1~0(!r1::~l1rlmarÿ\r':";'!-':.': ;;': :::~; 1;';:/1 '~. ;:,:: ':::{~:: ,:i::Sq'uø~ze:Oþe ï'"H,olë.(;':~Hf.i';::~'t~:i fi:!:':>':'(-~';::'i}11!::'SqÜeeze:1()âsllit:r': ;,:" :(;::>~,::, :~If." ',?:,::< r,';):; "I ,'::':;:J';H,::pr,:,u~f '::::i.::~<": ::;,;:{ 1':',,+\,/ Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 9.875 (in) 2,990 (ft) 3/31/2002 Surface Casing 7.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Hole Size: SO TMD: SO Date: SO Type: (ft) Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cementer: Steve . Pi~j~~k~~~hr , .' . Cmtd. Csg: Rot Time Start:: Time End:: RPM: Init Torque: (ft-Ibf) Rec Time Start:11:30 Time End: 17:15 SPM: 84 Stroke Length: 15.0 (ft) stä~~ ,~?é¡:~6. , , Type: Cement Casing Volume Excess %: 278.00 Meas. From: 143 Time Circ Prior To Cementing: 3.25 Mud Circ Rate: 231 (gpm) Mud Clrc Press: 450 (psi) Start Mix Cmt: 16:17 Start Slurry Displ: 16:17 Start Displ: 17:27 End Pumping: 18:00 End Pump Date: 3/31/2002 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 9.6 (ppg) Vise: 52 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: LEAD Slurry Interval: 2,310.00 (ftJI"o: (ft) Water Source: lake fresh Test Data Thickening Time: 60.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: ASLite Cmt Vol: 277.0 (bbl) Slurry Vol:365 (sk) Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating (ft) (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 75,000 (Ibs) Drag Down: 67,000 (Ibs) Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: , ' 5.00 (bbl/min) 5.50 (bbl/min) Y 750 (psi) 1,500 (psi) 15 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 143.00 (bbl) Ann Flow After: N Mixing Method: displaceme Density Meas By: meter/seal Class: G Density: 10.50 (ppg) Yield: 4.28 (ft3/sk) Water Vol: 168.0 (bbl) Other Vol: () Temperature:76 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: ;~,~~:~1~'?' . PV/yP: 17 (cp)/14 (lb/100ft2) Gels 10 see: 4 (lb/100ft2) Gels 10 min: 6 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 133.20 (bbl) . ":~~~;~~:}~~í~.f~:~~;{.~!#.;::: (OF) Purpose: FILLER CEM Mix Water: 19.40 (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/212003 3:15:42 PM ) ) Legal Well Name: 2P-431 Common Well Name: 2P-431 Event Name: ROT - DRILLING Report #: Start: 1 3/27/2002 Spud Date: 3/29/2002 Report Date: 3/31/2002 End: '.1.\ !'Ìj,;gr :'¡~"..I:; (" ',h:"f .I.': 'I' }'¡~~ ' L" J:J,',lct,... , j¡~,. J:~,ft~, !",~~t ;¡r~~ø. ''''';;:'.1,:I>,(.J:I:':' '"';"'! i:fd~{:\:~(;""I":I"'!'f;'). .::I, "')'":1:1,,:," )',1, ,tOll'"::'"''';'''"!' ':",'." ;T;~I.. . . '::;:~(V"';"'~ I,\¡},:j:~ .~ ,. '.. .~~~(~:.t.~" "'. r_f;¡:.qJ¡:;.~f~ :~r:;-:-- - '." '1:, ';':i' \ ¡:'f~1t r.rfi.m,;,'~- ':", ';p1.~:;H)., );'¡i:t::;;!' ;, ....~~..ftr:~: If:. ~1'if.~k~}\~!;r,':::r~',;~! ~:iW" "'/. ;.I.t.f'~l/'~" ¡,;:jJ/~;!:;-:':ii;' }1:J!t~l~~;:~~~;:, 'J ,,,,,Il"¡' tl;i~'¡]'þ('~'~*,'ifiiclfh ""'J"",;,,,,;,,"i;;g "':'~~!/'rt'~ ';::;1.1 ""If" ¡""f:\ !': ',.,1' ;',::, ".",.¡t>kl"~ '\:<.,1'1' ';f:.'> ,~..",j"[f":' t !""~r... "~:"!I:'!'¡;¿Y~!"':'~'\I'J}~'i:IJ~¡I~r 'r'-i"'1'!J:,'g~'i ,;¡"f E.: ,:' í""'}¡t'I~'4',,,,,;,, \1" ¡.it,.",: ,,\' ,':h'¡t',¡.:¡ t'! rit .;;, ,¡":,:, . ,:g~~![t~~:,!~¡:~jt::!~~~~~:¡i[rädã.í r;,~m'ëJf!1:,::i !~':i'f:-'~ ::: ~"~);l'~:" <'~~'\'~::';'l 0:di ' Ø)~:~:;:,il~i, " ; 0 '~eh1f~tt.dri~t~;~., "}i~};,¡il~'J.:' ::~¡:<'f.;:I~' [:1':' ')!:! i:;,:~'QO êf:i0ônë:~:- ,,' ;:):(~~~(, :",.:10n ts;;,~::'~'-:..\::i:k' 1.5C %BWOC 0.6C 0.5C 43.1C 30.00 1.5C .:. .'",~!¡¡~~~~;à¡~I~'~C~~f:~::~f'~Z:i :J':\/: , S001 D046 D065 D124(.66) D053 D079 Slurry Data Fluid Type: TAIL Slurry Interval: 3,005.00 (ft¡fo: Water Source: FW Lake Description: LiteCRETE 2,310.00 (ft) Cmt Vol: 94.0 (bbl) Slurry Vol:229 (sk) Class: G Density: 12.00 (ppg) Yield: 2.40 (ft3/sk) Water Vol: 47.0 (bbl) Other Vol: 0 Purpose: SHOE INTEG Mix Water: 82.48 (gal) Foam Job: N Test Data Thickening Time: 3.19 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature:76 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) . :"." 'I, ' ..~ta:!;y:o: .'~.....~ì~~Z~:~~t~~;F.~~.~:~:!S:. . DEFOAMER 0.6C %BWOC DISPERSANT 1.0C %BWOC EXTENDER 0.50 %BWOC , " 1 .. ", ':, I.,... ,;'/LiquidC¿rît;?:.S ','" '>Unif~( ," , D-46 D-65 0-79 S.}1}t:,?!:;~~ì¡¡~;T';~~ . Test Press: (psi) For: (min) Cement Found between Shoe and Collar: ';::"::;./.W~¡T';~~:::':";' Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: ,:.'jl;1,t'A.~Î~~~'Î~~:!:~~fi;nJ¡ii;;.-- 1,."'/ , ' , . "'. . ~ Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: ":(¡~fØt~~¡;~t,¡~~t~~~+å&(';\';:i:'::;.. Tool: Tool: " , \1,'.' . ,', ." , "~'~~$ij'rVey.Eyål'u~ti,øn" ,.::'~:..::..~>{ " .' "I,: ':", :..~ ~:\'.:-:,~:'''' ': .r,., CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) Printed: 9/2/2003 3:15:42 PM ) ') Legal Well Name: 2P-431 Common Well Name: 2P-431 Event Name: ROT - DRILLING Report #: Start: 1 3/27/2002 Spud Date: 3/29/2002 Report Date: 3/31/2002 End: . ~;.",;". '\::tW~' I:,:j.f".'.{ ('~" ,:.t.!.:' .<.. '..'''''''''1 ~ -:W''':''~ tl"-:' .:.' ).,.,i T I "1 'Id ltcI"' ,.\.., .":'1.' ¡", {{:, I "'f :" ,..; ú:, 1 ". i. ¡ :' :'~',I f, :,." 'It4J¡'.'PV'111l¡": I "il' ,{. '~i :!j :.,.r,,1 e~X¡~N,H"::il'l.¡-t::tl"lr"'~1 ,'... "';1iih~:" il,~~lt ;::1'11'1:' ['j:':: I".' ,(~, I'd¡i.,~.:-¡'ll n., 1.1.1' 1'111 ,T::':~, ,.¡: "nj¡1m::'.'t~':~:14' i" 1):" ." : '...; ¡." ..," . :~i'" ~ ,"'." , ':.. 't;~:;:f}\:;J;:i~;.!;~~.>.tMl-~¡:¡~:f}~ !¡~\:).i,'¡:£ mt~:~~:~l;.J',:~;::;\J:~nl~:,¡twtHí:I:: ;;;;:;,í:> Ii;';!,I~'Rê ".~:::rÎtít~':. .:'.::::'¡t':>',::::i:;, ~k 1'1 .' . ,,, .~~:;~:ffWf~t:¡::~%.\~~:~;l~:ær~.f.~!:f:iÆ~:.:¥¡J.Ì:it-!i~Þ0~~t:J~:t!t~n:NI~TW:r~?:f.U:i ::l~:;h{~,!;¡t¡A~m~~~~~1m1~f.' ..,...; .J;O)~~t;:~¡ Dowell cmted 7.625" csg as follows: Pumped 40 bbl CW 100 chem wash [pt lines to 3500 psi] @ 400 psi 15.6 bpm. Drop botttom plug. Then 40 bb110.5 Mudpush XL [wI red dye] weighted spacer @ 400 psi 14.4 bpm. Pump 365 sx [277bbl] of lead ARTICSET liTE CMT B-809 [ 10.7 ppg, wtr = 19.4 gal/sx, 4.28 cft I sx, ASL Blend; adds. = S001 = 1.5, 0046 = .60, 0065 = .5, 0124 = 43.1, 0079 = 1.5, 0053 = 30.0 - all % BWOC. Press I rates max - min - avg = 530 - 330 - 400 psi, 5.8 - 5.0 - 5.5 bpm. FOLLOW WI 220 sx [94 bbl] tali LiteCRETE cmt [ 12 ppg, wtr = 8.122 gall sx, yield = 2.4 cft I sx.-- Dry adds: D065 = 1.0% , D046 = .60%, 0079 = .5%: all BWOC. Press I Rates max - min - avg = 625 - 450 - 500 psi 15.5 - 2 - 5.5 bpm. Drop top plug & displace wI 133.2 calculated bbl 9.6 ppg mud. Press I rates max - min - avg = 750 - 625 - 700 psi 15.8 - 2.4 - 5.5 bpm. Plug hit 10 strokes early @ 1737 stks, bumped from 750 to 1500 psi holding for 15 min, bled off, plugs held good. Full returnes throughout. 143 bbl [179sx] 10.7 ppg cmt to surface. CIP @ 1800 hrs. Printed: 9/212003 3:15:42 PM ) ) 2P.431 JOB HUMBER I EVE~Dc;~~'1;; H::~;!"'T:~OO5.0 1';,389.0 DF:.~O "~~.;:~~. :~002 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANG NORDIC 3 n1433@ppco,com 3 Meltwater 9,967.0 0 0 ACCIDENTS LAsr 24 HRS. ? DAILY 'NT WIO MUD CUM INT ANG WI MUD 0 0 DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD 194,722 663,357 24 HR FORECAST Comp.nu-test bope/pu bhalrihltest csgldrlg out!run fit! LrrHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF Surface LAST SURVEY: DATE TMD 'NC AZIM I LAST CASING I NEXT CASING 3/30/2002 2,952.06 59.680 182.430 (in) @ (ft) (in) @ l~r~~W~W~!;j¡~:~~~,.~$~~. 1:~CtrJ¡6(!~~~~,,~:~.~=~1f.:~~:jf~;t:.'I""''!i!iiM~;) ,'\H\¡;ìlr¡j~~¡PJ;j~'~!:¡¡~i>:"'(¡~~' !;~S) 52 17/14 4/6 4.4/ / / /18.5 8.5/ / 1::~:f~E~Ó~'4~~')';:):~;:~;~:i~~t:.:<:':~~,~f.~~~~,~:~?,~:!~~~~~~,;;i':';¡~{;~~;~~~~;~~~;,'g,'J~~~~J~~ØU:.F.i 1,171.90 : I:D;:~:.' : ;Ç~NN sjiè \; -'cÓ~N'TY¡:iE'. SUPERVISOR Ralph Bowie CURRENT STATUS NUBOPE -N()jTs- 1 1 1 1 1 1 1 1 1 1 18 1 14 . :';,' ìTË~' DE.séi1ipTlON. Bit Mud Motor Stabilizer - Non Mag Crossover - NonMag MWD Crossover - Non Mag Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt ': ::L~NGiH 1.00 23.27 4.87 1.49 36.56 2.38 29.04 29.44 30.15 2.52 552.46 32.04 426.68 AFE -,; ~ -Qj)~..;.'::~-: 9.875 6.750 9.875 6.250 6.750 6.625 5.000 5.000 5.000 6.750 4.000 6.250 3.500 AUTH. AK0236 2,915,214 LAST BOP PRES TEST (ft) 2.810 2.810 2.250 2.875 2.810 2.810 2.810 2.250 2.250 2.250 2.250 1 / 1 9.875 SECURITY XL 1CN 750705 22/22/22/12// 115.0 3/28/20025-5-WT-A-E-2-NO-TD .:;;;:'~';~~~'.'[I"" ',,';~Ó~."".."I'.~~~ "".' ',,'i'~~,r,..'.p~~s~~~pÖ~~~~T~~s~~i.~~~i~,~,l,;,~~:;~~;:1~~~:~fJ.j.Þ~~~~~~'~~~~~f; ~~~~i '.,~':~{i~~UßS ',.cô¡j~..',.' ,'~OIiBLE "$IiÌl;.O~;.:t~d~~:SlJM~~~;Y;~;~;1W'~.¡:=~:~~m~~l\1';~~;!f\:):;'i11."!t:WìW 00:00 03:00 3.00 CASE P OTHR SURFAC Continue to Pooh to Iwd / mwd tools. 03:00 04:00 1.00 CASE P OTHR SURFAC Down load Iwd / mwd tools & Id bha not necessary for next hole section. 04:00 07:00 3.00 CASE P RURD SURFAC PJSM. Service rig & TDS. Ru csg crew. SURFAC 7.625" x 29.7 ppf x Bt&c mod x L-80 Csg ops: Pu / Mu shoe track [2 shoe jts] Weatherford super seal shoe & collar, Baker locking from float collar top connection down. Run a total of 68 jts O5g Installing Tam Diverter Collar @ 991', Land out @ 2990'. Used 12 bow type centralizers: one 10' up on jt # 1 & one floating on the next 11 jts, top centralizer @ 2384'. 07:00 12:00 5.00 CASE P RUNC Printed: 9/2/2003 3:16:02 PM ) ") 2P-431 . ";;"::',n~;:;~' ,.t. ¡"<-' I~'II' ,\.' I'i' :" :i I \1'¡,"'i:~mWFI"::lj:II.I~1 ,:: 'I~.¡,I '¡~~.!~'1ì;;":'::.r:11i¡'~: I (,. , " ;ri8Oi. £!~:A:~.. '~.~I. ~'}{~'ï{íit4rii.':À~tI.y. .,; I.; :':.' ¡'¡..."; "::')'Î,f..lÜI.1¡ '1: I'.." : 'Villi " ;,rlll, I~~. ~~J": ):1... ..p":,',:,,,",j., ~~;'{ :' '."; ','''' I ~ .11', ,:': " :'::: f~;~f~~";:':'.':;~;f;? ~¡iH~i~~O:i&~S'1'(0~r~~O:;!8~':Ê' .:;;:::: t:~~~!.~~r.~(j:~;~¡::S!;: ::~~)...:I~~~pS:~e..~~~..:~~~~.:~~t1J~'WI:.r¡r.1(~,[": .~:lr!t';~~~itjjßIf,¡~ ':Dj~ {~~~~~~ij:t1tl:;-(;r>i P::~~:j;~:¡;i~~'~::~:;,::!; :,./);¡(;:¡ ;Y~r'. ;'. :.'1\~ltQ.T.~~.~ ,rni~,~;):t:: ['.: "I' :V~Jt.~fJ.,.,. ( Ú~!f.i~".. .,~. .~!:'\; ,..~~~.~~,; /~: ~I U1g .:", ;;:~;~'~~¡"'""')~. ,!'¡':'~':'f¡~' ,~~ ,!.f):(!\:!:-:;'~¡:r~~:::'r",~~~ ~"~.l~I:r:~;\:';':':\~¡:'A ;,~~ ~:,:,!~~~~~:;¡f: .' .' I~~, ~fJlc~~i~:l}~¡:if"..:~ :" ::;'~ ~;':":, :':::!,~",t~~:r;~J;:~: :;'~"I.~-::;"r.::~:,'0~,!,r,~,;:<;"~ 07:00 12:00 5.00 CASE P RUNC SURFAC 12:00 15:00 3.00 CEMENT P CIRC SURFAC Clr Con 6 bpm I 350 psI. Reduce YP from 18 to 14, no change In mw of 9.6 ppg. Reciprocate esg 15' I 30 sec. Weights up I neu I dwn = 93k I a5k I 75k Ibs 15:00 15:30 0.50 CEMENT P 15:30 16:00 0.50 CEMENT P 16:00 18:00 2.00 CEMENT P SFTY SURFAC PJSM PUMP OTHR SURFAC Prime up emt trucks. 18:00 19:00 1.00 CASE P SURFAC Oowell emted 7.625" esg as follows: Pumped 40 bbl CW 100 chern wash [pt lines to 3500 psi] @ 400 psi I 5.6 bpm. Orop botttom plug. Then 40 bb110.5 Mudpush XL [wI red dye] weighted spacer @ 400 psi 14.4 bpm. Pump 365 sx [277bbl] of lead ARTICSET liTE CMT B-809 [ 10.7 ppg, wtr = 19.4 gallsx, 4.28 eft I sx, ASL Blend; adds. = S001 = 1.5, 0046 = .60, 0065 = .5, 0124 = 43.1, 0079 = 1.5, 0053 = 30.0 - all % BWOC. Press I rates max - min - avg = 530 - 330 - 400 psi, 5.8 - 5.0 - 5.5 bpm. FOLLOW WI 220 sx [94 bbl] tail LiteCRETE emt [ 12 ppg, wtr = 8.122 gal I SX, yield = 2.4 cft I sx.-- Dry adds: D065 = 1.0% , 0046 = .60%, D079 = .5%: all BWOC. Press I Rates max - min - avg = 625 - 450 - 500 psi I 5.5 - 2 - 5.5 bpm. Drop top plug & displace wI 133.2 calculated bb19.6 ppg mud. Press I rates max - min - avg = 750 - 625 - 700 psi 15.8 - 2.4 - 5.5 bpm. Plug hit 10 strokes early @ 1737 stks, bumped from 750 to 1500 psi holding for 15 min, bled off, plugs held good. Full returnes throughout. 143 bbl [179sx] 10.7 ppg emt to surface. CIP @ 1800 hrs. NUNO SURFAC Clean out diverter, rd emt equipment. 19:00 00:00 5.00 CASE P NUNO SURFAC Back out Idg jt, rd diverter line, nd riser & continue to nd diverter. 24 HR SUMMARY: Run & emt 7.625" csg/nd diverterl , " " ' , f'1;- ~: ~ ':.' ': ,1 ,; ~ COMf'AN,Y:' Nordic Catering ConocoPhillips Company ." "r' " ,", ':'.: .'~ERV CE'::;!i\ >:. ~ ."P,ERsoNNËL.DÄTÅ .":", . . NO.':< :::tiØUR~~: '/:/':::::;Jþ()MP~~Y" 2 . Baker Hughes Inteq 2 Baroid 1 apc . ..'~ ..';::::::.'.f:~:~~~ç;,~;~::\~}':: ::;",,;::..: :. ~~:';è:~:~>:::;: ,'0 ~j~t:~é:'\;. 6 3 1 '.UNltS-. gals BBI " '. '. M~TERIALS ICON~l!MP..TI()N"- " :I'US~G~<': :'oN HAND' ""':':o.;,:':::'::':jTEM"'" '-":,, '. 1,309 3,452 Camp Fuel 183 191 Camp Wtr , " ". " I .( " - . , '""" . ' . - ::.:' .Ü~~.!,.. ",:.~:t:.,..,;~.,~~t-§~~~::.: ::;,:",;.\:~ 'Ô~~A.N.p' bbls 2,275 bbls 11 36 " . . . ,1)1'E.' :" '. 2p. 415 NO. REMARKS 2P - 431 SUPPORt-:CRAFT . : .' ;::yyp'~ ". 2P-415 NOi:-' '1'.~~'I;M~Rk~ . .". Grizzly :. . ' " ~ES~.RVOnl NAME I 2p. 415 2P-415 .. .RESERVOIR:AN[fIN1iêFiVAL;DATA. . ".:ZONE . . : .TOP.,' . ,BASÈ"~:::- ': . 0 0 I ; "\~ ~~,J~¡~~~~;,);~i?:¡~~"~ ,~', ,t,r, " '. ':.".?ê,q~~~ÑTs,." . , ~" " " ,"~' '. ... '. 2P - 431 Grizzly -". " Printed: 9/2/2003 3: 16:02 PM ::=- en c. ---- w a: :J en en w a: c. 1,000 ~/ /Shut In 10.5 Minute Shut In - 750 - - . ~ IE ... . ~ -CASING TEST ~LOT/FIT -MAXIMUM VOLUME (BBLS) ~ 500 250 - 0 0 0 0 0 C\I 0 0 oo;t 0 0 CD 0 0 C() 0 0 ~ 0 "! T""" 0 ~ VOLUME (BBLS) ') ') SUPERVISOR Ralph Bowie CURRENT STATUS '" :::::/I':\;f::f;~;: ';::i-¡¡~", Y"~~:':{ rrU~;i ",'~F~I , :I~[,~, ,~ , " '" I ~~B NU~~~~ '~VE~ C~~E" ~4' HRS ~~~G ' 2P-431 ODR 1,271.0 I RIG NAME & NO. I FIELD NAME I OCS NO. NORDIC 3 n1433@ppco.com 3 Meltwater ACCIDENTS LAST 24 HRS.? ¡' I,:""" .. WELL NAME Drlg ahd @ 4665 TMD I'TVD ' DFS ' 4,276.0 3,057.0 6.00 AUTH MD I DAIL Y TANG 9,967.0 0 DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 187,168 REPT NO. DATE 7 4/2/2002 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 948,439 24 HR FORECAST Dir Drlg & survey. I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE Sd & Sh 15.62 AK0236 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 4/2/2002 4,238.99 57.040 184.190 7.625 (In) @ 3,005.0 (ft) 5.500 (in) @ 9,967.0 (ft) DENS~(Ppg) I 10.00, 'JpP,;1 IECDI IMUDIDAT-A I'DAILY,pOST,' 0 I:cUJi~Ó.ST,:'1 ° :','í:~l\,:':~\¡fj~,,: ;);~,~LS~: \\\íPH,fH.,p':' ,Fcri.'j;þL ,0IuWAT" '%SandtMBT' ':PhlpM ! PflMf CI" 'Co' H2S LIME ES 48 15/19 5/11 4.0/ 1 / 114.0 9.6/ 1 18 70 64 68 4,000 ft-Ibf 1,184.49 . ,~':riEMhESCRIPTlON:::' >' ' ,";','NOJTS' , ""LENGTH, "0.0.:, 'U)~':':, ,Þ():NN:si~,::~:c:þ~N'~E', 1 0.75 6.750 1 0.85 6.719 1 30.55 6.625 1 5.31 6.625 1 3.92 4.750 1 5.04 4.750 1 12.00 4.750 1 19.25 4.750 1 3.74 4.750 1 30.83 4.750 1 30.94 4.750 1 30.28 4.750 1 2.54 4.750 18 552.46 4.000 1 29.35 4.750 14 426.68 4.000 LrrHOLOGY AUTH. 2,915,214 LAST BOP PRES TEST , ' Bit Turbo-Back Stab Mud Motor Stabilizer - Non Mag LWD/MAP LWD/SRIG LWD/MPR MWD UP A Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Crossover Qrill Pipe - Heavy Wgt Jars Drill Pipe - Heavy W gt 1.500 2.250 2.812 2.812 2.812 2.812 2.812 2.690 2.690 2.690 2.250 2.250 2.250 2.250 "I' , ';,!, ',:, ':':~;>'~BltS'i::::,\/:,'<, ' , " :,i :::B,rr i~uN ':';}~i?E":i,' '0: ,':'MANÛF~":::':>:";;::liP.E"::,? :SERIÂ~:Np.,' ,:'U';:<JËtS-'ôR Tf"': 2 / 6.750 SMITH M93VYPX JS6688 13/13/13/13// . . :~.~')~.': :¡:.:. ,~I;:' -.:: \>1':; \¡~~"i;~':X</l(...!~'\;:~,;;-,i{~,: <~ ~~I ';,~'., ~+')~:/k;\\. :;',', ': ~:.',~ ;,' "'.; ; ",DEÞ~ iN;:DÄ~'íN '.,:::,i,)'~::~q~D~lf~~Ø;O~R', ' , 3,005.0 4/1/20020-0-NO-A-D-I-NO-TD . ...'~~r¡JJ~t;...... .y,98 .,\.;,'~~t.i-:..,~""'::]J~~~~ ~ltpd~~~~t~~r~\2.~rDist ..2.à,'~~~\;¡~~t~~~¡~J~~~~'Þ~~~ø~' 2/ 1 4/8 65/85 300 2,450 308 16.10 1,271.0 78.94 16.10 1,271.0 78.94 , , , ", ::. ,,',:':/< ,,',,' ,: :':',: />S~-~Y~~{.:'~,~TÄ:" , ',' , ,.AZ!MUTH,. ,~::T.V~f;)~; N/SCOM ElWCUM ,sEëTíON~ 'M~D.," I : INCL., 182.430 2,391.30 -1,437.7 -85.82 1,440.31 3,671.37 58.010 182.080 2,439.18 -1,518.8 -89.02 1,521.45 3,766.06 57.740 181.730 2,486.85 -1,600.7 -91.74 1,603.38 3,860.61 57.480 181.730 2,533.86 -1,682.6 -94.21 1,685.31 3,955.33 57.480 184.190 2,582.25 -1,764.2 -98.42 1,767.02 4,049.98 57.480 183.480 2,631.75 -1,844.0 -103.76 1,846.93 4,145.35 57.300 183.130 2,682.15 -1,924.4 -108.41 1,927.48 4,238.99 57.040 : ,- "ÂZIM"OTti ' " :,-,:,~;~~~~~{:~~~~~.; ~;~~ij::i~~Jj,ó~i:;, 184.540 2,732.77 -2,005.0 -113.81 2,008.22 184.190 2,783.12 -2,084.9 -119.91 2,088.39 184.540 2,833.77 -2,164.5 -125.99 2,168.21 183.830 2,884.69 -2,244.2 -131.82 2,248.06 183.830 2,935.58 -2,323.8 -137.15 2,327.86 184.540 2,986.97 -2,403.9 -143.01 2,408.18 184.190 3,037.74 -2,482.4 -149.00 2,486.84 , " ,')Jì:D;:' , 3,008.56 3,102.78 3,197.59 3,292.06 3,387.04 3,481.04 3,576.07 ',':INCL. ' 59.240 59.680 59.940 60.380 58.360 58.100 57.830 Printed: 9/2/2003 3:22:41 PM ) ) 2P-431 :. ;,,'; /:.:: ~",; :"; :;:,,:}(;;:;áðH):ltj:<:.:: : 'I:::~'j'//';/: :';::,:::\\:),) ::;H"::(\[f~~:~";¡' ~tr::I¡:;;:;:::; >õþ'~~\¡ '~~,::I~'N~:¡:~U!t:~uWî?~~:~i;(!:~~:r::~: :":;I\:::~: II'j": ':~!U~:¡~'I:i;j,Þ!¡:rjf:;::f¡:: !:'[, 1;:I-!>;{;:;;: :"l:;.j,;':::,;~:~¡Ji ':ill:d iJ\, I):<il"I::i;¡<I':}~t~8¡ ,t¡.Nf ".;\'õf~:~IY~"'¡" ,,\'¡~ ).~r', ~ ¡ }"J'r'1'r~:,\\ ~:'I-~l.:. "1) -"~l~i~'!~~.;r'S¡- ,:~'r\~'~!I\~-~.'-~r~,¡ ~]'~~;~~'("II,\~~~"I'I'~' '/!,r~-\1.!~t~:~~¡'-A_\-~I'r~'1'\'-I'/~\"AI-lf-~V~!'!'~1 -':~'\(.I".~t~ I f~9.iyJ" :' 1;;r'Q;H 7í1b.Ü~~':'¡ hJÇv,Ø,~r'::;:: m'~iïä,t!.~:,::: J1u'B :\':: :,,'¡P.~A~~.::;:~¡,~}$¡;,~!{'~,i~V~~:;;:~:;~¡~¡H:::~Wf:~f:~Mr~ii:,;¡'> ";: : I' ':;: p~,~ç I 'IP"Ø~'::', ',,':, :f:!::Yi ',\j1,H:i:; !:{'!,'¡~;~';M~í1~x~:l1~tt;i~N¡¡ 00:00 01 :00 1.00 DRILL P OTHR PROD Complete cutting drlg line. 01 :00 01 :30 0.50 DRILL 01 :30 02:00 0.50 DRILL 02:00 04:00 2.00 DRILL 04:00 05:00 1.00 DRILL PROD Drlg / wash out cmt to float collar, drlg plugs. collar, shoe track cmt & float shoe @ 2990'. Clean out 9.875" hole to 3005. PROD Drlg new hole for fit / lot. 3005 - 3025'. PROD Circulate bu, elect to x-out mud due to erratic cmt contamination & un- equal rheology / weights in pits. Disp to 10.0 ppg new mud. Pull Up into csg. PROD Conduct FIT w/ 10 ppg mud in hole. TVD = 2399'. Using bop test pump imposed 750 psi w/27 gallons of fluid. Pressure bled down to 700 psi & held stable of a total of 10.5 minutes. There was no break over in the pressure build up plot. Bled back 18 gallons of mud. RIH to 3025. Calculations EMW = 10 ppg + 700 psi / { .052 X 2399'} = 15.6 ppg Prior to the F.I.T. the surface system was tested to 4650 psi by bring the test up to speed 2 times [4 seconds each cycle] to impose the pressure between the pump & the low torque valves on the DP & annulus side. There was no leak off. 05:00 00:00 19.00 DRILL P DRLG PROD Dir Drlg 3025' [2399' tvd] - 4276' [tvd = 3057'] Parameters: Pump P. 2600 psi @ 295 gpm, Bit wt 4 -1 Ok Ibs, Troque on / off td = 4k / 3k ft-Ibs 65 rpm, weights up/dwn rot = 69/67 / 65k Ibs. Clean ecd 11.4, drlg ecd's in the 11.8 ?2 ppg range. ADT = 15.6 = rot 15 + slide .6 hrs. 24 HR SUMMARY: Cut drlg line / rih / drlg out / F.I.T./ drlg ahd. , ::,,:;~:< COMPANY Nordic Catering ConocoPhillips Company '~: ~êR\Îi,CE' : I' ':', :, "'::,:,,:!:~:ÞERSON'NEUDATA' ,,': "'¡:NO. , I':H,9iJ.FI,$:~: :COMPÅ~Y, ' 2 Baker Hughes Inteq 2 Baroid 1 apc ~, " . .' . .. . ',' '" "I,' ',' .' .' , , , $E~Vic~ ':-':~:NO;:::~:;, ,\'H9LÏRS' 6 3 1 ,ONiT.$'" gals BBI , ',: ',ivlATEFUAls/CONSUMÞTION , U$AGE~.', :' ~',: QN; ~,~~Q ::c:<n: ':~ :::'h-EM ' " 1,050 6,966, Camp Fuel 155 210 Camp Wtr ('-.',' . !', .'l:!~'< , , . . ,", ':>.:lTEpJ(:,' . Rig Fuel Rig Wtr , ,:~,NIjj;" bbls bbls . . ,. ..d.. .1.,. " ',:\US,~GE: ::: ':' :;:þRHÁNt>.:::~," 2,275 50 28 1YPE 2P- 415 2P-415 NO. 923 2P - 431 Grizzly REMARKS SUPPORT CRAFT 1YPE 2P-415 NO. 870 Heavenly REMARKS Printed: 9/212003 3:22:41 PM ) ) 2P- 415 2P-415 2P-415 2P - 431 Grizzly Heavenly ¡~1,. "I, " . ~~k , EVENT CODE 124 HRS PROG I TMD ODR 1,271.0 4,276.0 ¡~'~~~.~~' *i'b:ì:li'~'f~' ; ~', :'i:!!'6~,j~~ .~l~¡:';'¡'i!~'A'"' \ ,~, ;:;'í}[i;:P¡;it;'/¡$>~~i~£I~~¡li::n;'~J~r:':¡J'\';'¡1'..;<';' :I:::':j{;;'t~ l;<:~; ¡';:iiIJ~\dt"¡¡i:i~f~f.1rh'; ~~~:~p;; ~~\~~101:~~~~~~" ts~~~,~~,:,¡~ø(~:;,. ~,~::}>~\~Z~1d~,~~!:t!~t;Cff¡!:~~~:¡\~~~~:~~~hr1,~~i;~}~In¡f(1;;,;:¡Wh;I:;}i:~n11~~~~~':' " ,:r~'.f)t'~¡'~\;,' Ik'::,,,;.J:~;lì;::~,:,, l~i~à :~; .' I ' ~:::J~ :;nt¡i'rt;~:iJ:r~li;:'\;;:l?~¡¡F.!~t:ti~'~~~;~kiJ.i!\ t9ø.',M~~:~I~;{il{~r.;i~:hFi'I;~: ,:I!f!~1f;~:¡:::Ür.¡';1:"íÒ:~j';: 2 1000 923 0 870 2.7 800 2P-431 ~i.j\\j;.!;,~~~ co:,.. ... :~ij¡~¡:!;:ii~t1~t~~)~. Printed: 9/2/2003 3:22:41 PM ) Casing Detail ) 5-1/2" X 3-1/2" Product/on CaslnQ WELL: 2p.431 DATE: 04/06/2002 1 OF 1 LENGTH Phillips Alaska, Inc. #. ITEMS COMPLETE DE~CRIPTION OF EQUIPMENT RUN Nordic 3 R Floor to LOS = 25.65' RKB 25.65 2.50 8769.22 10.15 Jts 1 - 205 Pup Jt Hanger w/ pup 5-1/2", 15.5#. L-80,BTC MOD (205 joints) 5 1/2" 15.5 # 8T & C Mod Baker CSR Assy, SIZE 80-40, 5-1/2" x 5" XO 1.17' + Baker Seal Receptacle 19.22', + XO .60' 3-1/2" 9.3# L-80 8rd EUE [ 2 Jts} 3-1/2" 9.3# L-80 8rd EUE ( 1 joints) 3-1/2" 9.3# L-80 8rd EUE {Top of Bermuda 8903'} 3-1/2" 9.3# L-80 8rd EUE (21 joints) 20.99 10.05 30.08 6.02 655.53 Pup Jt jt 26 MARKER Jts 5 -25 Jt #4 3-1/2" 9.3# L-80 8rd EUE ( 1 Jt) wI Plug catcher in top Weatherford Float Collar 3-1/2" 9.3# L-80 8rd EUE (3 joints) Weatherford Float Shoe 30.16 .64 94.05 .59 Shoe ~ Jts.1-3 PluÇJ Catcher in the top of joint #4. cæ MD 9530'. PAGES DEPTH TOPS 25.65 28.15 8797.37 8807.52 8807.52 8828.51 8838.56 8868.64 8874.66 9530.19 9530.19 9560.35 9560.99 9655.04 9655.63 TO 6 3/4" Hole = 9685 (34) 3.5 x 6.625" Bow Spring Centralizers: one on each jt of 3.5" tubing. On jt #1 install the centralizer 10' above the shoe using stop collars. ( 16 ) 5.5 x 6.625 Bow spring centralizers: Float on 5.5" Jts # 1 through 16. ( 23) 5.5" X 6.5" centering guides 'on Jts# 190 through 212. **Fill on the fly and Top off every 5 joints **Baker Lock all connections from the Top of the FC down ** Break Circu above the shoe [5.5" jt #50], 5900' [5.5 jt # 119] & at 5.5 jt # 185 [above the Bermuda]. Bring pumps up slowly,but do not exceed 3 BPM Torque first 10 BT&C 5.5" and avg torque to Run-Watch Diamonds I Nordic 3 Drilling Supervisor: Ralph Bowie jr REMARKS: String Weights with Blocks:???K Up, ???K On, ??K Blocks. Ran 205 Joints 5.1/2" and 26 joints of 3.1/2" casing. Drifted 5.5" (4.825") & 3.5" (2.861") casing with plastic rabbit. Used Artic grade API modified No Lead thread compound on all connections. Casing is non-coated. Jt #10n the tally is the csg seal receptacle. ) ¡ ..... ...-..u ...... -----.--------.----Customër: I Scblumberger ~:~~~~entative: : OS Supervisor. I . ,..., ~~~. D~t.e: .?~~~~:~O~~.._n....... Well: PHILLIPS Prudhoe Bay DON WESTER Randy Jost 2P-431 ') . -"'.,,,,,,, '_n'-""''''---''---'-- -."... .. ........_-\ I l ¡ I ---...-.... ...--------.-- ----... ...-... ......1 .. ...._"....,. ,.' " ......-....,-...... ""--'.'" --"""'---...--.......-.. -..-.--.----. """-'-" ,.-.. .,..... ~.__........,-.... .-...." "'" " . -.............., .... Time PRESS Density RATE STAGE VOLUME mm:dd:yyyy:hh:mm:ss psi Ib/gal bbl/min bbl bbl .' -...." "'-'----""'''-''''''.''''--'---'''.''''-''''--''''-'-- --- -....- ......-.--- -..... - 0.'" 04:09:2002: 18:40:49 3 0.01 0.0 0.0 0.0 04:09:2002: 18:41 :01 Start Job 04:09:2002: 18:41 :01 -2 0.02 0.0 0.0 0.0 04:09:2002: 18:41 :12 PJSM 04:09:2002: 18:41 : 12 1 0.01 0.0 0.0 0.0 04:09:2002: 18:48:34 START SA TCHING CMT 04:09:2002: 18:48:40 1 0.01 6.1 0.1 0.1 04:09:2002: 18:48:54 START SATCHING CMT 04:09:2002: 18:48:54 0 0.01 12.5 1.5 1.5 04:09:2002: 18:51 :01 Reset Total, Vol = 0.00 bbl 04:09:2002: 19:20:43 1 8.35 0.0 0.0 0.0 04:09:2002: 19:20:51 CMT TO WT 04:09:2002: 19:20:51 5 8.35 0.0 0.0 0.0 04:09:2002: 19:24:28 6 8.35 1.5 0.0 0.0 04:09:2002: 19:24:41 START CW1 00 04:09:2002: 19:24:41 13 8.34 0.5 0.2 0.2 04: 09:2002: 19:25:28 498 8.36 3.2 1.8 1.8 04:09:2002:19:26:28 303 8.35 1.3 5.0 5.0 04:09:2002: 19:27:28 138 8.36 0.0 5.1 5.1 04:09:2002: 1 9:28:28 1895 8.35 0.0 5.1 5.1 04:09:2002: 19:29:28 3366 8.35 0.0 5.1 5.1 04:09:2002: 19:30:28 3341 8.36 0.0 5.1 5.1 04:09:2002: 19:30:34 P~essure Test Lines 04:09:2002: 1 9:30:34 3503 8.36 0.0 5.1 5.1 04:09:2002: 19:31 :28 25 8.36 0.0 5.1 5.1 04:09:2002:19:32:18 RESUME WAS.H 04:09:2002:19:32:18 273 8.36 1.5 5.3 5.3 04:09:2002: 19:32:28 415 8.35 2.7 5.6 5.6 04:09:2002: 19:33:29 740 8.35 4.5 9.9 9.9 04:09:2002:19:34:29 789 8.35 4.5 14.4 14.4 04:09:2002: 19:35:29 779 8.35 4.5 18.9 18.9 04:09:2002: 19:36:29 812 8.34 4.5 23.4 23.4 04:09:2002: 1 9:37:29 801 8.35 4.5 27.9 27.9 04:09:2002: 19:38:29 825 8.35 4.5 32.4 32.4 04:09:2002: 19:39:29 825 8.34 4.5 36.9 36.9 04:09:2002: 19:40:29 844 8.34 4.5 41.4 41.4 04:09:2002: 19:41 :29 844 8.34 4.5 45.9 45.9 04:09:2002: 19:42:29 872 8.34 4.5 50.4 50.4 04:09:2002: 19:43:29 881 8.34 4.5 54.9 54.9 04:09:2002: 19:44:29 657 8.34 3.6 58.8 58.8 04:09:2002: 19:45:30 273 8.35 0.0 60.0 60.0 04:09:2002: 19:46:30 275 10.61 0.0 60.0 60.0 04:09:2002: 19:47:30 269 12.V2 0.0 60.0 60.0 04:09:2002: 1 9:47:40 Reset Total Vol = 60.20 bbl 04:09:2002: 1 9:47:40 229 12.00 0.0 60.0 60.0 04:09:2002: 19:47:51 START SPACER 04:09:2002: 19:47:51 445 12.04 2.0 0.1 60.1 Page 1 of 4 ) ) Well: 2P-431 \.... . -'''-'' ""~i~;------"-(----;;~ss Density RATE L_...~~~d:y~!~~~:_~~:ss I n psi Ib/gal bbllmin 04:09:2002: 19:49:30 822 11.62 4.4 6.9 66.8 04:09:2002: 19:50:30 791 12.30 4.4 11.3 71.2 04:09:2002: 1 9:51 :30 342 12.77 1.0 15.1 75.1 04:09:2002: 1 9:52:30 458 11.57 2.6 17.2 77.2 04:09:2002: 1 9:53:30 760 12.00 4.5 21.6 81.6 04:09:2002: 19:54:30 743 11.93 4.6 26.2 86.2 04: 09:2002: 1 9:55:30 752 11.92 4.6 30.8 90.8 04:09:2002: 19:56:31 684 11.64 4.6 35.5 95.4 04:09:2002: 19:57:31 419 11.92 2.6 39.9 99.8 04:09:2002: 19:57:49 Reset Total, Vol = 40.,60 bbl 04:09:2002: 19:57:49 66 -3.10 0.0 40.0 100.0 04:09:2002: 19:58:01 Start Cement Slurry 04:09:2002: 19:58:01 58 15.45 0.0 0.0 100.0 04:09:2002: 19:58:31 752 15.81 4.2 1.1 101.1 04:09:2002: 19:59:31 873 15.86 4.6 5.7 105.7 04:09:2002:20:00:31 861 15.86 4.6 10.3 110.3 04:09:2002:20:01 :31 820 15.87 4.6 15.0 115.0 04:09:2002:20:02:31 797 15.87 4.7 19.6 119.6 04:09:2002:20:03:31 718 15.86 4.7 24.3 124.3 04:09:2002:20:04:31 624 15.85 4.7 28.9 128.9 04:09:2002:20:05:31 612 15.85 4.7 33.6 133.6 04:09:2002:20:06:31 640 15.84 4.7 38.2 138.2 04:09:2002:20:07:31 585 15.84 4.6 42.9 142.9 04:09:2002:20:08:32 564 15.85 4.7 47.6 147,6 04: 09:2002:20:09: 32 526 15.85 4.7 52.3 152.3 04:09:2002:20: 1 0:32 509 15.85 4.7 57.0 157.0 04:09:2002:20: 11 :32 194 15.84 3.0 61.2 161.2 04:09:2002:20: 12:32 12 8.44 0.0 63.8 163.8 04:09:2002:20: 13:32 65 8.41 0.0 63.8 163.8 04:09:2002:20: 14:32 47 8.39 0.0 63.8 163.8 04:09:2002:20: 15:32 45 8.39 0.0 63.8 163.8 04:09:2002:20: 16:32 44 8.38 0.0 63.8 163.8 04:09:2002:20: 16:54 RIG PUMPS DISPLACE .. 04:09:2002:20: 16:54 42 8.38 0.0 63.8 163.8 04:09:2002:20: 17:32 43 8.38 0.0 63.8 163.8 04:09:2002:20: 18:32 40 8.38 0.0 63.8 163.8 04:09:2002:20: 19:28 DROP PLUG 04:09:2002:20: 19:28 41 0.0 63.8 163.8 04:09:2002:20: 19:32 41 0.0 63.8 163.8 04:09:2002:20:20:33 42 0.0 63.8 163.8 04:09:2002:20:20:59 5 BPM 300 PSI 04:09:2002:20:20:59 40 8.38 0.0 63.8 163.8 04:09:2002:20:21 :33 39 8.38 0.0 63.8 163.8 04:09:2002:20:22:33 40 8.38 0.0 63.8 163.8 04:09:2002:20:23:33 40 8.37 0.0 63.8 163.8 04:09:2002:20:24:33 38 8.38 0.0 63.8 163.8 04:09:2002:20:25:33 35 8.38 0.0 63.8 163.8 04:09:2002:20:26:33 37 8.38 0.0 63.8 163.8 04:09:2002:20:27:25 WASH @SHOE 4.5 BPM 360 PSI 04:09:2002:20:27:25 35 8.38 0.0 63.8 163.8 04:09:2002:20:27:33 37 8.38 0.0 63.8 163.8 04:09:2002:20:28:33 36 8.38 0.0 63.8 163.8 04:09:2002:20:29:33 35 8.38 0.0 63.8 163.8 Job Date: 04..09-2002 I ---....-.. .--.....--' STAGE \ VOLUME I bbl bbl I j-----.---..... ..---...._......1 8.38 8.38 8.38 Page 2 of 4 Well: 2P-431 1--"" - ,. -----~;e---"'-""'-- \ .,.-., ~~~~_:.~y-~~~~~:mm::~_.." 04:09:2002:20:30:33 04:09:2002:20:31 :34 04:09:2002:20:32:34 04:09:2002:20:33:34 04:09:2002:20:34:34 04:09:2002:20:35:34 04:09:2002:20:36:34 04:09:2002:20:37:34 04:09:2002:20:38:34 04:09:2002:20:39:34 04:09:2002:20:39:59 04:09:2002:20:39:59 04: 09:2002: 20:40: 34 04:09:2002:20:41 :34 04:09:2002:20:42:34 04:09:2002:20:43:35 04:09:2002:20:44:35 04:09:2002:20:45:35 04:09:2002:20:46:35 04:09:2002:20:47:35 04:09:2002:20:48:35 04:09:2002:20:48:56 04:09:2002:20:48:56 04:09:2002:20:49:35 04:09:2002:20:50:35 04:09:2002:20:51 :05 04:09:2002:20:51 :05 04:09:2002:20:51 :35 04:09:2002:20:52:35 04:09:2002:20:53:35 04:09:2002:20:54:01 04:09:2002:20:54:01 04:09:2002:20:54:36 04:09:2002:20:55:36 04:09:2002:20:56:36 04:09:2002:20:57:36 04:09:2002:20:58:36 04:09:2002:20:59:07 04: 09:2002: 20: 59: 07 04:09:2002:20:59:36 04:09:2002:21 :00:36 04:09:2002:21 :01 :36 04:09:2002:21 :02:36 04:09:2002:21 :03:36 04:09:2002:21 :04:36 04:09:2002:21 :05:36 04:09:2002:21 :06:25 04:09:2002:21 :06:25 04:09:2002:21 :06:37 04:09:2002:21 :07:37 04:09:2002:21 :08:37 04:09:2002:21 :09:39 04:09:2002:21: 1 0:39 36 8.38 5 8.38 -17 8.38 3 8.38 -4 8.39 6 8.37 5 8.37 8 8.37 6 8.36 19 8.35 SPACER @ SHOE 4.5 BPM 230 PSI 20 8.36 17 8.31 11 8.31 19 8.26 19 8.27 18 8.25 16 8.25 15 8.25 12 8.24 13 8.22 CMT @ SHOE 4.5 BPM 550 PSI 14 8.24 10 8.33 6 8.30 4.5 BPM 650. PSI 97 8.32 67 8.28 16 8.28 136 8.33 175 BBL 4.5 BPM 750 PSI 140 8.33 144 8.32 74 8.32 14 8.34 143 8.32 80 8.38 196 BBL 3 BPM 660 PSI 144 8.32 5 8.34 3 8.34 4 8.34 4 8.33 6 8.34 4 8.34 6 8.34 BUMP PLUG 2500 PSI 30 7.72 70 0.72 32 0.23 47 1.79 37 0.07 29 0.09 ) , .-. PRESS psi Density Ib/gal Page 3 of 4 RATE bbl/min 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ) Job Date: 04.09-2002 '_.n._" -"T'" -"-"--- '- --"'''''''' 1 STAGE VOLUME \ bbl bbl -'-, --,....- -.- ...____n._" - ". I 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 ) Well: 2P-431 \_. -... . - -.-. ._~~~'.-----I PRESS Density \.. .. ~~~~~.~~~~~:h~:~m:s=--_.L~~- Ib/gal 04:09:2002:21: 11 :29 CHECK FLOATS 04:09:2002:21: 11: 29 30 04:09:2002:21: 11 :2.1 29 04:09:2002:21 :12:~,'-: 10 04:09:2002:21: 13::~j FLOA TSHELD 04:09:2002:21:13:: :3 6 0.04 0.0 04:09:2002:21:13:~~J 11 0.10 0.0 04:09:2002:21:13:t",2 GOOD RETURNS THOUGHOUT JOB 04:09:2002:21:13:~._:~ 10 0.09 0.0 04:09:2002:21: 13:£ :] End Job 04:09:2002:21:13:~",_~ 7 RATE bbllmin 0.18 0.16 0.12 0.0 0.0 0.0 0.05 0.0 Page 4 of 4 Job Date: 04.09-2002 --,-- --..----..-..... STAGE' VOLUME bbl bbl -.--- --....-.. ..---.. ---..I 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 63.8 163.8 Sch umlergel' ¡. ""W'~'II' Field ..---.-......--.-.".' .--.-.-. 2P-431 MELTWATER Engineer Country Randy Jost United States . ." . ..',. .....,. ...-... ~- ) Time . - '-' Pressure ,..' ... ---~.. -. -.-..-.--.....-. 'H,.".;:":,,,...III Cement Job Repor Client SIR No. Job Type Job Date ) CemCAT vl.C PHILLIPS 2201041397 -"--.'-----""--""-..--- "-'--"'''-'''-'' " ... -.... 5 1/2 X 3 1/2 CASING 04-09-2002 -....,.,-.",-..... .--.., -'-'Y'"'' "-'..-' "'''''-'''-''.---.. . ,.,...-...,.,. ..... ...,. ...---....... ----.-.---.---"-- ---..-.-- -- .-- Density ---,----' ----'''''--''-'.......-.-.-.-..'' -.-----..- Messages 18:1\0:49 18:57:53 I I I I j i ! i i I I ¡ I ! I ¡ i I I I ! I 19:14:57 '2 19:32:01 ~ 'Ir. r 19:49:05 3. 20:06 :09 r 20:23:13 20:40: 17 20:57:21 i 21:14:30 : hh:mm:ss i L::~ .::::.~.: .~~~ .:__..~.~. .~~~-- '" IJJJ 2000 ...-.. ,- ....._- J"JJ1 Rate ~ ~\ ~ :- .,--J -I- T , ~ ;. (> .~ - .-- ----. . . 6___-- - ...--- .000 0.0 1.7 u 5.0 3.3 4.~ 0.8 -''''--' 6/M f ::- ---' -~ ..-- - ...--- 7 ,.-."--" .-.~---'-'. '---'. 12 l' - L6/G .""---"---'''''-- "-.'-----'------"'-----'-- Start Job PJSM START BATCHING CMT START BATCH(NG CMT Reset Total, Vol = 0,00 bbl CMT TO WT START CW100 Pressure Test Lines RESUME WASH Reset Total, Vol = 60.20 bbl START SPACER Reset Total, Vol = 40.60 bbl Start Cement Slurry RIG PUMPS DISPLACE DROP PLUG 5 BPM 300 PSI WASH @ SHOE 4.5 BPM 360 PSI SPACER @ SHOE 4.5 aPM 230 PSI CMT @ SHOE 4.5 BPM 550 PSI 4.5 BPM 650 PSI 175 BBL 4.5 BPM 750 PSI 196 BBl 3 6PM 660 PSI BUMP PLUG 2500 PSI CHECK FLOATS FLOATS HELD GOOD RETURNS THOUGHOUT J08 End Job --. r" -..--.--" "'---'-'-''''----- .-' ." _.. --....--..-.- 16 18 -------- --'i),\,/Q<:I/IQQT'2.1-:3672,1 ) ) WELL NAME 'r~¡¡ .~:.. h~r; ',:¡ij;:;HT)i[,.;).::r ::~ ¡:rlf1i~H:l:';W:l!;11;¥.TI ~A, \J' J~:I' .. ',' ',jf ! ';;. . :!)"Vij:W¡ , ,,' , "',,' "I ~O~ 'NUMBER I' EV~m CODE 124 HRS"PRÖG ~MD '1'~D' 'I DFS 2P-431 ODR 9,685.0 5,824.0 13.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Donald L. Wester NORDIC 3 n1433@ppco.com 3 Meltwater 9,967.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Load 3.5" EUE tubing, Slip & cut Drlg line, Repair compensator ra 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Run 3.5" Completion, NID NIU Freeze protect. 170,343 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE Sd & Sh 15.62 AK0236 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 4n/2002 9,619.17 60.380 182.430 7.625 (in) @ 3,005.0 (ft) 5.500 (in) @ 9,967.0 (ft) ,DEf\iSrrvCPpg), I 9.~0 I':~~':::I 'ECD IMtUfoATAI,D!'ILYCost: 0 t"j::lJf.(p:~Sill" 0 '.::>'~v.:-.:' U~Y~~:.' ':.G~L$' ':':WLIH:TH.P., >.FCIT.SOL OILIWAT' "'%SandIMST "Ph/pM ,pflMf " C¡': ""CB' ; H2SLI~E ' ES. 40 8/14 4/9 3.61 11 I 115.0 8.91 I 'REPr NO.' 'DATE 14 4/9/2002 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1 ,884,569 AUTH. 2,915,214 LAST BOP PRES TEST . ! If. ~ .. , J ¡ ,'~ ~ .. ";,~!,:,:'\\'::'::""!;:<..?:,:},~il:'~::;;~~~'~>':"":'~'~:::':'"'I;''' ~ :~~'d~::' U~i:~~!;'::+~.;:~~¿'~~:::: "'", C.Q~~ ';:' ~Ol!Ei(~ ,:;/$~a' 00:00 01 :30 1.50 CASE P RUNC 01 :30 02:00 0.50 CASE P SFTY 02:00 06:00 4.00 CASE P RUNC 06:00 06:30 0.50 CASE P CIRC 06:30 09:30 3.00 CASE P RUNC 09:30 10:30 1.00 CASE P CIRC 10:30 15:00 4.50 CASE P RUNC 15:00 15:30 0.50 CASE P RURD 15:30 19:30 4.00 CASE P CIRC PROD RlU to running 5.5" x 3.5" esg. Change bails. & csg crew. PROD PJSM on running casing PROD Run 5.5" X 3.5" csing as programed. Fill on fly with fill up tool. to 2900' PROD Circulate at 1 bpm 470 psi. PROD Continue running 5.5" X 3-1/2" csg to 5900' PROD Circulate 1.5 bpm @ 600 psi PROD Continue running 5.5" x 3-1/2" csg to 9520'. Tight spot @ 8313' PROD M/U Hanger and landing joint. R.I.H circ down PROD Circulate & condition Mud Lower Pv to 15< na thin mud. Reciprocate & circ. Flush rig mud lines wi Brine. PUMP PROD Pump 5 bbl's CW100 P.T. Lines to 3500 psi. Continue pumping total of 60 bbl's CW100. Followed by 40 bbl's MudPUSH spacer weighted to 12.0 ppg. Followed by 62 bb 's (320 sx) Class 'G' GasBlok emt at 15.8 ppg slurry. Drop Dart and displaced wi rig pump and 9.6 ppg clear Brine @ 4.5 bpm slowed rate to 2.5 bpm for last 20 bbl's. Bumped Plug 3.8 bbl early wi 2500 psi. C.I.P. 2107 hrs 4/9/2002 Float held O.K. PULD PROD RID csg crew and equipment. UD landing jt. Install 5.5" X 11" packott. PT same to 5000 psi fl 10 min O.K. 24 HR SUMMARY: RlU and run 5.5" X 3-1/2" Csg to 9555' md. Cmt same. RID csg crew & equip. Install packott PT to 5000 psi 19:30 21 :30 2.00 CEMENT P 21 :30 00:00 2.50 CEMENT P .0.. 'ÎtEM::: Rig Fuel Rig Wtr , . .<.:~~~' P.E~~;u~~,NEL~:J~.i~j::' , 2 Baker Hughes Inteq 2 Baroid 2 apc .., .,.,:'.: ',MATERIAlS /ÇONäUM'P:TIÖN ., :.ÜSAGE:':' "ON'H'ÂÑif c'h:; ,~i~::i"~:':¡';".t"ri"EM.:,.',:i',<:', 1,190 4,640 Camp Fuel 198 92 Camp Wtr ... . L .:. ..." ,.'- :;; ,::::))~~~~¡¿~:':;,:'~' , . , .. , . . : ~OMPANY' "", Nordic Catering ConoeoPhillips Company " ."\ . SERVicE : '1 ", '. :',,: UNITS. bbls bbls .. . 'UNITS gals BBI , ; ':~' ONliÄND" , 2,375 39 11 NO. 500 2P - 431 290 Grizzly Re~"ARK$ ',SUPPORT'CRAfT ' . . TYPE: 2P-415 ;1 "'., TYPE 2P- 415 2P-415 ,':NO~ , 290 Heavenly REMARKS Printed: 9/2/2003 3:24:48 PM ) ) 2P-431 ~;; '~>:!I:.;;i1: i~I':~.:r;:;~i:I~:~£'i:'1"i?:::,~::-I.':" :,!.; /h:!:i:'I,I::., !.i;!.{~ir:~;,',i,~!:'J!.':::I}"~:, ¡;: '.::¡ ,1~fE;' §'~" R'k"'V'"O''' . 'I"R" 'I~;:~r~" ~,.'^~I,' ~ I': ;.1.. "'f:",h~l. ,':!:'l\.~I<"i1il"",,, '"'.''''' ". '.1.,. ".. '.-., ., "1,,""0'1""\ ",' I"il""""'" ,.1 - f' . .,~ ' " .~¡~..~:~~.~~) !::, ~).I"~.'''¡-I::: 'h~- "1~ 'J;~~~ r ~ ~ "~:" :h! ~~ .r. ~, I Y; 1¡:: ' /"""1:~"1:'~( I"c: ~.~..' ';,'.- IJ ,": -I" t ~t.,~{. ; I, ~ , - .l f~,:i ~~/~.~, ". - .:~". 'i ~ ~~\",,,p¡.f 1:~;' .,'II~! '", I, !'lJ""/io:. ~iiI; I¡, .,...1 lIÜA1ÎioCl.I.., 1..r 'J'>'I':[~"""I.,I,:. '":''''';¡¡Ö~I~''' . ,.'.¡......." ". .¡.".,,¡It...^ '.1'.'.','." :~¡.~:i.:'; i.: t.~~. '''~~~I!':t.~~. ..,....~", "~~¡' ', :: i.ï:~ {I; ¡d:/.:-tJ¡t:l';~:~.'¡':.:; ~.~: r':..f~ ~ I,"~ ~ ,:,' '" :-'" ',\1 .¡~: ',', r.~. 'r f \ ;~t' ';"~'!~~'A':::,(.t:::I:ì. ,t¡:" 2P- 415 2P - 431 500 2P-415 Grizzly 290 2P-415 Heavenly 290 '":~¡'*:j¡iI':;:I':~'iK~';'''>c~,.p:¡j''':I'''''''':I¡'\'' .''' :tOP . . , ~?!~Li;:tI~~'~itN{';t1)(,:: :?:!+¡N~ì~', .I~'~<:I.': I\~~ '.'1].1 ::»! i',,' ¡,..",:lrf' :t:I"¥, . '''¡.~ '!'Í.'<"" ,,!~ 1. ... ".:F:-i:::(:: ::Ici~.J¡,. ':~i':'%:'!'(': ~:¡J¡):¡:m >:::\I.I.! ;:~;;!9.H, ... ''''''.><.';' Printed: 9/2/2003 3:24:48 PM ~E: 2P-422A Annular Disposal Application ) Subject: RE: 2P-422A Annular Disposal Application Date: Wed, 22 Oct 2003 09: 11 :28 -0800 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> Tom, Here are the recalculated pump in pressures with some comments for the wells in question. (Did you want them in an excel spreadsheet ?) 2P-417: 14.3 ppg 2P-422: 15.2 ppg (unchanged as the difference between the correct and incorrect TVDs was so small) 2P-441: 17.2 ppg. This "new calculated" pump in pressure is greater than fhe or~inal FIT of 16.2 ppg. This is attributed to the fact that an intermediate casing string was run on this well due to a V{ell con!rol problem. This resulted in a shoe (and cement) approximately 1500 ft TVD higher than any of the other wells drilled on Meltwater. We conclude that the formations exposed on the other wells, including our candidate well 2P-422, are isolated in the case of 2P-441. Regards Philip -----Original Message----- From: Tom Maunder fmailto:tom maunder@admin.state.ak.usl Sent: Wednesday, October 22,20038:11 AM To: Hayden, Philip Subject: Re: 2P-422A Annular Disposal Application Philip, With regard to the "new calculated" pump in pressures for 2P-417, 2P-422 and 2P-441, would you please provide them?? Thanks, Tom Maunder "Hayden, Philip" wrote: > Tom, > > In response to your comments: > ./ > For the pump in test for well 2P-420 I must apologise for not having > made sure that the sheet had been correctly filled in. Your calculation > of 14.2 ppg EMW had been previously confirmed by us but the sheet had > not been corrected. / > ../ J v > For wells 2P-417, 2P-422 and 2P-441 the incorrect TVD was used for > calculating the EMW for injection at the shoe. This had been noted by us > and the corrected EMW for injection at the shoe had been determined and > found to be, in all cases, lower than the original injection pressure at > the initial leak off or formation integrity test. We did not amend these > files before sending them on to you as they are part of the official 1 of 3 1: t'.'~\> pot:'-\. c~ -\- ~ '\ ~ f\ ~ , ~ \) ~W\ <J..V \,\~~~\'C:)f'\ "~Þ\ c;.~'o~, \kJ' \~CC~ "> é) ~ -\ "t: {' \1", \ \ ~ '~~'~ ~(: ~ ap...\..\,-\\ \ è1\>-,",~\ d~_LI aÿ '\ ð~ -L\d') , ð?-~d{) . ~,,- L -- -- \ \\\ \ ~(( \<1 ~, :> ~<i: \ ,~ ~ ~ ð ---: . L c:J r~\.)'~~~' !Y<.Cê. '" c:.. W\C) \;)<! ~ -\0 ~ r€.......c. ~ "\- <'\ ~ \,,~ \ ~, 1\..,t SCt. ,,-\- -\--0 -\. h t"\T< c; ~ ~\ \ c)" \).J Co ~ \ ()~) ""':'ú.' ù.~'f pc:C-\.\ 'VC' \).)<ë\.1 ~:, \~~ , 1r2 9)tt1 l'D/ ..0 Id() 10/22/2003 9:59 AM ~E: 2P-422A Annular Disposal Application ) > files. This would have lead to two different sets of data for these > wells and we felt this could be potentially more confusing. On the other > hand we recognise now that we should have brought this to your attention > in our initial correspondence. We will be sure to do so in the future. > > For well 2P-431 we have been unable to locate any record of a pump in > test after the initial leak off test was performed. We do know that this > annulus has been freeze protected and also that methanol has been pumped > down it to remove a hydrate plug but accurate pressure information is > lacking. However, due to its location, between wells 429 and 441 we are > confident that its behaviour with respect to a pump in test is similar > to these wells. > > I hope this note adequately addresses your comments and questions. If > there is anything else please let me know. > > Regards > > PhHip > > -----Original Message----- > From: Tom Maunder (mailto:tom maunder@admin.state.ak.usl > Sent: Monday, October 20, 2003 9:07 AM > To: Hayden, Philip > Subject: Re: 2P-422A Annular Disposal Application > > Phil, > Here are my further comments/questions on the 2P-422A application. I > look > forward to your reply. > Thanks. > Tom Maunder, PE > AOGCC > > On the 2P-420 pump in test, the calculation has not been done. TVDs > have > not been entered. Using the 550 psi maximum pressure and the shoe tvd, >1 > calculate 14.2 EMW. The EMW of the sustained pump in pressure would be > slightly lower. > > On the pump in test of 2P-417, the calculation does not use the tvd of > the > rathole at the surface casing shoe. Using 2430' tvd, the EMW calculates > to > 14.2 which is in agreement with the calculation for 2P-420. > > Tom Maunder wrote: > > > Hi Phil~ > > Welcome back. I was looking at the application and I have a couple of > > questions. Please note that I am not finished with my review of the > > packet. This first note will allow you to capture my eddress. ) 2of3 10/22/2003 9:59 At\ :E: 2P-422A Annular Disposal Application ') ) » > > My questions/comments are: » > > On the pump in plot for 2P-422ST dated 4/22/02, the TVD used in the > > calculation is not the same as done on the initialleakoff dated > > 2/20/02. Why the difference?? » > > The TVDs on 2P-441 also are different. In particular the pump in TVD > is > > listed as the mid point between the top of cement and surface shoe. > All > > EMWs should be referenced to the surface shoe. » > > There is no pump in test for 2P-431. » > > You have made the appropriate tvd change on 2P-429. » > > Tom Maunder, PE > > AOGCC 3 of 3 10/22/2003 9:59 A~ ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2P-431 :: Contains the following: I LD\VG Compact Disc (Includes Graphic Image HIes) I LD\VG lister summary 1 blueline -MPR Measured Depth Log 1 blueline - MPR TVD Log ) ó/oa-05;S ,.:1. BAKER HUGHES Anchorage GEOScience Center LAC Job#: 275478 Sent B~orel Received ~ .fh ( 1 Qp°fA~ ..J Date: May 8, 2003 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 MAY 09 2003 ~I:::::::~::::~:~:' immmj¡iîÎiiiiíihi" !~~ .,..!~ ':~~':'~'~:;' ','" !~" . . . , . . . :;:~~ . . . , . :~':,;' , . . . , '11.... '.~I~ ""~', l~~~~~~~~J:~~~ï~~~~~~. I~=" ::: ! I ~ ¡ v.f.......";,,,,,, 1 5 'I i -'" i ~ ¡ j liî;:~j~:~':::;: e~~j1~~~~~~:~i~~~:~: ¡~]I~ ¡~ """"" ..".. Alaaita 011 & Gas Cons. Commieeion :: Anchorage l~'.~.....LL........... Schlumbel'gel' Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 1Y-27 1 A-OS 2F-08 2N-321 A 2P-451 2N-331 2A-13 2P-431 1Y-06A 1 G-05 1 H-04 1R-16 1Y-01 1 R-1 0 1G-02 1Y-08 10-03 Well Job # Log Description I '1.2, -l~'?L':ñ;') PRODUCTION PROFILE f~/-J04 LDL j '4 -();). } LDL / '6 -IÎ-~ INJECTION PROFILE ~~ -f}{) 'I NOISE LOG f ~-ll 1 INJECTION PROFILE I 5- ILJ'--I PRODUCTION PROFILE a~ -05 ~ NOISE LOG WITEMP I C¡ 7- 134 PRODUCTION PROFILE / ~-OdO INJECTION PROFILE / ~ -/O:~ INJECTION PROFILE J '~-I,S--~ PROD PROFILE W/DEFT l 3-0 ~ 0 INJECTION PROFILE / g1.. -oq 0 INJECTION PROFILE J 'i( d -I,~ INJECTION PROFILE /){3-0f;; . INJECTION PROFILE f Î q/(J LJ PROD PROFILE WIDEFT Date 11/14/02 10/26/02 11/15/02 10/29/02 11/03/02 10/28/02 11/16/02 10/31/02 10/30/02 11/18/02 11/19/02 11/22/02 11/25/02 11/21/02 11/17/02 11/08/02 11/09/02 5IGC~(~ DATE: 12/04/02 NO. 2579 Company:. Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL -/ Sepia CD Color 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 - $~~,~.~ ''i>. J1t::f""'~ !b# ¡b""" ¡¡ ~ 1 \ . t~ ~ F { '\ \l..""" \«;:,J ~- ~ '~f ~;0'; ~r~' DEC 1 () 2.002. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. . .' ¡~ast\~ iJii ë£ l~a~- ~:~ns, (;orn~-'1!~i~( Anch~-Wi{'; Se_llIII_erger NO. 2082 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth 05/16/02 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 Sepia 1 C- 119 AOJ-l, DRIFT & TAG 04/14/02 1 1 1 C-133 ÇN)/-O 7 PRESSURE/TEMP LOG 04/14/02 1 1 1 C- 133 ..v INJECTION PROFILE 04/14/02 1 1 1 D- 1 09 /q 7-:::J~S STATIC BOTTOM HOLE PRESSURE 04/11/02 1 1 1 D-119 aDJ-J~9 STATIC BOTTOM HOLE PRESSURE 04/11/02 1 1 1 D- 132 q?-l;)') TEMPERATURE WARMBACKS 04/18/02 1 1 1 D- 132 ~ INJECTION PROFILE 04/18/02 1 1 1 R-35 dD}-dlO PRESSURE TEMPERATURE 04/21/02 1 1 2D-02 I'¡q-I'SJ PRESSURE-TEMP STATIONS 04/16/02 1 1 2P-431 aDd -05 ~ PERF RECORD/STATIC SURVEY 04/19/02 1 1 2T-39 ~1-/R'3 PRODUCTION PROFILE 04/23/02 1 1 3B-14 / 'S-oa4 PRESSURE/TEMP LOG 04/15/02 1 1 3C-15 J ~5"'~Df) PRESSURE/TEMP 04/13/02 1 1 ,- SIGN~ {J. (1f!~ ') DATE: Please sign and return one copy of this transmittal to Sherrie at the åbove address or fax to (907) 561-8317. Thank you. Kuparuk CD Color RC:t::IVED t..~,.,'y' 1 -; 2002. 1.-'. I AJaskaOü& Gas Cons.Commis8ton Anchorage ) ) ~ 'rom "". PHilliPS Alaska, Inc. U A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 31,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2P-431 (202-053) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater well 2P-431. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sincerely, ~~ ~ \~ R. Thomas Greater Kuparuk Team Leader P AI Drilling RECEIVED JUN 0 5 2002 RT/skad Alaska Oii & Gas Gons. CommiSSIon Anchorage OR\G\N~\L ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address """"'.",, 'r'.',/.~ P. O. Box 100360, Anchorage, AK 99510-0360:,1~~~ 4. Location of well at surface r'" ""ë--"'-" ,I ~fi r,J ~¡ 943' FNL, 1914' FWL, Sec. 17, T8N, R7E, UM'," COi\~~E!ION ! (ASP: 443874,5868935) Is ," '.' , -.,~,.;,~ At TO~ Producing I~terval >:;,,,I.( /lJ:},o~ - -'~~:"~"»~'~;I,~.;"'rJr. 2356 FNL, 1526 FWL, Sec. 20, T8N, R7E, UM~, Vt~"",,"r"",,' .~ (ASP: 443458, 5862245) " At Total Depth ~ ---.,.A1i.~._-- ~ 2464' FSL, 1516' FWL, Sec. 20, T8N, R7E, UM \',-",~.~;...""..,,,,.,,,,~J (ASP: 443433, 5861785) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 254' AMSL ADL 389058 , ALK 4998 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., ~sp. Or A~nd. March 28, 2002 April 7, 2002 April P!"2002 ,IS]) 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 9685' MD 15823' TVD 9530' MD 1 5746' TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res/Den/Neut 23. 1. Status of well Suspended 0 Service 0 Abandoned 0 Classification of Service Well 7. Permit Number 202-053 1 8. API Number 50-1 03-20417-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2P-431 11. Field and Pool Meltwater Oil Pool Kuparuk River Field 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set Land nipple @ 509' 16. No. of Completions 1 21. Thickness of Permafrost 1390' GRADE B L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 115' Surface 2988' Surface 8828' 8828' 9655' CEMENTING RECORD 29.6 bbls AS 1 365 sx AS III Lite, 229 sx LiteCrete 320 sx Class G w/GasBlok AMOUNT PULLED CASING SIZE WT. PER FT. 62.5# 29.7# 15.5# 9.3# HOLE SIZE 16" 42" 7.625" 9.875" 8.5" 8.5" 5.5" 3.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 9290' - 9300' MD 5624' - 5629' TVD 6 spf (included above) 3.5" cement plug @ 8869' TUBING RECORD DEPTH SET (MD) 8803' PACKER SET (MD) N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9290' .. 9300' placed 308M# behind pipe, 100 ppa on perfs 26. 27. Date First Production May 4, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for OIL-BBL GAS-MCF 2535 GAS-MCF 5/6/2002 Flow Tubing press. 308 psi 28. Test Period> Calculated 24-Hour Rate> 34 hours Casing Pressure 1584 3460 OIL-BBL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A W A TER-BBL 291 W A TER-BBL CHOKE SIZE 100 OIL GRAVITY - API (corr) no available GAS-OIL RATIO 733 RECE'VED JUN 0 5 2002 ka Oil & Gas Cons. commission A\as" Anchorage Form 10-407 Rev. 7-1-80 0 R~"GTÎ\J Ä1:E SIDE R B 0 M S B Fl 6 2002 Submit in duplicate JUN c, :' 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. T3 T3.1 T-2 8906' 8714' 9396' 5428' 5330' 5678' Annulus left open - freeze protected with diesel. RECEIVED ,JUN 0 5 2002 Alaska Oil & Gas Cons. Comm1ssiøn AnchoraQ9 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Pat Reilly 265-6048 Signed~ \ ~ ~ Randy Thomas - Title Kuparuk Drilling Team Leader Date ç( 3 t ro'{. Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ""'-"'1 r, r I I ~...j I ~j t '\ ~ n ;' I~ ~. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 3/27/2002 08:00 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 13:30 13:30 - 18:00 ) ) PHILLIPS ALASKA INC. Operations Summary Report 2 P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 . ~Sub Hours Code Code Phase 2.00 RIGMNT RGRP MOVE 1.00 MOVE OTHR MOVE 1.00 DRILL OTHR MOVE 1.50 DRILL RIRD RIGUP 4.50 DRILL RIRD RIGUP 18:00 - 23:00 5.00 DRILL RIRD RIGUP 23:00 - 00:00 1.00 DRILL RIRD RIGUP 3/28/2002 00:00 - 00:30 0.50 DRILL OTHR RIGUP 00:30 - 01 :00 0.50 DRILL SFTY SURFAC 01 :00 - 03:30 2.50 DRILL PULD SURFAC 03:30 - 04:00 0.50 WELCTL BOPE SURFAC 04:00 - 05:00 1.00 DRILL CIRC SURFAC 05:00 - 07:00 2.00 DRILL DRLG SURFAC 07:00 - 07:30 0.50 DRILL TRIP SURFAC 07:30 - 13:30 6.00 DRILL DRLG SURFAC 13:30 - 13:31 3/29/2002 00:00 - 09:00 0.02 DRILL DRLG SURFAC 9.00 DRILL DRLG SURFAC Page 1 of7 Start: Rig Release: Rig Number: 3 Spud Date: 3/29/2002 End: Group: 3/27/2002 Description of Operations Start to move off well, problems w/ steering hydraulic system, troubleshoot & repair. Move diverter from 2P-441 to 2P-431 w/ cran e. Unable to move w/ loader. Complete level up rig, Rig accepted @ 1100 hrs. R/u handy berm, spot in cellar box. Nu diverter/ diverter line. x/a tds pipe grip per from 3.5 to 4". Spot in High Line Traile r. Ru solids control van. Service tds, xo savor sub, calibrate torque, ru high line power, set up floor for handling 4" d p. Load shed & pu / stand back 3.5" spiral wei ght & 4" dp. Off load mud to pit & load bha into shed. Spud meeting. Discuss shallow gas / warnin g signs / diverting / well plan / lessons lear ned/ Good meeting PJSM Pu bit & bha. Up load Mwd-Lwd. Conduct accumulator draw down test. Repla ce leaking 4 way shuttle valve. Continue w/ acc. checks. Run diverter test. Rih to tag cmt @ 97', filling hole & checking for leaks as run in. Drlg cmt & out of cond uctor @ 115'. Drlg unconsolidated surface materal 115 - 1 90' . Pooh & w/ 2 jts hwdp, replace w/ additional bha tools. Drlg 190 - 432', increasing flow rate to 500 gpm. ECD in the 11.5 ppg range while pump rates low, as rate increased ecd decreased to ?1 0.2 ppg. @ 320' started moving azmu th toward intended track - w/ high flow rate unable to develope any inclination, decread ed pump rate to 380 gpm to direct hole in sh ort slides. Continue to dir drlg 432 - 1077' [1068' tvd]. After 600' able to steer & keep flow rates i n the 450 - 500 gpm range. Ecds in the 10. 2 - 10.6 ppg range. Parameeters: Wob 6 - 10 k Ibs, Pump P. 1950 psi / 477 gpm. Tor que off / on bottom 70 rpm = 1950 /1550 ft -Ibs. Ecds 10.2 - 10.6 ppg w/ a 9.6 ppg stat ic weight. No connection / hole problems / mud losses. ADT = 14.6 hrs = 5.5 slide + 9.3 Rot Dir Drlg 1077' [1068 tvd] - 1546' Parameters : Wob 6 - 15 kl bs, Torque [70 rpm] on / off bottom = 2777 / 2400 ft-Ibs, Pump Pressur e 2100 psi /480 gpm. Ecds in the 10.5 ran ge ppg ?2. Printed: 4/29/2002 2:22:48 PM ~~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) PHILLIPS ALASKA INC. Operations Sum maryReport 2P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date From-To Hours Code Sub Phase Code 3/29/2002 09:00 - 10:00 1.00 DRILL CIRC SURFAC 10:00 - 12:00 2.00 DRILL TRIP SURFAC 12:00 - 13:00 13:00 - 14:30 14:30 - 00:00 3/30/2002 00:00 - 16:30 16:30 - 18:00 18:00 - 21 :00 1.00 RIGMNT RSRV SURFAC 1.50 DRILL TRIP SURFAC 9.50 DRILL DRLG SURFAC 16.50 DRILL DRLG SURFAC 1.50 CASE CIRC SURFAC 3.00 CASE OTHR SURFAC 21 :00 - 23:00 2.00 CASE CIRC SURFAC 23:00 - 00:00 1.00 CASE OTHR SURFAC 3/31/2002 00:00 - 03:00 3.00 CASE OTHR SURFAC 03:00 - 04:00 1.00 CASE OTHR SURFAC 04:00 - 07:00 3.00 CASE RURD SURFAC 07:00 - 12:00 5.00 CASE RUNC SURFAC 12:00 - 15:00 3.00 CEMENTCIRC SURFAC Page 2 of? Start: Rig Release: Rig Number: 3 Spud Date: 3/29/2002 End: Group: 3/27/2002 Description of Operations Cir / cond /sweep hole for short trip. Trip to bit, pulled 15k Ibs over @ 580'. N ote Clay Samples: collected 2 from shaker & 1 from bit & motor. Neither of great conce rn. Rig / tds service. Rih to 1456', precautionary wash ream to td of 1546', no fill detected. String took some minor weight between 500 & 650'. Dir Drlg 1546' - 2116' [1913' tvd] Parameter s: Wob 6 -15 kl bs, Torque [70 rpm] on / of f bottom = 2700 / 2400 ft-Ibs, Pump Pressu re 2200 psi /2210 gpm. Weights: Up / dwn / rot = 62 /63 / 63k Ibs @ 70 rpm. Ecds in t he 10.5 range ppg ?2. ADT = 12.8 hrs [ 6 .5 slide + 6.3 rot] ADT Bit #1 total = 27.4 = slide 11.8 + 15.6 rot hrs 2P - 415 Injecti on down 12 hrs due to transfeer pump failur e. Dir Drlg 2116' [1913' tvd] -3005' [2389' tvd - 7.625" csg pt] Parameters: Wob 10 -30 kl bs, Torque [70 rpm] on / off bottom = 31 00 /1900 ft-Ibs, Pump Pressure 2800 psi / 500 gpm. Weights: Up / dwn / rot = 64 /64 / 64 k Ibs @ 70 rpm. Ecds in the 10.3 rang e ppg ?2. 24 hr total ADT = 11.6hrs 9.3 rot + slide 2.3 hrs Total Bit #1 ADT = 3 9 = 24.9 rot + 14.1 hrs Cir 3x bottoms up, sweep hole on last b u [c lean returns throughout]. Reciprocate / rota te pipe slowly. Short trip to 1300', pulled free off bottom & 10 -15k Ibs over 1590-1525'. Clean to 13 00'. Rt to 2965', mu tds & rotate minimum r ate to td [fill detection] no fill. Clean trip in. Cir / pump sweep / Prepare to pooh for csg. Pooh for 7.625" csg. Continue to Pooh to Iwd / mwd tools. Down load Iwd / mwd tools & Id bha not nece ssary for next hole section. PJSM. Service rig & TDS. Ru csg crew. 7.625" x 29.7 ppf x Bt&c mod x L-80 Csg ops Pu / Mu shoe track [2 shoe jts] Weatherfo rd super seal shoe & collar, Baker locking f rom float collar top connection down. Run a total of 68 jts csg Installing Tam Diverter Collar @ 991'. Land out @ 2990'. Used 12 bow type centralizers: one 10' up on jt # 1 & one floating on the next 11 jts, top centra lizer @ 2384'. Cir Con 6 bpm / 350 psi. Reduce YP from 1 Printed: 4/29/2002 2:22:48 PM ) ~~ ~r~u. , , , ~ ~ ) PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date From - To Hours Code Sub PhaSe Code 3/31/2002 12:00 - 15:00 3.00 CEMENTCIRC SURFAC 15:00 - 15:30 0.50 CEMENT SFTY SURFAC 15:30 - 16:00 0.50 CEMENTOTHR SURFAC 16:00 - 18:00 2.00 CEMENT PUMP SURFAC 18:00 - 19:00 1.00 CASE NUND SURFAC 19:00 - 00:00 5.00 CASE NUND SURFAC 4/1/2002 00:00 - 01 :30 1.50 WELCTL NUND PROD 01 :30 - 02:00 0.50 WELCTL NUND PROD 02:00 - 04:00 2.00 WELCTL NUND PROD 04:00 - 08:30 4.50 WELCTL NUND PROD 08:30 - 09:00 0.50 WELCTL BOPE PROD 09:00 - 11 :30 2.50 WELCTL BOPE PROD 11 :30 - 12:30 1.00 WELCTL BOPE PROD 12:30 - 13:00 0.50 DRILL OTHR PROD 13:00 - 14:00 1.00 DRILL TRIP PROD 14:00 - 15:00 1.00 DRILL TRIP PROD 15:00 - 17:00 2.00 DRILL DEQT PROD Page 3 of7 Start: Rig Release: Rig Number: 3 Spud Date: 3/29/2002 End: Group: 3/27/2002 Description of Operations 8 to 14, no change in mw of 9.6 ppg. Recipr ocate csg 15' / 30 sec. Weights up / neu / dwn = 93k / 85k / 75k Ibs PJ S M Prime up cmt trucks. Dowell cmted 7.625" csg as follows: Pumpe d 40 bbl CW 100 chem wash [pt lines to 350 0 psi] @ 400 psi /5.6 bpm. Drop botttom p lug. Then 40 bbl 10.5 Mudpush XL [wI red d ye] weighted spacer @ 400 psi / 4.4 bpm. Pump 365 sx [277bbl] of lead ARTICSET liT E CMT B-809 [ 10.7 ppg, wtr = 19.4 gal/sx, 4.28 cft / sx, ASL Blend; adds. = S001 = 1 .5, D046 = .60, D065 = .5, D124 = 43.1, D 079 = 1.5, D053 = 30.0 - all % BWOC. Pres s / rates max - min - avg = 530 - 330 - 400 psi, 5.8 - 5.0 - 5.5 bpm. FOLLOW W/ 220 s x [94 bbl] tail LiteCRETE cmt [12 ppg, wtr = 8.122 gal / sx, yield = 2.4 cft / sx.-- Dry a dds: D065 = 1.0% , D046 = .60%, D079 = . 5%: all BWOC. Press / Rates max - min - a vg = 625 - 450 - 500 psi / 5.5 - 2 - 5.5 bpm. Drop top plug & displace w/ 133.2 calculat ed bbl 9.6 ppg mud. Press / rates max - mi n - avg = 750 - 625 - 700 psi / 5.8 - 2.4 - 5. 5 bpm. Plug hit 10 strokes early @ 1737 st ks, bumped from 750 to 1500 psi holding for 15 min, bled off, plugs held good. Full re turnes throughout. 143 bbl [179sx] 10.7 ppg cmt to surface. CIP @ 1800 hrs. Clean out diverter, rd cmt equipment. Back out Idg jt, rd diverter line, nd riser & continue to nd diverter. Continue to ND diverter system. Spot well hd spool in cellar. Ldg 7.625' csg hanger. Install csg & tbg hd Test to 1000 psi / 10 min good. NU 11' x 5k psi BOP, change upper & lower pipe rams to 4" & nu riser. Mu kill & choke Ii n e s. Function test rams & annular preventer. Test bope 250 low / 3500 psi high. annular t 0 250 / 3000 psi. Test floor equip as above Rd bope test equipment. Ru & calibrate Epoch block heigth sensor. Pu bit #2 [6.75"] & mwd / Iwd tools. Up loa d tools. Continue to rih [picking up bha] w/ bha to s hallow test point. Unable to obtain shallow test on mwd / Iwd t ools. Pull tool to floor for port access. Co nsult BHI Techinacal support. Traced to sur Printed: 4/29/2002 2:22:48 PM ~þ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/1/2002 4/2/2002 4/3/2002 ') ) PHILLIPS ALASKA INC. Operations Summary..Report 2P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 From -To Hours Code Sub Phase Codë 15:00 - 17:00 2.00 DRI LL DEOT PROD 17:00 - 17:30 0.50 DRILL DEOT PROD 17:30 - 21 :30 4.00 DRILL TRIP PROD 21 :30 - 22:00 0.50 DRILL REAM PROD 22:00 - 22:30 0.50 DRILL CIRC PROD 22:30 - 23:00 0.50 CASE DEOT PROD 23:00 - 00:00 1.00 RIGMNT RSRV PROD 00:00 - 01 :00 1.00 DRILL OTHR PROD 01 :00 - 01 :30 0.50 DRI LL PROD 01 :30 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 00:00 00:00 - 11 :00 11 :00 - 12:00 12:00 - 15:00 0.50 DRILL 2.00 DRILL PROD PROD 1.00 DRILL PROD 19.00 DRILL DRLG PROD 11.00 DRILL DRLG PROD 1.00 DRILL CIRC PROD 3.00 DRILL WIPR PROD Page 40f7 Start: Rig Release: Rig Number: 3 Spud Date: 3/29/2002 End: Group: 3/27/2002 Description of Operations face coding problemr - correct same. Upload tools & trip to shallow test point, ob tain test. Tih, picking pu 4" dp, rot through tam collar to tag cmt @ 2887. Wash / ream to float collar @ 2902'. Circulate / cond . Test csg to 2500 psi / 30 minutes, initial pr essure = 2550, final 2530 psi. Cut & slip drlg line - incomplete rpt time. Complete cutting drlg line. Drlg / wash out cmt to float collar, drlg plug s. collar, shoe track cmt & float shoe @ 299 0'. Clean out 9.875" hole to 3005. Drlg new hole for fit / lot. 3005 - 3025'. Circulate bu, elect to x-out mud due to err at ic cmt contamination & un- equal rheology / weights in pits. Disp to 10.0 ppg new mud. Pull Up into csg. Conduct FIT w/ 10 ppg mud in hole. TVD = 2399'. Using bop test pump imposed 750 ps i w/ 27 gallons of fluid. Pressure bled down to 700 psi & held stable of a total of 10.5 minutes. There was no break over in the pr essure build up plot. Bled back 18 gallons of mud. RIH to 3025. Calculations EMW = 10 ppg + 700 psi / { .052 X 2399'} = 15.6 ppg Prior to the F.I.T. the surface system was tested to 4650 psi by bring the test up to speed 2 times [4 seconds each cycle] to i mpose the pressure between the pump & the low torque valves on the DP & annulus side There was no leak off. Dir Drlg 3025' [2399' tvd] - 4276' [tvd = 305 7'] Parameters: Pump P. 2600 psi @ 295 gp m, Bit wt 4 -10k Ibs, Troque on / off td = 4k / 3k ft-Ibs 65 rpm, weights up/dwn rot = 69 /67 / 65k Ibs. Clean ecd 11.4, drlg ecd's in the 11.8 ?2 ppg range. ADT = 15.6 = rot 15 + slide .6 hrs. Dir drlg 4276' [3057'tvd] - 4999'. Parameter s: P. Pressure psi /0 = 3050 / 294 gpm, Bi t wt = 4/ 10 k Ibs, Torque on / off bottom = 4150 / 3400 ft-Ibs[ 70 rpm], Wts up / dwn / rot = 74 / 70 / 65 k Ibs. Flow ck @ 4760' no flow. ECDs: Clean hole 11.4 ppg, dril ling 11.8ppg ?2 ppg. Static mw = 10.0 ppg BG gas = 2 - 4 u Cir / sweep / cond for short trip. Sweep bro ught up small amt of debris, sd & monitor w ell static for 15 minutes. Short trip to 2975' [tight spot @ 4630', pull ad 8k Ibs over] rih to 4966', cir / rot to td, Printed: 4/29/2002 2:22:48 PM ~~ ~' '-¡:fj:¡ ~ ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) PHILLIPS ALASKA INC. OperatiónsSummary Report 2P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Page 50t 7 Start: Rig Release: Rig Number: 3 Spud Date: 3/29/2002 End: Group: 3/27/2002 Date From - To Hours Code Sub Phase Code 4/3/2002 12:00 - 15:00 3.00 DRILL WIPR PROD 15:00 - 00:00 9.00 DRILL DRLG PROD 4/4/2002 4/5/2002 4/6/2002 00:00 - 12:00 12:00 - 00:00 00:00 - 03:00 03:00 - 06:30 06:30 - 00:00 00:00 - 09:30 09:30 - 12:00 12:00 - 15:00 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 3.00 DRILL DRLG PROD 3.50 DRILL WIPR PROD 17.50 DRILL DRLG PROD 9.50 DRILL DRLG PROD 2.50 DRILL CIRC PROD 3.00 DRILL WIPR PROD Description of Operations no detected fill. Dir Drlg 4999' md - 5664' md, tvd = 3757'. PP / Q = 3040 psi / 301 gpm. Torque off / 0 n bottom @ 70 rpm = 5.2 / 4.1k ft-Ibs. Diff pump press on - off bottom = 300 psi. Pu / so / rot [70 rpms] weights = 83 / 73 / 75k I bs. Bit weights 5 - 8k Ibs. Precautionary s weeping hole w/ 30 bbl hi vis sweeps [per 5 00'], recovering small increase in amt of m aterial. Maintaining ecd in the 11.5 ppg ? .2. 24hr ADT = rot 15.2 + slide .9 = 16.1h r ADT total bit #2 = rot 30.3 + slide 1.5. = 31.8 hrs BG gas = 2 - 4 u Gas after sh ort trip = BG 3u, BU 33u. Dir drlg 5654' [3757' tvd] -- 6485' Paramete rs: Pump 300 psi @ 295 gpm / Bit wt 2 - 6 k Ibs / Torque on - off bottom 6900 - 6400 f t-Ibs / PU - SO - Rot weights 90 - 72 - 80 k Ibs @ 70 rpm / Ecd's in the 11.6 range w / 22 yp Dir drlg 6485 -- 7148' [4519' tvd] Paramet ers: pump 2990 psi - 295 gpm / bt wts 4 - 7 k Ibs / Torque on - off bottom 6.8 - 5.3 ft-Ib s @ 70 rpm / Weights pu - so - rot 93 - 83 - 87k Ibs ECDs in the 11.18 ppg range w/ yp of 12 to 14. 24 hr ADT = 17.3 = 12.9 r ot + 4.4hrs slide Bit #2 ADT = 48.1 = 42.2 r ot + 5.9hrs slide Dir dig 7148' [4519' tvd -- 7240'. Parameter s: pump 2800 psi -- 298 gpm / Bit wt 4 - 1 5k Ibs / Torque on -- off bottom 6.2--5.3k f t-Ibs 80 rpm / Pu So Rot weights 95 87 -- 88K Ibs @ 80 rpm. Ecd's in th e 11.3 ppg range. Short trip to 4950'. Good trip Dir dig 7240' -- 8348' [5153' tvd]. Paramet ers: pump 2910 psi -- 300 gpm / Bit wt 4 - 1 Ok Ibs / Torque on -- off bottom 7.15 -- 5.35 k ft-Ibs @ 80 rpm I weights pu -- so -- rot = 102 -- 99 -- 95k Ibs @ 80 rpm Ecds in t he 11.1 to 11.4 range. w/ static mw of 9.6 + ppg. 24hr adt = 14.5 = 11 rot + 3.5hrs bi t #2 adt = 62.6 = 53.2 rot + 9.4hrs slide Dir Drlg 8348' [5153' tvd] -- 8850' paramete rs: Pump 3000 psi -- 300 gpm / Bit weights 5 - 10k Ibs / Torque on off bot 8 -- 6.7ft-lb s 70 rpms / PU -- So - Rot 70 rpms / weight s 109 - 96 - 100k Ibs. Ecds 11.2 ppg ?2 Gas - BG 2-4u w/ trace of CG. Cir / sweep / cond mud for short trip. Monit or well stratic 30 min @ end of cir. Short trip up to 2950'. Pulled 5k Ibs over @ ? 8286'. Printed: 4/29/2002 2:22:48 PM ) ('~~ @! ) PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date From - To Hours Code Sub Phase Code 4/6/2002 15:00 . 17:00 2.00 RIGMNT RSRV PROD 17:00 - 20:00 3.00 DRILL WIPR PROD 20:00 - 21 :30 1.50 DRILL CIRC PROD 21 :30 - 00:00 2.50 DRILL DRLG PROD 4/7/2002 00:00 - 13:30 13.50 DRILL DRLG PROD 13:30 - 15:30 2.00 DRILL CIRC PROD 15:30 - 20:30 5.00 DRILL TRIP PROD 20:30 - 23:30 3.00 DRILL TRIP PROD 23:30 - 00:00 0.50 WELCTL BOPE PROD 4/8/2002 00:00 - 04:30 4.50 WELCTL BOPE PROD 04:30 - 10:00 5.50 DRILL TRIP PROD 10:00 - 13:30 3.50 DRILL CIRC PROD 13:30 - 18:00 4.50 DRILL TRIP PROD 18:00 - 19:30 1.50 DRILL OTHR PROD 19:30 - 22:00 2.50 WELCTL OTHR PROD 22:00 - 00:00 2.00 CASE OTHR PROD 4/9/2002 00:00 - 01 :30 1.50 CASE RUNC PROD 01 :30 - 02:00 0.50 CASE SFTY PROD 3/27/2002 Start: Rig Release: Rig Number: 3 Page 6öf? Spud Date: 3/29/2002 End: Group: Description of Operations Clean rig floor. Cut drlg line & Ser rig & TD S. Monitor well - no flow. Rih, washing {200 gpm] & reaming {precauti onary] 60' to TD, no detectable fill. Stage up pumps 60/90/120 spm over 1.5 hr. 11.0 ecd Targeted for Q increase. BG G = 2 - 4 units w/ Trip gas of 15u Dir Drlg 8850' -- 8880' [5413' tvd]. Paramet ers: Pump - 3000 psi @ 300 gpm / Bit wt 4- 9k Ibs / Torque on - off bot 8850 - 7300 ftr-I bs / Weights pu - so - rot = 108 - 95 - 100k Ibs @ 70 rpm. Ecds 10.6 ppg range. BG G = 7 unites, trace connection 24 hr adt = 7.8 = 5.1 rot + 2.7hr slide Bit #2 adt = 70. 4 = 58.3 rot + 12.1hr slide. Dir drlg 8880' [5413'tvd] -- 9685' [5786' tvd] Parameters: Pump 3000 psi -- 300 gpm / B it wt 4 --10k Ibs / Torque on --off bottom @ 70 rpm 8.85 -- 8k Ibs / pu--so--rot weights 1 13 -- 98 -- 105 k Ibs / Ecds in the 10.5 ran ge w/ 9.6 static mw. Passed through targe t tvd of 5552' [9145' md] 13.5' west. Back ground gas 7 or less, no conn gas, highest gas reading from 9176' md [Bermuda top @ 8903' md] 184u 24 hr adt = 8.2 = 6.8 rot + 1.4 hrs slide Bit #2 adt = 79.4 = 65.9 rot + 13.5 hrs slide. Cir / sweep hole / monitor Pooh for hole opener run. 1st 500' pulled 3 -5 klbs over randomly & 7k Ibs @ 4917'. Clean floor Dwn load tools & Ld bha. Pull wear bushing, run test plug & testing b ope 250 /3500 psi high low. Incomplete rpt t i me. Complete testing bope 250 / 3500 psi. No r epairs / no failures. Pu / rih hole opener & 3 pt reamer. Good t rip string took no weight on trip in, cir @ 10 w Q last 60' to td, no detectable fill. Cir cond -- sweep hole, spot new mud in bo ttom of hole over 3.5" x 6.75" geometry. Mo nitor well static. Pooh for csg. No over pulls, good trip. Clean floor, ship out bha, pull wear bush & Install test plug. Install 3.5 pipe rams n lower cavity & test PJSM Ru csg crew. csg & rih w/ same eta i I. R/U to running 5.5" x 3.5" csg. Change bails . & csg crew. PJSM on running casing in top cay & 5.5 rams i to 300 / 3500 psi. Pu 3.5" shoe track, 3.5 as per program / csg d Printed: 4/29/2002 2:22:48 PM ~ìPS.~ ~'Þ~~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) PHILLIPS ALASKA INC~ Operations Summary Report 2P-431 2P-431 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 . Date From - To Hours Code Sub Phase Code 4/9/2002 02:00 - 06:00 4.00 CASE RUNC PROD 06:00 - 06:30 0.50 CASE CIRC PROD 06:30 - 09:30 3.00 CASE RUNC PROD 09:30 - 10:30 1.00 CASE CIRC PROD 10:30 - 15:00 4.50 CASE RUNC PROD 15:00 - 15:30 0.50 CASE RURD PROD 15:30 - 19:30 4.00 CASE CIRC PROD 19:30 - 21 :30 2.00 CEMENT PUMP PROD 21 :30 - 00:00 4/10/2002 00:00 - 07:30 07:30 - 16:30 16:30 - 18:30 18:30 - 20:30 20:30 - 23:00 23:00 - 00:00 2.50 CEMENT PULD PROD 7.50 CMPL TN OTHR CMPL TN 9.00 CMPL TN RUNT CMPL TN 2.00 CMPL TN SOHO CMPL TN 2.00 CMPL TN NUND CMPL TN 2.50 CMPL TN OBSV CMPL TN 1.00 CMPL TN CIRC CMPL TN Page7of7 Start: Rig Release: Rig Number: 3 Spud Date: 3/29/2002 End: Group: 3/27/2002 Description of Operations Run 5.5" X 3.5" csing as programed. Filion fly with fill up tool. to 2900' Circulate at 1 bpm 470 psi. Continue running 5.5" X 3-1/2" csg to 5900' Circulate 1.5 bpm @ 600 psi Continue running 5.5" x 3-1/2" csg to 9520'. Tight spot @ 8313' M/U Hanger and landing joint. R.I.H circ do wn Circulate & condition Mud Lower Pv to 15< n a thin mud. Reciprocate & circ. Flush rig mu d lines wI Brine. Pump 5 bbl's CW100 P.T. Lines to 3500 psi. Continue pumping total of 60 bbl's CW100. Followed by 40 bbl's MudPUSH spacer weigh ted to 12.0 ppg. Followed by 62 bbl's (320 s x ) Class 'G' GasBlok cmt at 15.8 ppg slurry . Drop Dart and displaced wI rig pump and 9 .6 ppg clear Brine @ 4.5 bpm slowed rate to 2.5 bpm for last 20 bbl's. Bumped Plug 3.8 bbl early wI 2500 psi. C.I.P. 2107 hrs 4/9/2 002 Float held O.K. RID csg crew and equipment. LID landing jt. Install 5.5" X 11" packoft. PT same to 5000 psi f/ 10 min O.K. Load 3-1/2" 9.3# L-80 Eue tbg in house. Run 277 jt's of 3-1/2" 9.3# L-80 Eue Mod tb g completion as programed wI Seal stem and Jewelry. Baker PBR 8807' to 8828' MD Space out and make up Hanger. Land hgr an d RILDS. Test down tbg to 2000 psi O.K. Dr ain stack. Set 2 way check. NID BOP's Install pack off PT 250/5000 psi 15 min O.K. NIU 3" 5M production tree PT 250/5000 psi 15m in. R/U Kill Manifold PT wI air. Printed; 4/29/2002 2:22:48 PM Date 04/17/02 04/18/02 04/19/02 04/20/02 04/27/02 04/29/02 04/30/02 05/02/02 OS/29/02 ) ') 2P-431 Event History Comment TAG @ 94301 SLM W/2.6811 G. RING. DRIFT W/2.511 X 10' TO 94301 SLM.IN PROGRESS. REPLACED 111 SOV @ 87041 RKB W/111 PETREDAT SIDE POCKET GAUGE. GOOD PT ON TBG/CSG. [GLV, PT TBG-CSG, PRESSURE DATA] PERFORATE 92901-93001 WITH 2.511 HSD, 6 SPF, 60 DEG PHASED, HYPERJET CHARGES AT 3500 PSI SITP, PRESSURE IMMEDIATELY FELL TO 800 PSI. RIH FOR SBHP, AT 929512538 PSI @ 142 DEG, AT 9145' 2499 PSI @ 140 DEG. [PERF] PUMPED INITIAL FRAC. PLACED 308M# BEHIND PIPE, 100% OF DESIGN, 10 PPA ON PERFS, FLUSHED TO COMPLETION. SAW ABNORMAL PRESSURE RESPONSE IN DATAFRAC (PRESSURE DECLINE AND THEN INCREASE, SIMILAR TO OTHER MELTWATER FRACS). ADJUSTED PAD VOLUME DOWN TO 550 BBLS BASED ON DECLINE ANALYSIS. PUMPED BRACKETFRAC, THEN PROPPED FRAC. STAND BY FOR ROAD CONDITIONS. MOVE TO MELTWATER. [STANDBY, WEATHER DAY] PERFORMED A REVERSE FCO TO 9501.11 CTMD, PBTD. WELL FREEZE PROTECTED TO 9501.11 CTMD. LEAVE WELL SHUT IN FOR WIRELlNE TO PREP FOR PRODUCTION. [FCO] TAGGED FILL @ 9295' RKB, EST. 51 FILL. JOB SUSPENDED FOR WEATHER. [FRAC-REFRAC, GLV, TAG] PULLED PETREDAT SPG & SET 5/1611 OV @ 87041 RKB. PULLED CATCHER @ 8770' RKB. [GLV, FRAC- REFRAC] REPLACED CLOGGED OV @ 8704' RKB [GLV, PARAFFIN] Page 1 of 1 5/30/2002 Phillips Alaska, Inc. Drill Site 2P 431 slot #431 Meltwater North Slope, Alaska SUR V E Y LIS TIN G ~ Baker Hughes INTEQ Your ref: MHD <0 - 9685'> Our ref: svy6732 License: Date printed: 10-Apr-2002 Date created: 31-Mar-2002 Last revised: 10-Apr-2002 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 9.252¡w150 26 56.943 Slot Grid coordinates are N 5868934.839, E 443874.087 Slot local coordinates are 942.14 S 1917.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 18.66 Reference North is True North ) ) Phillips Alaska, Inc. 5URVEY LI5TING Page 1 Drill 5ite 2P,43l Your ref: MHO <0 - 9685'> Meltwater,North 5lope, Alaska Last revised: 10-Apr-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R DIN ATE 5 Deg/100ft 5ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 443874.09 5868934.84 120.00 0.00 0.00 120.00 O.OON O.OOE 0.00 0.00 443874.09 5868934.84 200.76 0.70 288.60 200.76 0.16N 0.47W 0.87 -0.13 443873.62 5868935.00 288.45 0.70 300.55 288.44 0.60N 1.44W 0.17 -0.52 443872.66 5868935.45 384.42 0.44 229.89 384.41 0.66N 2.22W 0.72 -0.54 443871.87 5868935.52 474.98 2.55 160.63 474.94 1.465 1.82W 2.68 1.56 443872.26 5868933.39 567.54 5.71 166.26 567.24 7.885 0.04W 3.44 7.87 443873.98 5868926.96 660.04 8.70 172.23 659.00 19.285 2.00E 3.33 19.15 443875.94 5868915.54 753.63 9.58 174.69 751.40 34.055 3.67E 1.03 33.81 443877.50 5868900.76 844.55 10.37 174.34 840.95 49.735 5.18E 0.87 49.39 443878.89 5868885.08 936.11 12.92 178.21 930.62 68.165 6.31E 2.91 67.74 443879.88 5868866.63 1028.60 16.96 181.73 1019.97 91.995 6.23E 4.47 91.54 443879.61 5868842.81 1120 . 17 22.15 186.30 1106.23 122.525 3.93E 5.90 122.15 443877.08 5868812.30 1214 . 11 24.26 187.70 1192.57 159.265 0.60W 2.32 159.07 443872.27 5868775.61 1308.56 25.49 187.35 1278.25 198.645 5.80W 1.31 198.67 443866.77 5868736.27 1401.97 28.56 187.00 1361.45 240.755 11 . 09W 3.29 241.00 443861.16 5868694.20 1497.10 31.20 183.83 1443.93 287.925 15.51W 3.23 288.33 443856.38 5868647.08 1591.69 34.37 183.48 1523.45 339.025 18 .77W 3.36 339.54 443852.74 5868596.00 1686.35 37.00 184.19 1600.33 394.115 22.47W 2.81 394.75 443848.61 5868540.95 1781.85 40.25 185.24 1674.93 453.515 27.39W 3.47 454.33 443843.24 5868481.59 1876.31 42.10 182.43 1746.03 515.555 31.52W 2.77 516.49 443838.64 5868419.60 1971 . 54 45.09 182.43 1814.99 581.155 34.31W 3.14 582.15 443835.36 5868354.03 2066.21 47.90 183.48 1880.16 649.715 37.86W 3.08 650.80 443831.28 5868285.50 2160.93 50.89 184.54 1941.80 721.445 42.90W 3.27 722.70 443825.69 5868213.82 2253.86 53.79 183.83 1998.57 794.805 48.26W 3.18 796.24 443819.77 5868140.50 2348.08 56.87 183.83 2052.16 872.115 53. 44W 3.27 873.71 443814.01 5868063.25 2441.77 58.97 183.83 2101.92 951.315 58.74W 2.24 953.09 443808.10 5867984.09 2538.64 58.89 184.54 2151.91 1034.065 64.80W 0.63 1036.04 443801.42 5867901.40 2632.03 58.54 184.89 2200.41 1113.605 71 . 36W 0.49 1115.82 443794.25 5867821.92 2727.18 59.59 183.13 2249.33 1195.015 77 .06W 1. 93 1197.41 443787.94 5867740.56 2823.18 59.85 181.72 2297.73 1277.845 80.56W 1.30 1280.31 443783.80 5867657.77 2915.40 59.77 181.37 2344.11 1357.525 82 . 71W 0.34 1359.99 443781.04 5867578.12 2952.06 59.68 182.43 2362.59 1389.165 83.76W 2.51 1391.65 443779.75 5867546.49 3008.56 59.24 182.43 2391.30 1437.785 85.82W 0.78 1440.31 443777.32 5867497.89 3102.78 59.68 182.08 2439.18 1518.875 89.02W 0.57 1521.45 443773.51 5867416.84 3197.59 59.94 181.73 2486.85 1600.775 91.74W 0.42 1603.38 443770.16 5867334.97 3292.06 60.38 181.73 2533.86 1682.685 94.21W 0.47 1685.31 443767.06 5867253.09 3387.04 58.36 184.19 2582.25 1764.295 98.42W 3.08 1767.02 443762.24 5867171.52 3481.04 58.10 183.48 2631.75 1844.025 103.76W 0.70 1846.93 443756.29 5867091.84 3576.07 57.83 183.13 2682.15 1924.455 108.41W 0.42 1927.48 443751.03 5867011.46 3671.37 58.01 184.54 2732.77 2005.015 113. 81W 1.27 2008.22 443745.02 5866930.95 3766.06 57.74 184.19 2783.12 2084.975 119. 91W 0.42 2088.39 443738.30 5866851.04 3860.61 57.48 184.54 2833.77 2164.585 125.99W 0.42 2168.21 443731.62 5866771.49 3955.33 57.48 183.83 2884.69 2244.235 131.82W 0.63 2248.06 443725.19 5866691.89 4049.98 57.48 183.83 2935.58 2323.865 137.15W 0.00 2327.86 443719.25 5866612.31 4145.35 57.30 184.54 2986.97 2403.985 143.01W 0.65 2408.18 443712.78 5866532.25 4238.99 57.04 184.19 3037.74 2482.445 149.00W 0.42 2486.84 443706.19 5866453.84 4334.21 57.04 184.54 3089.55 2562.105 155.08W 0.31 2566.71 443699.50 5866374.24 4428.86 56.34 184.19 3141.52 2640.975 161. lOW 0.80 2645.79 443692.88 5866295.42 4523.58 57.66 183.48 3193.11 2720.235 166.41W 1.53 2725.22 443686.97 5866216.22 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level). Bottom hole distance is 7163.02 on azimuth 183.11 degrees from wellhead. Vertical section is from wellhead on azimuth 183.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ J Phillips Alaska¡ Inc. 5URVEY LI5TING Page 2 Drill 5ite 2P,431 Your ref : MWD <0 - 9685'> Meltwater,North 5lope, Alaska Last revised: 10-Apr-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R DIN ATE 5 Deg/100ft 5ect Easting Northing 4618.24 58.71 183.48 3243.01 2800.525 171.29W 1.11 2805.65 443681.48 5866135.98 4713.68 59.50 183.83 3292.02 2882.255 176.51W 0.89 2887.55 443675.63 5866054.29 4807.35 60.56 183.13 3338.81 2963.245 181.44W 1.30 2968.69 443670.09 5865973.35 4902.54 61.44 183.83 3384.96 3046.345 186.49W 1.13 3051.94 443664.41 5865890.30 4997.30 61. 44 183.48 3430.26 3129.405 191.80W 0.32 3135.16 443658.47 5865807.29 5091.98 62.23 183.48 3474.95 3212.725 196.86W 0.83 3218.63 443652.77 5865724.02 5186.62 61.35 181.73 3519.69 3296.025 200.66W 1. 88 3302.02 443648.34 5865640.76 5281.45 61.88 181.02 3564.77 3379.435 202.66W 0.86 3385.41 443645.70 5865557.38 5376.31 60.91 181.02 3610.19 3462.705 204. 14W 1. 02 3468.64 443643.58 5865474.13 5471.69 58.97 180.32 3657.96 3545.245 205.11W 2.13 3551.12 443641.99 5865391.61 5565.31 59.77 181.02 3705.66 3625.795 206.06W 1. 07 3631.61 443640.43 5865311.08 5659.97 60.64 179.97 3752.70 3707.935 206.76W 1.33 3713.67 443639.10 5865228.95 5755.06 59.50 178.91 3800.14 3790.335 205.96W 1. 54 3795.92 443639.27 5865146.55 5849.77 57.39 179.97 3849.71 3871.035 205.17W 2.42 3876.46 443639.45 5865065.86 5944.37 56.78 180.32 3901.11 3950.445 205.37W 0.72 3955.77 443638.65 5864986.46 6038.82 57.39 178.91 3952.44 4029.725 204.83W 1.41 4034.92 443638.58 5864907.18 6133.83 58.18 181.02 4003.09 4110.105 204.79W 2.05 4115.18 443638.01 5864826.82 6228.10 58.27 181.73 4052.73 4190.225 206.71W 0.65 4195.29 443635.47 5864746.72 6323.88 58.62 182.78 4102.85 4271.775 209.92W 1. 00 4276.90 443631.64 5864665.20 6418.09 58.54 185.24 4151.97 4351.965 215.54W 2.23 4357.27 443625.41 5864585.07 6512 . 93 59.24 185.24 4200.97 4432.825 222.96W 0.74 4438.41 443617.38 5864504.27 6606.97 60.21 185.24 4248.38 4513.695 230.38W 1.03 4519.56 443609.35 5864423.47 6701.20 60.82 184.89 4294.76 4595.405 237.62W 0.72 4601.53 443601.48 5864341.83 6796.49 60.64 184.19 4341. 35 4678.265 244.20W 0.67 4684.63 443594.27 5864259.03 6891.31 59.77 183.48 4388.47 4760.365 249.70W 1.12 4766.90 443588.14 5864176.98 6986.31 60.12 182.78 4436.05 4842.465 254.19W 0.74 4849.13 443583.03 5864094.92 7080.71 59.06 183.48 4483.83 4923.755 258.63W 1.29 4930.54 443577.97 5864013.67 7175.51 57.60 183.48 4533.60 5004.285 263.53W 1.54 5011 .22 443572.46 5863933.19 7269.87 58.36 182.78 4583.63 5084.175 267.90W 1.02 5091.22 443567.48 5863853.35 7364.73 56.34 183.48 4634.81 5163.915 272.25W 2.22 5171.09 443562.52 5863773.65 7459.89 56.34 182.43 4687.55 5243.015 276.34W 0.92 5250.29 443557.83 5863694.59 7554.13 56.87 182.08 4739.43 5321.635 279.43W 0.64 5328.96 443554.14 5863616.00 7648.42 57.66 183.83 4790.42 5400.845 283.52W 1.77 5408.27 443549.44 5863536.84 7743.11 58.36 184.54 4840.58 5480.935 289.39W 0.98 5488.56 443542.97 5863456.80 7837.93 59.06 184.19 4889.83 5561.725 295.55W 0.80 5569.57 443536.19 5863376.06 7932.63 59.94 183.48 4937.89 5643.145 301.01W 1.13 5651.16 443530.12 5863294.70 8028.06 60.56 184.19 4985.24 5725.805 306.55W 0.92 5734.00 443523.94 5863212.09 8121.58 61.44 183.83 5030.58 5807.395 312.27W 1.00 5815.78 443517.60 5863130.55 8216.86 60.29 184.19 5076.97 5890.415 318.09W 1.25 5898.99 443511 . 15 5863047.59 8311 . 56 59.24 183.83 5124.66 5972.035 323.81W 1.16 5980.79 443504.81 5862966.02 8406.26 59.06 183.13 5173.22 6053.185 328.75W 0.66 6062.09 443499.26 5862884.92 8501. 17 58.97 183.83 5222.08 6134.405 333.69W 0.64 6143.46 443493.70 5862803.75 8596.14 59.50 184.54 5270.66 6215.785 339.64W 0.85 6225.04 443487.12 5862722.42 8689.92 59.94 183.13 5317.95 6296.585 345.06W 1.38 6306.02 443481.09 5862641.67 8785.70 59.59 183.13 5366.18 6379.215 349.57W 0.37 6388.77 443475.95 5862559.09 8880.92 59.24 182.78 5414.63 6461. 075 353.80W 0.49 6470.74 443471.10 5862477.27 8974.78 58.01 182.43 5463.49 6541 . 125 357.44W 1.35 6550.87 443466.84 5862397.26 9069.23 58.71 183.48 5513.04 6621.435 361.59W 1.20 6631.28 443462.09 5862317.00 9163.00 59.77 183.83 5561.00 6701.845 366.73W 1.18 6711.85 443456.33 5862236.63 9257.95 60.64 183.13 5608.18 6784.085 371.73W 1.12 6794.25 443450.71 5862154.44 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level). Bottom hole distance is 7163.02 on azimuth 183.11 degrees from wellhead. Vertical section is from wellhead on azimuth 183.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) Phillips Alaska, Inc. 5URVEY LI5TING Page 3 Drill 5ite 2P,431 Your ref : MHD <0 - 9685'> Meltwater,North Slope, Alaska Last revised: 10-Apr-2002 Measured Inclin Azimuth True Vert R E C TANGU L A R Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO RDINA T E 5 Deg/100ft 5ect Easting Northing 9353.05 59.50 183.48 5655.63 6866.365 376.48W 1.24 6876.66 443445.33 5862072.20 9446.86 58.89 182.08 5703.67 6946.845 380.39W 1. 44 6957.23 443440.81 5861991.77 9542.51 59.59 182.08 5752.59 7028.985 383.37W 0.73 7039.41 443437.20 5861909.66 9619.17 60.38 182.43 5790.94 7095.315 385.99W 1.10 7105.79 443434.08 5861843.36 9685.00 60.38 182.43 5823.47 7152.485 388.41W 0.00 7163.01 443431.22 5861786.21 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level) . Bottom hole distance is 7163.02 on azimuth 183.11 degrees from wellhead. Vertical section is from wellhead on azimuth 183.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) Phillips Alaska, Inc. Drill Site 2P,431 Meltwater,North Slope, Alaska SURVEY LISTING Page 4 Your ref: MHO <0 - 9685'> Last revised: 10-Apr-2002 Comments in wellpath -------- -------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 9685.00 5823.47 7152.485 388.41W Projection to TD 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 2990.00 2381.83 O.OOE 9555.00 5758.90 1421.835 7039.755 85.l5W 7 5/8 Csg 383.77W 5 1/2" Casing Targets associated with this wellpath ----------------- --- -------- ------------ Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(AE) Midpt TGT RVS 44347l.000¡5862257.000,999.00 5552.00 6681.365 352.22W 22-Feb-2001 ) I ) ~~~~E : F fÆ~fÆ~~~Ju ALASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AI( 99510 Re: Kuparuk River Unit 2P-431 Phillips Alaska, Inc. Permit No: 202-053 Sur Loc: 943' FNL, 1914' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 2115' FSL, 1494' FWL, Sec. 20, T8N, R7E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 2P must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (Ç¡~ (kU.~ C~y O~hsli Taylor Chair BY ORDER 91 THE COMMISSION DATED this.:£Iq day of March, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB = 254 feet AMSL 1a. Type of work: Drill ~ Redrill U Re-entry DDeepen 0 2, Name of Operator Phillips Alaska, Inc. 3, Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 943' FNL, 1914' FWL, Sec. 17, T8N, R7E, UM At top of productive interval , 2532' FSL, 1517' FWL, Sec. 20, T8N, R7E, UM At total depth 2115' FSL, 1494' FWL, Sec. 20, T8N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 2115' @ TO feet 2P-429, 40' at surface 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size Maximum hole angle 60.7 Hole Casing Weight 42" 16" 62.5# 9.875" 7.625" 29.7# 6.75" 5.5" 15.5# 6.75" 3.5" 9.3# Specifications Grade Coupling H-40 Weld L-80 BTCM L -80 BTCM L-80 EUE 8rd M Length 90' 2977' 9111' 826' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well cQnditiQn summary Total Depth: measured true vertical feet feet Effective Depth: measured true vertical feet feet Casing Conductor Surface 0 Length Size Cemented Perforation depth: measured true vertical Approved by Form 10-401 Rev. 12/1/85. 6. Property Designation AOL 389058 ALK 4998 7. Unit or property Name Kuparuk River Unit 8. Well number 2P-431 9. Approximate spud date March 15, 2002 14. Number of acres in property ~S{,,,o7 A 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2256 psig At total depth (TVD) psig Setting Depth feet ) w6A 3/5/0L d- "3!S-ð) Development Oil ~ Multiple Zone 0 10. Field and Pool Kuparuk River Field Meltwater Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 9967 ' MO 1 5786 ' TVD Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 30' 30' 120' 120' 9 cu yds High Early 30' 30' 3007' 2384' 370 sx AS Lite & 220 sx LiteCRETE 30' 30' 9141' 5382' 290 sx Class G w/GasBlok 9141' 5382' 9967' 5786' (included above) Plugs (measured) Junk (measured) Measured depth Commissioner by order of the commission 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis 0 Seabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true n correct to the best of my knowledge Questions? Call fJat Heilly 265-6048 Signed (!, re. 11 (M ./,/ Title: Drilling Engineering Supervisor Date '-I"Yl~ c)'¿ Chuck Mallary PrAnarArl hv Shamn AII.C:lln-nrakA . Commission Use Only Permit Numb~r I API num~er . I /. - I Approval date /J'r¡! .0 /7 Isee cover letter 20 :z.. - () 5' 3 50- / () 3 - '2D 7 / 7 Oð 'I J 1 0 V- for other requirements Conditions of approval Samples required 0 Yes []I No Mud log required U Yes bd No Hydrogen sulfide measures 0 Yes [g No Directional survey required [:&I Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0 Other: ~sca p~\ ~'\.~'N\.'-.)~~'?~c:>-\ ~~ Original Signed By CaUlIIIY O~ch~~¡ True Vertical depth RECEIVED MAR 0 4 2002 Alaska Oil & Gas Cons. Commission Anchorage Date 0/1/o'Þ 0 ; . 'G .'1 i 'A .: Submit in triplicate ) Apr Jion for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 Permit It - Meltwater 2P-431 Application for Permit to Drill Document M()ximizE Well Vol~1; Table of Contents 1. Well Name............................................... .................................................................. 3 Requirements of 20 AAC 25.005 (f)........................................................................................................ 3 2. Location Sum mary .............. ..................................................................................... 3 Requirements of 20 AAC 25.005(c)(2) .......................... ....... ................... .......... .... ........................ ..... ....3 Requirements of 20 AAC 25. 050(b)........... .......... ............ ........................ ....... ....... ........... ......... ... ..... .....3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 4 4. Dri II i ng Hazards Information ... ................................................................................ 4 Requirements of 20 AAC 25.005 (c)( 4) .................................................................................................. 4 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casi ng and Cementi ng 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. Drill i ng FI u id Program......... .................. .................................................................. 5 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 5 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 1 O. Seism i c Analysis............. ................................................. ........................................ 6 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 6 11.. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ..... ............. ........ .......... .... ......... ........................ ....... ................6 12.. Evi dence of Bond i ng ............................ ........................... ........................................ 6 Requirements of 20 AAC 25.005 (c)(12) ... ....... .......... .......... """"."'" '''''''''''''''' ..... ........... .........,... ....... 6 431 PERMIT IT TEMPLA TE.dot Page 1 of 7 J r) r l'~'Yf.. 'rUf3f: 'fr. flIa. r-02 J~¡ ¡ (;i ¡ {Vt1~ ) Apr. .)iOn for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 13. Proposed Dri II i ng Program.................................................. ................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................ ................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7 15. Attachments ................................................. ............................................................ 7 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................ 7 Attachment 2 Directional Plan ..... ....... ............ ..... ......... ............ ................. .... "".""'''''''' ....................... 7 Attachment 3 Drilling Hazards Summary............................................................................................... 7 Attachment 4 Well Schematic........................................... ..................................................................... 7 Attachment 5 Cement Details ..................................... ........................ .............. ....... ......... ..................... 7 431 PERMIT IT TEMPLA TE.dot 0 ~te~~.~¥ ^ ,1\ÃJivA~ ) Ap 1ion for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name de::,"ignated by the operator and a unique API number assigned by the comn7l:,,:<;ion under 20 MC 25JJ40(b), For a well with multiple well brancf1es~ 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-431. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Perrmt to 017/1 mw,t be accompanied by each of the following Items, except for an item already 017 fìle with the commission and identIfied in the application: (2) a plat Identifying the property and the pr()perty~ owners and show/flg (A)the coordinates of the proposed location ol the well at the sur(ace, at the top ol eadl objective formatior~ and at total depth referenæd to govemmental section /ínes. (8) the coordinates of'the proposed 10catio/7 of the well at the ::JïJrf'ace, ref"erenced to the state plane coordinate system for this state as maintained by the National Geodetic SWVt)' in the National Oæanic and Atmosphelic Adm/Í]istration; (C) the proposed depth olthe well at the top of each oL?Jecl:ìve formation and at total depth; Location at Surface NGS Coordinates Northings: 5868934.84 943' FNL, 1914' FWL, See 17, T8N, R7E, UM RKB Elevation: 254 ft AMSL Eastings: 443874.09 Pad Elevation: 224 ft AMSL ''-o.. ,. r ' 2532' ~ ~ FWL, See 20, TSN, R7E, UM i v />- .Jh ~J/ Measured Depth (RKB feet): 9241' True Vertical Depth (55 feet): 5177' True Vertical Depth (RKB feet): 5431' Eastings: 443460.97 Location at Top of Productive Interval (Bermuda Formation) NGS Coordinates Northings: 5862068.57 Location at Total Depth NGS Coordinates Northings: 5861436.8 Eastings: 443422.96 2115' FSL, 1494' FWL, See 20, T8N, R7E, UM Measured Depth (RKB feet): 9967' True Vertical Depth (55 feet): 5532 ' True Vertical Depth (RKB feet): 5786 ' and (0) other li7fbrmation required by 20 AAC 25. 050(b); Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviated, the application for a Per/77ft to Dr/II (Form 10-40.1) must (1) include a plat, drawn to a suitable scale, ShOWli7g the path of the proposed wellbore, including all a{j/acent wellbores wlthlfl 20(} feet of any port~o(} of the proposed well; Please see Attachment 2: Directional Plan and (2) for all viells it'v'lthIÌ7 200 feet of the proposed ~1/älbore (A) list the names of tl7e operators of those t~v'ell.", to the extent that tl70se names are known or discoverable Ii] public record~ and show that each named operator has been furnished a copy of the applicatIon by certified mai¿' or (B) state that tl7e applic,'Jnt is the only a(fected owner. The Applicant is the only affected owner. 431 PERMIT IT TEMPLATE.dot 0, ~~:¥~1^V l."\ I . U 111 ¡ i- ) API" )ion for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application lor a Penmt to Drill must be accompanied by each ol the following Item.~ except for an Item already on file with the comml<isíon and ídentífìed ín the application: (3) a diagram and descrliJtion of the b!owoutprevention equipment (BOPE) as requíred by 20 AAC 25:035; 20 AAC 2S,036r or 20 AAC 25:031, as applicable-- Please refer to Nordic 3 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An applk:ë1tíon lor a PermIt to Dríll must be acevmpaníed by each o{ the following Item5~ except for an Item already on file with the comml<isíon and ídentífìed ín the application: (4) information on drilling hazard~ inc/udl17g (A) the maximutn downhole pre.%iJre that may be encountere(~ critenà u!:'ì..;d to detenml7e it, and maximum potentJ~;¡1 surtàce pres.')llf'e based on a methane gradient/ The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.51 psijft, or 8.5 to 9.7 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2/2A, and on development wells. The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is: MPSP as a function of reservoir pressure =(5639 ft TVD)(0.51 - 0.11 psijft) = 2256 psi Assuming a LOT / FIT of 16 ppg based on open hole results from the closest offset well, MEL1WATER 2P- 438, MPSP as a function of LOT / FIT at the surface shoe (2384' TVD) =(16* .052*2384')-(2384*0.11) =1721 psi. Therefore, the MPSP may be based on the reservoir pressure calculation of 2256 psi./ (8) data on potential gas zones/' No potential gas zones have been identified along the planned well path. and (C) data concermi7g potenti/:JI causes olhole problems .')l/ch as abnormally geo.pressured str/Jta/ lost circulation zones, and zones tf7at have a propens1ty for dlfferent!';]1 sticking/ Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dnll must be accompanied by cacti or the {ollowing item~ exæ¡..'t lor an item already O!7 fife wIth tile commission a!7d Identified 1Ì7 the application: (5) a descriptio!7 of the procedure for conducting formation integnty test5~ as reqUIred under 20 MC 25.030(1); A formation integrity test will be performed after drilling out below surface in accordance with the Phillips Alaska LOT / FIT procedure, currently on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dnll must be accompanied by each of the tollowlÌ7g item5~ except tor an item already on file ~'./ith the commis..,,1ofl and Identified in the application: 431 PERMIT IT TEMPLA TE.dot Page 4 of 7 pr¡"le~ 1 ~~O7 ,r."J ~" L ~ '1/\:4 J\ijt:! ') Apr )tion for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 (6) a complete propo.':;'f.!d casing and cementing program as required by 20 AAC 25:030, and a de.';i'c:r!Ì)tion of any slotted Ilner~ pre- perfÒrated liner, or .';;,::reen to be Installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High Insulated Early 7 5/8 9 7/8 29.7 L-80 BTC AB 2977 30 / 30 3007/2384 370 sx 10.7 ./ MOD ppg AS3 Lead, 220 sx 12 ppg LiteCrete Tail Planned Top of Cement: SURFACE 5 1/2 6 3/4 15.5 L-80 BTC AB 9111 30 / 30 9141/5382 290 sx 15.8 /' MOD ppg Class 'G' 3 1/2 6 3/4 9.3 L-80 8RND 826 9141/5382 9967 / 5786 Planned Top of MOD Cement: 8641' MD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) All application for a Pelmlt to Drill mLlst be accompanied by each of'the following Items, except for an item already on file with the c;'()mn7l:~:t;iOI7 and Identified iI7 the application: (1) a diagram and desaiption of the dlverter system as required by 20 AAC 25: 035~ unless {hit; requirement Is waived by t/7e commission under 20 AAC 25:0J5(h)(2); Please refer Nordic 3 Diverter Schematic currently on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) All application for a penmt to Drill must be accompanied by each of the fo/lowing Items, except for an Item already on file with the corTl/77I:<ision and identified in the application: (8) a drilling fluid program, including a diagram and description of t/7e drilling flUId system, as required by 20 AAC 25: 033; Water based drilling fluid systems will be utilized to drill this well from spud to TO. These systems will be built and maintained to the following specifications: Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel o. "'" -.- .... Spud to 97/8" Surface Casing Initial Value Final Valu:; 9.6 9.6 150-200 150-200 Drill Out to Top Bermuda Initial Value Final Value 9.6 9.6 / 50 65 Top Bermuda To Well TD Initial Value Final Value 9.6 9.6 / 50 65 35-45 27 -40 10 25 10 25 8-15 11- 22 8-18 8-18 8-18 8-18 10-30 10-25 3 9 3 9 25 55 4 8 4 8 431 PERMIT IT TEMPLA TE.dot Page 5 of 7 (J~d' Ga']\¡ j\ . ' , , ill. ) APr" 'jiOn for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 Strength (lb1100 sf) PH API Filtrate(cc) 8-9 <15 8-9 <15 8-9 <6 8-9 <6 9-9.5 <6 9-9.5 <6 Please refer to Nordic 3 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/k-:C7tion for a Permit to Onll must be accompanied by each of the fo/lowinq items~ except for an item already on flle with the evmmiS':.sion and Identitìed in tlJe applic<.-:¡t!of7: (9) r-or an exploratOlY or stratigraphic test welt a tabulation setting out tfle depths of predìcted abl701mal/y geo-pres..svred strata as required by 20 AAC 25.033(1)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An appliŒtion for a Permit to Drill must be accompanied by each of the followinq items~ except for an item already on me wIth the commis.';,"ï'on and kjentified in tfle application: (W) for an explorat-ory or stratigraphic test well; a seismìc refraction or ret7ection analysìs as required by 20 AAC 25JJ61 (a); Not applicable: Application is not for an exploratory of stratigraphic test well. ./ 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applicatìo/7 for a Permit to On/I must be accompanied by each of'the following items~ exce¡..ìt for a/7 item already on flÏe wIth the commi!:;:.t:;I'on and Identifìed in the application: (11) for a well dn/led fi"om an oft,;hore platfÓrm, mobIle bottom..founded structufi:-;' jack'up r~q, or floating dn/llng vessel an analysis ofseabed conditions as reqU/i-ed by 20 AAC25.061(b),' Not applicable: Application is not for an offshore well. /" 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicatio/7 fÒr a Permit to Dn/I must be accompanied by eaäJ of the following items, except for an item already on fìle wIth the commiS:iion and Identifìed in the application: (12) eVIdence showing that the requirements of' 20 MC 25. 025 {Bonding}have been met,. Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. / 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Perrmt to Drill must be accompanied by each of the followlÍ7g Items, except for an Item already 017 file with the commission and identified íÍ7 the app/icatJÒn: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB. Weld landing ring on condugl' \J6A- 2. Move in / rig up N~. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to 7 5/8" surface casing point (+/- 3007 MDr) according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. ëkl-b/~~4 0;- 431 PERMIT IT TEMPLATE.dot Page 6 of 7 C~rGr;~ j ~ ì Apr )ion for Permit to Drill, Well 2P-431 Saved: 1-Mar-02 / 4. Run and cement 7 5/8" 29.7# L-80 BTC AB MOD casing to surface using ArcticSet 3 lead slurry and LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to ensure cement reaches the surface. Displace cement with mud. .,;"" 5. Nipple down diverter and install wellhead. Nipple ~..BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results. 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. .,/ 8. Directionally drill 6 3/4" hole to well total depth (+/- 9967' MD) according to directional plan. Run MWD / LWD logging tools in drill string for direçtional monitoring and formation data gathering. Circulate and condition hole. POOH. tJR/ !83ð17I/I1Y/ /\!livTRéW /1>G~ ITY / :B,t<êC-nOA./Þ4 '-- 9. Run open hole e-line ~ drill pipe conveyed logs as ne~d. ß 10. Run and cement 5 1/2" 15.5# L-80 BTC AB MOD x 3 1/2 9.3# L-80 8RND MOD tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' MD above the planned top perforation. 11. Run and land 3 1/2" 9.3#, L-80, 8RND MOD tubing. Displace well to completion brine. 12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull SPY. Install test plug. Pressure test production tree. Pull test plug. Secure well. 13. Freeze protect well. Set SPY. Release rig and turn well over to production. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. * Cement bond log will be run prior to perforating injectors. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An appliG~tion for a Permit to Drill mustc be accompanied by each of the (ollowing tlems~ except lor an item already Of) tile with the c(ìlmm~s:.sion and identitied in the application: (14) a general desLìiptio/7 Of'l70W the operator pla/7s to dispose or drilling mud and cuttings and a statement 01' whether the operator intends to request authonzatio/7 under 20 AAC 25.080 fÒr an annular di:.;fJosal operation in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down the annulus or hauled to the Prudhoe Say Field for temporary storage and eventual processing for disposal down an approved disposal well. At the end of drilling operations, a request will be submitted for this well to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details 431 PERMIT IT TEMPLA TE.dot Page 7 of 7 , Printed: 1-Mar-02 (; II Î ~J 3 j \~î rJ ¡" . °\ t ") """"""""""","""""""""'"''''''''''''''"'.m....'",-""""""""""""""""""""..............................,......................."""""""""""""""""""""""""" Phillips Alaska, Inc. Created by bmichael For: P Reilly Dato platted: 8-F'eb-2002 Plat Rerorence i. 2P-431 Version ~2. CoordinCltes ara in feet raferance slot '4:5 1 . ....-.---...-...---.......-......................-.-.-.-...."-'-"__'''M._.. Structure: Drill Site 2P Field: MeltwQter Well: 431 Location: North Slope, Alaska True Vertical Depth. are reference RK8 (Nordic 3). lOll IIAID!II -- INTÞ:I _M""'-""--""-""""'----"--"""""""''''''-.-...-..........-.-....-.......... 500 - . 1 000 - --.. 1 500 - +- Q) Q) 0 2000 - ...r:: +- g- 2500 - 0 0 3000 - U +- I... Q) > 3500 - Q) ::¡ I... 4000 - l- I V 4500 - 5000 - 5500 - 6000 - . 183.01 AZIMUTH 7095' (TO TARGET) ...Plone of Proposal... 0 ~ I RKB Elevation: 254' . KOP . 2.00 . 6.00 3/100 Build 15.00 21.00 DLS: 3.00 deg per 100 ft 27.00 Base Permafrost 33.00 39.00 45.00 51.00 Bose West Sak 57.00 EOC ~ TANGENT ANGLE 60.74 DEG / ~HI~LlP~ 5 1/2 X 3 1/2 Crossover T3 (Top Bermuda) T2 (Bose Bermuda) TO, Csg pt 0 500 1500 1000 2000 2500 3000 3500 4000 4500 5000 5500 Vertical Section (feet) -> Azimuth 183.01 with reference 0.00 N, 0.00 E from slot #431 6000 6500 8000 7000 7500 Oi¡G¡NÂ~ ') ...............................,..................."......................,...,........,....,....,..,...................................,"..........,..".,..",..,.....,.....,.............................................. . Phillips Alaska, Inc. r"'ë;~~t~'d-b~--b';;;¡~¡;'~;ï-"'-"'F~-;;"'p'ii~iïïÿ"''''.. I Date platted: 8-Feb-2002 Plat Reference I. 2P-431 Version *2. Coordinate. are In f.et ref.rence slat 1431. True Vertical Depth. are reference RKB (Nordic 3). -...--................-..--.-.--..-........__m.,._...-.......-..-..-.-"..".-.-.--.-.",".--.,.-..,...-.- Well: 431 Structure: Drill Site 2P Field: Meltwater Location: North Slope, Alaska <- West (feet) 19m IIAJœI - IN' ' (Q 800 400 0 400 400 1200 ........................................................'"''''''''''''''''''''''''''''''"""""'''''''''''' SURFACE LOCATION: 943' FNL, 1914' FWL SEC. 17, T8N, R7E KOP 3/100 Build G) Bose Permafrost .. - 0 - 400 Bose West Sak .. - 800 EOC.. - 1200 7 5/8 Csg ..J..l C80 .. - 1600 - 2000 183.01 AZIMUTH 7095' (TO TARGET) - 2400 ***Plane of Proposal*** .. C50 ~ - 2800 . <f .. C40 - 3200 (.f) .. C37 0 s:: -+ TRUE - 3600 :r ,,-... -+. CD - 4000 CD -+ ............ I - 4400 V - 4800 ..17 - 5200 - 5600 TOP BERMUDA LOCATION: 2532' FNL, 1529' FWL SEC. 20, T8N, R7E - 6000 - 6400 TARGET LOCATION: 2532'FSL. 1517' FWL SEC. 20, T8N, R7E .. T3.1 5 1/2 X 3 1/2 Cra..av.r. T3 (Tap 8.rmuda). - 6800 Target (:) T2 (80.. Bermuda).. - 7200 . TO LOCATION: 2115' FSL, 1494' FWL SEC. 20, T8N, R7E TO. Csg Pt ..J.l - 7600 - 8000 ~ O:.],NA.~ <:::) ::x:J --- Ç":) --- ::--:: ~ r- . : Created by b;;;~ For: P Reilly ! Date platted: B-Feb-2D02 j I Plol Reference is 2P-431 Version 1/2. I i Coordinates ore in feel reference slol 1431. : I'm' V,rt;,,' 0".., :¡:'"" '" ",ro;, ".1 L- IHTRQ r------ ~ ~ ~ c::::==:o '----- Point ----- jKOP !3/100 Build I Base Permafrost i ¡Base West Sak IEOe 17 5/8 eSG ¡e80 i ¡C50 IC40 le37 i iT7 j IT3.1 ! is 1/2 X 3 1/2 Crosso i jT3 (Top Bermuda) IT arget i MW(AE) Midpt TGT RVS IT2 (Base Bermuda) !TPLÇ?9....Et ... . Phillips Alaska, Inc.1 Structure: Drill Site 2P Field: Meltwater ¡ Well: 431 Location: North Slope, Alaska PROFILE COMMENT DATA MO 300.00 800.00 1390.45 2172.94 2491.35 "3007.16 3107.16 4222.21 4866.69 5220.64 7354.58 9071 .15 9140.96 9240.96 9488.50 9488.52 9666.52 ./ ""..h_h- ""___h_h___~_~_9JL;?hQ Inc 0.00 10.00 27.71 51.19 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 60.74 1 83.01 1 83.01 183.01 1 83.01 183.01 183.01 183.01 183.01 183.01 1 83.01 183.01 183.01 183.01 183.01 183.01 183.01 183.01 183.01 Oir TVO 300.00 797.4 7 1354.00 1954.00 2132.01 2384.12 2433.00 2978.00 3293.00 3466.00 No rt h 0.00 -43.46 -233.28 -726.33 -989.53 -1438.91 -1526.03 -2497.48 -3058.96 -3367.33 4509.00 -5226.44 5348.00 -6721.94 5382.12 -6782.76 5431.00 5551.99 5552.00 5639.00 5785.62 -6869.88 - 7085.54 - 7085.56 -7240.64 -7501.98 0.00 -2.28 -12.25 -38.15 -51.97 -75.57 -80.15 -131.17 -160.66 -176.86 -274.50 -353.04 -356.24 -360.81 -372.14 -372.14 -380.29 -=)94.01 East . . - - /PHILLIPS ." 0::::=:==::1 c:::::==::::::t c:==::I c:==:a V. Sect Oe9/1001 0.001 2.00: 3.001 -r" 0.00 43.52 233.60 727.33 990.89 3.001 3.001 O.OO¡ 1440.89 1528.14 0.001 2500.92 0.001 3063.17 0.001 3371.97 0.001 5233.65 0.001 6731.20 0.00¡ 6792.11 O.OO¡ 6879.35 0.001 7095.31 0.001 7095.33 O.OO¡ 7250.62 O.OO¡ 7 !2.1L~2______----..Q-~ 0 QJ -" ') '') For: P Reilly 11-Feb-2002 Structure: Drill Site 2P Well: 431 Phillips Alaska, Inc. Coordinates ere in feet reference slot #431. Field: Meltwater LocQtion : North Slope, Alaska Vertical Depths are reference RK8 (Nardic !Mi!!'ii! ~ INTE,) ~ @J ~ ~ 350 TRUE NORTH <> c=J 0 œ 10. &J ~ 3000 340 20 GS. .330 210 30 320 40 310 ~ r<;t',1500 3u~ 50 60 290 70 "r@ 280 270 260 8 100 250 1 1 0 240 120 230 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well C 1'G ^A.. ) ) Philli s Alaska ~ Inc@ /PHllLlP?~ [-"'or'; Pet F<eilly Dote plotted: , -Mor-.2002 Plot Reference is 2P-4.31 Vcr~ion #2. Coordinatos oro in 10Ðt roferenco slot #431. Structure: Drill Site 2P Field: Meltwater Well' 431 Location: North Slope, Alaska "' ... ~ "..J Vertical Dopths ore refarencCl RK8 (Nordic ~íi. BAKER Crected by bmichocl HUGHES fil~!: '2p'\:~1sp1 <- West (feet) 240 200 160 120 80 40 40 80 120 160 200 240 280 C%>, I '~ 1125~ ~ 1'250' , @11250 ".,,1900, '" >1\,1350 ".,,1850\1200 .1200 ,~1200 '-.If 1300 "", 18Qp1150 '.1150 ,.1150 1250 '17"^ ' 1100* 1100 '\II" '11<" ,~~r-'I 00 '" . 1 050 '", 1200 'II<'J~S~ß 'II< 1050 ! 1000 1150 ,..18~ '.1000 '" 950 - 80 . '>1\. ~1't>00 ' ,~ 900 " ,..,.B '-.If 1100 11< 959 1550 ,11,950 '" 850 e e, e,,~- , , 900 150Q 900 é ., 1050 ill, 85~'" 14~QJ50'¡' 750 e e sòë)"':"""""< ~ - \it 1000 '" '800 "'",1,7",~ Surface 0,00 N, 0,00 E,~ 650, , 8 '8 '.1+ 6"Ob 600 , >"<'0 40 950..: oJ; A 8 45()65"i 6èffi'3 " "', 900 "700 ~., ÖO 8 8 ÿ '" 500. 5~å5i!t 7S((JJÖ 700 " "'ó>- ~ "'", 850 ., 600 "',. 1100"", -$- ~ ,~75(!l 565500 ~ 6605~' !,,85ð~' Rri'ltr\* 800750'", - ~ 750 >1\ 500c.-, -$- "'" 55c1:,' 850'" "''' '1It'900'*",""~'<lU, 850 ~ , ",1250 "\ >It 8 ÿ* 550 65d\ Ii' ,~ 750 ""', 700 *, ~(){þ0 \ \., '" 900 ~ " '" '" ,1150 II< -.lf6~~0 -$- -$- ,~650 + 650 \. f580 '~'. 800 >It 750.'075§0~\.9 0 950 - 1000 , -$-;8 8550 .. 750 ,'" 750 750~ 1050 II< 850 :. 800 ," 8e~0 \iI;,*l Q)O~O ,1000 .", ~50 A e 8500 I 70; 650 ,>1\ 850 '" ~gg 11 O¿;~ 850 II< 900 \ 850 .:", 1100\ ",1 ~, 5d'O, 1050 - 40 e e ,,;(5f! 99\:h'00 f 75q; 7 . 900 '''' ' \ 900 '" 950 .", ~l%O*J ~?¡M -$- e ,,' ,,,,' 850>1\ 1 ð'5'ô .t 800¡. 868", 950. 900 1150" \ 950 ;. 1000 '" 900 .'. CJIlf'L \ , 1~~ - ~¡''ò ~,"ee ", '70W) 600 ,~ 950.'1' 7.000 J 85Q¡i 850 >1\ 1000* 950 120~ \' 1 050 ","'~LUU ~\¡, r-'~ - 80 'V6, 5,0",'1</9"'50 '~,On'" 650, Ii 1 00,0.," 1..'" 0, ' ¿ 900. 900 .,' 1 050 ~ 1000 125Ü",'" '~,' 1000 '**.. 950 ,'~ l5óJ . '~,2~2J50 ~ 750~,,,,". ¥ 700,* 1050. 1.¿ : 950 950' : i 1050 '" 1100 .., \ - ~ ;¡;, 1050 ..900i< 75, O,/>' 1100, '" ,. 11006. ,.. 1100 + 1050 130Ü",' ~ , :~ 1,000 '" i, ¡OIcPOO \ '~1,~50 @»'I!850>l'95~800*1150 ,;r~ ¡1050'" 1000 ..1150 .1100 '~\,1100~1150 , .,,1300' ¿ -120 "*1 0150009 850 ~/ 1200 .. J 488 / 1100* 1050, 1 1 350. ,~ 1200 :. 1050 ':,¡, 13~01 050 ~ "', , ' ,1 O'~.. . 1200 . 1150 ' 1150 . " ,., - '1<,1100.900.1250 ,~'450 11150",1100 , 1400- ~ '.. 14ÒO '" 1150 ""950,,,'1300'~1Jg5° i1200 1150 1'12501.1200' \~" 1200 ,~1250 :",1100. '" 1100 - 160 ~' 1200 , " jI'; 1100'/ '" I 1450" , ' &.10091350 ,11'1550 ,..1250 ..1300 11250,' \ ,~1300 '. 1150'~ 1450, , '~/ '" 1 200 f 1500" \.\, 1250 '" ~'" ;'" 1 050 1400 l' 1150 j, 1300 " , ,~ ,'/> '" 1 600,/ ,'" 1 250' 1350 '" 1 300 1 55( < ~ 1350 ., i'! 150 ",110Q'1450 ,,1200f 1350 , I'~ 1300", 1200' '" '", 1650 / ¡ 1300 - 1400 I 1350 l' 1600 i ,~ 1400 ' '" 1150, ' *1250 ¡ 1400 '" 'I' ~ 1350 . '" 1500 ''; 1 700,/ .; 1350 .. 1450 I ,~ 1650 '" 1550 .;1300 f 1450 + 1400 . 1700 . 1750 / ,;. 1500 I ",' 1)50 11500 '" 1400 ,~1450 .. 1750 , '" 1800 ,/ , ,~ 1800 .. 1400 ,~1550 '" 1 450 ~ 1550 I , ! '" 1500 ~ 1850 . 1850/1600 I .,: 14,50 / . 1500 . 1600 : ' '1900/ f 1550 '" 1950 '" i. 1650 I II' 1500 / ,,¡. 1550 .. 1650 1 . 2000 . 195,Þ1700 + 1600 .. 2050 . 1550: ~ 1600 .. 1700 'I .. 2100 ~ 20~q 750 r 1650 , .2150 . 1600: '" 1 650 . 1750 1 I. 2200 ~ 1700 I . 2250 I , r 1750 . 2350 , I I G0-, "\X - 160 - 120 (!J it 1450 U1 0 C -+ - 200 ::r --- -+. CD CD -+ "--'" - 240 1/1600 ~\ 1400 \ 1450 \ ~ 1500 . 1550 ',. 1250 ' ',1600,. ',~ 130~ - 280 I V ~ 1500 (!j . 1550 '. 1350 - 320 '" 1 900 ~ 1550 '" 1600 % - 360 i ~ 1600 . 1650 - 400 ~ 1650 '" 1700 - 440 . 2~5f:800 . 1650 . 1700 . 1800 . 2300 ~ 1700 . 1750 - 480 '" 1750 . 1800 - 520 . 1800 - 560 . 1850 \ID B - 600 . ~i ~§50 . 1700 . 1750 .. 1850 . 2400 . 2450 + 1800 I . 2500 I I . 2550 I]J .,;21§§0 . 1800 .. 1900 i ?§§@ , (!] @ @ 0 III. . . ] ¡. N h ~ If . ) Philli ') s Alaska, F"or': Pet F¿eílly Dote plotted: 1-Mor-2002 Plot Reference i~ 2P-4.31 Vcr:!lion H2. Coordinatð~ ore in feet reference slot #431. Structure: Drill Site 2P Field: Meltwater True Vertical Depths ore reference RK8 (Nordic Rill BAKER Created by bmichoel HUCifIES 'f ì ¡ (.~ : <- West (feet) 1500 (j; 900 , (j; (j¡ , '(!J@I!J Ifl' @J '@J' , " 2500", /" ", 2700 '260ð 2900 ';1< 3~OS8003300. I ,Ii! , . . ! J9oþ270~ It + 2800 , " .. 3000 2600!" ;"31 ~li4QOO 34 0.. I ,'" 270.0 , /320n., 3500, ,2900 . . fI' ;¡¡:"I-¥0~800.4< '" . )II' 3100, / ¡ 4200 360u I .. 280Q 2700.. i 3300 ' 37001' 1 3000 , ':' ,'" 430£900. T , * 3200 , "340~ 44'öÔ :JéIoct I ,* 290?' 2800~' /4500 3900~ .3100 . * 3300 ¡. 350CJl'46db300~000' : 3000' , /", ' 3200 'Ii, . 1- 360Q~4 700 4100!' f '3100;'" 3400 2900' i3700~8CJt310~20d' .l3300 !I' ,;' /..4900 430~ I , ;~ 3500 .' ¡ 3800 ~50~032004400'! 3400 '* 3200 . 3000. / . 5100 . I , ,,3900".' 4500< I )II 3600 /- 5~(iboo 4600. * 3500 ;" 3300 . 31 OO~. 4000 .", 53\¡J0 , I ,/3700 ,/. 5400 4 700~ ,~ 3600 l 41 00 ,~55~cf3400 4800~ I 3200", i 4200 ",:s50Ò 4900~ . 3700 .' /4300 *570ð 3500 5000. : ." '~' 3800 3300.. / lED 5100, I , l 4400 ~ 3600 5200** 3900 ¡ 4500 5300, I 3400': ! .~ 3700 5400. ~ 4000 .' ,/ 4600 5500~ I 3500..' /4700" 3800 5600" + 4100 ¡ 4800 5700~,~ 4200 ,~ 3900 rn I f 4300 I .. 4400 I t 4500 I ¡ ¡ 4600 I f 4700 I ,¡.4800 I ,~ 4900 I ,¡.5000 I ~ 5100 I J. 5200 I ~ 5300 I * 5400 I I .. 5500 I r 5600 I . 5700 I m 1200 600 300 .", 3800 ;3900 Ih <!J 3600': ¡ 4900 . / . f 5000 3700.~ ,/5100 , ¡ 5200 3800~ / . ,15300 , ! 3900 ,.' ¡ 5400 }* ,/ ¡ 5500 4000.. /5600 ¡ 5700 .~ 4000 ,; 4100 .4200 .4300 .. 4400 .. 4500 4100. ! 5800 ~ .. 4600 4200. .. 4700 (j] .. 4800 .. 4900 .. 5000 .5100 . 5200 {fJ Inc@ Well. 431 Location: North Slope, Alaska 300 600 900 1200 1500 I \~\I \~\ ~~\ \V~ ~ \ 3000 4000'2300 '~*280Q.1 ocr " 3100', 420Q\2400 ~ ' 4300* \ 3200(29004400* ~ ' 45001Ìl\2500 ,~ 3300¡J000 460~ \ ' 47 0 QiI! ,~3400 *31 00 4800~, 2600 ~ 3500 4900111.. \~3200 5000~", 2700 ~ 3600 '. 51 OO~, \ . 5200.,. .~ 3700 ~ 3300 530CJ'l':i': 2800 \ 540Qi¡. ~ 3800 '3400 550~, " .~ 5600~" 2900 , 3900 "." 3500 5700"', .~ 4000 ~ 5800~.. 3000 \ 5900", .~ 4100 " 3600 ~,6, 000 1 . ~ 3100 ~ 4200 ~ 3700 ", ~ 4300 ~ 4400 \ .~ 4500 \ ~ 4600 ~ 4700 ~ 4800 ~ 4900 ,~, 5000 ~ 5100 .~ 5200 ~ 5300 + 5400 ~ 5500 ~ 5600 ~HI~LlP~ " .; 1800 2100 2400 ~~ ~ ' , , , 1800 ~~~~~ - , \, 220611! ,\\*~8CQ"24ð'03200 - 2100 , '. '\ 35QO 3~06 ~ - 2300" '\, ' '\ ~ , "*, '.i300~ - 2400 3700 '\, ' ~ 240011! '\ - , \ (..0 - 2700 ~\ ~ 41 ÇJO~\~- , '. ~ " ~ - 3000 ~ ~ 3300 .it 3800 ~ 3900 ¡.4000 ... 4100 ... 4200 .. 4300 ~ 4400 .. 4500 ~ 5700 ~ 5800 .~ 5900 L6..000 ~ ~. 4600 .. 4700 - 3600 'if 3200 - 3900 ... 3300 :*. 3400 - 4200 :ÌI! 3500 (j) 0 - 4500 C -+- :::J :", 3600 3700", ,,--.., - 4800 -¡., <D <D -+- "'--/ ~- - 5100 I V - 5400 ~ 4800 ~ 4900 - 5700 .. 5000 - 6000 .. 5100 .. 5200 - 6300 .. 5300 .. 5400 - 6600 .. 5500 - 6900 .. 5600 .5700 - 7200 . 5800 - .. 5900- 7500 B - 7800 C ~/GI ~f AL ¡~J i~l For-: hJt F(eîlly Doto plotted: , -Mor-2002 Plot Rcferanc:c is .2P-431 VeJrsion ~2. Coordinatos are in f(lct roror~mco slot #431. Truð Vertical Depths ora reference RK8 (Nordic ftji.iI BAKER Crected by bmichoel HUGHES tile: 2[.14:51 sp2 I I I @ @ 1900;>ti' 2000:,.' ;r¡;'2400 (j) (JJ ) Philli s Alaska, Structure: Drill Site 2P Field: Meltwater ) Inc@ Well' 431 Location: North Slope, Alaska <- West (feet) 600 500 400 .300 200 100 0 100 I @I I~ ~2~00 I 1900: ~,2700 it 2000 ';.. 2800 I ~ 2900 : 1< .3000 ~2100,. 3100 .. 20001 .. I ~ 3200 ; ,it 3300 * 2200 I ~ 3400 2100t ,,. 3500 * 2300 :,¡. 3600 I ~ 3700 I ' I ,~3800 ~2400 220~ .. 3900 I .;. 4000 I I >It 4100 ;" 4200 I * 4300 2300f " 4400 .>It 2600 : ... 4500 @: .~ 4600 I 'it 4700 ~'2440ì:9° I.. 4900 :,. 5000 I." 5100 I I,. 5200 .>It 2900 25001. 5300 I >It. 5400 I 1>It 5500 :.. 5600 I,. 5700 2600t,. 5800 .. 3100 :,. 5900 ;§3 I .~ 2700 I @i I I t 2800 I I I I I I . 2900 I I I I I ø(j; 1800l I (f)!!i!J I!J 2000{ " , /~ 2300 '~ 1900 1900:~' l " ,,21 oar:, 2400 " ,,/r ~ 2000 2000;* , ./ ,~ 2500 2200l ' f 2100 ,~ 2200 ,. 2300 2100~ " 2100 ./ * 2600 / ! ~ 2700 ,'2300/, í I , / ,iii 2800 2200~ 24001 , / ,>Ii 2900 / >It 2200 ,. 2500 , 2500~ ,~3000 ,~2300 ~ 3100 .,¡.2700 2300~ I , 2600.f I,. 3200 1. 2400 2700.i ,/' * 2400 ./ I ¡ 2800 I ' ./ * 3500 0 ,. 3600 /29 0 .. 2500 ./ (J] /3000 ,. 3800 ¡ 3100 . 3900 .. 4000 f!J .4100 .. 4200 [3 ,. 2800 .~ .3300 ,. 3400 ,. 2500 .. 3000 it 2600 " 3200 . .3700 to 3300 ,. 2700 ,. .3400 . 3500 to 2800 ,. 3600 [j] @3700 @ 400 500 600 700 I~I I~~~I '. .~, 2100, " ~ - 600 --.. \ "" '';;''\. ~- , '. 2200 ' '\ - 700 , ~ '. 2300 "2.) 1700~, ", - 1500 :. 2500 - 1600 2700 - 1700 ¡. 2600 2800 - 1800 200 I~ "' 1900 .300 ~ 2000 ,. 2100 :~ 2200 ,. 2300 2400 3000 ~HI~LlP~~ ~ "J - 800 '.. 2400 ~- ,'I< 2500 - 900 1800,. .~ 2600 - 1000 ','. 2700 - 1100 ,:,. 2800 1900.' ",\ 2900 - 1200 300O,. '~ -1.300 ,. 2400 - 1400 U1 0 C -+ ::J ....-.. -... CD CD -+ '--" I V - 1900 >Ii 2700 - 2000 ,. 2800 - 2100 3100 - 2200 \3- - 2.300 3200 - 2400 . 3300 @ - 2500 (1'.1 o\t ... ') . Phillips Alaska, Inc. Drill Site 2P 431 slot 11431 Meltwater North Slope, Alaska PRO P 0 S ALL 1ST I N G . by Baker Hughes INTEQ Your ref: 2P-431 Version #2 Our ref: prop4522 License: Date printed: 8-Feb-2002 Date created: 25-Feb-2001 Last revised: 8-Feb-2002 . 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 9.252,w150 26 56.943 Slot Grid coordinates are N 5868934.839, E 443874.087 Slot local coordinates are 942.14 S 1917.27 E Projection type: alaska - Zone 4, Spheroid: Cl:arke - 1866 Reference North is True North . ) Oh¡ \iI¡/J¡4;~ ) Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,43l Your ref: 2P-43l Version 112 . Mel twater, North Slope, Alaska Last revised: 8-Feb-2002 Measured Inclin. A2:imuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 183 .01 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 183.01 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 183.01 300.00 0.00 N 0.00 E 0.00 0.00 KOP 400.00 2.00 183 .01 399.98 1.74 S 0.09 W 2.00 1.75 500.00 4.00 183 .01 499.84 6.97 S 0.37 W 2.00 6.98 600.00 6.00 183 .01 599.45 15.67 S 0.82 W 2.00 15.69 700.00 8.00 183.01 698.70 27.84 S 1.46 W 2.00 27.88 800.00 10.00 183 .01 797.47 43.46 S 2.28 W 2.00 43.52 3/100 Build 866.67 12.00 183.01 862.90 56.17 S 2.95 W 3.00 56.24 966.67 15.00 183 .01 960.13 79.47 S 4.17 W 3.00 79.58 1066.67 18.00 183 .01 1056.00 107.83 S 5.66 W 3.00 107.98 1166.67 21.00 183.01 1150.25 141.17 S 7.41 W 3.00 141.36 1266.67 24.00 183.01 1242.63 179.38 S 9.42 W 3.00 179.62 1366.67 27.00 183.01 1332.88 222.36 S 11.68 W 3.00 222.67 1390.45 27.71 183.01 1354.00 233.28 S 12.25 W 3.00 233.60 Base Permafrost 1466.67 30.00 183.01 1420.75 270.01 S 14.18 W 3.00 270.38 1566.67 33.00 183 .01 1506.01 322.18 S 16.92 W 3.00 322.62 1666.67 36.00 183 .01 1588.41 378.74 S 19.89 W 3.00 379.26 1766.67 39.00 183 .01 1667.74 439.52 S 23.08 W 3.00 440.13 1866.67 42.00 183 .01 1743.77 504.37 S 26.49 W 3.00 505.06 1966.67 45.00 183 .01 1816.30 573.10 S 30.10 W 3.00 573.89 2066.67 48.00 183.01 1885.12 645.53 S 33 .90 W 3.00 646.42 2166.67 51.00 183.01 1950.06 721.46 S 37.89 W 3.00 722.45 2172.94 51.19 183 .01 1954.00 726.33 S 38.15 W 3.00 727.33 Base West Sak 2266.67 54.00 183 .01 2010.93 800.68 S 42.05 W 3.00 801.78 2366.67 57.00 183 .01 2067.56 882.97 S 46.37 W 3.00 884.18 2466.67 60.00 ,183.01 2119.81 968.10 S 50.84 W 3.00 969.44 2491.35 60.74 183 .01 2132.01 989.53 S 51. 97 W 3.00 990.89 EOC 2500.00 60.74 183.01 2136.24 997.06 S 52.37 W 0.00 998.44 3000.00 60.74 183 .01 2380.62 1432.67 S 75.25 W 0.00 1434.65 3007.16 60.74 183 .01 2384.12 1438.91 S 75.57 W 0.00 1440.89 7 5/8 CSG 3107.16 60.74 183 .01 2433.00 1526.03 S 80.15 W 0.00 1528.14 C80 3500.00 60.74 183.01 2625.01 1868.28 S 98.12 W 0.00 1870.85 . 4000.00 60.74 183 .01 2869.39 2303.89 S 121.00 W 0.00 2307.06 4222.21 60.74 183 .01 2978 .00 2497.48 S 131.17 W 0.00 2500.92 C50 4500.00 60.74 183 .01 3113.77 2739.49 S 143.88 W 0.00 2743.27 4866.69 60.74 183 .01 3293.00 3058.96 S 160.66 W 0.00 3063.17 C40 5000.00 60.74 183 .01 3358.16 3175.10 S 166.76 W 0.00 3179.47 5220.64 60.74 183 .01 3466.00 3367.33 S 176.86 W 0.00 3371.97 C37 5500.00 60.74 183 .01 3602.54 3610.71 S 189.64 W 0.00 3615.68 6000.00 60.74 183 .01 3846.92 4046.31 S 212.52 W 0.00 4051.89 6500.00 60.74 183 .01 4091.31 4481.92 S 235.40 W 0.00 4488.10 7000.00 60.74 183 .01 4335.69 4917.53 S 258.27 W 0.00 4924.30 7354.58 60.74 183 .01 4509.00 5226.44 S 274.50 W 0.00 5233.65 T7 7500.00 60.74 183 .01 4580.07 5353.13 S 281.15 W 0.00 5360.51 8000.00 60.74 183 .01 4824.46 5788.74 S 304.03 W 0.00 5796.72 8500.00 60.74 183 .01 5068.84 6224.35 S 326.91 W 0.00 6232.92 9000.00 60.74 183 .01 5313.23 6659.95 S 349.79 W 0.00 6669.13 9071.15 60.74 183 .01 5348.00 6721.94 S 353 . 04 W 0.00 6731.20 T3.l All data is in feet unless otherwise stated. Coordinates from slot *431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea Bottom hole distance is 7512.32 on a2:imuth 183.01 degrees from wellhead. Total Dogleg for wellpath is 60.74 degrees. Vertical section is from wellhead on a2:imuth 183.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . ') level) . 0 ~~.; - i: ' ,; ,",',.\ ,'~ t11 U ß J '~ l~~ L . . . ') Phillips Alaska, Inc. Drill Site 2P,431 Me1twater,North Slope, Alaska Measured Inc1in. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COO R DIN ATE S 9140.96 60.74 183.01 5382.12 6782.76 S 356.24 W 9240.96 60.74 183.01 5431. 00 6869.88 S 360.81 W 9488.50 60.74 183.01 5551. 99 7085.54 S 372.14 W 9488.52 60.74 183.01 5552.00 7085.56 S 372.14W 9500.00 60.74 183.01 5557.61 7095.56 S 372.67W 9666.52 60.74 183 .01 5639.00 7240.64 S 380.29 W 9966.50 60.74 183.01 5785.62 7501. 98 S 394.01 W Dogleg Deg/100ft ') PROPOSAL LISTING Page 2 Your ref: 2P-431 Version #2 Last revised: 8-Feb-2002 Vert Sect 0.00 0.00 0.00 0.00 0.00 6792.11 5 1/2 X 3 1/2 Crossover 6879.35 T3 (Top Bermuda) 7095.31 Target 7095.33 MW(AE) Midpt TGT RVSD 29Jan01 7105.34 0.00 0.00 7250.62 T2 (Base Bermuda) 7512.32 TD, Csg pt All data is in feet unless otherwise stated. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea Bottom hole distance is 7512.32 on azimuth 183.01 degrees from wellhead. Total Dogleg for wellpath is 60.74 degrees. Vertical section is from wellhead on azimuth 183.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level). C ?iGfN,4L ') ') . Phillips Alaska, Inc. Drill Site 2P,431 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2P-431 Version *2 Last revised: 8-Feb-2002 Comments in wellpath -------------------- -------------------- MD Rectangular Coords. Comment TVD - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 300.00 300.00 0.00 N 0.00 E KOP 800.00 797.47 43.46 S 2.28 W 3/100 Build 1390.45 1354.00 233.28 S 12.25 W Base Permafrost 2172 . 94 1954.00 726.33 S 38.15 W Base West Sak 2491.35 2132.01 989.53 S 51.97 W EOC 3007.16 2384.12 1438.91 S 75.57 W 7 5/8 CSG 3107.16 2433.00 1526.03 S 80.15 W C80 4222.21 2978.00 2497.48 S 131.17 W C50 4866.69 3293.00 3058.96 S 160.66 W C40 5220.64 3466.00 3367.33 S 176.86 W C37 7354.58 4509.00 5226.44 S 274.50 W T7 9071.15 5348.00 6721.94 S 353.04 W T3.1 9140.96 5382.12 6782.76 S 356.24 W 5 1/2 X 3 1/2 Crossover 9240.96 5431.00 6869.88 S 360.81 W T3 (Top Bermuda) 9488.50 5551. 99 7085.54 S 372 .14 W Target 9488.52 5552.00 7085.56 S 372.14 W MW(AE) Midpt TGT RVSD 29Jan01 9666.52 5639.00 7240.64 S 380.29 W T2 (Base Bermuda) 9966.50 5785.62 7501.98 S 394.01 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 7501.98S 1438.91S 394.01W 3 1/2 Csg 75.57W 7 5/8 Csg O.OON O.OON O.OOE 9966.50 5785.62 O.OOE 3007.162384.12 Targets associated with this wellpath === = ========c= = ====== === ========= ==== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(AE) Midpt TGT RVS 443448.000.5861853.000,999.00 5552.00 7085.56S 372.14W 22-Feb-2001 . . U'"': ," .' è';,: ~\ u ~" , ~,' "" ',J .,' ;~ ,t ~ ~ I fiiUJjlYfL ') ) Phillips Alaska, Inc. Drill Site 2P 431 slot #431 Meltwater North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 2P-43l Version #2 Our ref: prop4522 License: Date printed: ll-Feb-2002 Date created: 25-Feb-200l Last revised: 8-Feb-2002 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 9.252,w150 26 56.943 Slot Grid coordinates are N 5868934.839, E 443874.087 Slot local coordinates are 942.14 S 1917.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-Jun-2001 140.2 100.0 100.0 25-May-2001 279.9 0.0 0.0 8-Feb-2002 179.6 300.0 300.0 5-Feb-2002 339.9 0.0 0.0 10-Jan-2002 339.9 0.0 0.0 28-Dec-2001 339.9 0.0 0.0 17-Dec-2001 319.7 200.0 200.0 2-Dec-2001 319.7 200.0 200.0 14-Jan-2002 220.0 100.0 100.0 I-Feb-2002 40.0 0.0 0.0 26-Feb-2001 287.1 9000.0 9000.0 6-Mar-2001 39545.1 9966.5 9966.5 26-Feb-2001 3682.1 3160.0 3160.0 26-Feb-2001 3434.1 2800.0 2800.0 MWD <0-9224'>,,438,Drill Site 2P MWD <0 - 6008'>,,417,Drill Site 2P MWD <0-777'>, ,422,Drill Site 2P MWD <4000 - 7593'>,,448B,Drill Site 2P MWD <754 - 8663'>,,448A,Dril1 Site 2P MWD <0-2040'>, ,448,Drill Site 2P MWD <5552 - 9038' >, ,USA, Drill si te 2P MWD <3660 - 1l075'>,,415,Drill Site 2P MWD <0-6860'>,,420,Drill Site 2P MWD <0-8974'>,,429,Drill Site 2P PMSS <0-6122 '>, ,MWN#l,Meltwater North #1 PMSS <0-8935'>, ,MWSouthl , Meltwater South #1 PMSS <0-6300'>"MWN#2,Meltwater North #2 PMSS <2212-7349' >, ,MWN#2A, Mel twater North #2 ~ = I ~/NA .' , .J ,M8W 8, ) . Phillips Alaska, Inc. Drill Site 2P 431 slot U31 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 2P-431 Version *2 Our ref: prop4522 License: Date printed: 8-Feb-2002 Date created: 25-Feb-2001 Last revised: 8-Feb-2002 . 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 9.252, w150 26 56.943 Slot Grid coordinates are N 5868934.839, E 443874.087 Slot local coordinates are 942.14 S 1917.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . ) 0 i;"-)")I1:~ ff fi J ~ L tli'llJir ) ") Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,431 Your ref: 2P-431 Version *2 . Meltwater,North Slope, Alaska Last revised: 8-Feb-2002 Measured Inclin. Azimuth True Vert RECTANGULAR Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth COO R DIN ATE S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 183.01 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 183.01 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 183 .01 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 2.00 183.01 399.98 1. 74 S 0.09 W 1. 75 1.05 1.05 0.60 N/A 500.00 4.00 183.01 499.84 6.97 S 0.37 W 6.98 1.36 1.31 0.75 3.01 600.00 6.00 183.01 599.45 15.67 S 0.82 W 15.69 1.73 1.58 0.90 3.01 700.00 8.00 183.01 698.70 27.84 S 1.46 W 27.88 2.20 1.86 1.05 3.01 800.00 10.00 183.01 797.47 43.46 S 2.28 W 43.52 2.77 2.16 1.21 3.01 866.67 12.00 183.01 862.90 56.17 S 2.95 W 56.24 3.23 2.36 1.31 3.01 966.67 15.00 183.01 960.13 79.47 S 4.17 W 79.58 4.08 2.69 1.48 3.01 1066.67 18.00 183.01 1056.00 107.83 S 5.66 W 107.98 5.11 3.05 1. 65 3.01 1166.67 21. 00 183.01 1150.25 141.17 S 7.41 W 141. 36 6.32 3.43 1.84 3.01 1266.67 24.00 183.01 1242.63 179.38 S 9.42 W 179.62 7.71 3.84 2.05 3.01 1366.67 27.00 183.01 1332.88 222 .36 S 11.68 W 222.67 9.26 4.29 2.28 3.01 1390.45 27.71 183.01 1354.00 233.28 S 12.25 W 233 .60 9.67 4.40 2.35 3.01 1466.67 30.00 183.01 1420.75 270.01 S 14.18 W 270.38 10.99 4.75 2.55 3.01 1566.67 33.00 183.01 1506.01 322.18 S 16.92 W 322.62 12.87 5.24 2.86 3.01 1666.67 36.00 183.01 1588.41 378.74 S 19.89 W 379.26 14.91 5.75 3.21 3.01 1766.67 39.00 183.01 1667.74 439 . 52 S 23 .08 W 440.13 17.10 6.28 3.62 3.01 1866.67 42.00 183.01 1743.77 504.37 S 26.49 W 505.06 19.43 6.82 4.07 3.01 1966.67 45.00 183.01 1816.30 573.10 S 30.10 W 573.89 21. 89 7.36 4.58 3.01 2066.67 48.00 183 .01 1885.12 645.53 S 33.90 W 646.42 24.49 7.90 5.15 3.01 2166.67 51. 00 183.01 1950.06 721.46-S 37.89 W 722.45 27.21 8.43 5.78 3.01 2172 . 94 51.19 183.01 1954.00 726.33 S 38.15 W 727.33 27.38 8.47 5.82 3.01 2266.67 54.00 183 .01 2010.93 800.68 S 42.05 W 801. 78 30.04 8.96 6.46 3.01 2366.67 57.00 183.01 2067.56 882.97 S 46.37 W 884.18 32.98 9.47 7.19 3.01 2466.67 60.00 183.01 2119.81 968.10 S 50.84 W 969.44 36.01 9.96 7.98 3.01 2491. 35 60.74 183.01 2132.01 989.53 S 51. 97 W 990.89 36.77 10.08 8.18 3.01 2500.00 60.74 183.01 2136.24 997.06 S 52.37 W 998.44 37.03 10.12 8.25 3.01 3000.00 60.74 183.01 2380.62 1432.67 S 75.25 W 1434.65 52.36 12.54 12.32 3.01 3007.16 60.74 183.01 2384.12 1438.91 S 75.57 W 1440.89 52.58 12.57 12.38 3.01 3107.16 60.74 183.01 2433.00 1526.03 S 80.15 W 1528.14 55.65 13.05 13.21 3.01 3500.00 60.74 183.01 2625.01 1868.28 S 98.12 W 1870.85 67.71 14.95 16.44 3.01 . 4000.00 60.74 183.01 2869.39 2303.89 S 121. 00 W 2307.06 83.07 17.37 20.58 3.01 4222.21 60.74 183.01 2978.00 2497.48 S 131. 17 W 2500.92 89.90 18.44 22.42 3.01 4500.00 60.74 183.01 3113.77 2739.49 S 143.88 W 2743.27 98.43 19.78 24.72 3.01 4866.69 60.74 183.01 3293.00 3058.96 S 160.66 W 3063.17 109.70 21. 55 27.76 3.01 5000.00 60.74 183.01 3358.16 3175.10 S 166.76 W 3179.47 113.80 22.19 28.87 3.01 5220.64 60.74 183.01 3466.00 3367.33 S 176.86 W 3371.97 120.58 23.26 30.70 3.01 5500.00 60.74 183.01 3602.54 3610.71 S 189.64 W 3615.68 129.17 24.60 33.02 3.01 6000.00 60.74 183.01 3846.92 4046.31 S 212.52 W 4051. 89 144.54 27.02 37.17 3.01 6500.00 60.74 183.01 4091.31 4481.92 S 235.40 W 4488.10 159.92 29.43 41.33 3.01 7000.00 60.74 183.01 4335.69 4917.53 S 258.27 W 4924.30 175.29 31.84 45.48 3.01 7354.58 60.74 183.01 4509.00 5226.44 S 274.50W 5233.65 186.19 33.55 48.43 3.01 7500.00 60.74 183.01 4580.07 5353.13 S 281.15 W 5360.51 190.67 34.25 49.64 3.01 8000.00 60.74 183.01 4824.46 5788.74 S 304.03 W 5796.72 206.04 36.67 53.80 3.01 8500.00 60.74 183.01 5068.84 6224.35 S 326.91 W 6232.92 221.42 39.08 57.95 3.01 9000.00 60.74 183.01 5313.23 6659.95 S 349.79 W 6669.13 236.79 41. 49 62.11 3.01 9071.15 60.74 183.01 5348.00 6721. 94 S 353.04W 6731.20 238.98 41. 83 62.70 3.01 All data is in feet unless otherwise stated. Coordinates from slot 1431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea Bottom hole distance is 7512.32 on azimuth 183.01 degrees from wellhead. Vertical section is from wellhead on azimuth 183.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . . 0\ ,," dL . /"¡l ~¡ ¡ J Jl-! . ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Drill Site 2P,431 Your ref: 2P-431 Version #2 . Meltwater,North Slope, Alaska Last revised: 8-Feb-2002 Measured Inclin. Azimuth True Vert RECTANGULAR Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth COO R DIN ATE S Sect Maj or Minor Vert. Azi. 9140.96 60.74 183.01 5382.12 6782.76 S 356.24 W 6792.11 241.13 42.17 63.28 3.01 9240.96 60.74 183 .01 5431. 00 6869.88 S 360.81 W 6879.35 244.20 42.65 64.12 3.01 9488.50 60.74 183.01 5551. 99 7085.54 S 372.14 W 7095.31 251.81 43.85 66.17 3.01 9488.52 60.74 183 .01 5552.00 7085.56 S 372.14 W 7095.33 251. 81 43.85 66.17 3.01 9500.00 60.74 183 .01 5557.61 7095.56 S 372.67 W 7105.34 252.17 43.90 66.27 3.01 9666.52 60.74 183 .01 5639.00 7240.64 S 380.29 W 7250.62 257.29 44.71 67.65 3.01 9966.50 60.74 183.01 5785.62 7501. 98 S 394.01 W 7512.32 266.51 46.15 70.15 3.01 POSITION UNCERTAINTY SUMMARY ============================== Depth From To position uncertainty Major Minor Vert. Survey Tool Error Model - - - - - - -- - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 9967 User specified 46.15 ARCO (H.A) Mag) 266.51 1. Ellipse dimensions are half axis . 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. . . All data is in feet unless otherwise stated. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea Bottom hole distance is 7512.32 on azimuth 183.01 degrees from wellhead. Vertical section is from wellhead on azimuth 183.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . 70.15 ONH.;u,JtiL . . . ) 1 Phillips Alaska, Inc. Drill 5ite 2P,43l Meltwater,North 5lope, Alaska PROP05AL LI5TING Page 3 Your ref: 2P-43l version *2 Last revised: 8-Feb-2002 Comments in wellpath ======::::============= MD Rectangular Coords. Comment TVD - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- 300.00 300.00 0.00 N 0.00 E KOP 800.00 797.47 43.46 5 2.28 W 3/100 Build 1390.45 1354.00 233.28 5 12.25 W Base Permafrost 2172 .94 1954.00 726.33 5 38.15 W Base West 5ak 2491.35 2132.01 989.53 5 51. 97 W EOC 3007.16 2384.12 1438.91 5 75.57 W 7 5/8 C5G 3107.16 2433.00 1526.03 5 80.15 W C80 4222.21 2978.00 2497.48 5 131.17 W C50 4866.69 3293.00 3058.96 S 160.66 W C40 5220.64 3466.00 3367.33 S 176.86 W C37 7354.58 4509.00 5226.44 5 274.50 W T7 9071.15 5348.00 6721.94 5 353.04W T3.1 9140.96 5382.12 6782.76 5 356.24 W 5 1/2 X 3 1/2 Crossover 9240.96 5431. 00 6869.88 S 360.81 W T3 I Top Bermuda) 9488.50 5551.99 7085.54 S 372.14W Target 9488.52 5552.00 7085.56 S 372.14 W MWIAE) Midpt TGT RV5D 29JanOl 9666.52 5639.00 7240.64 5 380.29 W T2 I Base Bermuda) 9966.50 5785.62 7501.98 5 394.01 W TD, Csg pt Casing positions in string 'A' ====================~::8== =::1:==:::=:::::: 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. DOE 9966.50 5785.62 O.OOE 3007.16 2384.12 7501.985 1438.915 394.01W 3 1/2 Csg 75.57W 7 5/8 Csg Targets associated with this wellpath ================::::::::: == ======== ====::: ==::: Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW IAE) Midpt TGT RV5 443448.000,5861853.000,999.00 5552.00 7085.565 372.14W 22-Feb-2001 Únl \.i¡¡¡YdL ) . Phillips Alaska, Inc. Drill Site 2P 431 slot t431 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2P-431 Version #2 Our ref: prop4522 License: Date printed: 8-Feb-2002 Date created: 25-Feb-2001 Last revised: 8-Feb-2002 . 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 9.252, w150 26 56.943 Slot Grid coordinates are N 5868934.839, E 443874.087 Slot local coordinates are 942.14 S 1917.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . ) Of"'" ., " , j II "" ~ ,: .,1" ' , '~ II ~ "J ,t J ,:'J L I , \¡II d ß r.~ ) ) Phillips Alaska, Inc. PROPQ5AL LISTING Page 1 Drill Site 2P,43l Your ref: 2P-43l Version #2 . Mel twa ter, North 5lope, Alaska Last revised: 8-Feb-2002 Measured Inclin Azimuth True Vert RECTANGULAR G RID COORDS G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5 0.00 0.00 0.00 0.00 O.OON O.OOE 443874.09 5868934.84 n70 3 09.25 w150 26 56.94 100.00 0.00 183.01 100.00 O.OON O.OOE 443874.09 5868934.84 n70 3 09.25 w150 26 56.94 200.00 0.00 183 .01 200.00 O.OON O.OOE 443874.09 5868934.84 n70 3 09.25 w150 26 56.94 300.00 0.00 183 .01 300.00 O.OON O.OOE 443874.09 5868934.84 n70 3 09.25 w150 26 56.94 400.00 2.00 183.01 399.98 1. 745 0.09W 443873.98 5868933.10 n70 3 09.23 w150 26 56.95 500.00 4.00 183.01 499.84 6.975 0.37W 443873.67 5868927.87 n70 3 09.18 w150 26 56.95 600.00 6.00 183 .01 599.45 15.675 0.82W 443873.14 5868919.17 n70 3 09.10 w150 26 56.97 700.00 8.00 183 .01 698.70 27.845 1. 46W 443872.41 5868907.01 n70 3 08.98 w150 26 56.99 800.00 10.00 183 .01 797.47 43.465 2.28W 443871.47 5868891.40 n70 3 08.82 w150 26 57.01 866.67 12.00 183.01 862.90 56.175 2.95W 443870.71 5868878.70 n70 3 08.70 w150 26 57.03 966.67 15.00 183 .01 960.13 79.47S 4.17W 443869.31 5868855.41 n70 3 08.47 w150 26 57.06 1066.67 18.00 183 .01 1056.00 107.835 5.66W 443867.60 5868827.06 n70 3 08.19 w150 26 57.11 1166.67 21. 00 183 .01 1150.25 141.175 7.41W 443865.60 5868793.75 n70 3 07.86 w150 26 57.16 1266.67 24.00 183 .01 1242.63 179.385 9.42W 443863.30 5868755.56 n70 3 07.49 w150 26 57.22 1366.67 27.00 183 .01 1332.88 222.365 11.68W 443860.72 5868712.59 n70 3 07.07 w150 26 57.28 1390.45 27.71 183 .01 1354.00 233.285 12. 25W 443860.06 5868701.69 n70 3 06.96 w150 26 57.30 1466.67 30.00 183.01 1420.75 270.015 14.18W 443857.85 5868664.97 n70 3 06.60 w150 26 57.35 1566.67 33.00 183.01 1506.01 322.185 16. 92W 443854.71 5868612.83 n70 3 06.08 w150 26 57.43 1666.67 36.00 183.01 1588.41 378.745 19. 89W 443851.31 5868556.30 n70 3 05.53 w150 26 57.52 1766.67 39.00 183 .01 1667.74 439.525 23. 08W 443847.66 5868495.55 n70 3 04.93 w150 26 57.61 1866.67 42.00 183 .01 1743.77 504.375 26.49W 443843.76 5868430.73 n70 3 04.29 w150 26 57.71 1966.67 45.00 183 .01 1816.30 573.105 30.10W 443839.63 5868362.04 n70 3 03.62 w150 26 57.81 2066.67 48.00 183.01 1885.12 645.535 33. 90W 443835.27 5868289.65 n70 3 02.90 w150 26 57.92 2166.67 51. 00 183 .01 1950.06 721.465 37. 89W 443830.70 5868213.76 n70 3 02. 16 w150 26 58.04 2172 .94 51.19 183 .01 1954.00 726.335 38.15W 443830.41 5868208.89 n70 3 02.11 w150 26 58.05 2266.67 54.00 183 .01 2010.93 800.685 42. 05W 443825.94 5868134.58 n70 3 01. 38 w150 26 58.16 2366.67 57.00 183 .01 2067.56 882.975 46.37W 443820.99 5868052.34 n70 3 00.57 w150 26 58.29 2466.67 60.00 183 .01 2119.81 968.105 50. 84W 443815.87 5867967.24 n70 2 59.73 w150 26 58.41 2491.35 60.74 183 .01 2132.01 989.535 51.97W 443814.58 5867945.83 n70 2 59.52 w150 26 58.45 2500.00 60.74 183 .01 2136.24 997.065 52.3 7W 443814.13 5867938.30 n70 2 59.45 w150 26 58.46 3000.00 60.74 183 .01 2380.62 1432.675 75.25W 443787.93 5867502.92 n70 2 55.16 w150 26' 59.12 3007.16 60.74 183 .01 2384.12 1438.915 75. 57W 443787.56 5867496.69 n70 2 55.10 w150 26 59.13 3107.16 60.74 183 .01 2433.00 1526.035 80.15W 443782.32 5867409.61 n70 2 54.24 w150 26 59.26 3500.00 60.74 183.01 2625.01 1868.285 98.12W 443761.74 5867067.54 n70 2 50.88 w150 26 59.78 . 4000.00 60.74 183 .01 2869.39 2303.895 121.00W 443735.54 5866632.16 n70 2 46.59 w150 27 00.44 4222.21 60.74 183 .01 2978.00 2497.485 131. 17W 443723.90 5866438.67 n70 2 44.69 w150 27 00.74 4500.00 60.74 183 .01 3113.77 2739.495 143. 88W 443709.35 5866196.79 n70 2 42.31 w150 27 01.11 4866.69 60.74 183.01 3293.00 3058.965 160. 66W 443690.14 5865877.49 n70 2 39.17 w150 27 01. 59 5000.00 60.74 183.01 3358.16 3175.105 166. 76W 443683.15 5865761.41 n70 2 38.02 w150 27 01.77 5220.64 60.74 183 .01 3466.00 3367.335 176.86W 443671.59 5865569.28 n70 2 36.13 w150 27 02.06 5500.00 60.74 183 .01 3602.54 3610.715 189. 64W 443656.96 5865326.03 n70 2 33.74 w150 27 02.43 6000.00 60.74 183.01 3846.92 4046.315 212. 52W 443630.76 5864890.65 n70 2 29.46 w150 27 03.09 6500.00 60.74 183.01 4091.31 4481.925 235.40W 443604.57 5864455.27 n70 2 25.17 w150 27 03.75 7000.00 60.74 183 .01 4335.69 4917.535 258.27W 443578.37 5864019.90 n70 2 20.89 w150 27 04.41 7354.58 60.74 183 .01 4509.00 5226.445 274. 50W 443559.80 5863711.14 n70 2 17.85 w150 27 04.88 7500.00 60.74 183 .01 4580.07 5353.135 281.15W 443552.18 5863584.52 n70 2 16.60 w150 27 05.08 8000.00 60.74 183 .01 4824.46 5788.745 304.03W 443525.98 5863149.14 n70 2 12.32 w150 27 05.74 8500.00 60.74 183.01 5068.84 6224.355 326. 91W 443499.79 5862713.76 n70 2 08.03 w150 27 06.40 9000.00 60.74 183 .01 5313.23 6659.955 349. 79W 443473.59 5862278 .39 n70 2 03.75 w150 27 07.06 9071.15 60.74 183.01 5348.00 6721.945 353.04W 443469.87 5862216.43 n70 2 03.14 w150 27 07.15 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level). Bottom hole distance is 7512.32 on azimuth 183.01 degrees from wellhead. Total Dogleg for wellpath is 60.74 degrees. Vertical section is from wellhead on azimuth 183.01 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . J 1/GINAL ') ) Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Drill site 2P,431 Your ref: 2P-431 version #2 . Me1 twa ter ,North Slope, Alaska Last revised: 8-Feb-2002 Measured Inc1in Azimuth True Vert RECTANGULAR G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE 5 9140.96 60.74 183.01 5382.12 6782.765 356.24W 443466.21 5862155.64 n70 2 02.54 w150 27 07.24 9240.96 60.74 183.01 5431. 00 6869. 88S 360. 81W 443460.97 5862068.57 n70 2 01.69 w150 27 07.38 9488.50 60.74 183 .01 5551.99 7085.545 372 .14W 443448.00 5861853.02 n70 1 59.56 w150 27 07.70 9488.52 60.74 183 .01 5552.00 7085.565 372 .14W 443448.00 5861853.00 n70 1 59.56 w150 27 07.70 9500.00 60.74 183 .01 5557.61 7095.565 372. 67W 443447.40 5861843.01 n70 1 59.47 w150 27 07.72 9666.52 60.74 183.01 5639.00 7240.645 380.29W 443438.67 5861698.01 n70 1 58.04 w150 27 07.94 9966.50 60.74 183 .01 5785.62 7501.985 394.01W 443422.96 5861436.80 n70 1 55.47 w150 27 08.34 . . All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #431 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level). Bottom hole distance is 7512.32 on azimuth 183.01 degrees from wellhead. Total Dogleg for wellpath is 60.74 degrees. Vertical section is from wellhead on azimuth 183.01 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ J/lIG .^t,¡. . . . ) ) Phillips Alaska. Inc. Drill Site 2P.431 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2P-431 Version #2 Last revised: 8-Feb-2002 Comments in wellpath -------------------- -------------------- MD TVD Comment Rectangular Coords. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -- 300.00 300.00 O.OON O.OOE KOP 800.00 797.47 43. 46S 2.28W 3/100 Build 1390.45 1354.00 233.285 l2.25W Base Permafrost 2172.94 1954.00 726. 33S 38.15W Base West Sak 2491.35 2132.01 989.53S 51.97W EOC 3007.16 2384.12 1438. 91S 75.57W 7 5/8 CSG 3107.16 2433.00 1526. 03S 80.15W C80 4222.21 2978.00 2497. 48S 131.17W C50 4866.69 3293.00 3058.96S 160. 66W C40 5220.64 3466.00 3367.33S 176. 86W C37 7354.58 4509.00 5226. 44S 274.50W T7 9071.15 5348.00 6721.94S 353. 04W T3.1 9140.96 5382.12 6782. 76S 356.24W 5 1/2 X 3 1/2 Crossover 9240.96 5431. 00 6869. 88S 360.81W T3 (Top Bermuda) 9488.50 5551.99 7085. 54S 372 .14W Target 9488.52 5552.00 7085.56S 372 .14W MW(AE) Midpt TGT RVSD 29JanOl 9666.52 5639.00 7240. 64S 380.29W T2 (Base Bermuda) 9966.50 5785.62 7501.98S 394.01W TD, Csg pt Casing positions in string 'A' ==== ==== == ====== c == == ======= ==== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 0.00 0.00 0.00 0.00 394.01W 3 1/2 Csg 75 . 57W 7 5/8 Csg O.OON O.OON O.OOE 9966.50 5785.62 O.OOE 3007.16 2384.12 7501.98S 1438.91S Targets associated with this wellpath == ======== == === ===== == ======== === == == == == Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(AE) Midpt TGT RVS 443448.000,5861853.000,999.00 5552.00 7085.56S 372.14W 22-Feb-2001 Ji1iGiNtlL ) ') 2P-431 Drillina Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) Surface Casina Interval .- Event J. n Risk ~~y~I--_. Tight hole / Packoff problems Moderate Conductor Broach Well Collision Low Low Gravel and sand sloughing Low Shakerffrough Cuttings System Overflow Permafrost Hydrates Low Low .// Shoe Fracture/Lost Returns during cement job Low Production Casina Interval Interval Risks Event Lost Circulation Risk Level High High ECO and swabbing if higher MW is required High Tight hole / Packott problems Moderate - Mi~.igation Stra.te.9Y .. Revised BHA design, good hole cleaning practices, new surface mud design - LSNO. Monitor cellar continuously during interval. Careful well planning and surveying, adherence to anti-collision policy Elevated mud viscosity from spud; Hi dens sweeps. Controlled ROP Controlled drilling, reduced pump rates, higher mud weights, cold mix water and mud, lower viscosities, and lecithin additions as needed. Reduced pump rates, and lightweight tail cement Mitigation Strategy Good drilling practices. LCM, InstanSEAL as needed. Stay within ECO hardlines Pumping and rotating out on all trips to reduce swab and barite sag potential. Keep hole mud system as clean as possible. Bring pumps on slowly. RIH / slowly to avoid surge. / Revised BHA design, good hole cleaning practices 2P-451 Drilling Hazards Summary.doc prepared by Pat Reilly 03/01/02 I' .. Page 1 ofì 1 U... ...' j . . , \,rJ d ~ IJ r'l ... ~ ') PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Meltwater 2P-4 -'~ Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +1- 120' MD r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Port Collar 1000' MD Depths are based on Doyon 141 RKB Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 3007' MD 12384' TVD 12' Pup (Critical) Intermediate csg. 5-1/2" 15.5# L-80 BTCM run CSR to surface +/- 9140' MD 15382 TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD TD to CSR +1- 9966' MD I 5785' TVD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ L. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ?~ ~m<H<J'" ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -- .... ~ +- ~ 9///.///1 ~ 't////y ~.c , ¡ , , , , , , , , , , , , , , , , . , , , , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .ìII/Ä v'" , ./ ...¡ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9,3# L-80 EUE8RD Tubing to Surface 3-1/2" Cameo 'DS' nipple w/ 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Cameo 'KBG-2-9' Mandrels wi DV's and RK latch's (Max. aD 4.725", ID 2.90"), IBT box x box, 3-1/2" X 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below. Spaced out w/ 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined 3-1/2" x 1" Cameo 'KBG-2-9' mandrel wi DCK-3 shear valve and bottom latch (Max. aD 4.725", ID 2,90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve wi 2.813" Camco No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Cameo 'D' nipple wi 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wi 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top - Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" aD x 4" ID 17' Seal Bore Extension CSR set at +1- 1 DO' MD above the top of the Bermuda (OR 1 DO' MD ABOVE THE TOP OF THE CAIRN IF THE CAIRN IS PRESENT) c q I GJJ¡V,AL Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 3/1/2002 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 233-8808 email: ceavant@slb.com ./ < TOC at Surface ../ Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 120 ft. MD < Base of Permaf rost at 1 ,390 ft. MD (1,354 ft. 1VD) < Top of Tail at 1,410ft. MD < 7 5/8", 29.7#, L-80 grade BTC, AB rv10dified in 97/8" OH TV at 3,007 ft. MD (2,384 ft. 1VD) . Mark of Schlumberger Schlumberger Cer,.vAD.E . preliminaryJqbDesign' 7.5/8"Surtac.e 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 20' below base of permafrost.) Lead Slurrv (minimum pump time 183 min.) ASLite @ 10.7 pp~, Class G + 50%0124, 9%D44, 0.4%D46, 30%053, 1.5%S1, 1 .5%079 - 4.44 ft Isk 0.9513 fe/ft x (120') x 1.00 (no excess) = 0.2148 fe/ft x (1390' - 120') x 5.50 (4500/0 excess) = 0.2148 fe/ft x (1410' -1390') x 1.45 (45% excess) = 114.2 fe + 1500.4 fe + 6}/fe = 1620.8 ft3 14.44 fe/sk =/ Round up to 370 sks 114.2 fe 1500.4 fe 6.2 ft3 1620.8 fe 365 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv (minimum pump time 134 min.) LiteCRETE @ 12.0 ppg - 2.40 ft3/sk 0.2148 ft3/ft x (3007' - 1410') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 497.4 ft3 + 20.6 ft3 /" 518 fel 2.40 fe/sk = / Round up to 220 sks 497.4 fe 20.6 fe 518 ft3 215.8 sks BHST = 56°F, Estimated BHCT = 73°F. (BHST calculated using a gradient of 2.3°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 40 6.7 16.4 Lead Slurry 6 293 48.8 65.2 Tail Slurry 6 94 15.7 80.9 Drop Top Plug 3.0 83.9 Displacement 6 114 19.0 102.9 Bump Plug 3 20 6.7 109.6 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ~ 17-20, T y ~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. 0"'" ~': !' ~ f :. .' . '..:.. I.,,' i ; ~ & ~~ 6 i 'iJ ,,' ~ - Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 3/1/2002 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 233-8808 email: ceavant@slb.com I ~11 ~rr II~ J A"evious Csg. < 75/8",29.7#, L-80 grade BTC, AB Modified at 3,007 ft. MO I < 5 1/2", 15.5#, L-80 grade BTC, AB Modified in 6 3/4" OH < Top of Tail at " 8,641 ft. MO .,/' < X-over at 9,141 ft. MO < Top of Bermuda Fm. at 9,241 ft. MD < 3 1/2",9.3#, L-80 grade BJE, 8rd Modif ied in 6 3/4" OH 1D at 9,967 ft. I\JD (5,786 ft. NO) . Mark of Schlumberger Schlumberger Can IvADE . Prèlil1'liriàty~()bDesigri 51/2". X 31/2" Production. Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurrv (minimum thickening time 142 min.) GasBLOK wI Class G + 053, 0600, 0135, 0800, 0047, 0065, per lab testing @ 15.8 ppg, 1.2 fe/sk 0.0835 fe/ft x 500' x 1.75 (75% excess) = 0.1817 fe/ft x (9967' - 9141 ') x 1.75 (75% excess) = 0.0488 ft3/ft x 80' (Shoe Joint) = 73.1 fe + 262.6 fe + 3.9-fe = 339.6 fel 1.2 fe/sk = /' v.'. Round up to 290 sks 73.1 fe 262.6 fe 3.9 ft3 339.6 fe 283 sks BHST = 134°F, Estimated BHCT = 115°F. (BHST calculated using a gradient of 2.3°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 6 60 10.0 10.0 Orop Bottom Plug 3.0 13.0 MudPUSH XL 6 40 6.7 19.7 Tail Slurry 6 62 10.3 30.0 Orop Top Plug 3.0 33.0 Displacement 6 215 35.8 68.8 Bump Plug 3 9 3.0 71.8 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv == 19-22, T y == 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~ ~ ,i" ,I \j' j II d 'w'.. ~ , \~I i' . ~ ;.". ~ PHILLI~ S Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 March 1, 2002 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2P-431 Surface Location: Target Location: Bottom Hole Location: 943'FNL, 1914'FWL,Sec. 17,T8N,R7E 2532' FSL, 1517' FWL, Sec.20,T8N, R7E 2115' FSL, 1494' FWL, Sec.20,T8N, R7E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-431. The well will be drilled and completed using D~1. Please utilize documents on file for this rig. Notð&."5 \tJt;,A Subject to AOGCC approval, fluids and cuttings generated fromdrilling the well will be pumped down an approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Steve Moothart, Geologist 265-6965 If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048. Sincerely, (].e~ Chuck Mallary C. Drilling Engineering Supervisor RECEIVED MAR 0 4 ZOO~ Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ) } PAY. . TO THE ORDERQF: FEBRUARY 14//2002 STATE OF ALASKA AOGCC . ..... . ~33W. 7TH AVENÜE¡SUITEJQ..O 249015t4a PHI.tJLI8S............ALASKAlN~. ALPINEDISSURSEMENTACCOÚNj:<. .. p.O. ~pXlq3240 .. .... ... ... .. AqGt1pr9ge,AK 99510"""'3240 ... ........-. BAN (= ONE. . -- BANK ONE, NA - 0710 Chicagg, I L Payab I~~hrough RepÜbfiCßank & Trust Campany TRACE NUMBER: 249015146 *** VOID AFTER 90 DA YS*** . . '. . DOLLARS AND 00 CENTS$**.******100fOØ ~:p- 43> 1 cŒ. ..........:~........ ........~..................... ..~./................ /~ .... ... C 1112 L. gO.. 5 .. L. bUI 1:08 .ll1 0... 21K21: 0 g gO ~ ~ 7111 CHECK 1 STANDARD LETTER DEVELOPMENT I DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL '\ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BEINCLUDEDINTRANSNUTTALLETTER WELL NAME Jó2tf:2f? tf3/ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) , ANNULAR DISPOSAL , <--J NO ANNULAR DISPOSAL <--J YES ANNULAR DISPOSAL THIS WELL' =7 SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" Tbe permit is for a new wellbore segment of existing wen ~ Permit No, ,API No. . ' Production sbould continue to be reported as a function of tbe original API number stated above. ' In accordance with 20 AAC 25.005(t), all records, data and logs acquired for' tbe pilot hole mu'st be clearly , differentiated in botb name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wen (n8:me on permit). , Annular disposal bas ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . Please note tbat an disposal of fluids generated. '. . Enclosed is tbe approved application for permit to drill the above referenced well. The permit is approved. subject to full compliance witb 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to tbe spacing exception tbat may occur. WELL PERMIT CHECKLIST COMPANY ß,ltjos WELLNAME¡¿.RLi 2P-'I~1 FIELD & POOL t./7'n / ,-/n fNIT CLASS "", FV í /J/l - ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . iN 2. Lease number appropriate.*: . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . ' N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N APJ'.J. DA!-E 12. Permit ca~ be issued without administrativ~ approval.. . . . . N ,.,ð f) 3' ~ .. 02--13. Can permIt be approved before 15-day walt.. . . . . . . . . . N ENGINEERING 14. Conductor string provided... . . . . . . . . . . . . . . . . . N W @ 12-0 I TV D. 15. Surface casing protects all known USDWs. . . . . . . Y N . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~ N ~ q ~ ~ U ~c; S ~4.#I -R..u.:i- - 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y 62. D 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . - NN -D():r~' III t-. ., J -, J .Ie. '2'" 20. Adequate tankage or reserve pit.. .. . . . . . . . . . . . . . . '.- F\W (U .::a 21. If are-drill, hàs a 10-403 for abandonment been approved. . . '¥.::-N-I'M 22. Adequate well bore separation proposed.. . . . . . . . , . . . i2. N 23. If diverter required, does it meet regulations. . . . . . . . . . @ N I 24. Drilling fluid program schematic & equip list adequate. . . . . i NN ~ M rJ ';. 9. (ç -#1 ~ . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 0 - 26. BOPE press rating appropriate; testto '5000 psig. N J./l c;..p - Z 1-$lP f ~ ¡/l1L..¡:. CSc). .þ~ t- ~ ~S 00 P ~ ' 27. Choke manifold complies w/API RP-53 (May 84), . . . , . . . ~ NN ~ . I. 28. Work will occur without operation shutdown. . . . . . . . . . . éiJ 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y tfP 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones. . . . . . . ¡£>r:Ff:. v4..-I ¡..<..~ v¿:> ¡~, ~$U¡;7!_:;' .:t re... 8'- S ,{;, 9.? ~ G".I?]¿.J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AP~ DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . /J JJ :3 . ( ,(5t- 34. Contact name/phone for weekly progress reports [explorat ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will npt contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G$. Y: ENGINEERING: UIC/Annular: COMMISSION: RP " TEM1íØ;-~ COT. ¡ SFD /' WGA \J.JC¡k DT~ 3/0 b û2- JMH Â1V\ H- 3-(£0(02-- APP~ Q.L\1E ~G", 3/5f0 'Z.. [æ9J1l). ~ I çrQ) GEOLOGY APPR DATE PROGRAM: Exp - Dev / Redrll- Serv - Wellbore seg - Ann. disposal para req - GEOL AREA 89() UNIT# (:) /1/ 00 ON/OFF SHORE (J/) c.5ù.A..'¡~ ~Ltl~~ ~ ~:DL 373//2- j -7"'2><:> f"t.Jc/ ~<14-1(.'/J~ 7?;>. ~ ß-PL- 3&9oç:g Y I (' Y N Y N D/{ ~ l ()S~~( (hiö otLt,/ Cjþ,A.. u fu ( . Comments/Instructions: G:\geology\templates\checklist.doc ), ) Well History File APPENDIX Information of detailed nature that is not particularly gennane 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 infonnation, information of this nature is accumulated atthe end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) **** REEL HEADER **** LDWG 03/05/09 AWS 01 **** TAPE HEADER **** LDWG 03/05/08 01 *** LIS COMMENT RECORD *** ) 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: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: MWD RUN 1 1 S. TUFTON R. BOWIE MSL 0) 2P-431 501032041700 Phillips Alaska, Inc. BAKER HUGHES INTEQ 08-MAY-03 MWD RUN 2 2 G. SUTING D. WESTER MWD RUN 3 17 8N 7E 254.00 224.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) aQ;).-053 /110 9Cf PER PHILLIPS ALASKA INSTRUCTIONS, THE GAMMA RAY 9.625 6.750 16.000 7.625 120.0 2988.0 9685.0 ) ) 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 3' 9.252" LONG: W150 DEG 26' 56.943" LOG MEASURED FROM D.F. AT 254.0 FT. ABOVE PERM. DATUM (M.S.L.). COMMENTS: 1) Baker Hughes INTEQ run 1 utilized Gamma Ray with Modular Annular Pressure (MAP) services from 120 - 2960 feet MD (120 - 2367' TVD). 2) Baker Hughes INTEQ run 2 utilized Multiple Propagation Resistivity (MPR) with Modular Annular Pressure (MAP) and Gamma Ray services from 2960 - 9685 feet MD (2367-5823' TVD). REMARKS: 1) Depth of 16 Inch Casing Shoe - Logger: 120 feet MD (120' TVD) Depth of 16 Inch Casing Shoe - Driller: 120 feet MD (120' TVD) 2) The interval from 2960 to 2988 feet MD (2367 - 2381' TVD) was not logged due to the presence of the 7 5/8" casing. 3) Depth of 7 5/8" Inch Casing Shoe - Logger: 2988 fee MD (2381' TVD) Depth of 7 5/8" Inch Casing Shoe - Driller: 2988 fee MD (2381' TVD) 4) The interval from 9634 to 9685 feet MD (5798 - 5823' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 74 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD MWD $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 120.0 2960.0 STOP DEPTH 2960.0 9685.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 120.0 2 3005.0 MERGE BASE 3005.0 9685.0 # REMARKS: MERGED PASS. MPR RESISTIVITY DO NOT BECOME NO DEPTH SHIFTS REFERENCE FOR DATA ALONG WITH FET & MTEM CURVE DATA VALID UNTIL RUN 2 BEGINS AT 2960' MD. WERE APPLIED AS THIS LOG IS THE DEPTH THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p431 5.xtf 150 - Phillips Alaska, Inc. 2P-431 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPS 0.0 RPX RPX RPCSHM 0.0 ROP ROP ROPS 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: 36 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length ) 1 GR MWD 68 1 GAP I 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 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 684 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 120.000000 9685.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 730 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILEOll.HED FILE HEADER FILE NUMBER: 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 120.0 STOP DEPTH 2960.0 # 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: # 30-MAR-02 MSB 18704 6.75 MAP MEMORY 3005.0 120.0 2960.0 0 .0 59.7 ) TOOL STRING (TOP TO VENDOR TOOL CODE DIR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL 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): # REMARKS: BIT RUN 1 (MWD Run 1). GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPS - RATE OF PENETRATION (FPHR) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p431.xtf 150 Phillips Alaska, Inc. 2P-431 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPS GRAM ROPS GRAM ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 ) TOOL NUMBER DAS 7071 1211 9.875 120.0 Spud Mud 9.60 .0 .0 800 .0 .000 .000 .000 .000 112.0 .0 .0 .0 .00 .000 .0 0 ) ) Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAM MWD ROPS MWD 68 68 1 1 GAP I FPHR 4 4 4 4 ------- 8 Total Data Records: 136 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 120.000000 2960.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 209 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 2960.0 STOP DEPTH 9685.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 07-APR-02 MSB 18704 4.75 MPR ) 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. RESIST. 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): REMARKS: # ) MEMORY 9685.0 2960.0 9685.0 0 59.0 61. 0 TOOL NUMBER DAS 1363 MPR 1073 SRIG 2117 6.750 120.0 LSND 9.60 .0 .0 500 .0 .000 .000 .000 .000 128.0 .0 .0 .0 .00 .000 .0 0 BIT RUN 2 (MWD Run 2) . GR/MPR. 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) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER PHILIPS 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 2p431. xtf 150 Phillips Alaska, Inc. 2P-431 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPCSHM 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 19 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: 1416 ) \ ) Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 2960.000000 9685.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 4 1515 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/05/08 01 **** REEL TRAILER **** LDWG 03/05/09 AWS 01 Tape Subfile: 5 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes
