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Home My WebLink About201-1021. 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: Extend Suspension Date 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): 8974' 8900' 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) 263-3731 Senior CTD/RWO Engineer KRU 2P-429 6002' 4779' 3527' 26', 575', 2598', 3025', 4779', 7555' 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: Leslie.Manning@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Leslie Manning STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst 7617' MD MD 110' 2434' 110' 2965' 5997'8966' 16" 9-5/8" 82' 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' (cemented) 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' (cemented) 7" x 4-1/2" Perforation Depth TVD (ft): 12/31/2025 4-1/2" Packer: Baker G-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Extend Suspension Date er Casing ame:4. Current Well Class:5. Permit to Drill Number: Exploratory Development Stratigraphic Service 6. API Number: g:8. Well Name and Number: ation or Conservation Order governs well spacing in this pool? Yes No esignation (Lease Number): 10. Field: D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): 8900' g Collapse al or e ate on SSSV Type:Packers and SSSV MD (ft) and TVD (ft): nts: Proposal Summary Wellbore schematic 13. Well Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service Date for 15. Well Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG esentative:GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: e: approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No (907) 263-3731 Senior CTD/RW O Engineer KRU 2P-429 6002'4779'3527'26', 575', 2598',3025', 4779', 7555' N/A Subsequent Form Required: Suspension Expiration Date: quire a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date: Tubing Size: Leslie.Manning@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Leslie Manning ADL0373112, ADL0389058 201-102 360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended s Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst 7617' MD MD 110' 2434' 110' 2965' 5997'8966' 16" 9-5/8" 82' 2936' 300-8350', 8386- 505' (cemented) 8941' 5549-5586',5621-5649',5670- 5698', 5732-5738' (cemented) 7"x 4-1/2" Perforation Depth TVD (ft): 12/31/2025 4-1/2" Packer: Baker G-22 Seal Assembly SSSV: None pth 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 326-015 By Grace Christianson at 10:34 am, Jan 09, 2026 10-407 X VTL 1/21/26 DSR-1/22/26 March 1, 2026 SFD 1/22/2026JLC 1/22/2026 01/22/26 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska January 7, 2026 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached, the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Well KRU 2P-429 (PTD# 201-102). This 10-403 is being submitted to request an extension of the Suspension Expiration Date to March 1, 2026. If you have any questions, please contact me at (907) 263-3731. Sincerely, Leslie Manning Senior CTD/RWO Engineer Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,779.0 2P-429 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed sand on cement 2P-429 9/15/2025 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: 3.70" RESTRICTION AT 122' RKB. POSSIBLE OVER TORQUED COLLAR. 9/21/2025 rmoore22 NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth 565.0 Set Depth 564.6 String Max No 4 1/2 Tubing Description Tubing Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.92 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 10.880 FMC 11' x 4 1/2" Gen V TBG hanger, 4 1/2" NSTC top thread FMC Gen V 3.920 552.6 552.2 5.16 Shoe - Mule 4.500 4 1/2", 12.6#, L-80, IBT (Mule Shoe) 3.920 Top (ftKB) 3,110.0 Set Depth 7,617.0 Set Depth 5,219.2 String Max No 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 575.0 574.6 5.74 CIBP K-1 CIBP 12/15/2025 0.000 2,595.0 2,212.5 52.86 SAND DUMP BAILED 27 GALLONS OF SAND (8.5 FT EQUIVALENT BY VOLUME). TAGGED 3 FT HIGHER. 9/15/2025 0.000 3,020.0 2,468.0 52.15 CUT MSC Casing Cut @ 3,020' 1/15/2025 6.950 3,025.0 2,471.1 52.12 CIBP 1/21/2025 0.000 3,110.0 2,523.5 51.77 CUT JET CUT AT 3110' RKB 9/19/2024 3.960 6,500.0 4,554.0 53.54 TUBING PUNCH SHOT 4.5 FT OF HOLES. 6 SPF. 8/4/2024 3.960 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 2,965.0 35.0 2,434.3 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 75Drag up (lbs): 135Time started reciprocating: 10:00Time stopped reciprocating: 23:58Annular flow after cement job (Y/N): NCirculating BHT (F): 70Pressure before cementing (psi): 80Hours circulated between stages: 10Pressure left on after job (psi): 686Returns (pct): Full Time cementing mixing started: 21:32 12/12/2001 7,200.0 8,966.0 4,970.6 5,997.1 Cement Casing Annular flow after cement job (Y/N): NCirculating BHT (F): 80Static BHT (F): 80Pressure before cementing (psi): 600Hours circulated between stages: 8Method used to measure density: scaleTime cementing mixing started: 11:00 12/19/2001 2P-429, 1/7/2026 3:45:02 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 3,020.0-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 Cement Casing; 7,200.0 ftKB CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 CIBP; 3,025.0 CUT; 3,020.0 SURFACE; 28.6-2,965.0 Cement Plug; 2,598.0 ftKB SAND; 2,595.0 Cement Casing; 35.0 ftKB CIBP; 575.0 CONDUCTOR; 28.0-110.0 Hanger; 25.6 Cement Plug; 25.6 ftKB KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug PUMP 15.8 PPG CEMENT LAY 3 BBLS ON TOP OF RETAINER. 6/20/2024 4,779.0 6,504.5 3,527.0 4,556.7 Cement Plug PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4779' SLM) 9/7/2024 2,598.0 3,025.0 2,214.3 2,471.1 Cement Plug 1/22/2025 25.6 575.0 25.6 574.6 Cement Plug Cement wet @ 12:19 Hrs. Pump 30 Bbls Surfactant wash @ 3 BPM, 280 PSI. 5 Bbls fresh water @ 3 BPM, 290 PSI, 52 Bbls 15.8 PPG PTA cement @ 3 BPM, 700 PSI. 7 Bbls 15.8 PPG cement returned to surface. Cement in place @ 12:51 Hrs. Close in production & IA vavles. 12/15/2025 2P-429, 1/7/2026 3:45:03 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 3,020.0-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 Cement Casing; 7,200.0 ftKB CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 CIBP; 3,025.0 CUT; 3,020.0 SURFACE; 28.6-2,965.0 Cement Plug; 2,598.0 ftKB SAND; 2,595.0 Cement Casing; 35.0 ftKB CIBP; 575.0 CONDUCTOR; 28.0-110.0 Hanger; 25.6 Cement Plug; 25.6 ftKB KUP INJ 2P-429 ... WELLNAME WELLBORE2P-429 Current Status of the KRU 2P Pad Plug and Abandon Campaign As of 01/13/2026 2P-422A 01/07/2026: Pulled shore can. Will request Final site clearance with 2P-424A and 2P-429. 2P-424A 01/10/2026: Pulled cellar box 01/09/2026: Wellhead cut and removed. Excavation is on hold due to weather conditions. 2P-429 01/11/2026: Pulled cellar box 01/10/2026: Wellhead cut and removed. Excavation is on hold due to weather conditions. 2P-406 Cemented to Surface 01/13/2026: Continue to monitor well pressures per AOGCC request. A new 10-403 will be submitted prior to any further intervention. (Reference Extension Request for further details.) 2P-447 Cemented to Surface 12/31/2025: 30 day pressure monitoring per AOGCC request. Surface Excavation procedures will begin once monitoring is complete. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Manning, Leslie To:Roby, David S (OGC); Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Hobbs, Greg S Subject:RE: [EXTERNAL]RE: DS 2P Suspension Extensions Date:Wednesday, January 21, 2026 9:52:02 AM Some people who received this message don't often get email from leslie.manning@conocophillips.com. Learn why this is important Dave - ConocoPhillips aimed to complete the abandonment of all remaining 2P wells by December 31, 2025, and as of the check in meeting on December 11, 2025, we were striving to meet that goal. However, due to weather conditions and operational delays encountered in late December, full abandonment could not be completed prior to the expiration of the wells suspension status. Following December 31, 2025, we evaluated the status of all remaining 2P wells and contacted the AOGCC to determine appropriate next steps for the work scope. Based on their guidance, we proceeded with submitting suspension extension requests for each well. Regards, Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Friday, January 16, 2026 3:45 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Manning, Leslie <Leslie.Manning@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL]RE: DS 2P Suspension Extensions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Leslie, Please also provide an explanation for why the suspension renewal requests were not submitted until after the suspensions had expired. Thank you, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 _____________________________________________ From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, January 12, 2026 8:35 AM To: Manning, Leslie <leslie.manning@conocophillips.com> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: DS 2P Suspension Extensions Could you please include the work remaining to be completed and the current status of the P&A. Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _____________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 9.625" L-80 2434' 7"x 4-1/2" L-80 5997' 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 8966' SIZE DEPTH SET (MD) 26' 62 5# 40# 110' 26' Sr Res EngSr Pet GeoSr Pet Eng Gas-MCF:Gas-MCF: 51 bbl 15.8 ppg Class G Cement 2598'-3025' 29 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl:Hours Tested: Production for Flow Tubing 4779'-6504' 7555' (SW TOC) -8966' MD SUSPENDED 8176-8240' Md and 5549-5586' TVD (cemented) 8300-8325' MD and 5621-5635' TVD (cemented) 8325-8350' MD and 5635-5650' TVD (cemented) 8386-8435' MD and 5670-5698' TVD (cemented) 8495-8505' MD and 5733-5738' TVD (cemented) Gas-Oil Ratio:Choke Size: 15.4 bbls 15.8 ppg Class G Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 42" 12.25" 60 bbl AS I 29'561 sx AS III Lite, 128 bbls LiteCrete 28' 2965'29' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26#/12 6# WT. PER FT.GRADE 12/17/2001 CEMENTING RECORD 1505' MD/ 1446' TVD SETTING DEPTH TVD 862830 TOP HOLE SIZE AMOUNT PULLED 9 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 50-103-20378-00-00 KRU 2P-429 ADL0373112, ADL0389058 934' FNL, 1953' FWL, Sec. 17, T8N, R7E, UM 1760' FNL, 2255' FEL, Sec. 20, T8N, R7E, UM ALK 4998 12/8/2001 8974' MD/ 6002' TVD 2598' MD/ 2214' TVD P.O. Box 100360, Anchorage, AK 99510-0360 y-y- 1077' FNL, 2319' FEL, Sec. 20, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc.11/10/2025 201-102/ 325-301 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 84 sx AS Lite, 500 sx Class G8.5" 7617' MD 4-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:19 pm, Dec 08, 2025 Suspended 11/10/2025 JSB RBDMS JSB 121925 xG Conventional Core(s): Yes No Sidewall Cores: N/A MD TVD Surface Surface 1505' 1446' 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: Erica Livingston Digital Signature with Date:Contact Email: Erica.J.Livingston@conocophillips.com Contact Phone:(907) 265-1588 Integrity and Interventions Engineer Suprv 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 TESTS30. N/A- Suspended N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov DTTMSTART JOBTYP SUMMARYOPS 1/28/2025 SUPPORT OTHER OPERATIONS (P&A) CMIT - T X SC TO 1500 PSI (FAIL) 6/8/2025 SUPPORT OTHER OPERATIONS LOGGED CASING & KILL STRING W/ 2.75'' 40 ARM CALIPER FROM TOC 2565' TO 2161 MD.. COMPLETE 7/7/2025 SUPPORT OTHER OPERATIONS TAG TOP OF CEMENT AT 2583'. PUH TO 2578' PUTTING SETTING TEST PACKER MID-ELEMENT AT 2575' (8' ABOVE TOC). MIT 9-5/8" SURFACE CASING TO 1500 PSI - PASS. JOB COMPLETE. 9/11/2025 SUPPORT OTHER OPERATIONS LRS PERFORMS PASSING MIT TO 1500 PSI. RUN 3" GAUGE RING DRIFT SD AND TAG TOC @ 2563' SLM (2598' RKB). JOB IN PROGRESS. 9/13/2025 SUPPORT OTHER OPERATIONS AOGCC WITNESSED (AUSTIN MCLEOUD) CMIT TO 1500 PSI FAILED. SEE LOG FOR DETAILS. 9/14/2025 SUPPORT OTHER OPERATIONS TAG TOP OF CEMENT @ 2598' RKB. DUMP BAIL 9 GALLONS OF SAND ON CEMENT. JOB IN PROGRESS. 9/15/2025 SUPPORT OTHER OPERATIONS DUMP BAIL 18 GALLONS OF SAND ON TOP OF CEMENT, TOTAL OF 27 GALLONS (8.5 FT BY VOLUME) OVER PAST 2 DAYS. TAG TOP OF SAND AT 2595' RKB. 9/18/2025 SUPPORT OTHER OPERATIONS SLB TO DRIVE TO LOCATION, SPOT EQUIPMENT, BUILD HEAD, START RU, AND PERFORM SURFACE CHECKS WITH BiSN. *** JOB IN PROGRESS**** 9/19/2025 SUPPORT OTHER OPERATIONS *** JOB CONTINUED FROM SEP 18 2025*** SLB TO DRIVE TO LOCTION, PERFORM SURFACE CHECKS, STAB ON START RIH. KEPT TAGGING AT ~125 FT RKB (TOOL BOTTOM) MULTIPLE TIMES. CONFER WITH CONORCO REP TO START POOH . PAINT SCRATCHED OF OF TOOL BOTTOM. STANDBY FOR SLICKLINE 9/19/2025 SUPPORT OTHER OPERATIONS DRIFT CLEAN W/ 3.5" GAUGE RING. SD @ 122' RKB W/ 3.75" GAUGE RING, UNABLE TO MAKE HOLE. RUN 3.60" BROACH GET PAST TIGHT SPOT AND CLEAN DRIFT TO MULE SHOE @ 2439' RKB. JOB IN PROGRESS. 9/20/2025 SUPPORT OTHER OPERATIONS SLB TO CONTINUE STANDING BY FOR HES SLK TO RUN DRIFTS/BROACHES. DISCUSS WITH CWG DECISION MADE TO RD AND DEMOB TO 2Z 9/20/2025 SUPPORT OTHER OPERATIONS UNABLE TO GET 3.83" IMPRESSION BLOCK PAST TBG HANGER. WORK BOTH 3.70" AND 3.72" BROACH PAST TIGHT SPOT @ 122' RKB. JOB IN PROGRESS. 9/21/2025 SUPPORT OTHER OPERATIONS SPOT IN SL UNIT AND SUPPORT EQUIPMENT. MAKE UP LUBRICATOR AND TOOLS. STANDBY FOR SCAFFOLD INSPECTION. JOB CANCELLED. RIG DOWN AND MOVE OVER TO 2P-422. 10/8/2025 SUPPORT OTHER OPERATIONS MIRU CTU 4 W/ 19,000' OF 2.0", 48.9 BBL REEL VOL. RAN 2.88" LH MOTOR & 3.80" ROUND NOSE MILL. MILLED THROUGH OBSTRUCTIONS IN 4-1/2" KILL STRING AT 109', 386', 848', 1250', 1373', 1498', 1590'. RUNNING LOW ON FLUIDS, POOH. MILL HAD MODERATE WEAR ON SIDE GAUGE & 2 CHIPPED CUTTERS. IN PROGRESS 10/9/2025 SUPPORT OTHER OPERATIONS RAN SAME 2.88" LH MOTOR & 3.80" ROUND NOSE MILL. DRY DRIFT CLEAN TO 1600'. MILLED THROUGH OBSTRUCTION IN 4-1/2" KILL STRING AT 1840', DRY TAGGED AT 2578'. WELL FREEZE PROTECTED TO 2460'. ((MILL HAD A FEW MORE CHIPPED CUTTERS, 3.81" GO/3.80" NOGO)). READY FOR ELINE 10/17/2025 SUPPORT OTHER OPERATIONS RIH W/ 3.80" X 19' DMY BiSN HEATER DRIFT, SD @ 103' SLM, UNABLE TO MAKE HOLE. RUN 3" X 5' DD BAILER, CLEAN DRIFT TO TOP OF SAND @ 2558' SLM (2562' RKB). RUN MULTIPLE CENTRALIZERS FROM 3.50" - 3.70", ALL FALL CLEAN TO TOP OF SAND. RUN 3.80" GAUGE RING SD @ 1673' SLM, UNABLE TO MAKE HOLE. SD @ 1673' SLM W/ 3.78" GAUGE RING. ** JOB IN PROGRESS ** 10/18/2025 SUPPORT OTHER OPERATIONS DRIFT W/ 3.75" & 3.77" BROACH, SMALL BOBBLE W/ 3.77" BROACH @ 1368' SLM, WORK PAST AND DRIFT TO BTM. RUN 3.82" BROACH SD @ 96' SLM WORK TOOLS UNABLE TO MAKE HOLE. NEED NEW PLAN FORWARD 10/22/2025 REPAIR WELL WAIT ON DECISION TO ASSIST FRAC ON 3T-622 OR HEAD TO 2P 10/23/2025 REPAIR WELL MIRU M/U BHA #1 3.83 LH MILL 3.825" STRING REAMER. RIH SET DOWN @ 110' MILLTO 112'. RECIP INTERVAL. MILL TO BOTTOM OF KILL STRING @ 2480' CLEAN. POOH FREEZE PROTECT FROM 2500'. RDMO 2P-429 Off Rig Suspend/Abandon Summary of Operations 10/26/2025 SUPPORT OTHER OPERATIONS DRIFT W/ 3.8" X 19' DMY BiSN HEATER SD @ 105' SLM. RAN 3.83" GUAGE RING SD @ 2' SLM. RAN 3.77" GAIGE RING TAG AT 2554' SLM. RIG DOWN FOR PLAN FORWARD. 11/10/2025 SUPPORT OTHER OPERATIONS INJECTIVITY TEST PUMPED A TOTAL OF 20 BBLS DIESEL DOWN TBG TO ESTABLISH AN INJECTIVITY RATE OF .016 BPM @ 2000 PSI 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): 8974' 8900' 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 12/15/2025 4-1/2" Packer: Baker G-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' (cemented) 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' (cemented) 7" x 4-1/2" Perforation Depth TVD (ft): 110' 2965' 5997'8966' 16" 9-5/8" 82' 7617' MD MD 110' 2434' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Cy Eller 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: Cy.Eller@conocophillips.com (907) 265-6049 CTD/RWO Engineer KRU 2P-429 6002' 4779' 3527' 2598', 3025', 4779', 7555' 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 325-726 By Grace Christianson at 8:01 am, Nov 25, 2025 TS 11/28/25 DSR-11/25/25 10-407 VTL 12/8/2025 BOP test to 2500 psig Annular preventer test to 2500 psig XX X 12/08/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 21, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to Plug & Abandon 2P-429 (PTD # 201-102). This Sundry application is intended to replace the previous Sundry request that was submitted on October 30, 2025, and Sundry # 325-301. 2P-429 was an injector that has been shut in since July of 2020. This well has been suspended with a reservoir cement plug and an intermediate cement plug. A surface shoe cement plug to isolate the C80 from the wellbore was placed on-rig with Nordic 3, but the subsequent pressure test to verify the plug failed. A remediation attempt using BiSn Wel-Lock following Sundry # 325-301 was planned, but was unsuccessful, as the BiSn heater was unable to be drifted through the kill string. To complete the abandonment of this well, CPAI is requesting approval to pull the 4-1/2 kill string, mill out cement from the 9-5/8 casing until injectivity is achieved, then set a cement retainer and pump cement. After remediating the surface shoe cement plug, we plan to run a kill string and complete the surface cement plug and execute the final abandonment. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 2P-429 P&A Procedure PTD #201-102 Page 2 of 4 Pre-Rig Work Remaining 1. Prepare well for rig arrival Rig Work MIRU 1. MIRU Nabors 7ES on 2P-429. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Record shut in pressures on the kill string and kill string x SC annulus. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. a. No BPV will be set for ND/NU due to two tested mechanical plugs in wellbore providing barrier to reservoir in addition to three cement plugs. Retrieve Kill String 4. MU landing joint and BOLDS. 5. Pull and lay down 4-1/2 kill string. Remove Cement from 9-5/8 Casing 6. MU cement milling BHA. 7. PU DP and RIH to top of cement in 9-5/8 casing. Circulate out sand from top of cement. a. Anticipated top of cement is 2,598 RKB. 8. Mill cement from 9-5/8 casing until injectivity is achieved. 9. TOOH and LD milling BHA. Set Cement Retainer 10. MU and RIH with cement retainer for 9-5/8 casing. Set retainer. a. Retainer set depth will be dependent on the depth that injectivity is achieved. 11. Pump cement through retainer. Release from retainer and place ~50 of cement on top of retainer. a. Cement volume will be determined based on the depth that injectivity is achieved. Test Cement Plug 12. Wait on cement. 13. Tag cement and PT to 1,500 psi for 30 minutes with State witness. Execute Final Abandonment Plug 14. POOH laying down drillpipe. 15. TIH with kill string. 16. Land kill string in casing hanger profile. 17. Circulate cement surface to surface until full cement returns observed. RDMO 18. Perform NFT. ND BOPE. NU tree. a. This step may be performed before pumping final abandonment plug for operational efficiency. 2P-429 P&A Procedure PTD #201-102 Page 3 of 4 19. RDMO. Execute Final Abandonment Surface Excavation 1. DHD perform drawdown test of kill string and annulus. 2. Bleed off any trapped pressure from tree. 3. Remove tree in preparation for excavation and casing cut. 4. Have shoring box installed during excavation as needed to prevent loose ground from falling into excavation. 5. Cut off wellhead and all casing strings at 4 feet below original ground level. 6. Perform top job if needed to ensure cement is in all casing strings. AOGCC witness and photo document required. 7. Send casing head with stub to materials shop. Photo document. 8. Weld ¼ thick cover plate (16 OD) over all casing strings with the following information bead welded into the top. Photo document and AOGCC witness required. a. ConocoPhillips b. KRU 2P-429 c. PTD# 201-102 d. API# 50-103-20378-00-00 9. Remove cellar. Backfill cellar with gravel as needed. Backfill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. 11. RDMO. 12. Report that final P&A has been completed to AOGCC. Photo document final location condition after completing work. General Well Information: Estimated Start Date: 12/15/2025 Current Operations: Suspended Well Type: Injector Wellhead Type: FMC Gen V. 11 5M casing head top flange. 11 5M tubing head top flange. 4- 1/16 5M tree. Scope of Work: Pull 4-1/2 kill string. Mill cement from 9-5/8 casing until injectivity is achieved. Set cement retainer and pump cement through retainer. Run 4-1/2 kill string and circulate cement to surface. Execute final abandonment. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams 2P-429 P&A Procedure PTD #201-102 Page 4 of 4 Well Data: Meltwater Formation: Reservoir pressure 7/8/2023 = 3052 psi @ 5400 TVD MASP = 2512 psi / 0 psi (Cemented) C-80 Formation: OA Pressure = 234 psi (11/5/22) (fluid packed with diesel) MASP = 811 psi / 0 psi (Cemented) Top of Sand on Surface Shoe Cement Plug: Slickline tag = 2,554 SLMD (10/26/2025) Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Intervention Engineer: Erica Livingston 2P-429 Current Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.06 62.5 Welded Surface Casing 2965 2434 9 5/8 8.83 40 L-80 BTC-M Production Casing (7" Section) Top - 3020 Btm - 7618 Top - 2468 Btm - 5220 7 6.28 26 L-80 BTC-M Production Casing (4- 1/2" Section) Top - 7618 Btm - 8966 Top - 5220 Btm - 5997 4 1/2 3.96 12.6 L-80 IBT-M Kill String 2462 2133 4 1/2 3.96 12.6 L-80 IBT-M Tubing Top - 3110 Btm- 7617 Top - 2524 Btm - 5219 4 1/2 3.96 12.6 L-80 IBT-M Surface Casing 2965' RKB Production Casing 8966' RKB Conductor Plug #1 - Reservoir TOC 7,555' RKB Retainer 7,725' RKB Tubing Cut: 3,110' RKB CIBP 3025' RKB Production Casing Cut: 3,020' RKB Production Casing Calculated TOC: 5,872' RKB Surface Casing TOC: Surface Plug #2 - Intermediate TOC 4,779' RKB BOC 6,504' RKB Surface Shoe Cement Plug Date Placed: 1/22/2025 TOC: 2,598' RKB Sand Placed for BiSn Plug Date Placed: 9/15/2025 Slickline Tagged TOC: 2,562' RKB T-3 Perfs 8176' - 8505' RKB Cmt Ret 2P-429 Proposed P&A Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.06 62.5 Welded Surface Casing 2965 2434 9 5/8 8.83 40 L-80 BTC-M Production Casing (7" Section) Top - 3020 Btm - 7618 Top - 2468 Btm - 5220 7 6.28 26 L-80 BTC-M Production Casing (4- 1/2" Section) Top - 7618 Btm - 8966 Top - 5220 Btm - 5997 4 1/2 3.96 12.6 L-80 IBT-M Kill String 2462 2133 4 1/2 3.96 12.6 L-80 IBT-M Tubing Top - 3110 Btm- 7617 Top - 2524 Btm - 5219 4 1/2 3.96 12.6 L-80 IBT-M Surface Casing 2965' RKB Production Casing 8966' RKB Conductor Plug #1 - Reservoir TOC 7,555' RKB Retainer 7,725' RKB Tubing Cut: 3,110' RKB CIBP 3025' RKB Production Casing Cut: 3,020' RKB Production Casing Calculated TOC: 5,872' RKB Surface Casing TOC: Surface Plug #2 - Intermediate TOC 4,779' RKB BOC 6,504' RKB Surface Shoe Cement Plug Date Placed: 1/22/2025 TOC: 2,598' RKB T-3 Perfs 8176' - 8505' RKB Cmt Ret Cmt Retainer Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,779.0 2P-429 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed sand on cement 2P-429 9/15/2025 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: 3.70" RESTRICTION AT 122' RKB. POSSIBLE OVER TORQUED COLLAR 9/21/2025 rmoore22 NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 2,461.7 Set Depth 2,132.6 String Max No 4 1/2 Tubing Description Tubing Kill String Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT 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 10.880 FMC 11' x 4 1/2" Gen V TBG hanger, 4 1/2" NSTC top thread FMC Gen V 2.910 2,439.3 2,119.3 53.44 Shoe - Mule 4.500 3.000 Top (ftKB) 3,110.0 Set Depth 7,617.0 Set Depth 5,219.2 String Max No 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,595.0 2,212.5 52.86 SAND DUMP BAILED 27 GALLONS OF SAND (8.5 FT EQUIVALENT BY VOLUME). TAGGED 3 FT HIGHER. 9/15/2025 0.000 3,020.0 2,468.0 52.15 CUT MSC Casing Cut @ 3,020' 1/15/2025 6.950 3,025.0 2,471.1 52.12 CIBP 1/21/2025 0.000 3,110.0 2,523.5 51.77 CUT JET CUT AT 3110' RKB 9/19/2024 3.960 6,500.0 4,554.0 53.54 TUBING PUNCH SHOT 4.5 FT OF HOLES. 6 SPF. 8/4/2024 3.960 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug PUMP 15.8 PPG CEMENT LAY 3 BBLS ON TOP OF RETAINER. 6/20/2024 4,779.0 6,504.5 3,527.0 4,556.7 Cement Plug PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4779' SLM) 9/7/2024 2,598.0 3,025.0 2,214.3 2,471.1 Cement Plug 1/22/2025 2P-429, 9/24/2025 8:17:14 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 3,020.0-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 CIBP; 3,025.0 CUT; 3,020.0 SURFACE; 28.6-2,965.0 Cement Plug; 2,598.0 ftKB SAND; 2,595.0 CONDUCTOR; 28.0-110.0 Hanger; 25.5 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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): 8974' 8900' 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) 263-4131 Staff Well Interventions Engineer KRU 2P-429 6002' 4779' 3527' 2565', 3025', 4779', 7555' 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: Jill.Simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned TVD Burst 7617' MD MD 110' 2434' 110' 2965' 5997'8966' 16" 9-5/8" 82' 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' (cemented) 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' (cemented) 7" x 4-1/2" Perforation Depth TVD (ft): 11/1/2025 4-1/2" Packer: Baker G-22 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 By Grace Christianson at 2:33 pm, Oct 31, 2025 Digitally signed by Jill Simek DN: CN=Jill Simek, E=jill.simek@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2025.10.30 17:33:41-08'00' Foxit PDF Editor Version: 13.1.6 Jill Simek 325-674 A.Dewhurst 31OCT25 X VTL 11/6/2025 DSR-11/6/25 December 31, 2025 10-407 X JLC 11/7/2025 11/07/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska October 29, 2025 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached, the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2P-429 (PTD# 201-102). This 10-403 is being submitted to request procedure changes to the existing Sundry Approved P&A procedure (Sundry# 325-301). If you have any questions, please contact me at 263-4131. Sincerely, Jill Simek Staff Well Interventions Engineer 2P-429 Plug and Abandon Revised Procedure PTD #201-102 Sundry #325-301 Page 1 of 2 2P-429 is a suspended injector, iden ed for P&A as part of ConocoPhillips 2P pad abandonment program. Currently, the well is suspended with 2 cement plugs. A third cement plug was a empted, on-rig, to isolate the C80 from the wellbore; however, this plug has a slow leak and requires remedia on. Under Sundry 325-301, an a empt has been made o -rig to isolate the C80 with a BiSN Wel-Lock plug. However, due to obstruc ons in the killstring, the BiSN heater is unable to get to the plug se ng depth. This revised procedure eliminates the BiSN Wel-Lok plug se ng steps and adds steps to place a ~100 cement cap on the exis ng cement plug. Once isola on has been con rmed, the well will be cemented to surface then excavated and wellhead removed. C80 Cement Plug Attempt (Rig): Summarized Operational Procedure o 29 BBL 15.8 Class G Cement o Displace with 9.8 PPG Brine o Planned TOC = 2,708ft KB Result o TOC tag 2,565 RKB (caliper log, tied into killstring) o Attempt to pressure test (1850psi). Failed. 9/15- 10/26/2025 C80 Cement Plug A empt (BiSN): o River sand dump bailed on cement. o RIH with BiSN heater; set down at 125ft KB o Mill with 3.80 round nose mill through multiple killstring obstructions o Drift with 3.80 x 19 dummy BiSN heater BHA; unable to get through killstring (set down at 103 SLM) o Mill with 3.83 (killstring drift ID) round nose mill through multiple killstring obstructions o Drift with 3.80 x 19 dummy BiSN heater BHA; unable to get through killstring (set down at 105 SLM) o BiSN job aborted Last Pressure Test: 9/13/2025: CMIT failed Initial: 1600/1600 psi 15 min = 1560/1560 (-40/-40) 30 min = 1530/1530 (-30/-30) 45 min = 1500/1500 (-30/-30) Procedure: 1. MIRU. 2. RIH with coil to TOC and place ~100ft cement plug, ~7.5bbls, leaving cement plug ~2,465ft KB. 3. RDMO. Wait on Cement. Tag and Pressure Test (Slickline) 4. Notify the AOGCC Inspector of timing for pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 5. MIRU. 6. RIH and tag TOC (witnessed). 7. Perform MIT to 1500psi on production casing (witnessed). 8. RDMO. Surface Cement Plug (Pumping) 9. MIRU 10. Pump ~178bbls permafrost cement in kill string and surface casing. 11. RDMO. Wait on cement. 2P-429 Plug and Abandon Revised Procedure PTD #201-102 Sundry #325-301 Page 2 of 2 Wellhead Excavation / Final P&A: 12. Confirm tubing and annulus pressures are at 0psi. 13. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 14. Remove the tree, in preparation for the excavation and casing cut. 15. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 16. Verify that cement is at surface in all strings. Perform cement top off job(s) if required. AOGCC witness and photo document required. 17. Send the casing head w/ stub to materials shop. Photo document. 18. Weld ¼ thick cover plate (16 O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 2P-429 PTD #: 201-102 API #: 50-103-20378-00-00 19. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. Obtain site clearance approval from AOGCC. RDMO. 4-½ Kill String to 2461' RKB Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB C80 @ 2950' KBC80 @ 2950' KB 2P-429 P&A Schematic - Current Conductor: 16" Conductor 110' KB 1 2 3 5 4Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4' KB T-3 Peforations: @ 8,176' 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB (2434' TVD) Production Tubing: 4 ½, 12.6# L-80 IBTM Set @ 7,617' KB Plug #1 reservoir TOC ± 7555' Retainer 7725' KB Plug #2 Intermediate TOC ±4779' RKB BOC @ ±6504' RKB Plug #3 Surface Shoe TOC 2565' RKB BOC @ ±3025' RKB 2 4-½ Kill String to 2461' RKB Plug #5 TOC @ Surface BOC ~2461' RKB Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB C80 @ 2950' KBC80 @ 2950' KB 2P-429 P&A Schematic - Proposed Conductor: 16" Conductor 110' KB 1 2 3 5 4Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4' KB T-3 Peforations: @ 8,176' 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB (2434' TVD) Production Tubing: 4 ½, 12.6# L-80 IBTM Set @ 7,617' KB Plug #1 reservoir TOC ± 7555' Retainer 7725' KB Plug #2 Intermediate TOC ±4779' RKB BOC @ ±6504' RKB Plug #3 Surface Shoe TOC 2565' RKB BOC @ ±3025' RKB 2 Plug #4 TOC ~2465' RKB MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:8974 ft MD Lease No.:ADL 0373112 Operator Rep:Suspend:NA P&A:X Conductor:16"O.D. Shoe@ 110 Feet Csg Cut@ NA Feet Surface:9-5/8"O.D. Shoe@ 2965 Feet Csg Cut@ NA Feet Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production:7"x4-1/2"O.D. Shoe@ 8966 Feet Csg Cut@ NA Feet Liner:NA O.D. Shoe@ NA Feet Csg Cut@ 3020 Feet Tubing:4-1/2"O.D. Tail@ 7617 Feet Tbg Cut@ 3110 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Open Hole Bridge plug 3025 ft 2598 ft 6.9 ppg N/A Initial 15 min 30 min 45 min Result Tubing IA OA 1590 1535 1490 Initial 15 min 30 min 45 min Result Tubing IA OA 1600 1560 1530 1500 Remarks: Attachments: I traveled to location to witness the mechanical integrity test (MIT) of the intermediate cement plug that was covering up a open hole section below the surface casing shoe. Kill string landed @ 2439 ft MD. With production casing cut and pulled tubing, inner and outer annulus were in communication. They pumped into the inner annulus flange on the wellhead. Target pressure of 1500psi - two attempts, both failing. Above Sundry # refers to the BisN bead plug. This test was the operator's optimistic attempt prior to committing to BisN plug. No tag done. September 13, 2025 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-429 ConocoPhillips Alaska, Inc. PTD 2011020; Sundry 325-301 none Test Data: F Casing Removal: Ryan Moore F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0913_Plug_Verificaton_KRU_2P-429_am                     Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-419 50-103-20483-00 910080528 Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-25 0 12 2P-429 50-103-20378-00 910080397 Kuparuk River Multi Finger Caliper Field & Processed 8-Jun-25 0 13 2T-38A 50-103-20229-01 910106462 Kuparuk River Plug Setting Record Field- Final 8-Jun-25 0 14 2Z-07 50-029-20946-00 910026798 Kuparuk River Plug Setting Record Field- Final 10-May-25 0 15 3K-20 50-029-23019-00 910080196 Kuparuk River Packer Setting Record Field- Final 18-May-25 0 16 3N-12 50-029-21582-00 910080396 Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-25 0 17 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 3-Jun-25 0 18 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 4-Jun-25 0 19 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 6-Jun-25 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40597T40598T40599T40600T40601T40602T40602T40602T40602204-017201-102197-205183-064201-088186-0796/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:47:18 -08'00'201-1022P-42950-103-20378-00 910080397Kuparuk RiverMulti Finger CaliperField & Processed8-Jun-2501 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): 8974'8900' 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 6/15/2025 4-1/2" Packer: Baker G-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' (cemented) 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' (cemented) 7" x 4-1/2" Perforation Depth TVD (ft): 110' 2965' 5997'8966' 16" 9-5/8" 82' 7617' MD MD 110' 2434' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Jill Simek 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: Jill.Simek@conocophillips.com (907) 263-4131 Staff Well Interventions Engineer KRU 2P-429 6002' 4779' 3527' 2589', 4779', 7555' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:15 pm, May 13, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.05.13 15:50:08 -08'00' 325-301 A variance is approved for the placement of a BISN plug under 25 AAC 25.112(i) with the following conditions: The BISN state witnessed plug tag and pressure test and 1 hour draw down test are required. A 24 hour draw down test is required with the results submitted to the AOGCC. A cement plug from the top of BISN plug to surface is required. X DSR-6/3/25 Abandonment must be complete by 12/31/2025. VTL 6/23/2025 X SFD 6/13/2025 X 10-407 December 31, 2025 *&: Jessie L. Chmielowski Digitally signed by Jessie L. 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KI0 1) <:" ) , "7 9 .LI('08EI< ; 1' """ <:. @) ,% 12 ! 3!4556 E @' +("'7 +(' > < '<: @;C< 5 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,779.0 2P-429 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-429 9/19/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED KNOWN OBSTRUCTION @ 7849' SLM 9/11/2017 pproven NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 2,461.7 Set Depth … 2,132.6 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT 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 10.880 FMC 11' x 4 1/2" Gen V TBG hanger, 4 1/2" NSTC top thread FMC Gen V 2.910 2,439.3 2,119.3 53.44 Shoe - Mule 4.500 3.000 Top (ftKB) 3,110.0 Set Depth … 7,617.0 Set Depth … 5,219.2 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,020.0 2,468.0 52.15 CUT MSC Casing Cut @ 3,020' 1/15/2025 6.950 3,025.0 2,471.1 52.12 CIBP 1/21/2025 0.000 3,110.0 2,523.5 51.77 CUT JET CUT AT 3110' RKB 9/19/2024 3.960 6,500.0 4,554.0 53.54 TUBING PUNCH SHOT 4.5 FT OF HOLES. 6 SPF. 8/4/2024 3.960 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug PUMP 15.8 PPG CEMENT LAY 3 BBLS ON TOP OF RETAINER. 6/20/2024 4,779.0 6,504.5 3,527.0 4,556.7 Cement Plug PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4779' SLM) 9/7/2024 2,598.0 3,025.0 2,214.3 2,471.1 Cement Plug 1/22/2025 2P-429, 5/12/2025 5:35:10 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 3,020.0-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 CIBP; 3,025.0 CUT; 3,020.0 SURFACE; 28.6-2,965.0 Cement Plug; 2,598.0 ftKB CONDUCTOR; 28.0-110.0 Hanger; 25.5 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev… 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE From:Loepp, Victoria T (OGC) To:Loepp, Victoria T (OGC) Subject:FW: [EXTERNAL]: KRU 2P-419 & 2P-429 Abandonment Sundries Date:Monday, June 23, 2025 12:27:12 PM -----Original Message----- From: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Sent: Monday, June 23, 2025 11:35 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Simek, Jill <Jill.Simek@conocophillips.com>; Bronga, Jaime <Jaime.Bronga@conocophillips.com>; Zwarich, Nola R <Nola.R.Zwarich@conocophillips.com>; Kolstad, Scott <Scott.Kolstad@conocophillips.com> Subject: RE: [EXTERNAL]: KRU 2P-419 & 2P-429 Abandonment Sundries Victoria, CPAI's proposal is to perform the following after placing the BiSN plug: - an AOGCC-witnessed tag per regulation - an AOGCC-witnessed pressure test per regulation - an AOGCC-witnessed 1-hour draw down test (DDT) - 24-hour DDT with the results submitted to the AOGCC Thank you for the consideration of this variance, E Erica Livingston Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska +1 907 854 6886 (cell) ekappel@conocophillips.com -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, June 16, 2025 3:32 PM To: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Simek, Jill <Jill.Simek@conocophillips.com>; Bronga, Jaime <Jaime.Bronga@conocophillips.com>; Zwarich, Nola R <Nola.R.Zwarich@conocophillips.com>; Kolstad, Scott <Scott.Kolstad@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: Re: [EXTERNAL]: KRU 2P-419 & 2P-429 Abandonment Sundries Please outline your proposal for PT and tag, drawdown test of the plugs. Sent from my iPhone > On Jun 16, 2025, at 3:08ௗPM, Livingston, Erica J <Erica.J.Livingston@conocophillips.com> wrote: > > 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. > Victoria, et al, > > Jill Simek is on vacation, so this e-mail is coming from me in her absence. > > Attached is the requested documentation that shows BiSN alloy plugs are as effective as cement in P&A applications. > > This technology is one that has been used and accepted by regulators around the world (see regions below). > [cid:image001.png@01DBDEC5.725888D0] > > > 1. The first attachment is the latest presentation that bisn gave to BSEE earlier this year. Slide 11 shows worldwide deployments through end of 2024. Slides 12-15 show more detail on U.S. BSEE deployments from Jul 2022 through Dec 2024. Summation of jobs to date shown in the screen shot above. > > > 1. The second attachment is a May 2022 SPE paper co-authored by Aker BP that details the success of bisn plugs in a 30 well P&A campaign in the Valhall field offshore Norway. This paper also documents the 2-year field verification that was successfully completed ahead of this campaign (see pages 10-11). An updated version of Figure 14 (page 15) is copied below and shows that these 30 wells with bisn plugs have not shown any signs of leaking since the 2021 campaign execution. > > [cid:image002.png@01DBDEC5.725888D0] > > > 1. The third attachment (bismuth-based-barrier-materials…) is third party testing that was conducted to benchmark the performance of bismuth alloy plugs against conventional cement. The results clearly demonstrate the superior mechanical sealing capability of bismuth alloys. > > * Slide 13 presents data confirming that bismuth alloy plugs exhibit significantly higher resistance to axial loads compared to cement, indicating better structural integrity under compressive forces. > * Slide 16 shows results from hydraulic push-out testing, where bismuth alloy plugs demonstrated significantly greater strength than cement. > * Slide 19 highlights bismuth alloy's superior resistance to gas migration, a critical factor for long-term well integrity and P&A. > Collectively, these tests validate that bismuth alloys outperform cement in key mechanical and sealing performance criteria. Slide 22 refers to future testing intended to further evaluate plug performance relative to plug length, casing size, and other variables to optimize design and deployment. > > > 1. The fourth attachment (Qualification of Bismuth Alloy Plugs for Plug & Abandonment (PDF) from January 2023 documents the qualification of BiSN alloy plugs for P&A applications in the North Sea UK adhering to the OGUK Guidelines for Qualification of Materials for Abandonment of Wells, Issue 2 of 2015. > > > 1. The fifth attachment (PD4977 Information – 2 May 2025) is a summary of Alaska deployments as well as a tool sequence depiction for the proposed 2P-419 and 2P-429 jobs. There is a slide summarizing global deployments as well. > > > > 1. The sixth attachment (PD4977 – BiSN Design Factor – V1) is the 2P-419 and 2P-429 Design Factor calculations for the proposed BiSN plugs. The BiSN plug barrier pressure rating is estimated to be 3,685 psi. > > Please reach out with any questions on the provided material. > > > Additionally, there was a request to place 25 ft of cement on top of the BiSN plug. > > In the sundry requests submitted, the plan is to place a cement plug from the top of the BiSN plug to surface (~2062 ft TVD in 2P-419 and ~2204 ft TVD in 2P-429). > I believe we incorrectly showed a gap above the BiSN plug in the sundry’s schematics (see below). Cement pumped down the kill string would displace lighter weight fluid above the BiSN plug effectively filling the entire wellbore above the BiSN plug with cement for the surface plug. > [cid:image003.png@01DBDEC8.4F825A90] > [cid:image004.png@01DBDEC8.4F825A90] > > Please advise if this is sufficient to meet the intent of the 25 ft cement plug requested. > > Thank you for the consideration of this variance, E > > Erica Livingston > Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska > +1 907 854 6886 (cell) > ekappel@conocophillips.com<mailto:ekappel@conocophillips.com> > > From: Loepp, Victoria T (OGC) > Sent: Wednesday, June 11, 2025 10:20 AM > To: Simek, Jill > <jill.simek@conocophillips.com<mailto:jill.simek@conocophillips.com>> > Cc: Rixse, Melvin G (OGC) > <melvin.rixse@alaska.gov<mailto:melvin.rixse@alaska.gov>>; Lau, Jack J > (OGC) <jack.lau@alaska.gov<mailto:jack.lau@alaska.gov>>; McLellan, > Bryan J (OGC) > <bryan.mclellan@alaska.gov<mailto:bryan.mclellan@alaska.gov>>; Boman, > Wade C (OGC) <wade.boman@alaska.gov<mailto:wade.boman@alaska.gov>> > Subject: KRU 2P-419 & 2P-429 Abandonment Sundries > > > Jill, > > The use of BISN beads does not meet the well plugging requirements of 20 AAC 25.112. However, a variance may be granted to the requirements if the variance provides for at least an equally effective plugging of the well 20 AAC 25.112(i). Please provide justification supporting a variance request for the use of the BISN beads. Include in your variance request the placement of 25’ of cement on top of the BISN beads. > > Victoria > > Victoria Loepp > Senior Petroleum Engineer > Alaska Oil & Gas Conservation Commission > Work: (907)793-1247 > > > 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 9.625" L-80 2434' 7"x 4-1/2" L-80 5997' 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, TUBING RECORD 84 sx AS Lite, 500 sx Class G8.5" 7617' MD 4-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 1/25/2025 201-102/ 324-647 50-103-20378-00-00 KRU 2P-429 ADL0373112, ADL0389058 934' FNL, 1953' FWL, Sec. 17, T8N, R7E, UM 1760' FNL, 2255' FEL, Sec. 20, T8N, R7E, UM ALK 4998 12/8/2001 8974' MD/ 6002' TVD 2598' MD/ 2214' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443913 5868944 1077' FNL, 2319' FEL, Sec. 20, T8N, R7E, UM 9. Ref Elevations: KB: 34' WT. PER FT.GRADE 12/17/2001 CEMENTING RECORD 5863513 1505' MD/ 1446' TVD SETTING DEPTH TVD 5862830 TOP HOLE SIZE AMOUNT PULLED 444898 444955 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 N/A PACKER SET (MD/TVD) 42" 12.25" 60 bbl AS I 29'561 sx AS III Lite, 128 bbls LiteCrete 28' 2965'29' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26#/12.6# 2598'-3025' 29 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 4779'-6504' 7555' (SW TOC) -8966' MD SUSPENDED 8176-8240' Md and 5549-5586' TVD (cemented) 8300-8325' MD and 5621-5635' TVD (cemented) 8325-8350' MD and 5635-5650' TVD (cemented) 8386-8435' MD and 5670-5698' TVD (cemented) 8495-8505' MD and 5733-5738' TVD (cemented) Gas-Oil Ratio:Choke Size: 15.4 bbls 15.8 ppg Class G Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 51 bbl 15.8 ppg Class G Cement 8966' SIZE DEPTH SET (MD) 26' 62.5# 40# 110' 26' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 11:07 am, Feb 19, 2025 Suspended 1/25/2025 JSB RBDMS JSB 022625 xGDSR-4/7/25VTL 7/30/2025 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1505' 1446' Top of Productive Interval N/A 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- Suspended N/A- Suspended Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 31. List of Attachments: Schematics, Summary of Operations 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. Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@conocophillips.comReason: I have reviewed this documentLocation: Date: 2025.02.19 10:36:25-09'00' Foxit PDF Editor Version: 13.0.0 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,779.0 2P-429 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-429 9/19/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED KNOWN OBSTRUCTION @ 7849' SLM 9/11/2017 pproven NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 2,461.7 Set Depth … 2,132.6 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT 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 10.880 FMC 11' x 4 1/2" Gen V TBG hanger, 4 1/2" NSTC top thread FMC Gen V 2.910 2,439.3 2,119.3 53.44 Shoe - Mule 4.500 3.000 Top (ftKB) 3,110.0 Set Depth … 7,617.0 Set Depth … 5,219.2 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,020.0 2,468.0 52.15 CUT MSC Casing Cut @ 3,020' 1/15/2025 6.950 3,025.0 2,471.1 52.12 CIBP 1/21/2025 0.000 3,110.0 2,523.5 51.77 CUT JET CUT AT 3110' RKB 9/19/2024 3.960 6,500.0 4,554.0 53.54 TUBING PUNCH SHOT 4.5 FT OF HOLES. 6 SPF. 8/4/2024 3.960 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug PUMP 15.8 PPG CEMENT LAY 3 BBLS ON TOP OF RETAINER. 6/20/2024 4,779.0 6,504.5 3,527.0 4,556.7 Cement Plug PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4779' SLM) 9/7/2024 2,598.0 3,025.0 2,214.3 2,471.1 Cement Plug 1/22/2025 2P-429, 2/19/2025 10:07:14 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 3,020.0-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 CIBP; 3,025.0 CUT; 3,020.0 SURFACE; 28.6-2,965.0 Cement Plug; 2,598.0 ftKB CONDUCTOR; 28.0-110.0 Hanger; 25.5 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev… 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 4-½” Kill String to 2461' RKB Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB C80 @ 2950' KBC80 @ 2950' KB 2P-429 Well Final P&A Schematic Conductor: 16" Conductor 110' KB 1 2 3 5 4Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4'’ KB T-3 Peforations: @ 8,176' – 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB (2434' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBTM Set @ 7,617' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϮΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϮϱΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬKƚŝƐ ΖyΖWƌŽĨŝůĞ ϳ͕ϱϱϬΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞ ϳ͕ϱϳϬ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌΘ^ĞĂů ƐƐĞŵďůǇ ϳ͕ϲϭϰ͘ϭΖ Plug #1 – reservoir TOC ± 7555' Retainer 7725' KB Plug #2 – Intermediate TOC ±4779' RKB BOC @ ±6504' RKB Plug #3 – Surface Shoe TOC 2598' RKB (2214' TVD) BOC @ ±3025' RKB 2 Page 1/11 2P-429 Report Printed: 2/19/2025 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) 1/14/2025 00:00 1/14/2025 08:00 8.00 MIRU, MOVE MOB P Pull support equipment away from rig. Pull rig off 2P-431. Move pipe bunks. Build new laydown area. Move kill tanks. Lay cellar pit liner and rig mats. Pull rig over 2P-429 @ 04:00AM. Spot in support equipment. Complete rig acceptance checklist. Accept rig @ 08:00. 0.0 0.0 1/14/2025 08:00 1/14/2025 12:00 4.00 MIRU, WELCTL RURD P RU circulation equipment. Load 9.8# Brine into pits. Build Deepclean pill. RU and PT hardline. Line up to pump down Tubing, taking returns from the IA to tiger tank. Gather initial pressures (T/I/O) = 0 / 50 / 0 psi. Cont. spot in support equipment. Move HAL cementing equipment. Measure RKB's. ULDS = 27.05'. 0.0 0.0 1/14/2025 12:00 1/14/2025 12:45 0.75 MIRU, WELCTL KLWL P Bleed free gas F/ Tubing and IA. Kill well with 9.8# Brine. Pump 33 bbls Deep Clean @ 4 BPM / 540 psi. Pump 145 bbls of brine @ 5 BPM / 880 psi. Measure consistent 9.8# returns density. SD pumps. 0.0 0.0 1/14/2025 12:45 1/14/2025 13:15 0.50 MIRU, WHDBOP OWFF P OWFF for 30-min. 0.0 0.0 1/14/2025 13:15 1/14/2025 18:45 5.50 MIRU, WHDBOP NUND P ND tree. Repair pin hole leak in Pill Pit. Inspect hanger threads. Function test NSTC XO. 7.5 turns to fully MU NSCT thread in hanger neck. Install BPV + test dart. NU BOP. NOTE: CHANGE JOB PHASE AFTER NUND 0.0 0.0 1/14/2025 18:45 1/14/2025 20:30 1.75 MIRU, WHDBOP RURD P RU testing equipment. Fill stack. Purge air. Grease valves 0.0 0.0 1/14/2025 20:30 1/15/2025 00:00 3.50 MIRU, WHDBOP BOPE P Perform shell test. Perform initial BOP test to 250/2500 psi for 5-min each. Tested annular on 3 1/2" and 7" test joints, Test UVBR's on 3 1/2" and 4 1/2" TJs. Test LVBR's on 7" TJ. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" IF safety valve, FOSV, and IBOP. Tested 3-1/2" and 4 1/2" EUE FOSV. Test 2" rig floor Demco kill valves. 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. Test gas detectors, PVT and flow show. AOGCC.witness waived by Brian Bixby 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 2/11 2P-429 Report Printed: 2/19/2025 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) 1/15/2025 00:00 1/15/2025 01:00 1.00 MIRU, WHDBOP BOPE P Perform shell test. Perform initial BOP test to 250/2500 psi for 5-min each. Tested annular on 3 1/2" and 7" test joints, Test UVBR's on 3 1/2" and 4 1/2" TJs. Test LVBR's on 7" TJ. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" IF safety valve, FOSV, and IBOP. Tested 3-1/2" and 4 1/2" EUE FOSV. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1600 PSI, 200 PSI attained = 23 sec, full recovery attained = 125 sec. UVBR's = 5 sec, Annular = 19 sec. Simulated blinds = 5 sec. LVBR’s = 5 sec. HCR choke & kill = 1 sec each. 5 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. AOGCC.witness waived by Brian Bixby. 0.0 0.0 1/15/2025 01:00 1/15/2025 01:30 0.50 COMPZN, RPCOMP RURD P Blowdown. R/D testing equipment. Clean and clear rig floor. 0.0 0.0 1/15/2025 01:30 1/15/2025 02:00 0.50 COMPZN, RPCOMP MPSP P Pull BPV + Test Dart. 0.0 0.0 1/15/2025 02:00 1/15/2025 02:45 0.75 COMPZN, RPCOMP PULL P MU 4 1/2" Landing Joint (3 1/2" IF Joint w/ NSCT bottleneck XO). Thread into tubing hanger. Count threads. Ensure fully engaged. Tight fit w/ bottleneck clearance. Screw in TD. Set 10K down. BOLDS. Pull hanger to rig floor. Unseat @ 64K. Drag to floor @ 63K. 3,110.0 3,076.0 1/15/2025 02:45 1/15/2025 03:00 0.25 COMPZN, RPCOMP CIRC P Circulate B/U // 7 bpm @ 280 psi 3,076.0 3,076.0 1/15/2025 03:00 1/15/2025 07:30 4.50 COMPZN, RPCOMP PULL P Pull production 4.5" tubing from pre-rig cut @ 3110', pipe clean. Saved 98 Full Joints of 4 1/2" IBT Tubing for contingency. L/D Cut Joint. Length = 23.10'. 3,076.0 0.0 1/15/2025 07:30 1/15/2025 08:00 0.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. Load Yellow Jacket tools. 0.0 0.0 1/15/2025 08:00 1/15/2025 08:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #1 (7" CIBP). 0.0 10.0 1/15/2025 08:30 1/15/2025 10:00 1.50 COMPZN, RPCOMP TRIP P TIH w/ CIBP to 2,970'. B/O single. Drop Ball. MU single. Obtain parameters. PUW = 69K. SOW = 64K. 10.0 2,970.0 1/15/2025 10:00 1/15/2025 10:30 0.50 COMPZN, RPCOMP MPSP P Set CIBP (COE) @ 3,025'. Top @ 3,024'. Pressure up to 1540 psi to set. See 1st Shear. Cont. pressure up to 2,900 psi. Did not shear to release. Press. up to 3,400 psi. Did not release. Bleed off. Re-attempt to shear. Press. up to 3500 psi. No Joy. Press up to 3,600 psi. Sheared out. Released off CIBP. 2,970.0 3,026.0 1/15/2025 10:30 1/15/2025 11:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #1 (CIBP setting tool) 3,026.0 10.0 1/15/2025 11:30 1/15/2025 11:45 0.25 COMPZN, RPCOMP BHAH P L/D BHA #1 (CIBP setting tool) 10.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 3/11 2P-429 Report Printed: 2/19/2025 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) 1/15/2025 11:45 1/15/2025 12:00 0.25 COMPZN, RPCOMP RURD P RU testing equipment w/ sensator on test spool. Close blinds. 0.0 0.0 1/15/2025 12:00 1/15/2025 12:30 0.50 COMPZN, RPCOMP PRTS P PT CIBP to 1,000 psi for 10-min. Charted. 0.0 0.0 1/15/2025 12:30 1/15/2025 13:45 1.25 COMPZN, RPCOMP BHAH P M/U BHA #2 (MSC) 0.0 12.0 1/15/2025 13:45 1/15/2025 15:00 1.25 COMPZN, RPCOMP TRIP P TIH w/ MSC to 3,025'. Set 5K down on CIBP. PUH to 3,015' (10' above planned cut depth). 12.0 3,015.0 1/15/2025 15:00 1/15/2025 16:30 1.50 COMPZN, RPCOMP CPBO P Screw in TD. Obtain parameters. Monitor OA pressure gauge in cellar for indications of 7" x 9 5/8" communications during cut. PUW = 69K. SOW = 64K. Free Torque = 2.2K @ 90 RPM. Bring pumps online at 2 BPM / 560 psi to break tape. Slow rate to 1BPM / 170 psi. TIH to confirm no collars at cut depth. PUH to cut depth @ 3,020'. Rotary = 100 RPM @ 1.9K Torque. Pump Rate 2 BPM @ 560 psi. Torque = 3.5-4K. Saw torque drop off to 2.3K after cut. Start cut @ 16:11. End @ 16:19. Set 3K down in cut to confirm w/ knives. Did not see OA pressure indicator after cut. 3,015.0 3,020.0 1/15/2025 16:30 1/15/2025 16:45 0.25 COMPZN, RPCOMP CIRC P RU OA hose to tank manifold. Close bag. Line up to pump down 3 1/2" DP taking returns from OA to tiger tank. OA likely contains gas cut fluids. Bring pumps online and attempt to circ. out OA. Press. up to 600 psi. Unable to circulate up OA. 3,020.0 3,020.0 1/15/2025 16:45 1/15/2025 17:45 1.00 COMPZN, RPCOMP CPBO P PUH. Locate collars in cased hole @ 2,954' above surface casing shoe. Repear cut process. Cut 7" casing @ 2,950' (4' above collar). Monitor OA pressure during cut. Max TQ 3500 ft/lbs pump 1.5 bpm @ 580 psi, no change to OA pressure, close pipe rams pressure up to 480 psi @ 14 gal per min no returns shut down pumps 3,020.0 2,950.0 1/15/2025 17:45 1/15/2025 18:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min 2,950.0 2,950.0 1/15/2025 18:15 1/15/2025 19:45 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #2 (MSC). 2,950.0 0.0 1/15/2025 19:45 1/15/2025 20:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #2. Inspect cutter blades. Good indication of cut on cutter blades 0.0 0.0 1/15/2025 20:00 1/15/2025 20:30 0.50 COMPZN, RPCOMP WWSP P Pull packoff 0.0 0.0 1/15/2025 20:30 1/15/2025 22:00 1.50 COMPZN, RPCOMP THGR P Make up landing jt, run in make up to hanger, BOLDS, pull on casing string up to 100k over ( 200k ), set back in profile, RI 4 LDS prep for CBL 0.0 0.0 1/15/2025 22:00 1/16/2025 00:00 2.00 COMPZN, RPCOMP WAIT P Wait on E-line // On location 23:00 start re-head 0.0 0.0 1/16/2025 00:00 1/16/2025 02:00 2.00 COMPZN, RPCOMP WAIT P Wait on e-line to re-head, found second bad spot in wire re-head 2nd time 0.0 0.0 1/16/2025 02:00 1/16/2025 02:30 0.50 COMPZN, RPCOMP ELOG P Rig up E-line to run CBL 0.0 0.0 1/16/2025 02:30 1/16/2025 04:30 2.00 COMPZN, RPCOMP ELOG P CBL determine top of fill @ 2,250' 0.0 0.0 1/16/2025 04:30 1/16/2025 05:15 0.75 COMPZN, RPCOMP ELOG P Rig down e-line 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 4/11 2P-429 Report Printed: 2/19/2025 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) 1/16/2025 05:15 1/16/2025 06:00 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 3 MSC for 7" casing 0.0 12.0 1/16/2025 06:00 1/16/2025 07:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole to 2,190' 12.0 2,190.0 1/16/2025 07:00 1/16/2025 08:00 1.00 COMPZN, RPCOMP CPBO P Locate collar @ 2,198'. TIHH and position cutter blades @ 2,219'. Monitor OA pressure for communication. OA initial = 10 psi. Free Torque (pumps off) @ 100 rpm @ 1.5K. Bring pumps online. 1 BPM / 162 psi. Tq = 1.7K. 1.5 BPM / 360 psi. Tq = 2.2K. 2 BPM / 477 psi. Tq = 2.7-4K. Start cut @ 07:45. End cut @ 07:56. Tq max during cut = 4K. OA pressure pre-cut = 10 psi. OA presure post-cut = 50 psi. 2,190.0 2,221.0 1/16/2025 08:00 1/16/2025 08:45 0.75 COMPZN, RPCOMP CIRC P Line up to circ out OA to tiger tank. Close bag. Bring pumps online @ 1 BPM / 580 psi for 5 bbls. Unable to circulate up OA. SD Pumps. 2,221.0 2,221.0 1/16/2025 08:45 1/16/2025 09:45 1.00 COMPZN, RPCOMP CPBO P PUH and position cutter blades @ 1,941'. Bring pumps. Attempt to cut casing Unable to build torque. Troubleshoot. Decide to TOOH to inspect cutter. Blowdown Top Drive. 2,221.0 1,941.0 1/16/2025 09:45 1/16/2025 10:00 0.25 COMPZN, RPCOMP OWFF P OWFF 1,941.0 1,941.0 1/16/2025 10:00 1/16/2025 10:30 0.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #3 (MSC). 1,941.0 12.0 1/16/2025 10:30 1/16/2025 11:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 (MSC) 12.0 0.0 1/16/2025 11:00 1/16/2025 12:30 1.50 COMPZN, RPCOMP PULL P Drain Stack. BOLDS. Pull Pack-off. MU 7" Landing Joint. Pull 200K (120K over string wt). No movement. Pulled 250K (170K over). No movement. Set hanger back down in wellhead. 0.0 0.0 1/16/2025 12:30 1/16/2025 13:00 0.50 COMPZN, RPCOMP RURD P L/D 7" Landing Joint. Re-install pack- off. RILDS. 0.0 0.0 1/16/2025 13:00 1/16/2025 14:00 1.00 COMPZN, RPCOMP BHAH P Load and MU BHA #4 (MSC). 0.0 12.0 1/16/2025 14:00 1/16/2025 15:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #4 (MSC) to 1,943'. 12.0 1,943.0 1/16/2025 15:00 1/16/2025 16:00 1.00 COMPZN, RPCOMP CPBO P Obtain parameters. PUW = 58K. SOW = 57K. Cut 7" casing @ 1,941'. Rotary = 100 RPM. F.T. = 1.2K. Pump Rate/Press. = 3 BPM / 470 psi. Max Torq seen during cut = 2.1K. Torque fell off to 1.2K. Set down 5K on knives to confirm cut. 1,943.0 1,943.0 1/16/2025 16:00 1/16/2025 16:15 0.25 COMPZN, RPCOMP CIRC P Line up to circ out OA to tiger tank. Close bag. Bring pumps online @ 1 BPM / 620 psi. Unable to circulated. Injecting into OH and/or open SC shoe below backside fill. Blowdown hardline to tank to confirm clear flowpath. 1,943.0 1,943.0 1/16/2025 16:15 1/16/2025 16:45 0.50 COMPZN, RPCOMP CPBO P PUH and position cutter knives @ 1,510'. Obtain parameters. 100 RPM. 4 BPM @ 700 psi. Torque Range during cut = 2-2.5K. See OA indicator during cut. OA pressure climbed to 240 psi. 1,943.0 1,510.0 1/16/2025 16:45 1/16/2025 18:15 1.50 COMPZN, RPCOMP CIRC P Line up to take returns to tiger tank. Bring pumps online @ 1.5 BPM / 500 psi. Establish returns to Tiger Tank. Increase rate to 2 BPM @ 670 psi. Pump 80 bbls Deep Clean pill. Chase with 9.8# Brine until have clean returns. 1,510.0 1,510.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 5/11 2P-429 Report Printed: 2/19/2025 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) 1/16/2025 18:15 1/16/2025 19:45 1.50 COMPZN, RPCOMP OWFF P OWFF some flow circ BU OWFF blow down to pull out of hole 1,510.0 1,510.0 1/16/2025 19:45 1/16/2025 20:30 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #4 (MSC) 1,510.0 0.0 1/16/2025 20:30 1/16/2025 21:00 0.50 COMPZN, RPCOMP THGR P BOLDS and pull packoff 0.0 0.0 1/16/2025 21:00 1/16/2025 21:30 0.50 COMPZN, RPCOMP THGR P Make up landing jt and change elevators, pull hanger to floor 90K off seat drag @ 80k // 40' off floor pull 100k pipe jumping 0.0 1,500.0 1/16/2025 21:30 1/16/2025 22:00 0.50 COMPZN, RPCOMP RURD P Rig up GBR, attempt to circulate while rigging up, unable to circulate 1,500.0 1,500.0 1/16/2025 22:00 1/16/2025 22:30 0.50 COMPZN, RPCOMP PULL P Pull 2 jts 7" casing, well swabbing 1,500.0 1,347.0 1/16/2025 22:30 1/16/2025 23:00 0.50 COMPZN, RPCOMP CIRC P Make up TD, work pipe while pumping 400 psi to break up packoff, gain circulation 7 bpm @ 45 psi // Hole unloaded fine sand from back side of 7", continue to circulate till hole clean 1,347.0 1,347.0 1/16/2025 23:00 1/17/2025 00:00 1.00 COMPZN, RPCOMP PULL P Blow down TD, continue to pull and lay down 7" BTC casing // 1,258' start swabbing again, make up TD, work pipe and circulate hole clean 1,347.0 1,100.0 1/17/2025 00:00 1/17/2025 01:30 1.50 COMPZN, RPCOMP PULL P Pull and lay down 34 full jts 7" BTC Casing and 1 Cut jt 33.76' 1,100.0 0.0 1/17/2025 01:30 1/17/2025 03:30 2.00 COMPZN, RPCOMP WAIT P Secure well, wait on crew change out due to modules moving through field, crews met @ 2S access road to change out 0.0 0.0 1/17/2025 03:30 1/17/2025 04:00 0.50 COMPZN, RPCOMP CLEN P Prep to pick up fishing BHA and clear pipe shed 0.0 0.0 1/17/2025 04:00 1/17/2025 04:45 0.75 COMPZN, RPCOMP BHAH P MU BHA #5 (7" Spear) 0.0 232.0 1/17/2025 04:45 1/17/2025 06:00 1.25 COMPZN, RPCOMP TRIP P TIH to top of fish @ 1,510'. PUW = 65K. SO = 62K. 232.0 1,510.0 1/17/2025 06:00 1/17/2025 06:45 0.75 COMPZN, RPCOMP FISH P Engage fish w/ spear. Hit 8 jar licks. Straigh pull to 265K (200K over). Fish free. PUH 1 stand. 1,510.0 1,393.0 1/17/2025 06:45 1/17/2025 11:15 4.50 COMPZN, RPCOMP CIRC P Circ BU @ 7 BPM / 580 psi. Grab sample of debris from shakers. Gas bubble at surface set off gas alarms. SD pumps. Close UPR. Take returns to tiger tank to allow gas to clear. Circ 3X BU to clear gas from well. 3 BPM @ 300 psi. SD pumps. 1,393.0 1,393.0 1/17/2025 11:15 1/17/2025 11:45 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min 1,393.0 1,393.0 1/17/2025 11:45 1/17/2025 13:15 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #5 (Spear) + Fish 1,393.0 232.0 1/17/2025 13:15 1/17/2025 15:45 2.50 COMPZN, RPCOMP BHAH P RU GBR equipment. L/D BHA #5. L/D 7" upper cut joint, 9 - 7" full joints, 4 centralizers, and lower cut joint. Upper cut Joint length = 9.1' long. Lower cut Joint length = 38.7' long. 232.0 0.0 1/17/2025 15:45 1/17/2025 17:00 1.25 COMPZN, RPCOMP BHAH P MU BHA #6 (Spear w/ pack-off). 0.0 232.0 1/17/2025 17:00 1/17/2025 18:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ spear to top of fish @ 1,940'. 232.0 1,940.0 1/17/2025 18:00 1/17/2025 18:30 0.50 COMPZN, RPCOMP FISH P Engage fish @ 1,940'. Warm up jars. Hit 4 licks @ 100K over, with 300K straight pulls. Fish moving freely 1,940.0 1,940.0 1/17/2025 18:30 1/17/2025 21:00 2.50 COMPZN, RPCOMP CIRC P Circ STS. x 3 to clean up well, 1,940.0 1,940.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 6/11 2P-429 Report Printed: 2/19/2025 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) 1/17/2025 21:00 1/17/2025 22:30 1.50 COMPZN, RPCOMP TRIP P Trip out of hole to BHA 1,940.0 600.0 1/17/2025 22:30 1/18/2025 00:00 1.50 COMPZN, RPCOMP BHAH P Rack collars and lay down spear // Swap elevators to pull casing 600.0 300.0 1/18/2025 00:00 1/18/2025 01:00 1.00 COMPZN, RPCOMP PULL P Lay down recovered 7" BTC casing from well, 6 full jts, 32.21' Cut Jt, 2 Centralizers // Clean and clear rig floor 300.0 0.0 1/18/2025 01:00 1/18/2025 02:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #7 (Spear w/ pack-off). 0.0 232.0 1/18/2025 02:00 1/18/2025 04:00 2.00 COMPZN, RPCOMP TRIP P TIH w/ spear to top of fish @ 2,219'. 232.0 2,219.0 1/18/2025 04:00 1/18/2025 05:00 1.00 COMPZN, RPCOMP FISH P Engage fish @ 2,219'. Warm up jars. Hit 50 licks @ 130K over, with 375K straight pulls. 2,219.0 2,219.0 1/18/2025 05:00 1/18/2025 06:00 1.00 COMPZN, RPCOMP SFTY P Perform derrick inspection. 2,219.0 2,219.0 1/18/2025 06:00 1/18/2025 06:30 0.50 COMPZN, RPCOMP JAR P Hit 10 more licks @ 130K over w/ 400K max straight pulls. No movement. Release from 7" fish. 2,219.0 2,219.0 1/18/2025 06:30 1/18/2025 07:30 1.00 COMPZN, RPCOMP CIRC P Gas bubbles in well. Line up to take OA returns out to tiger tank. Close UPR. Circ BU @ 4 BPM / 480 psi, sending gas cut brine to tiger. SD pumps. 2,219.0 2,219.0 1/18/2025 07:30 1/18/2025 08:00 0.50 COMPZN, RPCOMP OWFF P OWFF. 2,219.0 2,219.0 1/18/2025 08:00 1/18/2025 09:15 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #7 (Spear) 2,219.0 232.0 1/18/2025 09:15 1/18/2025 09:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #7 (Spear) 232.0 0.0 1/18/2025 09:45 1/18/2025 10:30 0.75 COMPZN, RPCOMP BHAH P MU BHA #8 (MSC) 0.0 11.0 1/18/2025 10:30 1/18/2025 12:00 1.50 COMPZN, RPCOMP TRIP P TIH to top of fish @ 2,219'. Drift through top and drift to 2,605'. PUW = 66K SOW = 61K. 11.0 2,605.0 1/18/2025 12:00 1/18/2025 13:30 1.50 COMPZN, RPCOMP CPBO P Screw in TD. Obtain parameters. 100 RPM. FT = 1.5K. Locate collars @ 2,610' and 2,654'. Position cutter blades and cut 7" casing @ 2,680'. Bring pumps online. 1 BPM @ 50 psi. Start cut: 12:47. Increase rate to 1.5 BPM @ 100 psi. Torque = 1.7K. Increase rate to 2 BPM / 175 psi. Torque = 1.8K. Max Torque during cut = 3K. Finish cut: 01:00 (13 minutes). Good cut indicators. SD pumps. Top Drive Lube Pump Pressure alarm. Low pressure. Troubleshoot. 2,680.0 2,680.0 1/18/2025 13:30 1/18/2025 14:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. T/S and repair Top Drive issue w/ lube oil pressure. 2,680.0 2,680.0 1/18/2025 14:00 1/18/2025 16:00 2.00 COMPZN, RPCOMP CPBO P TOOH to 2,421'. Screw in TD. Obtain parameters. Locate collars @ 2,439' and 2,482'. Position cutter blades and cut 7" casing @ 2,460'. Repeat w/ same parameters. 3K max torque seen during cut. Good cut indicators. 2,680.0 2,460.0 1/18/2025 16:00 1/18/2025 17:30 1.50 COMPZN, RPCOMP CIRC P Circ BU through gas buster @ 3 BPM / 502 psi. 2,460.0 2,460.0 1/18/2025 17:30 1/18/2025 18:00 0.50 COMPZN, RPCOMP OWFF P OWFF 2,460.0 2,460.0 1/18/2025 18:00 1/18/2025 19:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #8 (MSC) 2,460.0 11.0 1/18/2025 19:00 1/18/2025 19:30 0.50 COMPZN, RPCOMP BHAH P L/D MSC. Inspect blades 11.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 7/11 2P-429 Report Printed: 2/19/2025 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) 1/18/2025 19:30 1/18/2025 20:00 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 9 fishing spear BHA 0.0 300.0 1/18/2025 20:00 1/18/2025 21:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ spear to top of fish @ 2,219'. 300.0 2,219.0 1/18/2025 21:00 1/18/2025 21:15 0.25 COMPZN, RPCOMP JAR P Spear top of fish @ 2219' , P/u 100 k over 1 jar hit, fish moving up hole 2,219.0 2,212.0 1/18/2025 21:15 1/19/2025 00:00 2.75 COMPZN, RPCOMP CIRC P Circulate well @ 4 bpm @ 255 psi, circulate SxS still seeing gas break out at surface continue to circulate well checking on B/U for gas breaking out // Circulate through poor boy at 3 bpm @ 193 psi 2,212.0 2,212.0 1/19/2025 00:00 1/19/2025 01:15 1.25 COMPZN, RPCOMP TRIP P TOOH to BHA 2,212.0 550.0 1/19/2025 01:15 1/19/2025 02:15 1.00 COMPZN, RPCOMP BHAH P Rack collars and lay down BHA to fish 550.0 250.0 1/19/2025 02:15 1/19/2025 03:15 1.00 COMPZN, RPCOMP PULL P Pull 4 jts casing, 8.23 and 23.40' cut jts, and 2 centralizers 250.0 0.0 1/19/2025 03:15 1/19/2025 04:00 0.75 COMPZN, RPCOMP BHAH P Pick up Fishing BHA# 10 0.0 300.0 1/19/2025 04:00 1/19/2025 04:45 0.75 COMPZN, RPCOMP TRIP P TIH w/ spear to top of fish @ 2,460'. 300.0 2,460.0 1/19/2025 04:45 1/19/2025 05:00 0.25 COMPZN, RPCOMP FISH P Spear top of fish @ 2,460' , P/u 125 k over 3 jar hits,w/ 325 straight pull , Fish free moving up hole 2,460.0 2,460.0 1/19/2025 05:00 1/19/2025 07:15 2.25 COMPZN, RPCOMP CIRC P Circulate well clean through Poorboy until clean. LIne up to take returns down flowline. Bring pumps on @ 5 BPM / 490 psi. Circ out until clean. 2,460.0 2,460.0 1/19/2025 07:15 1/19/2025 07:45 0.50 COMPZN, RPCOMP OWFF P OWFF 2,460.0 2,460.0 1/19/2025 07:45 1/19/2025 09:00 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #10 (Spear) + 7" casing fish. 2,460.0 476.0 1/19/2025 09:00 1/19/2025 09:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #10 (Spear ). 476.0 244.0 1/19/2025 09:30 1/19/2025 10:30 1.00 COMPZN, RPCOMP PULL P Pull and L/D 7" casing. 1 - 19.37' long upper cut joint. 4 - full joints, 2 - centralizers, 1 - 28.38' long deep cut joint. 244.0 0.0 1/19/2025 10:30 1/19/2025 11:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #11 (Spear) 0.0 232.0 1/19/2025 11:30 1/19/2025 12:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #11 (Spear) to above next 7' fish @ 2620'. PUW = 76K. SOW = 65K 232.0 2,620.0 1/19/2025 12:30 1/19/2025 13:30 1.00 COMPZN, RPCOMP FISH P Spear top of fish @ 2,680' , Hit 1 jar licks @ 50K over, with 100K over straight pulls. 2,620.0 2,680.0 1/19/2025 13:30 1/19/2025 15:15 1.75 COMPZN, RPCOMP CIRC P Bring pumps on @ 4 BPM / 477 psi. Circ out until clean. 2,680.0 2,680.0 1/19/2025 15:15 1/19/2025 15:30 0.25 COMPZN, RPCOMP OWFF P OWFF 2,680.0 2,680.0 1/19/2025 15:30 1/19/2025 16:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #11 (Spear) + 7" casing fish. 2,680.0 476.0 1/19/2025 16:30 1/19/2025 17:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #11 (Spear ). 476.0 244.0 1/19/2025 17:00 1/19/2025 18:00 1.00 COMPZN, RPCOMP PULL P Pull and L/D 7" casing. 1 - 14.35' long upper cut joint. 5 - full joints, 2 - centralizers, 1 - 14.35' long deep cut joint. 244.0 0.0 1/19/2025 18:00 1/19/2025 19:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #12 (Spear) 0.0 232.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 8/11 2P-429 Report Printed: 2/19/2025 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) 1/19/2025 19:00 1/19/2025 20:15 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #12 (Spear) to above next 7' fish @ 2620'. PUW = 76K. SOW = 65K 232.0 2,950.0 1/19/2025 20:15 1/19/2025 21:15 1.00 COMPZN, RPCOMP FISH P Unable to get into fish, stack out @ 2,952', attempt to wash into pipe, unable to work past packoff 2,950.0 2,952.0 1/19/2025 21:15 1/19/2025 21:45 0.50 COMPZN, RPCOMP CIRC P Bring pumps on @ 4 BPM / 477 psi. Circ out until clean. 2,950.0 2,950.0 1/19/2025 21:45 1/19/2025 22:30 0.75 COMPZN, RPCOMP TRIP P OWFF and TOOH w/ BHA #12 (Spear) to check bha 2,950.0 2,400.0 1/19/2025 22:30 1/20/2025 00:00 1.50 COMPZN, RPCOMP SLPC P Cut and slip drill line 2,400.0 2,400.0 1/20/2025 00:00 1/20/2025 01:00 1.00 COMPZN, RPCOMP TRIP P OWFF and TOOH w/ BHA #12 (Spear) to check bha 2,400.0 260.0 1/20/2025 01:00 1/20/2025 02:00 1.00 COMPZN, RPCOMP BHAH P Rack collars and re-configure spear // Found packoff to be damaged keeping us from engaging pipe // Spear confugured for short catch w/o packoff 260.0 0.0 1/20/2025 02:00 1/20/2025 03:15 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #13 (Spear - Short Catch) to above next 7' fish @ 2950'. PUW = 76K. SOW = 65K 232.0 2,950.0 1/20/2025 03:15 1/20/2025 05:30 2.25 COMPZN, RPCOMP FISH P Engage fish @ 2,950'. Did not fully no- go. Likely fill in/around the top of fish. Hit 60 jar licks @200K over, straight pull to 375K. No movement. Release from fish. 2,950.0 2,952.0 1/20/2025 05:30 1/20/2025 06:45 1.25 COMPZN, RPCOMP SFTY P Perform post-jarring derrick inspection. OWFF (monitor on trip tank). 2,952.0 2,952.0 1/20/2025 06:45 1/20/2025 08:00 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #13 (Spear) 2,950.0 232.0 1/20/2025 08:00 1/20/2025 09:15 1.25 COMPZN, RPCOMP BHAH P L/D BHA #13 232.0 0.0 1/20/2025 09:15 1/20/2025 10:00 0.75 COMPZN, RPCOMP BHAH P MU BHA #14 (Cleanout - 3 1/2" muleshoe w/ 6 1/8" string mill) 0.0 9.0 1/20/2025 10:00 1/20/2025 11:30 1.50 COMPZN, RPCOMP TRIP P TIH to top of fish @ 2,888'. Obtain parameters. PUW = 68K. SOW = 61K. 9.0 2,888.0 1/20/2025 11:30 1/20/2025 13:45 2.25 COMPZN, RPCOMP WASH P Tagged top of fill/fish@ 2,946'. PU off tag. Obtain parameters. Circ high rate to clean fill out of the well, reciprocating/rotating pipe. Pump rate = 6 BPM @ 684 psi. 12% flow. Wash 7" casing down to 3,019'. Pump 20 bbl hi- vis sweep around. Circ out. 2,888.0 2,950.0 1/20/2025 13:45 1/20/2025 14:15 0.50 COMPZN, RPCOMP OWFF P OWFF 2,950.0 2,950.0 1/20/2025 14:15 1/20/2025 15:30 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #14 (Cleanout) 2,950.0 9.0 1/20/2025 15:30 1/20/2025 16:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #14 (Cleanout) 9.0 0.0 1/20/2025 16:00 1/20/2025 17:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #15 (MSC) 0.0 11.0 1/20/2025 17:00 1/20/2025 18:30 1.50 COMPZN, RPCOMP TRIP P TIH w/ MSC to 2,970'. PUW = 70K. SOW = 63K. 11.0 2,970.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 9/11 2P-429 Report Printed: 2/19/2025 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) 1/20/2025 18:30 1/20/2025 19:30 1.00 COMPZN, RPCOMP CPBO P Obtain parameters. Bring pumps on at 0.5 BPM @ 70 psi. TIH and locate collar @ 2,990'. PUH and park cutter blades on depth @ 2,986' (21' below SC shoe). Rotary = 100 RPM. F.T. = 1.8K ft-lbs. Pump rate = 1.5 BPM @ 130 psi. Increase to 2 BPM @ 221 psi. Max Torque during cut = 2.5 K. Saw torque spike then drop off. Cut in 26 minutes. Indicator of good cut. Set 5K on blades to confirm. 2,970.0 2,986.0 1/20/2025 19:30 1/20/2025 20:30 1.00 COMPZN, RPCOMP CIRC P Circ BU 2,986.0 2,986.0 1/20/2025 20:30 1/20/2025 21:00 0.50 COMPZN, RPCOMP OWFF P OWFF 2,986.0 2,986.0 1/20/2025 21:00 1/20/2025 22:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #15 (MSC) 2,986.0 11.0 1/20/2025 22:00 1/20/2025 22:15 0.25 COMPZN, RPCOMP BHAH P L/D BHA #15. Inspect Blades. 11.0 0.0 1/20/2025 22:15 1/20/2025 22:45 0.50 COMPZN, RPCOMP BHAH P MU BHA #16 (Spear). 0.0 232.0 1/20/2025 22:45 1/20/2025 23:45 1.00 COMPZN, RPCOMP TRIP P TIH with BHA# 16 fishing spear, engage fish @ 2,950' 232.0 2,950.0 1/20/2025 23:45 1/21/2025 00:00 0.25 COMPZN, RPCOMP JAR P Engage fish @ 2,950' , 1 jar hit @ 100K over , pull 275K fish moving up hole 2,950.0 2,950.0 1/21/2025 00:00 1/21/2025 01:30 1.50 COMPZN, RPCOMP CIRC P Circulate well clean pump 3 bpm @ 217 psi through gas buster, OWFF 2,950.0 2,950.0 1/21/2025 01:30 1/21/2025 03:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ fish // Blow down TD and standpipe 2,950.0 300.0 1/21/2025 03:00 1/21/2025 04:00 1.00 COMPZN, RPCOMP BHAH P Rack collars and lay down spear 300.0 30.0 1/21/2025 04:00 1/21/2025 04:15 0.25 COMPZN, RPCOMP PULL P Lay down 7" casing //36.74' cut jt, 30.0 0.0 1/21/2025 04:15 1/21/2025 04:30 0.25 COMPZN, RPCOMP BHAH P MU BHA #17 (Spear). 0.0 232.0 1/21/2025 04:30 1/21/2025 05:45 1.25 COMPZN, RPCOMP TRIP P TIH with BHA# 16 fishing spear, engage fish @ 2,988' 232.0 2,988.0 1/21/2025 05:45 1/21/2025 09:00 3.25 COMPZN, RPCOMP JAR P Engage fish @ 2,988' , ~70 jar hit @ 100K over , pull 400K fish moving up hole 2,988.0 2,988.0 1/21/2025 09:00 1/21/2025 11:45 2.75 COMPZN, RPCOMP CIRC P Circulate well clean, 2,988.0 2,980.0 1/21/2025 11:45 1/21/2025 13:15 1.50 COMPZN, RPCOMP TRIP P TOOH to BHA, 2,980.0 260.0 1/21/2025 13:15 1/21/2025 15:00 1.75 COMPZN, RPCOMP BHAH P Lay down collars, lay down fishing spear // Lay down cut jt casing 35.15 // Clean and clear floor 260.0 0.0 1/21/2025 15:00 1/21/2025 16:30 1.50 COMPZN, RPCOMP RURD P Rig up to run 4.5" cement string. Verify pipe count 0.0 0.0 1/21/2025 16:30 1/21/2025 22:00 5.50 COMPZN, RPCOMP PUTB P Pick up and run 97 jts 4.5" IBT tubing. Wash down 2964 to 3029. Tag plug @ 3029' 3K down. Pump Hi Vis sweep. 2 BPM @ 80 PSI. Chase with 9.8 PPG 7 BPM @ 100 PSI/ , space out 10' for cement job. PUW=61K, SOW=57K 0.0 3,029.0 1/21/2025 22:00 1/21/2025 23:00 1.00 COMPZN, RPCOMP RURD P R/U cement equipment. PT cement lines to 2500 PSI 3,029.0 3,018.0 1/21/2025 23:00 1/22/2025 00:00 1.00 COMPZN, RPCOMP CMNT P Batch up cement 3,018.0 3,018.0 1/22/2025 00:00 1/22/2025 01:18 1.30 COMPZN, RPCOMP CMNT P Pump spacers - cement per HES program 3,018.0 3,018.0 1/22/2025 01:18 1/22/2025 02:18 1.00 COMPZN, RPCOMP PULL P Pull 4 1/2 cement string to safety 3,018.0 2,318.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 10/11 2P-429 Report Printed: 2/19/2025 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) 1/22/2025 02:18 1/22/2025 02:48 0.50 COMPZN, RPCOMP CIRC P Circ STS 7 BPM @ 102 PSI 2,318.0 2,318.0 1/22/2025 02:48 1/23/2025 00:00 21.20 COMPZN, RPCOMP WOC P Wait on cement, Replace drilling line spool. Replace saver sub. Full derrick, crown, draw works, and top drive inspection 2,318.0 2,318.0 1/23/2025 00:00 1/23/2025 02:00 2.00 COMPZN, RPCOMP WOC P Continue waiting on cement 2,318.0 2,318.0 1/23/2025 02:00 1/23/2025 02:42 0.70 COMPZN, RPCOMP PULD P All samples solid. RIH to tag TOC 2,318.0 2,561.0 1/23/2025 02:42 1/23/2025 03:00 0.30 COMPZN, RPCOMP WASH P KU, Start washing down to TOC, RIW=54K. 2,561.0 2,589.0 1/23/2025 03:00 1/23/2025 05:00 2.00 COMPZN, RPCOMP CIRC P Tag @ 2589 W/7K down. PUH pumping at 1 BPM. PUW=56K to 2530. Circ BU @ 7 BPM @ 91PSI 2,589.0 2,529.0 1/23/2025 05:00 1/23/2025 06:30 1.50 COMPZN, RPCOMP PRTS T Attempt pressure test of cement plug // unable to build above 160 psi 2,529.0 2,529.0 1/23/2025 06:30 1/23/2025 07:30 1.00 COMPZN, RPCOMP RURD T Rig down test equipment // Prep to TOOH with stands of 4.5" 2,529.0 2,529.0 1/23/2025 07:30 1/23/2025 09:00 1.50 COMPZN, RPCOMP TRIP T TOOH racking 4.5" in derrick 2,529.0 0.0 1/23/2025 09:00 1/23/2025 15:15 6.25 COMPZN, RPCOMP WAIT T Wait for test packer and scraper 0.0 0.0 1/23/2025 15:15 1/23/2025 15:30 0.25 COMPZN, RPCOMP BHAH T Pick up casing scraper 0.0 8.0 1/23/2025 15:30 1/23/2025 18:00 2.50 COMPZN, RPCOMP TRIP T TIH to clean up test packer set depth. Start washing 2580 // Tag cement @ 2593'. Set down 15K. PUW=65K. SOW=59K 8.0 2,593.0 1/23/2025 18:00 1/23/2025 18:30 0.50 COMPZN, RPCOMP CIRC T Circ BU 6 BPM @ 675 PSI, Blow down top drive, OWFF 2,593.0 2,563.0 1/23/2025 18:30 1/23/2025 19:00 0.50 COMPZN, RPCOMP TRIP T POOH 2563 to surface. 2,563.0 14.6 1/23/2025 19:00 1/23/2025 19:30 0.50 COMPZN, RPCOMP BHAH T Lay down BHA # 18 Scraper 14.6 0.0 1/23/2025 19:30 1/23/2025 21:00 1.50 COMPZN, RPCOMP TRIP T M/U BHA # 19, 9 5/8" test packer Test packer, Trip in to 2542' 0.0 2,542.0 1/23/2025 21:00 1/23/2025 21:30 0.50 COMPZN, RPCOMP CIRC T Circ 30 BBls @ 30 BPM @ 3 BPM 161 PSI 2,542.0 2,542.0 1/23/2025 21:30 1/23/2025 22:30 1.00 COMPZN, RPCOMP MPSP T Set packer, Found packer leaking, Drag packer uphole 10' set again. Still leaking. PUH to COE @ 2506. Packer holding 2,542.0 2,506.0 1/23/2025 22:30 1/23/2025 23:00 0.50 COMPZN, RPCOMP RURD T Rig up test equipment 2,506.0 2,506.0 1/23/2025 23:00 1/24/2025 00:00 1.00 COMPZN, RPCOMP PRTS T Pressure test cement plug, 8 strokes to pressure up to 1850 PSI. Unable to get passing test Bleed off and attempt again. Less pressure drop. 190 PSI 13 minutes. Unable to get passing test 2,506.0 2,506.0 1/24/2025 00:00 1/24/2025 02:30 2.50 COMPZN, RPCOMP PRTS T 2538’, Packer seeping 2535’, Packer seeping 2532. Packer sealing. Pressure up to 1700PSI. Lost 170 PSI in 12 min 2506’ TOC lost 200 PSI in 10 min 2569’ TOC lost pressure. 2585’, TOC lost pressure. Good casing test to surface 1650 PSI. 2,506.0 2,585.0 1/24/2025 02:30 1/24/2025 06:00 3.50 COMPZN, RPCOMP TRIP T Trip out of well with 9 5/8" test packer, PUW=61K // Test packer hung up in well head // work free and lay down 2,585.0 0.0 1/24/2025 06:00 1/24/2025 07:00 1.00 COMPZN, RPCOMP WAIT P Develop plan forward with interventions for abandon well ops 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 Page 11/11 2P-429 Report Printed: 2/19/2025 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) 1/24/2025 07:00 1/24/2025 10:30 3.50 COMPZN, RPCOMP TRIP P Pick up hanger, ensure will go into profile, RIH w/ 4.5" mule shoe and 78 jts 4.5" IBT tubing T/ 2475' 0.0 2,475.0 1/24/2025 10:30 1/24/2025 11:30 1.00 COMPZN, RPCOMP THGR P Pick up tubing hanger and land on profile, RILDS 2,475.0 2,475.0 1/24/2025 11:30 1/24/2025 13:30 2.00 COMPZN, RPCOMP PRTS P Rig up test equipment // Pressure test casing aginst cement plug 1500 psi 1 hr // Rig down test equipment 2,475.0 2,475.0 1/24/2025 13:30 1/24/2025 14:45 1.25 COMPZN, RPCOMP THGR P Pull hanger, run 4 jts 4.5" IBT tubing, re- land hanger RILDS 2,475.0 2,585.0 1/24/2025 14:45 1/24/2025 15:45 1.00 COMPZN, RPCOMP PRTS P Pressure test casing aginst cement 1500 psi 30min 2,585.0 2,585.0 1/24/2025 15:45 1/24/2025 17:30 1.75 COMPZN, RPCOMP WAIT P Wait for plan forward. Sent state witness back toward Deadhorse due to poor weather / phase conditions. Phase two to rig for change out 2,585.0 2,585.0 1/24/2025 17:30 1/24/2025 18:30 1.00 COMPZN, RPCOMP SFTY P Make change out. PJSM. R/U test equipment for cement plug test 2,585.0 2,585.0 1/24/2025 18:30 1/24/2025 22:00 3.50 COMPZN, RPCOMP PRTS P Attemp pressure test of shoe cement plug. Try multiple senerios to obtain test. Inspector wanted to see no more then 1/2 pressure dropped in last 15 minutes versus first 15 minutes. We obtained overall pressure drop good test. Not within schedule per 15 minute blocks. 2,585.0 2,505.0 1/24/2025 22:00 1/24/2025 22:30 0.50 COMPZN, RPCOMP RURD P Rig down pressure test equipment. R/D digital wireless pressure transducer. 2,505.0 2,505.0 1/24/2025 22:30 1/25/2025 00:00 1.50 COMPZN, RPCOMP THGR P BOLDS. Pull hanger to floor. Lay down. C/O handleing equipment. Lay down 4 joints 4 1/2" tubing. C/O elevators. P/U Landing joint. M/U to hanger. Make up to tubing. Land hanger. RILDS. Muleshoe @ 2461.66 2,505.0 2,461.7 1/25/2025 00:00 1/25/2025 01:30 1.50 COMPZN, WHDBOP NUND P ND BOPE stack. Pull mouse hole 2,461.7 2,461.0 1/25/2025 01:30 1/25/2025 03:00 1.50 COMPZN, WHDBOP NUND P Install test dart. Nipple up tubing head adapter. Test hanger void 5K for 10 minutes 2,461.0 2,461.0 1/25/2025 03:00 1/25/2025 04:30 1.50 COMPZN, WHDBOP RURD P Start Rig down for move to 2P-429, wait on LRS for freeze protect 2,461.0 0.0 1/25/2025 04:30 1/25/2025 07:00 2.50 DEMOB, MOVE FRZP P Rig up LRS, PT tree 5000 psi good test, pull BPV, pump 80 bbls LEPD freeze protect // Let well U-tube Rig released 07:00 on 1/25/25 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 1/25/2025 DTTMSTART JOBTYP SUMMARYOPS 1/14/2025 RECOMPLETION Pull support equipment away from rig. Pull rig off 2P-431. Move pipe bunks. Build new laydown area. Move kill tanks. Lay cellar pit liner and rig mats. Pull rig over 2P- 429. Spot in support equipment. Complete rig acceptance checklist. Gather initial pressures. RU hardline to tanks. RU circulation equipment. Load 9.8# Brine into pits. Build Deepclean pill. RU and PT hardline. Kill well with 9.8# Brine. Pump 33 bbls Deep Clean. Pump 145 bbls of 9.8# brine. Good 9.8# returns. SD pumps. Blowdown. OWFF. ND tree. Repair pin hole leak in Pill Pit. Inspect hanger threads. NU BOP.Flood BOPs with water and surface lines, grease valves on stack and choke, Shell test BOP's, Start full BOP test 250/2500 psi AOGCC witness waived Brian Bixby 1/15/2025 RECOMPLETION Perform initial BOP test to 250/2500 psi. Test annular w/ 3 1/2” & 7” TJ’s. Test UPR’s w/ 3 1/2” and 4 ½” TJ. LRPs on 7”. Test 3 ½” and 4 ½” EUE FOSV. R/D testing equipment. Pull BPV and test dart. MU 4 ½” Landing Joint (3 ½” IF DP + NSCT bottlenecked XO, CPAI #735). Thread into 4 ½” Tubing Hanger. Have FMC verify full makeup. Count turns.Screw in TD. Set 10K down. BOLDS. Pull hanger to rig floor.64k off seat drag 63K to rig floor.L/D landing joint and 4 ½” Tubing Hanger w/ pup. . Circ BU 7 bpm @ 280 psi . R/D circ. hose and head pin. OWFF. Pull 4 ½” Tubing from pre-rig cut @ 3,110’ to surface. Clean and clear floor. MU BHA #1 (7" CIBP). TIH and set CIBP @ 3,025'. Pressure up and release from CIBP. TOOH and L/D setting tool. PT CIBP to 1,000 psi for 10-min. MU BHA #2 (MSC). TIH w/ MSC. Confirm no collars at cut depth. Cut 7" casing @ 3,020' (55' below SC shoe). Saw good torque indicators of a good cut. Set 3K down to confirm knives in cut. No OA pressure indicator. Attempt to establish OA circulation. Unable. PUH and locate collar @ 2,954' in cased hole. Perform 2nd 7" casing cut @ 2,950'. No indicator of cut, attempt to circulate, no returns, mobilize E-line for CBL, pull packoff on 7", attempt to pull 7" 100K over string wt (200K) no movement, set packoff prep for E- line run 1/16/2025 RECOMPLETION RU E-Line. RIH w/ CBL. Log CBL F/ 2,890' to surface. RD E-line. MU BHA #3 (MSC). TIH w/ MSC. Review CBL data with Town Engineers. Cut 7" casing @ 2,219'. Attempt to establish OA circulation. Unable to circulate OA. SD pumps. PUH and cut 7" casing @ 1,940'. Unable to build torque. Troubleshoot MSC. OWFF. TOOH to inspect cutter. L/D BHA #3 (MSC). No damage to tool. Load backup MSC. Drain stack. Pull pack-off. M/U 7" landing joint. Pull 250K (170K over). No movement. L/D landing joint. Install pack-off. RILDS. MU BHA #4 (MSC). TIH and cut 7" casing @ 1,941'. Attempt to establish OA circulation. No Joy. PUH and cut 7" casing @ 1,510'. See OA press. indicator. Establish OA circulation. Circulate 70 bbls Deep Clean pill followed by 9.8# till clean, TOOH, pull packoff and hanger to floor 90K off seat, pull pipe, swabbing well, rig up circulate hole clean, continue pulling pipe and cleaning backside when needed 1/17/2025 RECOMPLETION Pull 7" casing from cut @ 1,510', lay down cut jt, secure well. Wait on Willow modules for crew change out. MU BHA #5 (7" Spear). TIH to top of fish @ 1,510'. Engage and jar fish free. Circ 3X BU. Take returns to tiger tank to clear gas. OWFF. TOOH. L/D spear and 420' 7" casing fish. MU BHA #6 (Spear). TIH to top of 7" fish @ 1,940'. Engage fish. Jar 4 times @ 150K over, fish free, circulate hole clean, TOOH with fish 2P-429 Rig Suspend Summary of Operations 1/18/2025 RECOMPLETION L/D 7" casing fish. MU BHA #7 (Spear). TIH and engage fish @ 2,219'. Hit 60 jar licks @ 130K over with 400K max straight pulls. No movement. Perform derrick inspection. Release from fish. Circ BU. OWFF. TOOH and L/D BHA #7 (Spear). Inspect. MU BHA #8 (MSC). TIH and cut 7" casing @ 2,680' and 2,460'. Circ BU. OWFF. TOOH w/ BHA #8 (MSC). L/D same. MU BHA #9 (Spear). TIH and engage fish @ 2,219'. Hit 1 Jar licks @ 100K over with 275K straight pull, circulate gas and debris out of well 1/19/2025 RECOMPLETION OWFF. TOOH and L/D BHA #9 (Spear) BHA and 7" fish. L/D 7" casing fish. MU BHA #10 (Spear). TIH and engage fish @ 2,460'. Jar free w/ 3 licks and straight pull to 325K. Fish free. Circ BU through Poorboy until clean. OWFF. TOOH and L/D BHA #10 (Spear) and 7" fish. MU BHA #11 (Spear). TIH and engage fish @ 2,680'. Jar on fish. Jar fish free with 1 lick @ 50K over, and 100K over straight pulls (176K total). Circ BU. OWFF. TOOH and L/D BHA #11 and 7" fish T/ 2,950'. MU BHA #12 (Spear). TIH and attempt to engage fish @ 2,950'. Unable to get packoff past top of pipe, circulate B/U, TOOH to inspect spear 1/20/2025 RECOMPLETION TOOH w/ BHA #12 (Spear). Found pack-off damaged. Reconfigured spear. MU BHA #13 (short catch spear). TIH and engage 7" fish @ 2,950'. Hit 60 jar licks @ 200K over, with straight pulls to 375K. No movement. Release spear. Perform derrick inspection. OWFF. TOOH and L/D BHA #13. MU BHA #14 (Cleanout). TIH and cleanout well and 7" casing fish to 3,019'. Reciprocate at high rate to clear debris. Pump hi-vis pill. Circ out. TOOH and L/D BHA #14 (Cleaanout). MU BHA #15 (MSC). TIH and cut 7" casing @ 2,986'. Circ. BU. OWFF. TOOH w/ BHA #15 (MSC). L/D MSC. MU BHA #16 (Spear). TIH and engage fish @ 2,950'.1 jar hit 100K over and straight pull 275K fish moving up hole 1/21/2025 RECOMPLETION Circulate well clean from pulling fish free, OWFF, TOOH lay down collars & fishing BHA. Prep and ruyn 4 1/2" cementing string. RIH. Wash down 2964 to tag @ 3029'. Pump sweep. circulate to dsurface. R/U HES cementers 1/22/2025 RECOMPLETION Complete pumping 29 BBls 15.8PPG cement per HES progran. Pull 4 1/2 cement string to safety 2320. WOC 1/23/2025 RECOMPLETION Continue waiting on cement. RIH, wash down to TOC @ 2598' Circ BU, 7 BPM @ 190 PSI. Rig up test equipment. Injecting @ 164 PSI. Make scraper run in preperarion for test packer run. Run test pack. Get set 2538' packer seeping, 2535 packer seeping. 2532. packer sealing cement failed test. Set @ 2506'. Able to pressure up to 1850 PSI. Lost 190 PSI in 13 Min. Try PT to surface Holding. RIH reset packer @ 2569'. No passing cement test. RIH Set @ 2585'. No passing cement test. Good test on casing to surface. 1/24/2025 RECOMPLETION Continue attempting to get PT on cement plug. Obtain passing casing pressure test from bottom. Unable to get passing cement plug PT. Run 4 1/2" cementing string to 2585. Land hanger. RILDS. Work on cement plug pressure test. Unable to get satisfactory test. BOLDS. Pull hanger to floor. Lay down 4 joints 4 1/2" tubing. Mule shoe @ 2461.6' landed. RILDS. Set BPV 1/25/2025 RECOMPLETION Nipple down stack, nipple up tree, PT tree 5000 psi, freeze protect well 1000', Rig released 07:00 1/28/2025 SUPPORT OTHER OPERATIONS (P&A) CMIT - T X SC TO 1500 PSI (FAIL) ORIGINATED TRANSMITTAL DATE: 1/27/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5249 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 5249 2P-429 50103203780000 Cement Bond Log 15-Jan-2025 RECIPIENTS CONOCO PHILLIPS ALASKA, LLC DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 0 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 201-102 T40019 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 09:50:08 -09'00' 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: 30.12 ft Total Depth: 8974 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ NA Feet Surface: 9-5/8" O.D. Shoe@ 2965 Feet Csg Cut@ NA Feet Intermediate: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production: 7"x4-1/2" O.D. Shoe@ 8966 Feet Csg Cut@ NA Feet Liner: NA O.D. Shoe@ NA Feet Csg Cut@ 3020 Feet Tubing: 4-1/2" O.D. Tail@ 7617 Feet Tbg Cut@ 3110 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole Bridge plug 3025 ft 2598 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1860 1680 IA 0 0 OA 0 0 Initial 15 min 30 min 45 min Result Tubing 1860 1550 IA 0 0 OA 0 0 Remarks: Attachments: Chase Erdman F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to location to witness the tag and pressure test (mechanical integrity test) of a cement plug covering up a small open hole section (C80 formation) beneath the surface casing shoe. Cement was to be brought up into the surface casing ~ 150 ft. With a 4-1/2" work string they tagged 10 barrels high with 12k pounds at 2598 ft MD - hard tag. Victoria Loepp (AOGCC) approved proceeding with the high tag. With the string parked at 2526 ft MD, they closed in the well and attempted the pressure test. Could not build pressure above 180 psi - FAIL. I returned later on 1/23 to attempt again with a test packer set above tag depth. Attempted at multiple test packer depths from 2506 to 2585 ft MD 1/23 and 1/24 - all FAIL with 10%+ pressure loss observed in under 10 minutes. Two representative tests shown above. January 24, 2025 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-429 ConocoPhillips Alaska, Inc. PTD 2011020; Sundry 324-647 none Test Data: F Casing Removal: rev. 3-24-2022 2025-0124_Plug_Verificaton_KRU_2P-429_am 9 9 9 9 9 9 999 9 9 9 9 9 9 9 999 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.04 15:14:58 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 8974'8900' 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. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell 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 12/20/2024 4-1/2" Packer: Baker G-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' (cemented) 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' (cemented) 7" x 4-1/2" Perforation Depth TVD (ft): 110' 2965' 5997'8966' 16" 9-5/8" 82' 7617' MD MD 110' 2434' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Shane Germann 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 (907) 263-4597 Senior Well Interventions Engineer KRU 2P-429 6002' 4779' 3527' 4779', 7555' 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 MPSP (psi): 811 By Grace Christianson at 9:30 am, Nov 13, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E =shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2024.11.12 15:44:21-09'00' Foxit PDF Editor Version: 13.0.0 324-647 DSR-11/21/24 BOP test to 2500 psig Annular preventer test to 2500 psig See attached "Conditions of Approval" X XXX 10-407 SFD 12/2/2024 June 30, 2025 VTL 11/27/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.03 14:34:16 -09'00'12/03/24 RBDMS JSB 120424 KRU 2P-4Ϯϵ 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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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 7/8/2023 = 3052 psi @ 5400’ TVD x MASP = 2512 psi C-80 Formation: x OAP = 234 psi (11/5/22) (fluid packed with diesel) x MASP = 811 psi Intermediate plug TOC = 4779’ MD Tubing cut depth = 3110’ MD Well Name Previous plug tag depth (RKB)PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-429 4779' Pass 9/15/2024 0 psi 0 psi 240 psi 9/19/2024 Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB C80 @ 2950' KBC80 @ 2950' KB 2P-429 Well Suspension Schematic Conductor: 16" Conductor 110' KB 1 2 3 5 4Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4'’ KB T-3 Peforations: @ 8,176' – 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB (2434' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBTM Set @ 7,617' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &DdƵďŝŶŐ,ĂŶŐĞƌ Ϯϯ͘ϮΖ Ϯ ĂŵĐŽ>ĂŶĚŝŶŐEŝƉƉůĞ ϱϭϳ͘ϱΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬKƚŝƐ ΖyΖWƌŽĨŝůĞ ϳ͕ϱϱϬΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞ ϳ͕ϱϳϬ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌΘ^ĞĂů ƐƐĞŵďůǇ ϳ͕ϲϭϰ͘ϭΖ Plug #1 – reservoir TOC ± 7555' Retainer 7725' KB Plug #2 – Intermediate TOC ±4779' RKB BOC @ ±6504' RKB Surface Casing Plugs – Rig Date: 11-12-2024 Prepared by: Shane Germann Estimated Start Date: 12-20-2024 MIRU 1. MIRU on 2P-429. 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 25 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 7” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 7” casing is 150’ – 200’ MD above target TOC and space out with a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB C80 @ 2950' KBC80 @ 2950' KB 2P-429 Well Surface Shoe Cement Schematic Conductor: 16" Conductor 110' KB 1 2 3 5 4Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4'’ KB T-3 Peforations: @ 8,176' – 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB (2434' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBTM Set @ 7,617' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϮΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϲϱΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬKƚŝƐΖyΖ WƌŽĨŝůĞ ϳ͕ϱϱϬΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞ ϳ͕ϱϳϬ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌΘ^ĞĂůƐƐĞŵďůǇ ϳ͕ϲϭϰ͘ϭΖ Plug #1 – reservoir TOC ± 7555' Retainer 7725' KB Plug #2 – Intermediate TOC ±4779' RKB BOC @ ±6504' RKB Plug #3 – Surface Shoe TOC 2714' RKB (2284' TVD) BOC @ ±3065' RKB Base of 7” Casing 300'-350' MD Inside Surface Shoe 2 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 3015 3065 Open Hole 8.5 0.060898 3.0 Displacement of Prod Casing Stub Included in BBL/FT calc 2965 3015 Open Hole 8.5 0.070187 3.5 2714 2965 Surface Casing 8.83 0.075742 19.0 25.5 Total Volume of Plug Surface Casing 23 2714 Surface Casing 8.83 0.066454 178.8 Displacement of Prod Casing Included in BBL/FT calculation Execute Final Abandonment Surface Excavation 12. DHD to perform drawdown test on tubing, IA, and OA 13. Remove well house. 14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system. 15. Remove tree in preparation for excavation and casing cut. 16. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level. 18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 19. Send the casing head with stub to materials shop. Photo document. 20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 2P-429 c. PTD #: 201-102 d. API #: 50-103-20378-00-00 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 23' RKB BOC @ ±2714' RKB Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB C80 @ 2950' KBC80 @ 2950' KB 2P-429 Well Final P&A Schematic Conductor: 16" Conductor 110' KB 1 2 3 5 4Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4'’ KB T-3 Peforations: @ 8,176' – 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB (2434' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBTM Set @ 7,617' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϮΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϲϱΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬKƚŝƐΖyΖ WƌŽĨŝůĞ ϳ͕ϱϱϬΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞ ϳ͕ϱϳϬ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌΘ^ĞĂůƐƐĞŵďůǇ ϳ͕ϲϭϰ͘ϭΖ Plug #1 – reservoir TOC ± 7555' Retainer 7725' KB Plug #2 – Intermediate TOC ±4779' RKB BOC @ ±6504' RKB Plug #3 – Surface Shoe TOC 2714' RKB (2284' TVD) BOC @ ±3065' RKB 2 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,779.0 2P-429 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-429 9/19/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED KNOWN OBSTRUCTION @ 7849' SLM 9/11/2017 pproven NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 7,617.0 Set Depth … 5,219.2 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.2 23.2 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 517.5 517.3 4.40 NIPPLE 5.250 CAMCO DB LANDING NIPPLE CAMCO DB 3.875 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,994.0 1,833.8 43.10 TUBING PUNCH TUBING PUNCH (1994' - 1997' RKB) 9/8/2024 3.960 3,110.0 2,523.5 51.77 CUT JET CUT AT 3110' RKB 9/19/2024 3.960 6,500.0 4,554.0 53.54 TUBING PUNCH SHOT 4.5 FT OF HOLES. 6 SPF. 8/4/2024 3.960 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,500.2 5,149.3 53.52 1 GAS LIFT DMY BTM 1 0.0 2/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug PUMP 15.8 PPG CEMENT LAY 3 BBLS ON TOP OF RETAINER. 6/20/2024 4,779.0 6,504.5 3,527.0 4,556.7 Cement Plug PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4779' SLM) 9/7/2024 2P-429, 11/12/2024 3:12:52 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 25.5-8,966.4 FLOAT SHOE; 8,964.8-8,966.4 FISH; 8,900.0 FLOAT COLLAR; 8,870.2- 8,871.7 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 SBR; 7,617.5-7,618.6 SEAL; 7,614.1 NIPPLE; 7,570.6 Cement Plug; 7,555.0 ftKB SLEEVE; 7,550.0 GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 SURFACE; 28.6-2,965.0 FLOAT SHOE; 2,963.3-2,965.0 FLOAT COLLAR; 2,886.0- 2,887.5 TUBING PUNCH; 1,994.0 PORT COLLAR; 1,007.1- 1,010.1 NIPPLE; 517.5 CONDUCTOR; 28.0-110.0 HANGER; 28.6-29.8 HANGER; 25.5-27.3 HANGER; 23.2 Casing 1; 0.0 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev… 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE ϮWͲϰϮϵϭϬĂůĐƵůĂƚĞĚWdKΛϱϴϮϳ͛Z<^^ŚŽĞΛϮϵϲϱ͛Z</WΛϯϬϵϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϳϭϰ͛Z<WƵƚΛϯϬϭϱ͛Z<ϴϬdŽƉΛϮϵϱϬ͛Z<ϴϬĂƐĞΛϰϲϳϬ͛Z< 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 110' 9.625" L-80 2434' 7"x 4-1/2" L-80 5997' 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, TUBING RECORD 84 sx AS Lite, 500 sx Class G8.5" 7617' MD 4-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 9/19/2024 201-102/ 324-395 50-103-20378-00-00 KRU 2P-429 ADL0373112, ADL0389058 934' FNL, 1953' FWL, Sec. 17, T8N, R7E, UM 1760' FNL, 2255' FEL, Sec. 20, T8N, R7E, UM ALK 4998 12/8/2001 8974' MD/ 6002' TVD 4779' MD/ 3527' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443913 5868944 1077' FNL, 2319' FEL, Sec. 20, T8N, R7E, UM 9. Ref Elevations: KB: 34' WT. PER FT.GRADE 12/17/2001 CEMENTING RECORD 5863513 1505' MD/ 1446' TVD SETTING DEPTH TVD 5862830 TOP HOLE SIZE AMOUNT PULLED 444898 444955 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 N/A PACKER SET (MD/TVD) 42" 12.25" 60 bbl AS I 29'561 sx AS III Lite, 128 bbls LiteCrete 28' 2965'29' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26#/12.6# 4779' (SW TOC) -6504' MD 51 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 8176-8240' Md and 5549-5586' TVD (cemented) 8300-8325' MD and 5621-5635' TVD (cemented) 8325-8350' MD and 5635-5650' TVD (cemented) 8386-8435' MD and 5670-5698' TVD (cemented) 8495-8505' MD and 5733-5738' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 8966' SIZE DEPTH SET (MD) 26' 62.5# 40# 110' 26' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:05 pm, Oct 02, 2024 Suspended 9/19/2024 JSB RBDMS JSB 100924 xGDSR-10/14/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1505' 1446' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended N/A- Suspended Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=USReason: I am the author of this document Location: Date: 2024.10.02 13:42:03-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,779.0 2P-429 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-429 9/19/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED KNOWN OBSTRUCTION @ 7849' SLM 9/11/2017 pproven NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 7,617.0 Set Depth … 5,219.2 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.2 23.2 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 517.5 517.3 4.40 NIPPLE 5.250 CAMCO DB LANDING NIPPLE CAMCO DB 3.875 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,994.0 1,833.8 43.10 TUBING PUNCH TUBING PUNCH (1994' - 1997' RKB) 9/8/2024 3.960 3,110.0 2,523.5 51.77 CUT JET CUT AT 3110' RKB 9/19/2024 3.960 6,500.0 4,554.0 53.54 TUBING PUNCH SHOT 4.5 FT OF HOLES. 6 SPF. 8/4/2024 3.960 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,500.2 5,149.3 53.52 1 GAS LIFT DMY BTM 1 0.0 2/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug PUMP 15.8 PPG CEMENT LAY 3 BBLS ON TOP OF RETAINER. 6/20/2024 4,779.0 6,504.5 3,527.0 4,556.7 Cement Plug PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4779' SLM) 9/7/2024 2P-429, 10/2/2024 9:20:55 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 25.5-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 TUBING PUNCH; 6,500.0 Cement Plug; 4,779.0 ftKB CUT; 3,110.0 SURFACE; 28.6-2,965.0 TUBING PUNCH; 1,994.0 NIPPLE; 517.5 CONDUCTOR; 28.0-110.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev… 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 8/4/2024 ACQUIRE DATA MITIA PASSED TO 1500 PSI. RAN TUBING PUNCH. PUNCH INTERVAL: 6500' - 6504.5' 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), 9/6/2024 SUPPORT OTHER OPERATIONS PUMP INTERMEDIATE CEMENT PLUG. INTERMEDIATE CEMENT BALANCE PLUG. LOAD TBG & IA WITH 30 BBL OF SURFACTANT WASH. 250 BBL OF 10.8 PPG KWF. 9.8 BBL OF FW SPACER. THEN PUMPED 51 BBLS OF 15.8 PPG CLASS G CEMENT & DISPLACED CEMENT w/ 8 BBLS OF FRESH WATER FOLLOWED BY 68 BBLS OF 10.8 PPG KWF. PLACING TOC IN TBG & IA @ ~5000' MD. 9/8/2024 SUPPORT OTHER OPERATIONS LOG CORRELATED TO TUBING TALLY DATED 12/20/2001 SHOOT 2 TUBING PUNCHES TO ESTABLISH T X IA COMMUNICATION FOR FREEZE PROTECT (NO COMM AFTER FIRST PUNCH) PUNCHER #1 DEPTH=1997'-2000' PUNCHER #2 DEPTH=1994'-1997' LRS CONFIRMED COMMS AFTER SECOND PUNCHER ** (LRS TO RETURN 9/9 TO PUMP 67 BBL FP & U-TUBE) ** 9/9/2024 SUPPORT OTHER OPERATIONS FREEZE PROTECTED TBG AND IA PUMPED 67 BBLS DSL INTO TBG, TAKING RETURNS UP IA TO OPENTOP U-TUBED TAG HUNG JOB COMPLETE 9/15/2024 SUPPORT OTHER OPERATIONS **STATE WITNESSED (SEAN SULLIVAN)** TAGGED TOP OF CEMENT @ 4779' SLM, OBTAINED PASSING CMIT TO 1500 PSI, READY FOR TUBING CUT 9/19/2024 SUPPORT OTHER OPERATIONS CUT 4.5" TUBING AT 3110' RKB WITH 3.5" JET CUTTER. JOB COMPLETE, READY FOR RIG 2P-429 Intermediate Suspend Summary of Operations ORIGINAL TRANSMITTAL DATE: 9/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5070 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 5070 2P-429 50103203780000 Tubing Cut Record 19-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 201-102 T39582 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.24 10:01:32 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:8,974 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 2965 Feet Csg Cut@ Feet Intermediate:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Production:7" x 4-1/2"O.D. Shoe@ 8,966 Feet Csg Cut@ Feet Liner:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 7,617 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 6,500 ft 4,779 ft 9.6 ppg Wireline tag Initial 15 min 30 min 45 min Result CMIT TxIA Tubing 1800 1720 1685 IA 1950 1875 1840 OA 479 438 427 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Travel to KRU 2P pad for tag and test of the intermediate balanced plug. Tag was good at 4,779 ft MD and a good cement sample was returned in the bailer. Fluid pumped: 1bbl, fluid back: 1 bbl. Passing CMIT TxIA. September 15, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-429 ConocoPhillips Alaska Inc. PTD 2011020; Sundry 324-395 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0915_Plug_Verification_KRU_2P-429_ss                       ORIGINAL TRANSMITTAL DATE: 9/10/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5043 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 5043 2P-429 501032037800 Tubing Puncher Record 8-Sep-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 201-102 T39539 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 11:31:05 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated: Delivered to:22-Aug-24 Alaska Oil & Gas Conservation Commiss 22Aug24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 2P-429 50-103-20378-00-00 201-102 Kuparuk River WL Puncher FINAL FIELD 4-Aug-24 2P-431 50-103-20417-00-00 202-053 Kuparuk River WL Puncher FINAL FIELD 5-Aug-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Puncher FINAL FIELD 6-Aug-24 2P-422A 50-103-2040-01-00 202-067 Kuparuk River WL Puncher FINAL FIELD 7-Aug-24 2W-05 50-029-21208-00-00 184-191 Kuparuk River WL IPROF FINAL FIELD 8-Aug-24 WSW-05 50-029-20838-00-00 182-164 Kuparuk River WL Lee LDL FINAL FIELD 9-Aug-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL Patch FINAL FIELD 13-Aug-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL Patch FINAL FIELD 14-Aug-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39470 T39471 T39472 T39473 T39474 T39475 T39476 T39477 2P-429 50-103-20378-00-00 201-102 Kuparuk River WL Puncher FINAL FIELD 4-Aug-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.23 08:12:18 -08'00' 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 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 110' 9.625" L-80 2434' 7"x 4-1/2" L-80 5997' 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 8966' SIZE DEPTH SET (MD) 26' 62.5# 40# 110' 26' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 7555' (SW TOC) -8966' MD 15.4 bbls 15.8 ppg Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 8176-8240' Md and 5549-5586' TVD (cemented) 8300-8325' MD and 5621-5635' TVD (cemented) 8325-8350' MD and 5635-5650' TVD (cemented) 8386-8435' MD and 5670-5698' TVD (cemented) 8495-8505' MD and 5733-5738' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 42" 12.25" 60 bbl AS I 29'561 sx AS III Lite, 128 bbls LiteCrete 28' 2965'29' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26#/12.6# WT. PER FT.GRADE 12/17/2001 CEMENTING RECORD 5863513 1505' MD/ 1446' TVD SETTING DEPTH TVD 5862830 TOP HOLE SIZE AMOUNT PULLED 444898 444955 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 50-103-20378-00-00 KRU 2P-429 ADL0373112, ADL0389058 934' FNL, 1953' FWL, Sec. 17, T8N, R7E, UM 1760' FNL, 2255' FEL, Sec. 20, T8N, R7E, UM ALK 4998 12/8/2001 8974' MD/ 6002' TVD 7575' MD/ 5194' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443913 5868944 1077' FNL, 2319' FEL, Sec. 20, T8N, R7E, UM 9. Ref Elevations: KB: 34' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/5/2024 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 84 sx AS Lite, 500 sx Class G8.5" 7617' MD 4-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 14. Permit to Drill Number / Sundry: 201-102/ 323-610 By Grace Christianson at 4:10 pm, Jul 10, 2024 Suspended 7/5/2024 JSB RBDMS JSB 071824 xGDSR-8/27/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1505' 1446' 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: 2024.07.10 14:57:10-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Known Restriction) 7,844.0 2P-429 7/28/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: set cement retainer and plug 2P-429 6/20/2024 kleinpd Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED KNOWN OBSTRUCTION @ 7849' SLM 9/11/2017 pproven NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 7,617.0 Set Depth … 5,219.2 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.2 23.2 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 517.5 517.3 4.40 NIPPLE 5.250 CAMCO DB LANDING NIPPLE CAMCO DB 3.875 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,500.2 5,149.3 53.52 1 GAS LIFT DMY BTM 1 0.0 2/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug 6/20/2024 2P-429, 7/10/2024 2:26:35 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 25.5-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 SURFACE; 28.6-2,965.0 NIPPLE; 517.5 CONDUCTOR; 28.0-110.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev… 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 6/19/2024 SUPPORT OTHER OPERATIONS TRAVEL FROM 3H PAD. RU CTU #11, RIH AND SET CEMENT RETAINER AT 7,725' CTMD. PT BACKSIDE OF RETAINER TO 1,500 PSI - GOOD. JOB IN PROGRESS. 6/20/2024 SUPPORT OTHER OPERATIONS PUMP 12.4 BBLS 15.8 CEMENT BELOW CEMENT RETAINER AND 3 BBLS ABOVE, CLEAN OUT TO 7,575' RKB- TOC. POOH WASHING JEWELRY. FP WITH 30 BBLS OF DIESEL FROM 2,000' CTMD TO SURFACE. TRAP 1,400 PSI ON TUBING. JOB READY FOR SLICK LINE. 7/5/2024 SUPPORT OTHER OPERATIONS TAG TOC @ 7555' SLM. PERFORM PASSING MIT-T TO 1500 PSI. STATE WITNESSED BY BRIAN BIXBY. READY FOR NEXT CEMENTING PROCEDURE. 2P-429 Suspend Summary of Operations 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): 8974'8900' 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 Senior Well Interventions Engineer KRU 2P-429 6002' 7555' 5182' 7555' 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): 7614' MD and 5217' 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 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst 7617' MD MD 110' 2434' 110' 2965' 5997'8966' 16" 9-5/8" 82' 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' (cemented) 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' (cemented) 7" x 4-1/2" Perforation Depth TVD (ft): 7/22/2024 4-1/2" Packer: Baker G-22 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 By Grace Christianson at 4:16 pm, Jul 10, 2024 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com , C=US Reason: I am the author of this document Location: Date: 2024.07.10 15:46:17-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-395 SFD 7/11/2024 DSR-7/10/24 Suspend 10-407 VTL 7/17/2024 X X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.17 14:24:23 -08'00'07/17/24 RBDMS JSB 072324 2P-429 Intermediate plug Date Wrien: 7-10-24 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-429 was an injector shut-in in mid 2020. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad on rig as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well was suspended in summer 2024. The objective of this procedure is to pump an intermediate cement plug before the full abandonment in Q4 2024. Well Data Reservoir pressure 07/28/23 = 3052 psi at 5400’ TVD MASP = 2512 psi Coil pumped reservoir abandonment, passing MIT-T to 1500 psi Tagged TOC in tubing 7555’ SLM Procedure Coil 1. RIH and punch tubing ~6500’ KB 2. Pump the following schedule: 1. ±50 bbls surfactant wash 2. ±250 bbls 10.8 ppg brine (KWF) 3. ±51 bbls 15.8 ppg class G cement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 5000’ KB 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi Eline/Relay 1. Cut tubing at ±3110’ KB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 4-1/2" tubing 0 6500 4.5" 12.6# 3.96" 0.0152 6500 99.0 65.6 from punch depth 4-1/2" x 7" Annulus 0 6500 4.5" 12.6# x 7" 26# 6.28" x 4.5" 0.0186 6500 121.2 53.6 from punch depth Tubing Cement 5000 6500 4.5" 12.6# 3.96" 0.0152 1500 22.9 65.6 Annular Cement 5000 6500 4.5" 12.6# x 7" 26# 6.28" x 2.875" 0.0186 1500 28.0 53.6 C80 @ 2950' KBC80 @ 2950' KB 2P-429 Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB 1 2 3 5 4 Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4'’ KB T-3 Peforations: @ 8,176' – 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB Production Tubing: 4 ½”, 12.6# L-80 IBTM Set @ 7,617' KB Item Depth - tops (KB) 1 FMC Tubing Hanger 23.2' 2 Camco DB Landing Nipple 517.5' 3 Baker CMU Sliding Sleeve w/ Otis 'X' Profile 7,550' 4 Camco DB-6 Nipple 7,570.6' 5 Baker G-22 Locator & Seal Assembly 7,614.1' Plug #1 – reservoir TOC ± 7555' Retainer 7725' KB Plug #2 – Intermediate TOC ±5000' RKB BOC @ ±6500' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Known Restriction) 7,844.0 2P-429 7/28/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: set cement retainer and plug 2P-429 6/20/2024 kleinpd Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED KNOWN OBSTRUCTION @ 7849' SLM 9/11/2017 pproven NOTE: TAGGED KNOWN OBSTRUCTION @ 7857' RKB 8/3/2017 pproven NOTE: 17" x 1-11/16" ELINE SPINNER LEFT IN HOLE 4/27/2015 hipshkf NOTE: OBSTRUCTION (7840') IS 1003' HIGHER THAN 1/18/2007 TAG (8859') 7/28/2009 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 WELDED SURFACE 9 5/8 8.83 28.6 2,965.0 2,434.3 40.00 L-80 BTCM PRODUCTION 7"x4.5" @7638' 7 6.28 25.5 8,966.4 5,997.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 7,617.0 Set Depth … 5,219.2 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.2 23.2 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 517.5 517.3 4.40 NIPPLE 5.250 CAMCO DB LANDING NIPPLE CAMCO DB 3.875 7,500.2 5,149.3 53.52 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.838 7,550.0 5,179.0 53.28 SLEEVE 5.582 BAKER CMU SLIDING SLEEVE w/OTIS 'X' PROFILE BAKER CMU 3.812 7,570.6 5,191.4 53.15 NIPPLE 5.450 CAMCO DB-6 NIPPLE CAMCO DB-6 3.750 7,614.1 5,217.5 52.88 SEAL 4.750 BAKER G-22 LOCATOR & SEAL ASSY BAKER 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,725.0 5,284.8 52.37 CEMENT RETAINER 4.5" cement retainer Quadco serial number 005-3593-50C 6/19/2024 0.000 8,900.0 5,960.3 56.09 FISH 17" x 1-11/16" ELINE SPINNER 4/27/2015 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,500.2 5,149.3 53.52 1 GAS LIFT DMY BTM 1 0.0 2/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,176.0 8,240.0 5,549.5 5,586.3 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,300.0 8,325.0 5,620.8 5,635.2 T-3, 2P-429 1/14/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,386.0 8,411.0 5,670.2 5,684.5 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,411.0 8,435.0 5,684.5 5,698.2 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3, 2P-429 1/13/2002 6.0 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,555.0 8,966.0 5,182.0 5,997.1 Cement Plug 6/20/2024 2P-429, 7/10/2024 2:26:35 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @7638'; 25.5-8,966.4 FISH; 8,900.0 IPERF; 8,495.0-8,505.0 IPERF; 8,411.0-8,435.0 IPERF; 8,386.0-8,411.0 IPERF; 8,325.0-8,350.0 IPERF; 8,300.0-8,325.0 IPERF; 8,176.0-8,240.0 CEMENT RETAINER; 7,725.0 Cement Plug; 7,555.0 ftKB GAS LIFT; 7,500.2 SURFACE; 28.6-2,965.0 NIPPLE; 517.5 CONDUCTOR; 28.0-110.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 33.91 RR Date 12/20/200 1 Other Elev… 2P-429 ... TD Act Btm (ftKB) 8,974.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037800 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 8,902.56 WELLNAME WELLBORE2P-429 Annotation Last WO: End DateH2S (ppm) DateComment 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: Rig Elevation: Total Depth: 8974 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2965 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" x 4 1/2" O.D. Shoe@ 8966 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 7617 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 7725 ft 7555 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1740 1720 1720 IA 605 605 605 OA 251 251 251 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Pre-test pressures Tbg = 580 / IA = 505 / OA 240 July 5th 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-429 ConocoPhillips Alaska Inc. PTD 2011020; Sundry 323-610 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0705_Plug_Verification_KRU_2P-429_bb 9 99 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.14 14:45:37 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8974'8900' 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 12/1/2023 4-1/2" Packer: Baker G-22 Locator and Seal Assy SSSV: None Perforation Depth MD (ft): L-80 2936' 8176-8240', 8300-8350', 8386- 8435', 8495-8505' 8941' 5549-5586', 5621-5649', 5670- 5698', 5732-5738' 7" x 4-1/2" Perforation Depth TVD (ft): 110' 2965' 5997'8966' 16" 9-5/8" 82' 7617' MD 110' 2434' 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 ADL0389058 201-102 P.O. Box 100360, Anchorage, AK 99510 50-103-20378-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7614' MD and 5217' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-429 6002' 7844' 5356' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.11.09 13:02:02-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 323-610 By Grace Christianson at 12:24 pm, Nov 14, 2023 VTL 11/14/2023 DSR-11/15/23SFD 11/16/2023 SFD 10-407X ADL0373112, 12/31/2024 X *&:JLC 11/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.17 13:14:34 -09'00'11/17/23 RBDMS JSB 112823 2P-429 Suspension Date Wrien: 10-30-23 Execuon Date: Dec 1, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-429 was an injector shut-in in mid 2020. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad on rig 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 07/28/23 = 3052 psi at 5400’ TVD MASP = 2512 psi Known obstruction at 7871’ KB 2.3” restriction, @ 7742’ KB 3.5” restriction Water injectivity test in 2017 – 4.8 bpm @ 900 psi Size Length ID bbls/ft volume ft/bbl 4.5" 12.6# 7617 3.96" 0.0152 116.0 65.6 4.5" 9.3# x 7" 15.5# 7638 6.28" x 4.5" 0.0186 142.4 53.6 4.5" liner 1328 3.75" 0.0137 18.1 73.2 Procedure Coil 1. RIH and set retainer at ±7725’ KB 2. Total cement pumped will be 14.5 bbls (12 below retainer and 2.5 above retainer) for a planned TOC at 7575’ KB. 3. Pump the following schedule: 1. ±10 bbls diesel to establish injectivity 2. ±10 bbls freshwater 3. ±14.5 bbls 15.8 ppg class G cement 4. After 12 bbls pumped, unsting from retainer and lay in the remaining 2.5 bbls. This should fill up tubing to ~7560’ KB 5. Begin pumping contam pill and clean out tubing down to a TOC of 7575’ KB. 6. POOH and circulate clean from 7575’ KB to surface Wireline 7. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 8. RIH and tag TOC, approx.7,575’ RKB (MUST BE AOGCC WITNESSED) 9. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 10. Perform DDT to 0 psi and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval C80 @ 2950' KBC80 @ 2950' KB 2P-429 Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 107 bbls of 15.8# Class G Cement Calculated TOC @ 5,872' KB 1 2 3 5 4 Production Casing: 7" x 4.5" @ 7,638' KB, 26# x 12.6#, L- 80 BTCM Set @ 8,966.4'’ KB T-3 Peforations: @ 8,176' – 8,505' KB (329') Surface Casing: 9-5/8", 40#, L-80 BTCM Set @ 2,965' KB Production Tubing: 4 ½”, 12.6# L-80 IBTM Set @ 7,617' KB Item Depth - tops (KB) 1 FMC Tubing Hanger 23.2' 2 Camco DB Landing Nipple 517.5' 3 Baker CMU Sliding Sleeve w/ Otis 'X' Profile 7,550' 4 Camco DB-6 Nipple 7,570.6' 5 Baker G-22 Locator & Seal Assembly 7,614.1' Plug #1 – reservoir TOC ± 7575' Retainer 7725' KB 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Wednesday, August 17, 2022 10:00 AM To:Regg, James B (OGC); Wallace, Chris D (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:CPAI 2P-Pad shut in tests 08-16-22.xlsx Attachments:MIT KRU 2P PAD SI TESTS 08-16-22.xlsx All Attached is the 10 426 form for the shut in tests performed on 2P pad on the 16 th of Aug 2022. Please let me know if you have any questions or concerns. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040170 Type Inj N Tubing 2605 2620 2610 2610 Type Test P Packer TVD 5209 BBL Pump 3.2 IA 470 3590 3500 3480 Interval V Test psi 2900 BBL Return 3.1 OA 203 360 310 290 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011820 Type Inj N Tubing 827 827 828 828 Type Test P Packer TVD 5428 BBL Pump 1.0 IA 460 3210 3145 3130 Interval V Test psi 2900 BBL Return 0.9 OA 277 363 319 309 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020180 Type Inj N Tubing 808 1001 980 953 Type Test P Packer TVD 5456 BBL Pump 2.3 IA 410 3200 3090 3075 Interval V Test psi 2900 BBL Return 2.0 OA 277 576 515 484 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011020 Type Inj N Tubing 875 876 876 876 Type Test P Packer TVD 5219 BBL Pump 2.1 IA 390 3200 3110 3100 Interval V Test psi 2900 BBL Return 1.8 OA 236 569 539 531 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020910 Type Inj N Tubing 1091 1091 1091 Type Test P Packer TVD 5177 BBL Pump 3.2 IA 450 3200 2105 Interval V Test psi 2900 BBL Return OA 278 405 345 Result F Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031530 Type Inj N Tubing 886 887 887 887 Type Test P Packer TVD 5141 BBL Pump 1.6 IA 470 3210 3110 3090 Interval V Test psi 2900 BBL Return 1.6 OA 254 356 321 312 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010820 Type Inj N Tubing 112 288 298 294 Type Test P Packer TVD 5274 BBL Pump 1.7 IA 950 3210 3110 3100 Interval V Test psi 2900 BBL Return 1,6 OA 211 428 303 253 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031540 Type Inj N Tubing 882 882 882 882 Type Test P Packer TVD 5234 BBL Pump 2.0 IA 210 3210 3110 3110 Interval V Test psi 2900 BBL Return 1.8 OA 438 444 444 443 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 2P-438 2P-447 MITIA every 2 yr to max anticipated injection pressure per AIO 21C.002 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-429 2P-432 2P-434 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-427 Notes:MITIA every 2 yr to max anticipated injection pressure per AIO 21C.001 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 ConocoPhillips Alaska Inc, Kuparuk / KRU / 2P Pad Witness Waived by Guy Cook Beck / Borge 08/16/22 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Tubing plug set at 8110' MD Notes: Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-419 2P-420 Form 10-426 (Revised 01/2017)2022-0816_MIT_KRU_2P-pad_8wells 2P-429 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Plug Perforations Fracture Stimulate Performed: Suspend Pull Tubing LJ P ❑ Perforate ❑ Other Stimulate 1:1 Alter Casing ❑ Plug for Redrtll ElPertorate New Pool ❑ Re air Well ?. Operator Co 0-1,illips Alaska, Inc. p ❑ Reenter Susp Well ❑ Jame: 4. Well Class Before Work: 5. Perr t. Address: P. O. Box 100360, Anchorage, Alaska 99510eve DStrati P ph c ent❑ Exploratory ❑ 201-10 g ❑ Service ❑✓ 6. API 1 ADL 373112, ADL 389058 List logs and submit electrc NA per 2P-429 700 AUG 14 2019 Operations shutdown ❑ Change Approved Program ❑ her: WAG Injection startup 2] Total Depth measured 8974 feet true vertical 6— p feet meas measured None feet JuPlug Junk measured None feet Effective Depth measured 8505 feet true vertical 5— 73g —feet Packermeasured 7614 feet --�_ true vertical 5218 feet Casing Length Size Structural MD TVD Burst Conductor 82' 16" Surface 2936' 9.625" 110' 110' Intermediate 2965 2434' Production 8941' 7" Liner 8966' 5997' Perforation depth Measured depth 8176-8505' feet True Vertical depth 554 feet rubing (size, grade measured and t rue vertical depth) 4.5" L-80 and SSSV (type, measured and true vertical depth) SEAL ASSY: SEAL ASSY: BAKER G-22 SSSV:NONE ...tion or cement squeeze summary: None treated (measured): None nt descriptions including volumes used and final pressure: None Prior to well operation: v2200y Subsequent to operation: 0 14. Attachments (require. per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after wor Daily Report of well Operations Q Copies of Logs and Surveys Run ❑ Exploratory ❑ Printed and Electronic Fracture Stimulation Data 16. Well Status after woi ❑ GSTOR ❑ WINJ 17. 1 he certify that the foregoing is true and correct to the best of my knowledge. �0 Name: Sayeed Abbas d Title: Staff Petroleum Engineer d Signature: IITL 9/q�,% Form 10-404 Revised 4/2017 /)it Collapse 7617' 5219' SEAL ASSY: MD= 7,614', TVD= 5218' NA or Service 121 WAG ❑ GINJ Pressure SPLUG ❑ I 318-453 Contact Name: Sayeed Abbas Contact Email: sayeed.abbas@conocophillips.com A'l sod Contact Phone: 907-265-1109 �BDMS!L6LJAUG 15 2019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 August 5th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. has completed changing the service of the Kuparuk River Unit (Meltwater) Well 2P-429 from Gas Injection to Water Alternating Gas Injection. Enclosed you will find a 10-404 report of Sundry Well Operations for ConocoPhillips Alaska, Inc. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, S1lt�o(- Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Report of Sundry Well Operations Daily report of Well Operations Well Schematic KUP INJ Co iocoPhillipsWell Attributes Alaska, Inc Flew Name MELTWATER NIPPLE WELLNAME 2P-429 WELLBORE 2P-429 WO: 3P -d9 W1YA198.e041 AM Last Tag WMyvnemaec lacmell Are.l.n DepI effl BI 1 End Odle WalYore Last Maley Las, TBg:RKB ],871.0 4162019 "Pee leerepaig ............................ cases 1: oo ..................... Last Rev Reason Anno.'onsaddensWaIIMR Last Mona, lVWOER; P] Rev Reason Pulled A- l lnjeclion Val ve 112212019 2P-029 (e,gusp Casing Strings Dan, Deaurywon oD(In, to (in) rip 110(.1 sepaPN11n(B) sNOeptn RV.)...WIILenp._erme Top rnmm CONDUCTOR 16 1506 280 110.0 110.0 WELDED Ca.'re.esorlmon ODINI est eas Deselaide Set pe Pa DVD)... Wln.en(I Ill..) I.I.Tiprnrem SURFACE 95M 8.83 28.6 2,965.0 2,434.3 40.00 LA0 BTCM Caslip.esarlpalon OR pi) ID lin) TOPI.µ BI N Dep0(nKB) set Depin DVD).. WYLen(L...I.s. Tip Tnrtao PRODUCTION]"x4.5' 7 6.28 25.5 8,966.4 5,9973 2600 L-80 BTCM p,966 @]638' Tubing Strings Tonne 0 .....amn slrina Ma... m fin rop nRB) sea Dep[n In_ saa Daptn DVDI1... VROD•'lll erne iop conn«non TUBING 412 39fi 23.2 ],61].0 52192 1260 L -BD IBTM CONDDCTOR'i0.011D0 Completion Details iop Me TOP Inc, N.send TYphtKid (nKBI r) Item Des Com ID(a) 23.2 23.2 0.00 HANGER FMC TUBING HANGER 4.500 NIPRE:s[s 517.5 517.3 4.0 NIPPLE CAMCO DB LANDING NIPPLE 3.875 7,5504 5,1790 5328 SLEEVE BAKER CMU SLIDING SLEEVE WOTS'W PROFILE 3812 7,5705 5,1914 5315 NIPPLE CAMCO DBS NIPPLE 3750 7,6141 5,2175 5288 SEAL BAKER 1-22 LOCATOR BSEAL ASSY 3875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.( TopINDI Top Incl iop ,IKe) nKal 1°) Des Com Run Odie IO dn) 69000 5960.3 56.09 il. 17"x1-11116"ELINESPINNER 41Z7I2015 0.000 Perforations 8 Slots sI1RFACE ffi.1 $not ons TA,nvDI elm(ND) (orad", Top Dd(B) etm(tMB) skis legigh 4nktl Zone oh ) Type om 8.1760 8.2400 5,549.5 5,5863 T -3,2P429 111412002 6.0 IPERF .5"HS ,2 O6Powerjet HMX Chga, W deg phase Drs LIFT. 7.6mz 8,3000 8.325.0 5,620.8 5,6352 T -3,2P429 111412002 60 IPERF T5 C, 250 ower jet HMX Chgs, DO deg phase 8,325.0 8,350.0 5,6352 5,649.5 7-3,2P429 I/7Yjff2 60 IPERF 2.5" DEC, 2506 Power jet HMX Chgs, 60 deg phase 8,3860 8,411.0 5,670.2 5684.5 T -3,2P429 11132002 6.0 IPERF 75" HSC, 2506 Power lel HMX Chgs, 60 deg phase SLEEYAL7sso0 8,411.0 6,435.0 5,884.5 5,6982 T-3. 2P-429 1/132002 6.0 IPERF 50 Power lel HMX Chips, 60 deg phase 8,495.0 8,505.0 5,]32.5 SJ38.1 T -3,2P-429 11132002 60IPERF "H Poedi NIPPLE; Teses HMX Chgs. ED deg pflase Mandrel Inserts a, Top IflK. NIpsl) Top DVD) 11iK B) Mdke MWaI Jordon] Sery - Type LM[M1 Type Porl Ska Ind TRO RYn Run oh Gam ) ],500.2 5,1493 CAMCO KBG-2 1 GAS LIFT DMV BTM 0.000 00 2/812015 SEAL:7,e141 Notes: General & Safety end.am AenoWlon 72812009 VOTE. OBSTRUCTION (784V)IS 1003' HIGHER THAN 1/182007 TAG (6859) 1122/2010 NOTE: VIEW SCHEMATIC sheaths Scherratic9.0 412712015 NOTE'. 17'x1-11116- ELINE SPINNER LEFT IN HOLE W312017 NOTE'. TAGGED KNOWN OBSTRUCTION @ 7857' RKB W112017 NOTE'. TAGGED KNOWN OBSTRUCTION @784'SLM IPEAF;e17609a400� IPERF8.300.09AE0� IPERFI8.315.09.311 IPERF, 8380 .4110- IPERF, a4la.09..a- IPERF: a. des, 50a.- FISX:B .FOO W10D11CTK)N TICS ®real .r.I.4 2P-429 DAILY REPORT WELL OPERATIONS 7/31/2019: 2P-429 started water injection as part of the process to change the well from Gas Injection (GINJ) designation to Water -Alternating -Gas (WAG) designation 10 OF Tit,• THE STATEsKA • _��\ /<, ,, ®® Alaska Oil and Gas E,• 41 Of 1Z Conservation Commission ,,...: -- r 333 West Seventh Avenue \_rh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O �� Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Vanessa Angel Senior Petroleum Engineer ConocoPhillips Alaska, Inc. SG1�N�E® AUG 2 2-017, PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2P-429 Permit to Drill Number: 201-102 Sundry Number: 317-358 Dear Ms. Angel: 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, sti ' athy . Foerster I(11 Commissioner DATED this/.day of August, 2017. RBDMS Vi AUG2 3 2017 0 • RECEIVED STATE OF ALASKA AUG Q 1/54 f ` ALASKA OIL AND GAS CONSERVATION COMMISSION p7-5 it6 i7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 • 1.Type of Request Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdowns Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: Water Inj Test 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 1 201-102' 3.Address: Stratigraphic 0 Service z 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 40 50-103-20378-00' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2P-429' Will planned perforations require a spacing exception? Yes El No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 389058 1 3?! ll2. MI Kuparuk River Field/Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,974' • 6,002' . 8505 • 5738. 958 NONE 8900 Casing Length Size MD TVD Burst Collapse Conductor 82' 16" 110' 110' Surface 2,936' 9 5/8 2,965' 2,434' Production 8,941' 7" 8,966' 5,997' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8176-8505• 5549-5738 4.500" L-80 7,617' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER- NONE N/A SSSV: - A-1 INJECTION VALVE on 3.875"DB Lock w.80 BEAN • 517.5 MD and 517.3 ND 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: ill Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development , Service III 14.Estimated Date for 8/15/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0, Op Shutdown ❑ Abandoned ❑ 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: Vanessa Angel Contact Name: Vanessa Angel Authorized Title: Senior Petroleum Engineer Contact Email: Vanessa.M.Angel@conocophillips.com n 3' ' 26 Contact Phone: (907)265-1018 Authorized Signature: VC0141/004... C�� Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1Z- 36Y I Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 • Other: Post Initial Injection MIT Req'd? Yes 0 No V Spacing Exception Required? Yes ❑ No ,❑i' Subsequent Form Required: /U 4 0 4 RBDMS L1 v AUG 2 3 2017 / / APPROVED BY Approved by: � COMMISSIONER THE COMMISSION Date: g,. ( - (7 *a d a v`-ri-g/i 'J'9 cl)w $19120,7 -f,17,-//, Submit Form and Form 10-403 R 4/2017 O RpI°8 +�tiAs�ali.d for 12 months from the date of approval. Attachments in Duplicate • 2P-429 • Water Injection Test DATE: 07/25/17 Objective/Background Meltwater(2P) area has been on gas injection only since 2009. A water injection test into 2P-429 will enable data to be gathered on the water injection capability at the low maximum surface injection pressure of 958 psi. Meltwater online producers will also be monitored for changes in performance which may occur during the injection test period. The results of the test will be used to analyze whether long term water injection at—950 psi maximum surface pressure is economically feasible at Meltwater. / Downhole pressure will be gathered utilizing memory gauges from two wells with bottom hole locations near 2P-429, before, during, and after the injection testing. Memory gauges will be run approximately two weeks before the start of the injection test into injectors 2P-429 and 2P-434 (LTSI injector) and low rate producer 2P-422A. Producer 2P-422 (-50 BOPD) will be SI and a downhole memory gauge will be run into the well at least two weeks prior to the start of the injection test. Injectors 2P-427 and 2P-432 will also be shut in just prior to the beginning of the injection test and remain shut in for the duration of the test. The intended start date for beginning injection into 2P-429 is 08/15/17 and a 2-week duration is planned. CPF2 produced water as the injection fluid during the test; the produced will trucked to 2P and a pump truck will be used to inject the water. A drawing showing the approximate location of all equipment is attached to this procedure. Items to Note: - The absolute surface pressure limit of 958 psi is based on a maximum reservoir sandface injection pressure of 3400 PSI at the top of the perfed sand in the 2P-429 well. Below that depth, the higher hydrostatic gradient will increase above 3400 psi. This is the current interpretation of the AIO injection pressure limit. - 2P-429 MITIA to 3300 psi passed 8/20/2016. Expected Well Test Duration: • 2 weeks Anticipated Initial Injection Rate and pressure: • 4000 BWPD • 930 psi maximum wellhead injection pressure Annulus Monitoring: • DSO to Monitor Annulus Pressures: • 2400 psi on the IA • 1000 psi on the OA. Be aware of the potential for increase in pressure due to thermal expansion. • Well Integrity Status is NORMAL,no ANNCOMM issues. 1/5 8/1/2017 • 2P-429 S Water Injection Test Safety: • Ensure that the on-tour pump operator can be reached by field radio at all times. • Follow all contractor company SOPs and the ASH handbook. • Keep non-intrinsically safe devices such as cell phones out of classified areas such as the wellhouse and modules on the 2P pad. • Ensure all equipment and tanks are electrically grounded. • Report any Accidents, Spills, or Near-Misses to supervisor immediately. • H2S should not be present but every worker must wear a I12S monitor within 9" of the mouth at all times when on the job site. • The pump operator will neither operate nor defeat wellhead safety systems except to shut in the well in an emergency situation via wellhead safety system(s). • A pre job safety walk through will be conducted after connection to the Kuparuk piping or live process prior to pumping operation being initiated. This pre job walkdown should include the DS Lead, DSO, CPA Safety Specialist, CPA Production Engineer, CPA DS Facility Engineer and the pump operator. • Any significant change in from this procedure during the execution of the job, including use of different metering or a different pump, during the job set up will be reviewed and approved by the 2P DSO (radio call number 233) and the Production Engineer. Injection Procedure: 1) Prior to starting injection CPF2 Instrument Techs will install a Panemetrics flow meter and pressure gauge (with wireless transmitters) on the piping downstream of the pump discharge: 2) Prior to starting injection,the Production Engineer will verify that correct changes in IP21 to convert the well from GI to WI service for 2P-429 in IP21 have been completed and that the wireless transmitters for the Panemetrics flow meter and pressure gauge have been added to IP21. 3) Tanker trucks will take on water at the CPF2 PWI truck loading facility(or possibly a temporary truck loading station set up at 2N) and haul the water to a 4-tank battery on site in front of 2P-429. 4) Initiate water injection into 2P-429 ramping up to 4000 bwpd at a well head injection pressure of no more than 930 psi. DSO to verify the Panemetrics flow meter and pressure gauge and wireless transmitters are functioning properly. 5) Immediately notify the CPF2 PE should any significant changes to injection pressure and/or rate occur to the well during the injection test. 6) Objective is two weeks of continuous injection into 2P-429. Short term interruptions in injection into the well due to problems with truck delivery of water or pump maintenance, for example, will not cause the test to be ended prior to the planned two-week duration nor is it likely to be extended. 7) DSO and Production Engineer to obtain frequent well tests on producers most likely to interact directly with 2P-429. 8) DSO to monitor IA and OA pressures on all Meltwater wells while paying close attention to those most likely to interact with 2P-429. 2/5 8/1/2017 • 0 2P-429 S • Water Injection Test , — ------------- ---- 1 .... ,„......,...,,,,.,NAO..Ott.,W.••••,• Ift WO VCOAO VA.V... ; z ova.kezdzol.N.K or me -0-sweat,A WAWA AVM • . t I I .•Ill ,•. 1.0. ..... '.' ' *V-% ." '..gd*:',1.0:. 1 , .,,„„:„..,.......VA.40 W.AC MP' I : ,sw.:xrc;rert,,.7.,..m...rg.,..•••••••:".LWOW I A • I i ..1.a.,.•...v....1...m.*Wt,AA WO ........ I . SAO J.YR VAX.Ot.3 AROV.A.....AVOW, F , AA AWS.924 vt—lenaL.......0.3.a,. ; ,:.e.-....,,,.,,,..,--4switg..-.1.44•4%..f.f. I I I ,,, • .1.,,AW"`'''''.ot 8 tt.'"'•,•.; ''''' I 'Ae!".'''' ' ot..ffiv..,/ ow ...........J . . • . I i I I : „....,:.... .t... . '•P' .: ,I I 2: .e41 r'..” '' A 1 •.. ..,„,.....,..,, ,.....X.r;.i." ,,,,,•:;4,„,„443, . .• 1 • i ,,,,,,,,,„,,,,, ..4,y,,,, i . , I .«-i,'/- ' '''' 40 I-. ' I - I r-,"6-1 .... .1 • '...' AWt. itcgAl- i,i'Ot 1 WO i rg/ Li t . r',.....7.-...., I I I I I , I I 'AA, II t it.ftC44E.‘" : I I I I t I I VAV. I ..A WOO M.N.','.. .t,.,,,,, iff..U.Q9 .8 pf-xnr.. - WitAA WS. ifiSitIMN NITMI‘i 001411-1 WAVA.O.SA t. 144.IA WV.AA VW.2 ...,WOV AO. AV WA WOOS MI..— "Irto llhps MY WV4.,.Qs .... ..„,„ _ PIO"•,,,...K.1...num. MAIIII,Ir& MOWN MIAIS 'f7scr rif'a r"14,. -,41,t Milli, M • 3/5 8/1/2017 • 2P-429 • Water Injection Test . CAUTION i THIS DRILL SITE IS TO BE CONSIDERED AN H 2S AREA. .t Dir -4ENV! .. T/r i �l14I1 l k / % �i.1 Ia �f/ pecondariCantiment 11B ?.Relief 6ERmal , ,v4 T a o ! X U1 1 6 �o nary 1 w t e v w ve VII ! Jf o en m ; a “il'4 N a yygo r y:: . — ,. v. :SES. I i ,°Clw ;1 S u _ fr, 1 0: oras FEATURE LOCATIONS .. ..... ••• •••••• •••••••.. •• ..•..•....• • LEGEND ., WESTING PROMOS y EXISTING INIECTOR 0 NEW PROOLIOER LEGEND NOTE: ,, NEW INJECTOR t%,'';1-CLEAN SNOW SUP AREA,ALL EautPNENT. tt RESCUE EOAJPNENT NO SNOW IS TO BE PLACED IN • 0PRODUCER TO INJECTOR EfIt7AONYENTAL ANEA-NS SNOW DUMPING„ * Wail LOCATIONS �`''•, LLL DESIGNATED sats AREA PRIMARY) ANY RESERVE PIT OR LINED PIT. E56�WCa07GMi Fr*fT-POWERLCNE-WAT(yq CLEARANCE!t, 5 E% RRY 07td�lXTQt BLOWERS MAY NIT LINES WITH?DISCHARGE. ��,„*,,,1 DESIGNATED SAFE AREA(SECONDARY) MOO-SNOW BLS IN u AREA(NQY. 1`•-& E'VACUAfl POUTS DEPENDING ON WINO lam°"ai' A Keep 5' cleorance frosty all floe/lines due SOOQOE-NO SNOW DUMPING AReA. r. . c. 1 RR[WCOE/ESC RST[ to high voltage electrical bines. If you ce SDN`” need to get closer, contact RW-7948. LoUNSBURY FIRE row INC . MeV Ax Conoczhfflips AREA:2P MODULE:XXXX UNIT:D2 APP14004.: Alois, w` 052P FACILITY EXPANSION 3 2/05/10 Md Therrnosiphssns, Per K100021ACS *1RBJFC _ FEATURE LOCATION 2 9/16/08 Change Legend&Hatch, Per K080095ACS ,FC MRT 4+1E 02/20/02 LK621631 I 6/05/05 Rev. Per K.05073ACS MRT ORACII,*41 PART: REI. ig I DUE Rrnsies so ate At II CE A—D2PX—3006 001 3 4/5 8/1/2017 KUP I 2P-429 Con©coPhillips a Well Attribut Max Angle TD + Alaska,1i)t:,. Wellbore API/UWI Field Name Wellbore Status eel(°) MD(ftKB) Act Btm(EKE) Corwcv'ahigips 501032037800 MELTWATER INJ 56.09 8,902.56 8,974.0 ° ... Continent H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 2P-429,8/1/20172.39:34 PM SSSV:NIPPLE Last WO: 33.91 12/20/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Castle 1;o.o Last Tag:SLM 7,849.0 2/9/2015 Rev Reason:GLV C/0,Pull plug/catcher,Tag, hipshkf 5/7/2015 Set INJ VLV,Fish Casing Strings HANGER;23.2 'CU. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(EKE) Set Depth(WD)... Wt/Len(I...Grade Top Thread II: -" ig CONDUCTOR 16 15.062 28.0 110.0 110.0 WELDED IIL M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 28.6 2,965.0 2,434.3 40.00 L-80 BTCM Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(WD)...Wt/Len II...Grade Top Thread PRODUCTION 7"x4.5" 7 6.276 25.5 8,966.4 5,997.3 26.00 L-80 BTCM '1 • @7638' 11 Tubing Strings r Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/21 3.9581 23.21 7,617.01 5,219.21 12.601 L-80 I IBTM Completion Details Nominal ID CONDUCTOR;28.0-110.0 , Top(ftKB) Top Iwo)(ftKB) Top Inc)(°) Item Dec Com (In) 23.2 23.2 0.00 HANGER FMC TUBING HANGER 4.500 '11517.5 517.3 4.40 NIPPLE CAMCO DB LANDING NIPPLE 3.875 VALVE sn s 7,550.0 5,179.0 53.28 SLEEVE BAKER CMU SLIDING SLEEVE w/OTIS'X'PROFILE 3.812 NIPPLE;5175, "I` 7,570.6 5,191.4 53.15 NIPPLE CAMCO DB-6 NIPPLE 3.750 7,614.1 5,217.5 I 52.88 SEAL BAKER G-22 LOCATOR 8 SEAL ASSY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(WD) Top Incl Top(ftKB) (kKB) (°) Des Com Run Date ID lin) 517.5 517.3 4.40 VALVE 4.5"A-1 INJECTION VALVE ON 3.875"DB LOCK 5/4/2015 0.800 w.80 BEAN(S/N:HRS-51) 8,900.0 5,960.3 56.09 FISH 17"x 1-11/16"ELINE SPINNER 4/27/2015 0.000 IPerforations&Slots Shot SURFACE;28.8-2,965.0--, ` Dens Top(TVD) Btm(WD) (shots/ Top(ftKB) Btm(ftKB) OMB) (ftKB) Zone Date ft) Type Com • 8,176.0 8,240.0 5,549.5 5,586.3 T-3,2P-429 1/14/2002 6.0 IPERF 2.5"HSC,2506 Power ° jet HMX Chgs,60 deg phase GAS LIFT;7,500.2 8,300.0 8,325.0 5,620.8 5,635.2 T-3,2P-429 1/14/2002 6.0 IPERF 2.5"HSC,2506 Power II jet HMX Chgs,60 deg phase 8,325.0 8,350.0 5,635.2 5,649.5 T-3,2P-429 1/13/2002 6.0 (PERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase SLEEVE;7,550.0 8,386.0 8,411.0 5,670.2 5,684.5 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase _ 8,411.0 8,435.0 5,684.5 5,698.2 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power NIPPLE,7,570.6 jet HMX Chgs,60 deg 111 phase I 8,495.0 8,505.0 5,732.5 5,738.1 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase Mandrel Inserts st ati SEAL;7,614.1 on Top(TVD) Valve Latch Port Size TRO Run N Top MKS) (060) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 7,500.2 5,149.3 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 0.0 2/8/2015 ' Notes:General&Safety End Date Annotation 7/28/2009 NOTE:OBSTRUCTION(7840')IS 1003'HIGHER THAN 1/18/2007 TAG(8859') 11/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 4/27/2015 NOTE: 17"x 1-11/16"ELINE SPINNER LEFT IN HOLE IPERF;8,178.0-0,240.0 IPERF;8,300.0-0,325.0 IPERF;8,325.08,350.0 IPERF;8,386.0-8,411.0 IPERF;8,411.0-8,435.0 IPERF,8,495.0-0,505.0 1.- FISH; FISH;8,800.0 -11 PRODUCTION Tx4.5"9(7638';_� 25.5-8,986.4 • I Roby, David S (DOA) From: Angel,Vanessa M <Vanessa.M.Angel@conocophillips.com> Sent: Thursday,August 03, 2017 9:58 AM To: Roby, David S (DOA) Cc: Jolley, Liz C Subject Meltwater water injection Hello Dave, Per our conversation I just wanted to note that for the 2P-429 WI test,the sundry says we will not exceed 958psi surface pressure with water. I just wanted to clarify that to take the well from gas injection to water injection we will need to pump 1 tubing volume of water at a higher pressure. 2P-429 is currently injecting gas at 2200 psi,so we need our pump rate to start at 2200 psi to overcome that pressure and get water into the well,then we can decrease over time.Once approximately 1 tubing volume is in place,we will stay at our expected pressure of 930 psi,within the do not exceed pressure of 958 psi. Thanks, Vanessa 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 22,2016 TO: Jim Regg !7 L IZ`b(1(a SUBJECT: Mechanical Integrity Tests P.I.Supervisor / CONOCOPHILLIPS ALASKA INC 2P-429 FROM: Brian Bixby KUPARUK RIV U MELT 2P-429 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J-13(2— NON-CONFIDENTIAL — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U MELT 2P-429 API Well Number 50-103-20378-00-00 Inspector Name: Brian Bixby Permit Number: 201-102-0 Inspection Date: 8/20/2016 Insp Num: mitBDB160821044335 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min well 2P-429 1Type Inj G TVD 5218 , Tubing 2450 2450 - 2450, 2450- PTD 2011020 - Type Test SPT Test psi 2900 • IA 820 3300 • 3260 - 3250 • Interval I QVAR P/F P ✓ OA 685 700 _ 701 701 - Notes: AIO-21B SCANNED MAY 19 2017 Monday,August 22,2016 Page 1 of 1 STATE OF ALASKA AL A OIL AND GAS CONSERVATION CON ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed SuspendPerforate r r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Logging 17 2.Operator Name: 4.Well Class Before Work 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-102 3.Address: 6.API Number Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20378-00 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 0389058 _ KRU 2P-429 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): TMD3D Water Flow log Kuparuk River Field/Meltwater Oil Pool 11.Present Well Condition Summary: Total Depth measured 8974 feet Plugs(measured) none true vertical 6002 feet Junk(measured) 8900 Effective Depth measured 8869 feet Packer(measured) none true vertical 5943 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 2936 9.625 2965 2434 PRODUCTION 8941 7 8966 5997 ' L 1:1 G E V E D p1ED .i�I;, 21,1 JUN 193 %GIS Perforation depth: Measured depth: 8176-8240,8300-8350, 8386-8435, 8495-8505 Ll;iL' = True Vertical Depth: 5550-5586, 5621-5650, 5670-5698,5733-5738 Tubing(size,grade,MD,and TVD) 4.5, L-80, 7617 MD, 5219 TVD Packers&SSSV(type,MD,and ND) no packer NIPPLE-CAMCO DB LANDING NIPPLE @ 518 MD and 517 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 13800 Subsequent to operation 4300 14.Attachments(required per zo AAC 25 070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ 147 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 314-645 Contact Kasper Kowalewski no 265-1363 Email Kasper.KowalewskiCa�conocophillips.com Printed Name Kaass er Kowale s Title Sr. Drillsite Petroleum Engineer Signature Phone:265-1363 Date c'//137/5 VTC 7/`ll i .--' RBDMSA\ JUN 2 5 2015 t- j- Form 10-404 Revised 5/2015 Submit Original Only • 1,„ / 1 KUP INJ 2P-429 ConocoPhillips 1 Well Attributes Max Angle&MD TD Alaska Inc. - Wellbore API/USN Field Name Wellbore Status ncl(°) MD(ttKB) Act Btm(ttKB) cmnm�tkgp 501032037800 MELTWATER INJ 56.09 8,902.56 8,974.0 y --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2P-429,5/7/201510.07:24AM SSSV:WRDP Last WO: 33.91 12/20/2001 Vertical schemata(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By"• -End Date Last Tag:SLM 7,849.0 2/9/2015 Rev Reason GLV 0/0,Pull plug/catcher,Tag. hipshkf 5/7/2015 Set INJ VLV,Fish HANDER;23.2---{.M4..:-.a -Casing Strings ® Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(NO)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 110.0 110.0 WELDED Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 28.6 2,965.0 2,434.3 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(ND)...WVLen(i...Grade Top Thread Ll # PRODUCTION 7"x4.5" 7 6276 25.5 8,966.4 5,997.3 26.00 L-80 BTCM v�1I .� [i' @7638' 'rr'''Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 23.2 7,617.0 5219.2 12.60 L-80 IBTM ----- Completion Details CONDUCTOR;251.0-110.0-A ' Top(ttKB) Top(ND)(ttKB) Top Incl(°) Item Des Com Nominal ID (in) 23.2 23.2 0.00 HANGER FMC TUBING HANGER 4.500 517.5 517.3 4.40 NIPPLE CAMCO DB LANDING NIPPLE 3.875 VALVE;5175 NIPPLE,51.51 7,550.0 5,179.0 53.28 SLEEVE BAKER CMU SLIDING SLEEVE w/OTIS'X'PROFILE 3.812 7,570.6 5,191.4 53.15 NIPPLE CAMCO DB-6 NIPPLE 3.750 _ 7,614.1 5,217.5 52.88 SEAL BAKER G-22 LOCATOR&SEAL ASSY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) II Top(ND) Top Incl Top(ttKB) (ftKB) (°) Des Com Run Date ID(in) 517.5 517.3 4.40 VALVE 4.5"A-1 INJECTION VALVE ON 3.875"DB LOCK 5/4/2015 0.800 w.80 BEAN(S/N:HRS-51) 8.900.0 5,960.3 56.09 FISH 17"x 1-11/16"ELINE SPINNER 4/27/2015 0.000 Perforations&Slots Shot SURFACE;28.6-2,965.0 4. Dens Top(ND) Btm(ND) (shofs/F Top(ftKB) Btm(ftKB) IftKB) (ttKB) Zone Date t) Type Com . 8,176.0 8,240.0 5,549.5 5,586.3 T-3,2P-429 1/14/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg GAS LIFT;7,500.2 _ 1. phase 1. 8,300.0 8,325.0 5,620.8 5,6352 T-3,2P-429 1/14/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase 8,325.0' 8,350.0 5,6352 5,649.5 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase SLEEVE;7.550.0 I I 8,386.0 8,411.0 5,6702 5,684.5 T-3,2P429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase NIPPLE;7.5706 a:.RI 8,411.0 8,435.0 5,684.5 5,698.2 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase 8,495.0 8,505.0 5,732.5 5,738.1 T-3,2P-429 1/13/2002 6.0 (PERF 2.5"HSC,2506 Power jet HMX Chgs,60 deg phase Mandrel Inserts St SEAL;7.614.1 ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ttKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,500.2 5,149.3 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 0.0 2/8/2015 Notes:General&Safety End Date Annotation 7/28/2009 NOTE:OBSTRUCTION(7840')IS 1003'HIGHER THAN 1/18/2007 TAG(8859') 11/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schemalic9.0 4/27/2015 NOTE: 17"x 1-11/16"ELINE SPINNER LEFT IN HOLE IPERF;8,176.0-8,240.0 IPERF;8,300.0-8,325.0 IPERF;8,325.0-8,350.0 IPERF;8,386.0-8,411.0 IPERF;8,411 0.8,435.0 IPERF;8,4950-8,505.0 Hi FISH;8,900.0 PRODUCTION 7"04.5"e7638'; 25.5-8.966.4 2P-429 WELL WORK SUMMARY DATE SUMMARY 12/16/2014 WELL DISPLACEMENT/30 BBLS 160* DIESEL/360 BBLS WATER/31 BBLS DIESEL DOWN TBG. / FREEZE PROTECT NEEDS 20 MORE BBLS DSL/JOB NOT COMPLETE 12/20/2014 (DELAYED BY RIG MOVE) PULLED A-1 INJECTION VALVE @ 517' RKB; BRUSH N FLUSHED TUBING DOWN TO 7600' SLM, IN PROGRESS. 12/21/2014 SET 3.75" DBP PLUG W/SINGLE SPARTEK GAUGE @ 7570' RKB (PRONG HAS 4 1/2" BAIT SUB); MITT & DDT (PASS); SET CATCHER @ 7570' RKB & PULLED DV @ 7500' RKB (READY FOR CIRC OUT). IN PROGRESS. 12/22/2014 circ-out well, 265 bbls CI S/W, 82 bbls dsl down tbg taking returns up IA,u-tube well, combo MITTxIA to 2500 psi (PASSED),draw down to 0 psi,(PASSED), Ready for DHD Testing. 12/24/2014 (SEC) : T-POT (PASSED), T-PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED). 12/30/2014 (SEC) : BPV TEST PASSED, DDT T/IA IN-PROGRESS. 1/2/2015 (SEC) : IA-DDT (PASSED). 1/13/2015 (MISC): SHELL TEST-PASSED. 2/7/2015 DRIFT DOWN TO CATCHER @ 7570' RKB; ATTEMPT TO SET DV © 7500' RKB (DROPPED DV); ATTEMPT TO FISH W/ NO SUCCESS. IN PROGRESS. 2/8/2015 PULLED CATCHER (RECOVERED DV) @ 7570' RKB; DEPLOY CATCHER & SET DV @ 7500' RKB; PULLED CATCHER @ 7570' RKB. LEFT LRS ON LOCATION FOR MITIA (PASSED). IN PROGRESS. 2/9/2015 PULLED DBP PLUG © 7570' RKB; DRIFT W/20'x 2" BLR TO KNOWN OBSTRUCTION @ 7849' SLM. READY FOR E-LINE (TMD3D). 3/29/2015 ATTEMPT TO PERFORM TMD3D WATER FLOW LOG. 1502 QUARTER TURN VALVE WAS LEAKING. ATTEMPT TO FIX BY PACKING WITH GREASE, CYCLING VALVE AND APPLYING HEAT. POOH TO CHANGE VALVE, PHASE CONDITIONS OCCURED. RIG DOWN. JOB IN PROGRESS. 4/27/2015 LOG WITH TMD3D LOOKING FOR UPFLOW BEHIND THE PRODUCTION CASING. LOGGED AT SURFACE PRESSURES AND RATES OF 550 PSI -0.5 BPM, 750 PSI - 2.5 BPM, AND 1000 PSI -4.5 BPM. PERFORMED IMPULSE TESTS PLACING NEUTRON GENERATOR AT 7835', 7800', AND 7300' FOR EACH PRESSURE. NO UP FLOW OBSERVED. PUMPING INHIBITED SEAWATER. TAGGED OBSTRUCTION AT 7858'. LOG CORRELATED TO WELLBORE EQUIPMENT REPORT DATED 06 DEC 2001. JOB COMPLETE. UPON REACHING SURFACE, NOTICED THAT THE CTF HOUSING HOLDING THE SPINNER HAD BACKED OFF AND WAS LEFT IN THE HOLE. EXAMPLE GIVEN TO CPAI REP TO HELP FOR FISHING. 5/4/2015 ATTEMPT TO FISH LOST SPINNER UNABLE TO PASS KNOWN TIGHT SPOT @ 7721' SLM, SET 3.875" DB LOCK&A-1 INJ VLV W/ .80 BEAN (S/N: HRS-51) GOOD CLOSURE TEST. COMPLETE. 2-0k- \02. 2519 WELL LOG TRANSMITTAL DATA LOGGED 5/2.112015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 062015 RE: Leak Detect Log with TMD3D: 2P-429 AOGCC Run Date: 4/27/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2P-429 Digital Data in LAS format, Digital Log file 1 CD Rom 50-103-20378-00 Leak Detect Log with TMD3D (Field print) 1 Color Log 50-103-20378-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton "— Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 sCA► w° IN 1 5 2015 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 1)9Al2.2-0...,GX) ,.E;�ti; �PJ�► XHVZE ( ( Image Project Well History File Cover Page 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. ::¿ 0 L - L Q ~ Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~escan Needed 1111111111111111111 R~CAN v6' ?olor Items: ~reYSCale Items: DIGITAL DATA ~skettes. No. I D Other, No/Type: OVERSIZED (Scannable) D Maps: D Poor Quality Originals: D Other Items Scannable by a Large Scanner 0 Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Scanning Preparation BY: Helen ~ If D Other::.. Dat~ç¡ ~I 6L- 151m P . , 1111111111111111111 Daté1. ~/. Df 151 WI P x 30 = J áD + ~~ = TOTAL PAGES 14-~ ~~~~r!t l"lm;I~f¡~;I;: p BY: Helen ~ Project Proofing BY: Helen (Maria) Production Scanning Stage 1 Page Count from Scanned File: J 43 (Count does include cover sheet) Stage 1 Page Count Matches Number in Scanning Preparation: Helen ~ If NO in stage 1 page(s) discrepancies were found: V YES NO ¡ Date:O{ I ~ ~ fJlf /5/ YES NO VVlP BY: BY: Helen Maria Date: /5/ 1111'- Î 11-11111 Scanning is complete at this point unless rescanning is required. ReScanned 11111-111111111 BY: Helen Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • •OF 711, w-IAP\ %% s� THE STATE Alaska it and Gas A� = Of ,Conservation '1 IlsS1 == 'q. GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op, ,L Anchorage, Alaska 99501-3572 Main: 907.279.1433 SCANNED u t 'a i3' Fax: 907.276.7542 Thomas Nenahlo Drillsite Petroleum Engineer Q01-- `I a ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P-429 Sundry Number: 313-567 Dear Mr. Nenahlo: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this ' day of November, 2013. Encl. _. STATE OF ALASKA KA OIL AND GAS CONSERVATION COMMSN *ix∎ (IC] 2 5 2013 APPLICATION FOR SUNDRY APPROVALS kk# 20 AAC 25.280 ,. 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r°"` Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate Alter casing r r Other:Logging EW- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 201-102 3.Address: 6.API Number: Stratigraphic r Service p P.O.Box 100360,Anchorage,Alaska 99510 50-103-20378-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2P-429 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0389058 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): 8974 6002 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 2936 9 5/8 2965' 2434' PRODUCTION 8941 7 8966' 5997' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8176-8240,8300-8325,8325-8350,8386-5550-5586,5621-5635,5635-5650,5670- 8411,8411-8435,8495-8505 5685,5685-5698,5732-5738 4.5 L-80 7617 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL-BAKER G-22 LOCATOR &SEAL ASSY MD=7614 TVD=5218 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program Pr BOP Sketch r Exploratory r Stratigraphic r Development r Service P 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ P WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tommy Nenahlo Email: Thomas.L.Nenahlo @cop.com Printed Name Thomas jJ nahlo Title: Drillsite Petroleum Engineer Signature ----ILA,—..- f_ , . Phone:265-6934 Date:10/25/2013 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3■.3-5*cta Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBDMS NOV 15W' Other: 10 _ /,, /jet( o PP,` 'v ctco>ria ice -'r /& Atx0 .21 A .00? Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / APPROVED BY Q Approved by: Approved p 'c io is V MMI months from the COMMISSION SION al. Date: it-O -l3 Form 10-403(Revised 10/ 12) O ii O I t (jn� '9 t/ is Submit Form and Attachments in Duplicate v-L r/!/b// " - v 7 • • . v OCT 172013 Conoco Phillips 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, ,a,e1,46 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 Pool Injection Wells Technical Justification for Administrative Relief Request,AIO 21A,from Rules 7 and 8 Purpose ConocoPhillips Alaska, Inc. (CPAI)requests that the AOGCC approve this Administrative Relief as per Area Injection Order(AIO)21A(Amended),Rule 10,for temporary relief from criteria set forth in Rules 7 and 8 that defines the authorized pressure and fluids for injection,respectively. CPAI requests temporary relief from these rules to conduct video and Spectra Flow®logging on six Meltwater injectors, 2P-419(PTD# 204-017),2P-420 (PTD#201-182),2P-427(PTD#202-018),2P-429(PTD#201-102),2P- 434 (PTD#203-153),and 2P-447(PTD#203-154). By conducting video logging on these injectors,the Meltwater team is looking to inspect possible collapsed liner,as has been indicated by recent and historic well work. By conducting Spectra Flow®logging,the Meltwater team is looking to determine if there is fluid movement around the production casing cement shoe over a range of sand face injection pressures. Video Logging Campaign Summary During recent and historic well work,indications of potentially collapsed liner in injectors 2P-419,2P- 420, 2P-429,2P-434, and 2P-447 have arisen. In a number of these injectors it is believed that these potential collapsed liner locations are limiting our injection into the Bermuda formation. To aid in characterizing and understanding these potential collapsed liner locations, as well as to formulate a plan to remediate this issue, it is necessary to run video logs to inspect the locations. To safely execute a video log on a miscible injectant(MI) injector it is necessary to adequately displace the near wellbore formation to ensure that MI returns are not taken to surface. Therefore, it is recommended that the near wellbore formation be displaced with a minimum three tubing volumes of hot diesel. Upon adequately displacing the near wellbore formation,the video log will be run while injecting filtered sea water to allow for the optimum video resolution to inspect these potential collapsed liner locations. The ability to provide a sufficient injection rate at Meltwater is critical as it is necessary to ensure that adequate lift gas temperatures are maintained at the Meltwater's Drill Site,2P. Drill Site 2P is located approximately twelve miles from the nearest drill site,2N. This distance provides a significant amount of time for cooling of the MI that is used as injection fluid as well as a lift gas for the producers. During winter months and low injection rate periods,the temperature of the lift gas has historically become low enough to cause rapid paraffin deposition in the upper wellbore of the producers and can choke flow to a point at which the well would need to be shut in. If enough production is shut in the temperature of the Meltwater produced oil line could become low enough to require it to be shut in and de-inventoried to mitigate the potential for the line to freeze. In 2012, modeling was completed to determine the minimum MI gas delivery temperature at Meltwater to ensure that this issue can be mitigated. As anticipated,the variable with the greatest effect on the MI gas delivery temperature at Meltwater is the MI injection rate. By completing video logs on these potential collapsed liner locations to aid in developing a remediation strategy it is believed that this risk of low lift gas temperature and a produced oil line freezing scenario can be reduced. To successfully complete this video logging campaign,temporary relief from AIO 21A(Amended) Rules 7 and 8 is requested to adequately displace the formation and conduct these video logs. CPAI Well Integrity Director 10/17/2013 • • Spectra Flow®Logging Campaign Summary To successfully complete this Spectra Flow®logging campaign,temporary relief from AIO 21A (Amended)Rule 8 is requested to allow for the temporary injection of sea water into the Bermuda formation. Sea water is not an authorized injection fluid in AIO 21A(Amended). The Halliburton®Spectra-Flow logging technology is capable of identifying fluid movement around the production casing shoe by identifying the presence of oxygen. Sea water will provide the oxygen in the injection fluid to ensure the logging campaign can be completed successfully. To achieve the most information from the logging campaign,temporary relief from AIO 21A(Amended) Rule 7 is requested for exceeding the established pressure limit during injection of sea water into the Bermuda formation while logging. The Meltwater team would like to vary the injection pressures of the sea water while performing Spectra Flow®logging runs to complete the following objectives: 1. To confirm there is not fluid movement around the production casing shoe when injecting within the sand face injection pressure limit established by Rule 7 in AIO 21A(Amended). 2. To determine if MI migration is a result of historic sand face injection pressures at Meltwater prior to the issuance of AIO 21A(Amended). The second objective stated above is intended to further the Meltwater team's understanding of the MI migration mechanism. As discussed in the November 2012 hearing with the AOGCC,the Meltwater team proposed two potential MI migration mechanisms. One of these migration mechanisms includes the possibility of MI migration around the production casing cement shoe. By completing the aforementioned objectives,the Meltwater team will be able to make more informed decisions to ensure the field is operated safely and effectively. Video and Spectra Flow®Logging Procedure Outline The following is an outline of the procedure for the proposed Spectra Flow®Logging campaign to be performed on each of the six injectors. 1. Displace the near wellbore formation with a minimum three tubing volumes of hot diesel to mitigate the risk of taking MI returns at surface during well work operations. o Injection pressure at surface not to exceed 2,495 psig with diesel(4475 psig at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs) 2. Rig up E-Line with Spectra-Flow®Logging tools and IPROF string to monitor bottomhole conditions. 3. Little Red Services(LRS)to pump sea water down on well using a step rate approach as defined below. During each step,the Spectra-Flow®logging tool will be passed up and down to identify the possible height of injected fluid above the perforations. a. Step 1: 500 psi WHIP (2975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) b. Step 2: 750 psi WHIP(3225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) c. Step 3: 1,000 psi WHIP (3475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs)\ d. Step 4: 1,250 psi WHIP(3725 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) e. Step 5: 1,500 psi WHIP(3975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) CPAI Well Integrity Director 10/17/2013 2 • f. Step 6: 1,750 psi WHIP(4225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) g. Step 7: 2,000 psi WHIP.(4475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) 4. Upon completion of the step rate logging runs,E-Line and LRS will rig down and move off the well. 5. Injection of seawater will cease on each individual well after the logging runs are completed. 6. The well bores will then be freeze protected with the injection of hot diesel with the injection pressure at surface not to exceed 2,495 psig(4475 psig at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs) Administrative Approval Request: CPAI requests temporary relief from(AIO)21A(Amended),Rules 7 and 8 to conduct Video and Spectra Flow®logging on six Meltwater injectors: 2P-419 (PTD#204-017), 2P-420(PTD#201-182), 2P-427(PTD#202-018), 2P-429(PTD#201-102), 2P-434(PTD#203-153), 2P-447(PTD#203-154). 1. Temporary relief from AIO 21A(Amended)Rule 7 is requested for exceeding the pressure limit during injection of sea water into the Bermuda formation during the logging operations only. The approval is requested for a period of six months from the date of the AOGCC approval. 2. Temporary relief from AIO 21A(Amended)Rule 8 is requested to allow for injection of sea water into the Bermuda formation for the purposes of performing the logging operations only. The approval is requested for a period of six months from the date of the AOGCC approval. CPAI Well Integrity Director 10/17/2013 3 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 25th, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Response to Questions Regarding Requests for Administrative and Sundry Approvals for Meltwater Surveillance Initiatives Dear Mr. Wallace: Thank you for your reply regarding our requests for Administrative and Sundry Approvals for the Meltwater surveillance initiatives. Please find below the responses to your questions in your emails that were sent October 22nd, 2013. Injected Volumes and Duration Per the plan developed by the Meltwater team, it is expected that no more than 6,000 barrels of Beaufort seawater will be required to be injected at each injector to complete the video and Spectra-Flow® logging initiatives. This estimate of 6,000 total barrels includes the procedures to complete the miscible injectant displacement, video logging, and Spectra-Flow®logging procedures. Below is a high level breakdown of this estimate for clarity: • Displacement volume estimate: 1,000 BBLs of seawater per well o This is volume that we may need during the video and/or Spectra-Flow®logging campaign to mitigate the potential for having miscible injectant present in the wellbore. • Video Logging volume estimate: 1,600 BBLs of seawater per well o To minimize the turbidity of the fluid, and thus increase our video resolution at the potential collapsed liner locations, filtered seawater will be used to displace the wellbore and ensure it remains displaced throughout the video logging procedure. • Spectra-Flow®Logging volume estimate: 3,400 BBLs of seawater per well o This estimated volume of 3,400 BBLs is planned to be split evenly amongst the seven pressure stages outlined in the Technical Justification for Administrative Relief Request, AIO 21A(Amended), from Rules 7 and 8, that was submitted to the AOGCC on October 17th, 2013. o It is preferred that seawater be used for the Spectra-Flow®logging as upright tanks will be on location at Drill Site 2P to store the seawater that will support the aforementioned video logging. Operationally, it is preferred that Kuparuk produced water be kept separated from seawater due to corrosion concerns. The above logging initiatives may require up to 168 hours(7 days)to complete, per well. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Beaufort Seawater Compatibility Study A Meltwater field fluid sensitivity and stimulation study was completed in March of 2001. This study utilized core samples from the Meltwater North #1 and Meltwater North#2 wells that included an investigation into the sensitivity of preserved reservoir samples to the proposed flood waters. These proposed flood waters included a Kuparuk produced water blend and a 75% Kuparuk produced water/25% Beaufort seawater blend. The investigation into the sensitivity of the Meltwater North#1 and Meltwater North#2 core samples to the proposed flood waters concluded that there were no adverse reactions to the75% Kuparuk produced water/25% Beaufort seawater blend identified. The Meltwater team plans to inject 100% Beaufort seawater to minimize the turbidity of the fluid while conducting video logging. Although we do not have fluid sensitivity studies completed with 100% Beaufort seawater, the salinities of the Kuparuk produced water and the Beaufort seawater are similar, and no appreciable compatibility problems for either the Meltwater formation or its confining zones are expected. If injectors do incur damage from sea water injection the damage will be contained within a small radius of the wellbore due to the small volume of fluid required to complete the logging initiatives. Any damage to the near wellbore formation that may arise can be reversed by employing remedial treatments. Sundry Requests Attached you will find six Application for Sundry Approvals, one for each of the six wells that we are requesting approval to conduct video and Spectra-Flow®logging. If you require any further information, please do not hesitate, I would be more than happy to address them for you. Thanks, Tommy Nenahlo Drill Site Petroleum Engineer 2T (Kuparuk&Tabasco)&2P (Meltwater) North Slope Operations & Development ConocoPhillips Alaska Anchorage: (907)265-6934 Mobile: (720) 273-2685 Enclosures: Applications for Sundry Approval (Quantity 6) Wellbore Schematics (Quantity 6) • • 1.-,, KUP 2P-429 Conoc Phillips I/ 9 ' ' Well Attributes Max Angle&MD TD r� Alaska Inc Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) Conocod'tvlkps =4 501032037800 MELTWATER INJ 56.09 8,902.56 8,974.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:INJ VALVE Last WO: 33.91 12/20/2001 Well ConSq:-2P-429,11/13/2012 10:42:34 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod... End Date Last Tag:SLM 7,856.0 7/26/2009 Rev Reason:SET VALVE ninam 11/13/2012 Casing 2,0 - ------ ---- Casing Strings Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd HANGER,23 CONDUCTOR 16 15.062 28.0 110.0 110.0 WELDED Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd P. SURFACE 9 5/8 8.835 28.6 2,965.0 2,434.4 40.00 L-80 BTCM Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd PRODUCTION 7 6.276 25.5 8,966.4 5,997.3 26.00 L-80 BTCM 7"x4.5"@7638' Tubing De Strings g String Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd TUBINGescri lion String 0... Str3.958 23.2 7,617.0 5,219.2 12.60 L-80 IBTM Completion Details ...____,„ Top Depth (ND) Top Inc! Noml... Top(ftKB) (ftKB) (1 item Description Comment ID(in) CONDUCTOR, 23.2 23.2 -0.33 HANGER FMC TUBING HANGER 4.500 28-110 517.5 517.3 4.40 NIPPLE CAMCO DB LANDING NIPPLE 3.875 7,550.0 5,179.1 53.12 SLEEVE BAKER CMU SLIDING SLEEVE w/OTIS'X'PROFILE 3.812 VALVE,518 7,570.6 5,191.4 53.03 NIPPLE CAMCO DB-6 NIPPLE 3.750 NIPPLE,518 ''.! 7,614.1 5,217.5 52.85 SEAL BAKER G-22 LOCATOR &SEAL ASSY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Inc! Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 518 517.3 4.40 VALVE 4.5"A-1 INJECTION VALVE ON 3.875"DB-6 LOCK 11/12/2012 0.806 , (OAL=40") Perforations&Slots . Shot Top(TVD) Btm(TVD) Dens t Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment■ 8,176 8,240 5,549.5 5,586.2 T-3,2P-429 1/14/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs, SURFACE,5 60 deg phase 8,300 8,325 5,620.7 5,635.1 T-3,2P-429 1/14/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs, el 60 deg phase IF 8,325 8,350 5,635.1 5,649.5 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs, 60 deg phase GAS LIFT, 7,500 8,386 8,411 5,670.2 5,684.5 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs, 60 deg phase 8,411 8,435 5,684.5 5,698.2 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs, 60 deg phase al 8,495 8,505 5,732.5 5,738.1 T-3,2P-429 1/13/2002 6.0 IPERF 2.5"HSC,2506 Power jet HMX Chgs, 60 deg phase SLEEVE,7,550 II Notes:General&Safety End Date Annotation 7/28/2009 NOTE:OBSTRUCTION(7840')IS 1003'HIGHER THAN 1/18/2007 TAG(8859') NIPPLE,7,571 11/22/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 a SEAL,7,614 S, 1 IPERF, 8,176-8,240 IPERF, 8,300-8,325 IPERF, 8,325-8,350 Mandrel Details IPERF, Top Depth Top Port 8,386.8,411 (TVD) Inc! OD Valve Latch Size TRO Run IPERF, Stn Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (pal) Run Date Corn... 8,411-8,435 1 7,500.2 5,149.4 53.52 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 0.0 1/6/2002 IPERF, 8,495-8,505 _ - I I PRODUCTION 7'x4.5"538', 26-768,966 TD,8,974 Hunt, Jennifer L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 26, 2013 12:39 PM To: NSK Fieldwide Operations Supt Cc: Hunt, Jennifer L (DOA) Subject: RE: Meltwater SSSV Testing I missed that one... thanks.Transposed with 2P-419 PTD too. Here is updated corrected wells and PTD's. So a total of six wells. Well PTD 2P-447 203-154 2P-419 204-017 2P-434 203-153 2P-427 202-018 2P-420 201=182 2P-429 201-102) Guy Schwartz SCANNED FEB 2 0 2014 Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSupt @conocophillips.com] Sent: Wednesday, June 26, 2013 12:30 PM To: Schwartz, Guy L (DOA) Subject: RE: Meltwater SSSV Testing Guy, We also have well 2P-447 as a WAG injector. I don't have the PTD number handy, but I do have the API number— 501032046800. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent N2072ConocoPhillips.com 907-659-7042 Pager 659-7000 x604 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, June 26, 2013 10:59 AM To: NSK Fieldwide Operations Supt Cc: Regg, James B (DOA); Ferguson, Victoria L(DOA); Hunt, Jennifer L(DOA) Subject: [EXTERNAL]RE: Meltwater SSSV Testing Larry, 1 • After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ (gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if water is again available for injection on Meltwater the status can be reverted back to WAGIN. The wells in our database that need to have status changed from WAGIN to GINJ are: Well PTD 2P-419 203-154 2P-434 203-153 2P-427 202-018 2P-420 201-182 2P-429 201-102 We will change status in our database today... Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSuot @conocophillips.com] Sent: Tuesday, June 25, 2013 4:35 PM To: Schwartz, Guy L(DOA) Subject: Meltwater SSSV Testing Guy, We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period. We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or report SSSV testing for DS-2P during the July pad SVS testing. I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent N2072ConocoPhillips.com 907-659-7042 Pager 659-7000 x604 2 Hunt, Jennifer L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, June 26, 2013 11:26 AM To: Hunt, Jennifer L (DOA) Subject: meltwater wells status change WAGIN to GINJ Put this in comments for 5 Meltwater wells: Well status change to GINJ: No injection water available on Meltwater pad for foreseeable future. Well needs to have SSSV tested every 6 months. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,June 26, 2013 10:59 AM To: 'NSK Fieldwide Operations Supt' Cc: 'Regg,James B (DOA) (jim.regg @alaska.gov)'; Ferguson,Victoria L(DOR); Hunt,Jennifer L(DOA) Subject: RE: Meltwater SSSV Testing Larry, After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ (gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if water is again available for injection on Meltwater the status can be reverted back to WAGIN. The wells in our database that need to have status changed from WAGIN to GINJ are: Well PTD 2P-419 203-154 2P-434 203-153 2P-427 202-018 2P-420 201-182 2P-429 201-100 We will change status in our database today... SCANNED FEB 2 0 2014 Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailtp_NSKFieldwideOperarion SSupt 9 conoconlliilips.cOm] Sent: Tuesday,June 25, 2013 4:35 PM To: Schwartz, Guy L(DOA) Subject: Meltwater SSSV Testing Guy, We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period. We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or report SSSV testing for DS-2P during the July pad SVS testing. I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent 1 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 TO: Jim Regg ~ ~~ ~'13~ro P.I. Supervisor f ~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-429 FROM: Bob Noble KUPARUK RIV U MELT 2P-429 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~ Comm Well Name: KUPARUK RIV U MELT 2P-429 API Well Number: 50-103-20378-00-00 Insp Num: mitRCN100809172131 Permit Number: 201-102-o Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 8/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2P-429 ' jTYPe Inj. N TVD 5218 ~ IA 435 1820 - 1770 1760 P.T.D 2ouaz° 'jTypeTest SPT Test psi 182° OA 310 442 ~~ 348 339 InterVal4YRTST per, P - Tubing 910 910 910 910 Notes: /,A~.~. Tc~q~ -~~~f /~v~si Tuesday, August 10, 2010 Page 1 of 1 U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks@alaska_gov; tom.maunder@alaska.gov; doa.aogcc.prudhce.bayl@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU ! 2P 08/08/10 Colee /Coleman - AES Robert Noble Packer Pretest IniFral 15 Min. 30 Min. Well 2P-419 T In". G TVD 5,202' Tu ' 3,700 3,700 3,700 3,700 Interval 4 P.T.D. 2040170 T test P Test 1500 2,716 3,300 3,260 3,260 P/F P Notes: OA 29t 335 338 336 We11 2P1120 T In'. G TVD 5,428' Tubi 3,050 3,050 Interval 4 P.T.D. 2011820 T test P Test 1500 1,850 1,769 P/F F Notes: Pumped 13bbls. With rto pressure increase. OA 291 275 We11 2P-427 T In'. G TVD 5,455 T 3,100 3,100 3,100 3,100 interval 4 P.T.D. 2020180 T test P Test 1500 1,925 2,600 2,520 2,520 P/F P Notes: OA 675 676 676 676 We11 2P~29 T In'. N TVD 5,218' T 910 910 910 910 Interval 4 P.T.D. 2011020 T test P Test 1500 435 1,820 1,770 1,760 P1F P Notes: OA 310 442 349 339 We11 2P-434 T In". N TVD 5,129' T 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2031530 T test P Test 1500 Casi 5 2,390 2,290 2,280 P/F P Notes: OA 100 101 101 101 Well 2P-447 T Iri . G TVD 5,226` T 3,500 3,500 3,500 3,500 Interval 4 P.T.D. 2031540 T test P Test 1500 240 1,840 1,810 1,810 PIF P Notes: OA 1175 1176 1195 1201 Well T In'. TVD Tut~i interval P.T.D. T test Test Casi P/F Notes: OA Well T In'. TVD Tu ' Interval P.T.D. T test Test - P/F Notes: OA {^j a D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test ~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27!07 MIT KRU 2P Pad OS-0&10.x1s WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 2P-429 Run Date: 3/12/2010 March 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2P-429 Digital Video File (AVI) 50-103-20378-00 1 DVD Rom PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A C;UYY ur 1tt~ TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto t'-~ 4+~r n': ~ i~: _' ~ ~.. L -_ ~-~ Date: h~AR ~ ~~ 201 ~~~'~~~ ~ ~ G! to ~ l Signed: 4 .~ ~_-. O„p .. : t Cow .:~. Ç) ScblulRbel'gep NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NOV 1 3 Z006 (:¡~~ CM~. ())ffim\~ A!1c\mX~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U,IC- db{ -IDd- Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23106 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K,28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G..16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2~-432 11415644 INJECTION PROFILE 10/26106 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE WIDEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2l:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2K.27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 11/10/06 . . e Conoc~illips Alaska e .\= ~~ Ii ¡¡ '.¡~ .~.~, í' U1 0 6 J!.",)L 'J' ..J '- P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 :¿i !~ült~~~nge June 06,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 '';'f'~''',,¡,~~¡¡;:';ifi ~\¡t;,t ,2 '",~' ~__~'/ r. ð..; 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~~cl d~ r:::>6/~ 0 !tJ6 Attachment dCl-- (Gd e e ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Name Initial top PTD # of cement ft Final top of Cement top cement off date ft Corrosion inhibitor/ sealant date 5/19/2006 · Conoc~illips Alaska ac -JjJ [\j ~'\.' t: '..' j Oil & G~$ Ancl'mrage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 dl(J¡-lfj~ June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 r,{'I;\~~\\'::"~) ';J'...., ~., .';r ., Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfi1l404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05, 2006. Sch1umberger 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. ConocoPhillips Problem Well Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Vol. of cement Final top of Cement top um ed cement off date bbls ft e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Schlumbel'ger NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 10/07/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ANNEl2' NOV Ð 2 20G5 Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10102/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1 G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1D-114 11015728 INJECTION PROFILE 09/04/05 1 2V -08A 11072913 INJECTION PROFILE 10/03105 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10/02/05 1 1 E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: tLlaiU DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk _J Color CD _~J / 7 (\)~JvN- r- ~~t,-{ò ~ F: {.4. ( ,- \ 1-ŒCHANICAL INTEGRITY REPORT' ...... j ~.'~ ~PUD DA~:::: OPER & FIELD ~ ~ G R E L :s ;- s :.:: . ~'"ELL NUKB ER K~ TVD; DV: !:ill TVD MD .Tvu HD -:VD ~t:..LL DATA TD: .MD.. C2-siIlg: ~~ \\- MD Shoe: _=-::ìe"!" I Shoe: M:D ~"JD:i..:;g : Packe::.:::- \ HI) ~--:ole '\ !I S :..z e 'If ana í TVD; :?BTD: TVD; :CP: TVTI; See ë. t Perf .3 \ to ::-::E C?.ÞJrr C;..L INTEGRITY - PART ¡ 1 Annulus Press Test: ~p 15 min 30 min COWElents: ~,,~ ---- ~CRÞ_?\!ICÞ.L INTEGRITY - PART 42 '\\ C em en t: Vol UTIle S:' .Am t G L in er ; Csg ; DV \ ()(:;;~~ {~ ?! !- ~ tY Ü Dø .f, CWL ~ol to CQve::.:::- perfs Q '~\ ~,. . '- \cC"'\, "-- .!..2eore tlcal Toe \Ç-<-\ '?,OC(:~ '~c...! ? \r.;¿ '-JL.'>i~(Lf"'\'~ <:J\.~~,-\Q'\-~'- \~~.\}~. s ~ \- Cement Bond Log (Yes or No) ~~- '7 ; In AOGCC File yr~~,,~~\\C)'v''''\ .~ CEL ~valuation, =one above perfs ì 't~CQ: \\ <-~\-."' P roà.uc...tion La g : Type Evaluation CONCLUSIONS: :? 2.r-:: i 2: '" 'c..,. \ :J-~"'" .lì. - Cl..L L t ~ . /' 21'-431 @ 4500 , SOOO I , 5500 "'< "2...0 '%"'-\2:; )0\ - \0) 2 29 ~(~ ~,\,< T",,-~ GI. ~ 'N) ~ "- "",--\'CJ..~ ,c,~,,- s 'J~' I ~í'" j "- \6'.... ~.'v~- v ; 'LQ¡~(.¿~ ""7 '') .-/ f----- "--:> v- ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h){1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 4th 0 0 2004/1st 31842 100 2004 / 2nd 0 0 2004 / 3rd 0 0 Total Ending Volume (bbls): 31842 100 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ 0 WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-357 (h)(3) Other Commission approved substances (include descriptions in block 12) 12/3/2003 Volume (bbls): Number of days disposal occurred 63* 63* 0 0 0 31942 0 0 0 0 48 63 32005 48 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Step Rate Test D Signature: \ ~. -.J ~ \ l.....:.-- Date: Printed Name: Randy Thomas Form 1 0-423 Rev. 2/2004 Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-102 2P-429 8. API Number: 50-103-20378-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 0 1/5/2004 2/25/2004 2P-424, 2P-419, 2P-449, 2P-443 0 0 ""-'" Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNE[)¡ JAN 1 4 2005 l (, (6!!Þ- Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. 'I. ~ \~ - r-- 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added ,~ Previous totals (bbls): 2003 / 4th 0 2004/1st 31842 2004 / 2nd 0 2004 / 3rd 0 ,~ Total Ending Volume 31842 (bbls): 0 100 0 0 100 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s ): Pressure vs. Time 0 Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory D 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 303-357 (h)(3) Other Commission approved substances (include descriptions in block 12) 12/3/2003 Volume (bbls): Number of days disposal occurred 63* 63* 0 0 0 31942 0 0 0 0 48 63 48 32005 Step Rate Test 0 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-102 2P-429 8. API Number: 50-103-20378-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 1/5/2004 2/25/2004 2P-424, 2P-419, 2P-449, 2P-443 0 0 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNED NOV 0 4 2.004 \ D /'1«1. (0 'I Phone Number: (907) 265-6830 Submit in Duplicate DATA SUBMITTAL COMPLIANCE REPORT 9/21/2004 Permit to Drill 2011020 Well Name/No. KUPARUK RIV U MELT 2P-429 Operator CONOCOPHILLlPS ALASKA INC MD 8974 / NO 600~ Completion Date 1/13/¿ Completion Status WAGIN Current Status WAGIN API No. 50-103-20378-00-00 _W_--- ----~~-------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~-,= DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital Type Med/Frmt ~Ò 0 ~. C Pdf ~ ED C ~. ,J.-E< Electr Dataset Number 4'0765 LA1351 ~1440 Name LIS Verification See Notes t--1j c, ß L,--- C¡J j w... ~(j.\1 j., ) Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ------__.~__k- 1 28 8932 Open 4/19/2002 1 28 8974 Case 11/6/2002 Digital Well Log data 1 2815 8354 Case 11/29/2002 5 Blu 2815 8354 Case 11/29/2002 2 Blu 7550 8378 Case 5/30/2003 Memory PSP Injection Ò :) frî ~cl Profile - ~ ~surefTemp/Caliper/FB . S 2 Blu 7550 8378 Case 7/23/2003 Memory PSP Injection Profile - nL~ Pressu refT emp/Caliper/FB '] J ~~ ~ - t ìù~ C1,~ ) S - REVISED , -~---------- Reservoir Saturation Reservoir Saturation Inj~ ~ Injection Profile Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM~N Well Cored? YW Daily History Received? Æ: Chips Received? -¥ / N ~ Formation Tops Analysis Received? -Y/N --~~~---~---- Comments: DATA SUBMITTAL COMPLIANCE REPORT 9/21/2004 Permit to Drill 2011020 Well Name/No. KUPARUK RIV U MELT 2P-429 MD 8974 1VD 6002 Completion Date 1/13/2002 Completion Status WAGIN Current Status WAGIN Compliance Reviewed By: Operator CONOCOPHILLlPS ALASKA INC Date: API No. 50-103-20378-00-00 UIC Y -~-~-~------------- ----~------~------_._. ------~- . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation E! or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 14th 0 0 31842 100 0 0 20041 1st 2004 / 2nd 2004 1 3rd Total Ending Volume (bbls): 31842 100 Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic 0 Service E! Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJE! WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 303-357 (h)(3) Other Commission approved substances (include descriptions in block 12) 12/3/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 201-102 2P-429 8. API Number: 50-103-20378-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 63* 63* 0 0 0 0 31942 48 1/5/2004 2/25/2004 2P-424, 2P-419, 2P-449, 2P-443 0 0 0 63 32005 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. 't, ~ \~ Step Rate Test 0 -- Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 48 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7(810 ~7 Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation D or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 4th 0 0 20041 1st 31842 100 2004 1 2nd 2004 1 3rd Total Ending Volume (bbls): 31842 100 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ 0 WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-357 (h)(3) Other Commission approved substances (include descriptions in block 12) 12/3/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 201-102 2P-429 8. API Number: 50-103-20378-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 63* 63* 0 0 0 0 31942 48 1/5/2004 2/25/2004 2P-424, 2P-419, 2P-449, 2P-443 63 32005 Pressure vs. Time D 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Step Rate Test D * Freeze protect volumes I hereby certify that the foregoin~e and correct to th~ best of my knowledge. Signature: . \ ~~ ~ ... -- Printed Name: ~..,.....;...) ~o C""".... ~ Title: Form 10-423 Rev. 9/2003 Date: ~ r-t,5 \' e,,1.-. Lc~oJ INSTRUCTIONS ON REVERSE SIDE "'-'" 48 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. '1 ((6/Õ'1 Phone Number: C-6Ç/;-¿'SD Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service 0 Development 0 Exploratory D 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 303-357 (h)(3) Other Commission approved substances (include descriptions in block 12) 12/3/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 63* 63* 2003/ 4th 0 2004/ 1st 2004 / 2nd 2004 1 3rd Total Ending Volume (bbls): 0 0 0 63 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the fore~ue and correct to the best of my knowledge. Signature: . \ ~- - I~ Printed Name: ~o....l"\,cÅì \. ~C) ""-'"'i,.s Title: Step Rate Test D Date: \) t-~ \: ~""'--- ~.{ ¡::nrm 1 O-.1?~ RA\I Q/?OO~ IN~TRlJCTI()N~ ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-102 2P-429 8. API Number: 50-103-20378-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: /'~~ ,,-,~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. , (~b(oy Phone Number: US- 6'830 Submit in Duplicate Note to File 2P-429 (201-102...303-357) Kuparuk River Unit ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No remarkable events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. The reports for the cementing operation state that 188 bbls of cement was circulated to surface. The net cement remaining in the surface hole according to the cement calculation sheet was 124% XS of the calculated hole volume. --On the initial leak off test, 16.0 ppg EMW was reached after pumping 10 strokes. During the observation period, the pressure declined with the open hole holding 15.0 EMW. The well was not actively pumped into. --No problems are reported for drilling the 8-1/2" hole, running or cementing the 7" x 4- 1/2" tapered casing string. --A subsequent injectivity test was done down the 9-5/8" x 7" annulus. The pressure smoothly increased to constant pressure of 750 psi where it breaks. This is 15.4 EMW. No pressure bleed of information is included. The injection pressure is similar to other recently analyzed wells at Meltwater. --CPA provided a listing of all surface casing shoes within ~ mile of 2P-429. All wells have been examined in the cement calculation spreadsheet and no anomalies have been identified that would preclude granting CPA's request. Based on examination of the submitted ConocoPhillips' request for the subject well. ~~~ Sr. Petroleum Engineer December 2, 2003 information, I recommend approval of ( Conoc6P'hillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Philip Hayden Phone (907) 265-6481 Fax: (907) 265-1336 Email: philip.hayden@conocophillips.com December 2, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundrv Approval for Annular Disposal of Drilline: Waste on we1l2P-429 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that 2P-429 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on 2P-429 approximately December 15,2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe) with Daily Drilling Report. 6. Production Casing Description 7. Production Casing Cementing Report & Daily Drilling Report during cement job. 8. Formation LOT on 7-5/8" x 5-1/2" casing annulus with Daily Drilling Report. 9. Plan View of Existing Adjacent Wells / J 10. Details on all wells within 1.4 mile of 2P-429 at the surface casing shoe; 2P-441, 2P-438, 2P-432, 2P-431, 2P- V427, 2P-422. For wells 2P-441, 2P-431, 2P-427 and 2P-422 we make reference to our previous application for annular disposal in we1l2P-422A dated October 1,2003. With reference to item (8) in the attachments, the calculated Equivalent Mud Weight (EMW) as printed is incorrect due to the use of an erroneous TVD. Using 2458 ft TVD the recalculated EMW is 15.5,pp,g. This deeper LOT occurred at a lower equivalent mud weight than the casing shoe test. Therefore we conchide that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. V With reference to item (10), we1l2P-438 in the attachments, the calculated Equivalent Mud Weight (EMW) as printed for the formation LOT on the 9 5/8" x 7" casing annulus is incorrect due to the use of an erroneous TVD. Using 2475 ft TVD the recalculated EMW is 15.3pp,g~,-. "" ",,'.. If you have any questions or require further information, please contact Philip Hayden at 265-6481, or Randy Thomas at 265-6830. Sincerely, pI. In Ik, J. Phi~Yden r RECEIVED DEC - 2 2m3 Alaska Oil & Ga. tins. Conrniss.on AnchÐflge Conoc~hillips Post Office Box 100360 Anchorage, Alaska 9951 Q..0360 Philip Hayden Phone (907) 265-6481 Fax: (907) 265-1336 Email: philip.hayden@conocophillips.com Drilling Engineer Cc: 2P-429 Well File Randy Thomas Sharon Allsup-Drake ATO-1576 ATO-1530 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D Perforation Depth MD (ft): 8176 - 8505 Packers and SSSV Type: Baker GBH 22 Seal ass. with receptacle, Camco 'DB' nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation Depth TVD (ft): 5549 - 5738 Packers and SSSV MD (ft): Seal bore receptacle @ 7617', nipple @ 517' 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas. D WAG 0 GINJ D R. Thomas Title Kuparuk Drilling Team Leader \.~ \ ~ - PhO~OMMISSI~~.~:OONL y Conditions of approval: Notify Commission so that a representative may witness RECEIVED . DEC - 2 2003 C¡ \JU..~ç\ '-\ \I1:ÇIC.-\- 0 ~ 1ê.\.1'C\ J..û'~ 'ì<>~il & Gas Cons. Commission " Anchorage , Original Signed By BY ORDER OF ~Q ")..'!L . sarah Pain COMMISSIONER THE COMMISSION Date: lU' ~) Ö) DEC, ... 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: Suspend D Repair well D Pull Tubing D ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' Above GL 8. Property Designation: ADL 32092 / 32409 / ALK 373112 / 389058 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8974 6002 8329 Casing Length Size Structural Conductor 80 16" Surface 2937 95/8" Intermediate Production 8938 7" x 4 1/2" Liner 12/15/2003 Date: Printed Name Signature Plug IntegrityD BOP Test D Mechanical Integrity Test D Other: Subsequent Form Required: Approved by: Form 10-403 Revised 2/2003 ~ Z),. ~d6 V V Plug Perforations Perforate D Stimulate D Other D D Time Extension D Variance Annular Dispos. 0 Perforate New Pool Re-enter Suspended Well D 5. Permit to Drill Number: 4. Current Well Class: Development D Exploratory D Stratigraphic D Service 0 201-102 6. API Number: 50-103-2037800 9. Well Name and Number: 2P-429 10. Field/Pools(s): Kuparuk River Field / Meltwater Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 5637 MD TVD Burst Collapse 108' 1081 29651 2434' 5750 3090 8966' 5997' 7240 / 8440 5320 / 7500 Tubing Size: 41/2" Tubing Grade: L-80 Tubing MD (ft): 7617 Service 0 Plugged D WINJ D Abandoned D WDSPL D Contact Philip Hayden 265-6481 Date \ <:..-/ , I 0 > Sundry Number: Location Clearance D .203'-3~~7 n Q , h 1 f\f ð , IØIIS BfA.. SUBMIT IN DUPLICATE ( ( Annulus Disposal Transmittal Form - We1l2P-429 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: 2P-429 2 The depth to the base of freshwater aquifers and permafrost, if No Aquifers 1 Base Permafrost = +1- 1352' TVD RKB present. 3 A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin~ waste. 5 Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. From the 9-5/8" shoe to the cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non-hydrocarbon bearing sands. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate waste under (h)(3) of this section. 7 An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showin~ how this value was determined. 8 Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Maximum anticipated pressure at the outer casing shoe during disposal operations is 2025 psi. See attached calculation pa~e. See attached: cementing reports, LOT 1 FIT reports and casing reports. See attached casing summary sheet and calculation pages. 9 Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the NI A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The welles) where the drilling waste to be disposed of was or will be generated. 15 If the operator proposes not to comply with a limitation established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm containment of drilling waste. N/A 2P-434, 2P-424, 2P-447, 2P-443 N/A N/A RE: 2P-422A Annular Disposal Application ( Subject: RE: 2P-422A Annular Disposal Application Date: Wed, 22 Oct 200309:11 :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-44~: 17.2 ppg. This "new calculated" pump in pressure is greater than fhe original 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 control 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: i )\> pot'.\. c:,~ -\- ~ '\ ~ ~ '\) ~ I c...V \> \ ~ <J:.I. -\.\ ~'" c..:~ þ., ~ ~\>...:. ~~ \ItCC~'> ê)~ -\,,~ ~\~"-J\~ ~\I è)?- "-\'-\ \ \ ~ Ç>- ~ ~ \ d ~- L. ap '\ð~ -L\d~, C7?-'--\"dO . ~,,- L -- --- \ \\\ \ ~~ \<t ~\ ~ ~« , \ ~ ~~ txr;..---: . L "f '-\,),~~~ Q«.~"'c..W\C)\:)<!~ ~ ~ rli.""'c. ~ "\,, ~ \,,~ \" \). 1\, ~,,+ -\.0 ~~t' \r<<;~Cl.\.\~", '^-JCo~ \ 0 "') 'Ñc.... 'f. c. ~'f p(; C-\- \ \JC" \1..)0\ ~:\ \~~ , ~2~ t '0/ ..( Id() 10/22/20039:59 Ar RE: 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. > > 1 hope this note adequately addresses your comments and questions. If > there is anything else please let me know. > > Regards > > Philip > > -----Original Message----- > From: Tom Maunder (mailto:tom maunder@admin.state.ak.us) > 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 myeddress. 2of3 10/22/20039:59 AI RE: 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 initial leakoff 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 30f3 10/22/20039:59 AI Pressure Calculations for Annular Disposal Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure Well Date 2P-429 11/712003 1,500 psi 12 ppg 0.4525 psi/ft 0.11 psi/ft 0 psi Maximum Fluid Densitv to Burst Surface Casing Pburst85% = PHydrostatic + P Applied - PFormation MWmax 4,888 = ( 2,434 * 0.052 * MW max ) + 1500 - (0.4525 * 2,434) 35.5 ppg 2,434 TVD Surface Casing String !:IJ !:IJ = = í.Þ í.Þ Size Weight Grade PburstlOO% Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure =sJ = .~ U : = = = r-= TOC Est. @ 7,618' MD 5,219' TVD 9.625 in 40 ppf L 80 5,750 psi 4,888 psi 2,434 ft 16 ppg 15.5 ppg 1,500 psi or 2,025 psi Maximum Fluid Density to Collapse 2nd Casing String P collapse85% = PHydrostatic + P Applied - P Gas Gradient - PHeader MW max 4,599 = ( 5,219 * 0.052 * MW max ) + 1,500 - ( 0.1100 * 5,219) - 0 13.5 ppg = 41/2"Tbg 2nd Casing String 5,997 TVD Size 7 in Weight 26 ppf Grade L 80 Maximum Allowable Pressure at Surface Casing Shoe P collapse 100% 5,410 psi P collapse85% 4,599 psi P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Top of Cement 5,219 ft Gas Gradient 0.11 psi/ft P max allowable = ( 2,434 * .052 * 16 ) Max Surf. Pressu 1,500 psi Header Press 0 psi P max allowable = 2,025 psi OS/28/03 Schlumbepgep NO. 2860 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth .~ 3S-23 2N-319 2N-343 2N-348 2P-429 2P-420 3J-17 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Field: Date BL Color 04/29/03 1 04/27/03 1 05/02/03 1 05/01/03 1 05/06/03 1 05/06/03 1 05/08/03 1 CD Kuparuk Job# Log Description fX)j-()~~ PERF & SBHP W/JEWELRY LOG \ q~~ - \ ('1 PRESSITEMP SURVEY ~~R-rA ,. INJECTION PROFILE " ("'j \... \ L\" INJECTION PROFILE .. 0 \ '" ~rfMEM PSP INJECTION PROFILE ( \'" \ MEM PSP INJECTION PROFILE -, <q I (j'-) 0 MEMORY LDL RECEIVED ~ \ -. ~~ SIGNED: "'"\<.Cì\ ~ )~:\ J C'¡ ~ -~ ~_f'y\ DATE: MAY 30 2003 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Alaska Oi'i & Gas Cons. Commleion And10rage --- "-....- v..~ Sl~lull~epgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job# 2P-429aOI...JOø. 22496 1D-113 I CJ8-li'r 22472 RST -SIGMA RST-SIGMA S'GNEd~ {~ (};~ Log Description Date DATE: NO. 2557 11/25/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 field: BL Sepia 10/20/02 09/12/02 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD Color 1 1 RECEIVED NOV 292002 Alaska ON & Gas Co .". . Anctt ns. CommISSion , orage ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2P-429, November 04, 2002 AK-MM-11208 aOIr-/()~ 1/351 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2P-429: Digital Log Images 50-103-20378-00 1 CD Rom RECE.\\I\SO /f'd',("? \~O\ 0 6 LVV~ (:.G', ~i'\~~~n . . f'.f",t".", J~'fo!~\~I.W 0:1 ~'. ~.aß \NI \'-'. '. . ,.,\-" i¡ ~ \or f'A AA(b~.~ (' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille o. Taylor uI Chair ~ ~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder v -. Phillips Alaska P.I. Supervisor ~ , /O~ 2P Pad ~' %{ 5 FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL DATE: August 3, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well 2P-420 Type Inj. G T.V.D. 5428 Tubing 2450 2400 2400 2450 Interval I P.T.D. 2011820 Type test P Test psi 1500 Casing 1250 1990 1950 1950 P/F .e Notes: Initial MIT Well 2P-429 Type Inj. G T.V.D. 5218 Tubing 2575 2575 2575 2575 Interval I PoI.D. 2011020 Type test P Test psi 1500 Casing 1000 1910 1900 1900 P/F .e Notes: Initial MIT Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F t -. ~ Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test T es~ psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. p= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey v= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey w= Test during Workover 0= Differential Temperature Test 0=. Other (describe in notes) Test's Details I traveled to PAl's 2P Meltwater Pad to witness Initial MIT's on MI injectors. This was the fIrst opportunity to travel to 2P Pad since breakup. The Pad is still very soft & muddy. Nordic 3 is stacked on 2P Pad waiting for Pad conditions to allow the Drilling program to continue. Road conditions to 2P Pad are fair for light truck travel. The SVS tests for 2P Pad will be conducted this Month. M.I.T.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 4 hrs. cc: M IT report form 5/12/00 L.G. MIT KRU 2P 08-03-02 JC.xls 8/5/2002 aO/-JO~ WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7fu Avenue, Suite 100 Anchorage, Alaska April 10, 2002 RE: MWD Formation Evaluation Logs 2P-429, AK-MM-11208 1 LDWG formatted Disc with verification listing. llPI#: 50-103-20378-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RE;CI:IVED t.PR 1 9 2002 Alaska Oil & Gas Cons, Commission .Anchorage Si~ú-~r~ 1 qö -/51 d.~. ð05 I q 1~{)5D a 0/- ({),;J. Sc~lulBb8rgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Well Job # Log Description 1A-17 2P-448A 3N-19 2P-429 PREssrrEMP SURVEY PERF RECORD/SBHP USIT SCMT 22046 22045 SIGNED(~~¥ LtOoof'D Date 01/28/02 01/27/02 01/14/02 01/13/02 DATE: NO. 1788 02/06/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: BL Sepia 1 1 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD Color 1 1 RECEIVED FEB 0 C 2002 Ala8ka0i1 & Gas Cons. Commission Anchorage ,--' ( /PiiiûiPS) PHilliPS Alaska, Inc. ~. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 February 7, 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-429 (201-102) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater well 2P-429. If you have any questions regarding this matter, please contact Pat Reil1y at 265-6048. Sincerely, /1 ().. ~ Cl- """'/ c. Miillary (¡. Drilling Engineering Supervisor PAl Drilling CMlskad RECEIVED FEB 0 8 Z002 AI_o;I&Gas (i-~ . Anœ;;~ ORIGINAL (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of well Classification of Service Well OilO GasO 2. Name of Operator ~~.....~ ... '."IXJ~h''''' Phillips Alaska, Inc. :'b::~~f:U~ 201-1021 3. Address ' ~~ .. 8. API Number P.O: Box 100360, Anchorage, AK 99510-0360 .-~.". !su~').i 50-103-20378-00 4. Location of well at surface r ~'.' ":;.'. ' " ~ < 9. Unit or Lease Name 934' FNL, 1953' FWL, Sec. 17, T8N, R7E, UM t :';-"':~ß ,':~ ; (ASP: 443913, 5868944f"~'~:;':.l~}:.. Kuparuk River Unit At Top Producing Interval Lj' ¡, 13,' ç;e:~¡ 10. Well Number 1077' FNL, 2319' FEL, Sec. 20, T8N, R7E, UM....... fjIIOI>..~E.~:1'¡:.::¡'ç;r.-, ~ (ASP: 444898.5,5863513) At Total Depth . .. ' -~.- i . '. ~~:,>"",,"':')""'io,1~~-," 1760' FNL, 2255' FEL, Sec. 20, T8N, R7E, UM . . (ASP: 444955.5, 5862830) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 255' AMSL feet ADL 389058 & 373112 , ALK 4998 12. Date Spudded 13. Date T.D. Reached 14. Date.Comp., S~p. Or Aband. . 15. Water Depth, if offshore 16. No. of Completions ..J~n. J ~'2..C:{) ¿.. December 8,2001 December 17, 2001 [)p.~pmbor 1J,?t)01 r .~ N/A feet MSL 1 17. Total Depth (MD + TVD) 18. PlugBack Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8974' MD 1 6002' 1VD 8869' MD 15943' TVD YES 0 No 0 None 22. Type Electric or Other Logs Run GR/Res/Den/Neu, SCMT 23. Suspended 0 Abandoned 0 Service 0 WAG Injector 7. Permit Number 2P-429 11. Field and Pool Meltwater Oil Pool Kuparuk River Field feet MD 1505' 16" WT. PER FT. 62.5# 40# 26# 12.6# GRADE B L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 110' Surface 2965' Surface 7619' 7619' 8966' HOLE SIZE 42" CEMENTING RECORD 60 bbl AS 1 561 sx AS III Lite, 128 bbls LiteCrete 84 sx AS Lite, 500 sx Class G (included above) AMOUNT PULLED CASING SIZE 9.625" 12.25" 7" 8.5" 8.5" 4~5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE cement plug @ 8869' TUBING RECORD DEPTH SET (MD) 7617' PACKER SET (MD) N/A 4.5" 8495' - 8505' MD 8386'...- 8435' MD 8300' - 8350' MD 8176' - 8240' MD 5733' - 5738' TVD 5670' - 5698' TVD 5621' - 5650' 1VD 5550' - 5586' TVD 6 spf 6 spf 6 spf 6spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Date ofT est Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 27. Date First Production Flow Tubing Casing Pressure Production for OIL-BBL Test Period> Calculated 24-Hour Rate> OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A fEB Os 2002 Alaska Oil & Gas Coos. Commission . Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate OR\G\NALRBDMS BFL FFR I , '-, I ..'JfYI') {J,J(}i:..... . 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 8145.5' 7979' 5532' 5435' Annulus left open - freeze protected with diesel. 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. Signoo 2 Chg=~ l '( TIIi. Questions? Call Pat Reilly 265-6048 Drilling Engineerina Supervisor Dat. J... 'r(o? . 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. RECEIVED Item 28: If no cores taken, indicate "none". ORIG\ J\L FEB 0 8 2002 Alaska Oil & Gas Coos. Commission Anchorage Form 10-407 ( '~~ ~ \~ Page 1 of 5 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From~T() . Hours Code Sub Phase Code 12/6/2001 15:00 - 16:00 1.00 MOVE MOVE MOVE 16:00 - 18:00 2.00 MOVE MOVE MOVE 18:00 - 18:30 0.50 MOVE MOVE MOVE 18:30 - 19:00 0.50 MOVE MOVE MOVE 19:00 - 20:00 1.00 MOVE MOVE MOVE 20:00 - 22:00 2.00 MOVE MOVE MOVE 22:00 - 00:00 2.00 MOVE MOVE MOVE 12/7/2001 00:00 - 02:30 2.50 MOVE MOVE MOVE 02:30 - 06:00 3.50 MOVE MOVE MOVE 06:00 - 11 :30 5.50 WELLSR PULD SURFAC 11 :30 - 13:00 1.50 RIGMNT RSRV SURFAC 13:00 - 14:30 1.50 WELLSR PULD SURFAC 14:30 - 17:00 2.50 WELLSR PULD SURFAC 17:00 -18:00 1.00 RIGMNT RSRV SURFAC 18:00 - 00:00 6.00 WELLSR PULD SURFAC 12/8/2001 00:00 - 02:30 2.50 WELLSR PULD MOBMIR 02:30 - 03:00 0.50 WELCTL OTHR MOBMIR 03:00 - 05:00 2.00 DRILL PULD SURFAC 05:00 - 05:30 0.50 DRILL SFTY SURFAC 05:30 - 06:00 0.50 DRILL CIRC SURFAC 06:00 - 09:30 3.50 DRILL DRLG SURFAC 09:30 - 11 :00 1.50 DRILL PULD SURFAC 11 :00 - 00:00 13.00 DRILL DRLG SURFAC 12/9/2001 00:00 - 05:00 5.00 DRILL DRLG SURFAC 05:00 - 05:30 0.50 DRILL CIRC SURFAC 05:30 - 08:00 2.50 DRILL WIPR SURFAC 08:00 - 09:30 1.50 DRILL WIPR SURFAC 09:30 - 14:00 4.50 DRILL DRLG SURFAC 14:00 - 14:30 0.50 RIGMNT RSRV SURFAC 14:30 - 00:00 9.50 DRILL DRLG SURFAC Spud Date: 12/8/2001 End: 12/20/2001 Group: Start: 12/6/2001 Rig Release: 12/20/2001 Rig Number: 141 Description of Operations Move & Stage Pipe Shed & Rock Washer Move & Stage Boiler,Mtr,Pump & Pit module s Move Sub Move Sub Move Sub Pick up & s Pick up and set Rock Washer - Layout elect ric service lines Set Rock Washer & Both Pipe sheds - R/U in terconnects on all modules - Start N/U Diver ter - R/U Hi Line Power Level & Shim both pipe sheds - Build spill b erm f/ Rock Washer Accept Rig 0600 hrs - Load DP & Sperry BH A in pipe shed - OffLoad mud inti pits Serv TO - Align Top Drive Rail to Rotary P/U 5" Handling tools - C/O Saver Sub to 4 1/2" IF - Remove all HT38 equip from floor P/U & SIB 5" DP in derrick Slip & Cut Drill Line ( 94' cut) Load HWDP in shed - Con't P/U & SIB DP in derrick ( P/U total 83 stds DP) P/U HWDP & SIB in derrick - P/U 1 std DCs & SIB in derrick - P/U 4 1/2" IF surface tool s Fuction Test diverter - AOGCC rep Chuck Sc heve waived witness test P/U BHA# 1 - Orient Tools Pre-Spud meeting in top dog house wI crew & all contractors Fill Con d u c tor and all Sur f ace Ii n e s - C h e c k for leaks - "ALL OK" Tag @ 97' RKB - CIO Ice & CMT 97' to 137' - Spud well - Drlg 137' to 278' MD SIB 2 stds HWDP - P/U remaining BHA (2 st ds DCs) Dir Drlg & Slide 278' to 1250' MD ( 1222' TV D) ART 5.5 hrs , AST 5.8 hrs Pump sweeps as needed to maximize hole cleaning- Pum ped @ 992' D i r D rig & Slide 1 2 5 0 I to 15 4 0 M D Circ BU - Pump Wt / Hi Vis Sweep - Circ hol e clean Observe Well - TOH to DCs - **Note**(Pump Out f/ 1356' to 901' -Large guage motor & st abs swabbing) TI H to 1325' - Wash & Ream 1325' to 1540' - Clay balls to surface on BU Dir Drlg & Slide 1540' to 1813' MD S e r v Rig & T D - S him & L e ve I for T D Dir Drlg & Slide 1813' to 2390' MD ( 2090' T Base off 2P-415 Base dn pad sideways to 2P-429 Base over 2P-429 Set Boiler,Mtr,Pump & Pit module Printed: 1/18/2002 4:24:56 PM ~, T¡r¡I ~ ( Page 2 of 5 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/9/2001 14:30 - 00:00 9.50 DRILL DRLG SURFAC 12/10/2001 00:00 - 10:00 10.00 DRILL DRLG SURFAC 10:00 - 12:00 2.00 DRILL CIRC SURFAC 12:00 - 15:00 3.00 DRILL WIPR SURFAC 15:00 - 16:00 1.00 DRILL WIPR SURFAC 16:00 - 20:30 4.50 DRILL CIRC SURFAC 20:30 - 00:00 3.50 DRILL TRIP SURFAC 12/11/2001 00:00 - 03:00 03:00 - 04:30 04:30 - 10:00 3.00 DRILL PULD SURFAC 1.50 CASE RURD SURFAC 5.50 CASE RUNC SURFAC 10:00 - 20:00 10.00 CEMENTCIRC SURFAC 20:00 - 21 :00 1.00 CEMENTSFTY SURFAC 21 :00 - 21 :30 21 :30 - 00:00 0.50 CEMENTCIRC SURFAC 2.50 CEMENT PUMP SURFAC 12/12/2001 00:00 - 01 :30 1.50 CEMENT DISP SURFAC Spud Date: 12/8/2001 End: 12/20/2001 Group: Start: 12/6/2001 Rig Release: 12/20/2001 Rig Number: 141 Description of Operations VD) 24 hr Total ART 4.4 hrs , AST 5.4 hr s Dir Drlg & Slide 2390' to 2972' MD (2438' T VD) ART 7.0 hrs AST 0.9 hrs Circu & Condition - Pump Wt I Hi Vis Sweep CBU - Circu hole clean (Total circu 18000 stks (1818 bbls) Wiper Trip to 1177' (HWDP) - Tight & Swab @ P Frost 1570' to 1480' - Large guage stab s creating swab - Work until clean TIH - Wash 60' to Bttm -No fill CBU - Pump tandem sweeps Wt /Hi Vis & Vis back to back -(Large amount of debris back on first BUs) - Circu & Condition per Bario d rep & well plan - Final Mud properties 9.7 +ppg , 55 Vis, YP 30 , PV18 TOH No excess over pull - Hole took Proper Fill - No Swab L/D BHA #1 - SIB HWDP R/U to Run 9 5/8" 40# L-80 BTCM Csg Run 9 5/8" Csg per well plan - Ran 72 jts - Shoe @ 2965' MD (2435' TVD) Tight f I 216 0' - 2365' Circu & Condition Mud for CMT - Staged circ u up to 6 bpm - No losses - Running 40 BPH water - Condition Mud per well plan specs - Properties at start: Wt 9.9+ppg, Vis 54 , PV 18 , YP 28 , Gels 10/20/21 Final properti es: Wt 9.7ppg , Vis 41 , PV 13 , YP 15 , Gel s 5/7/9 **Note** Only able to recip 5' - We drained diverter and made sure csg hanger was centered "OK" It was- After checking fig ures it appears Csg collar on #3 jt hanging up on bttm of conductor. PJSM with Rig Crew & all contractors - CIO Franks fill tool - M/U Dowell CMT head Re-establish circu wI CMT head CMT per well plan - Pump 5 bbl CW100 - Tes t CMT lines to 3500 psi - Con't pump 35 bbl s CW100 @ 8.4ppg , Drop Bttm plug, pump 50 bbl MudPUSH @ 10.2ppg , pumped 443 bb Is Lead CMT (561 sxs), 128 bbls Tail CMT @ 11.5 to 11.7 ppg, Drop Top plug, pump 10 bbl wash up,Turn over to rig - Rig will displ ace w/ 2071 stks(Calulated) **NOTE** We were unable to mix the Tail to preposed 12. Oppg ,it Avg'd 11.6ppg . Talked to Dowell en g & Team Leader. It was decided to con't a nd complete the CMT pumping. Dowell lab e ngineer(Perry) advised that the loss on com pressive strength would be minimal. Con I t t 0 displace C M T - Bum pp lug @ 2 03 9 s t k s (C a I cui ate d 2 0 7 1 s t k s ) Fit s h el d . C I P 0 Printed: 1/18/2002 4:24:56 PM ~'. I'fTiI ~~ Page 3 of 5 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/12/2001 00:00 - 01 :30 1.50 CEMENT DISP SURFAC 01 :30 - 03:00 1.50 CEMENT PULD SURFAC 03:00 - 05:00 2.00 WELCTL NUND SURFAC 05:00 - 06:00 1.00 WELCTL NUND PROD 06:00 - 10:00 4.00 WELCTL NUND PROD 10:00 - 11 :00 1.00 WELCTL NUND PROD 11 :00 - 12:00 1.00 WELCTL BOPE PROD 12:00 - 15:30 3.50 WELCTL BOPE PROD 15:30 - 16:00 0.50 WELCTL BOPE PROD 16:00 - 17:00 1.00 DRILL PULD PROD 17:00 - 18:00 1.00 DRILL PULD PROD 18:00 - 20:00 2.00 DRILL PULD PROD 20:00 - 21 :30 1.50 DRILL PULD PROD 21 :30 - 22:30 1.00 WELLSR DEQT PROD 22:30 - 00:00 1.50 DRILL DRLG PROD 12/13/2001 00:00 - 00:30 0.50 DRILL DRLG PROD 00:30 - 01 :30 1.00 DRILL CIRC PROD 01 :30 - 02:00 0.50 DRILL LOT PROD 02:00 - 05:00 3.00 DRILL DRLG PROD 05:00 - 06:00 1.00 DRILL OTHR PROD 06:00 - 12:00 6.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 12/14/2001 00:00 - 02:30 2.50 DRILL DRLG PROD 02:30 - 04:00 1.50 DRILL CIRC PROD 04:00 - 05:30 1.50 DRILL WIPR PROD 05:30 - 06:00 0.50 RIGMNT RSRV PROD 06:00 - 07:00 1.00 DRILL WIPR PROD 07:00 - 07:30 0.50 DRILL CIRC PROD 07:30 - 12:00 4.50 DRILL DRLG PROD Spud Date: 12/8/2001 End: 12/20/2001 Group: Start: 12/6/2001 Rig Release: 12/20/2001 Rig Number: 141 Description of Operations 1 :30 hrs (For CMT & pump detail see Report #612/11/01) RID CMT Equip - LID LJ N/D Diverter System N/U Csg Head & Test to 1000 psi - hold 10 min N/U 13 5/8" 5K BOPs - Change bttm pipe r ams to 5" -( 3 1/2" X 6" VBRs in Top Rams) Remove equip from floor - C/O TD bails R/U to test BOPs Test BOPs & Choke Manif 250psi 10 & 3000 psi High. Ea. test held 5 Min. No failures Pull test plug - Set wear bushing - Blow dn choke manifold P/U BHA #2 tools to Rig floor - PJSM on RA scorces M/U BHA #2 - P/U Bit, TurboBack Stb, re-co nfigure to 1.0 AKO & Scribe M/U Sperry Tools - Program MWD - Load RA Scorces P/U 3 NMDCs & TIH - Rotate Slowly thru por t collar @ 1006' - Tag up @ 2884' R/U to test Csg - Circu air from system - Te st Csg to 2500' psi - Pump 12 stks - Hold on Chart 30 min - (Loss 35 psi) Drlg Plugs, FC , CMT & Drilling on FS Drlg FC & 30' new hole to 3002' Circu hole clean - Displace New conditioned 9.6 ppg mud into system.(Blended the last 278 bbls of new mud into our system) Pull back to shoe - Preform LOT to 16 EMW - (818 psi @ surface, 2458'TVD wI 9.6ppg Mud) PSI loss to 670 psi after 10 min Dir Drlg & Slide 3002' to 3246' MD Sperry Sun Preform & record PWD Base line test - ECD hardline 11.7 @ 3200 to 11.9ppg @ 9000' Dir Drlg & Slide 3246' to 3860' MD (2972' T VD) ART 6.2 hrs , AST 0.5 hrs Dir Drlg & Slide 3860' to 4700' MD (3481' TVD) ART 8.3 hrs , AST 0.5 hrs D i r Dr I 9 & S lid e 4700' to 501 0' M D ( 3663' T VD) ART 1.6 hrs , AST 0.4 Circu Wt I Hi Vis Sweep - Circu hole clean Wiper Trip to Shoe @ 2965' ( Tight spot @ 4 640' worked clean- ) Service Rig & TD Con't Wiper Trip to Bttm - No tight hole - N 0 problems C B U to red u c e E C Ds an dun loa d cut tin 9 s fro m wiper trip Dir Drlg & Slide 5010' to 5340' MD ( 3862' T VD) ART 2.5 hrs , AST 0.7 hrs Printed: 1/18/2002 4:24:56 PM ( ~~ TfTiI ~!:Ø ( Page 4 of 5 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/14/2001 12:00 - 00:00 12.00 DRILL DRLG PROD 12/15/2001 00:00 - 10:00 10.00 DRILL DRLG PROD 10:00 - 11 :30 1.50 DRILL CIRC PROD 11 :30 - 12:00 0.50 DRILL WIPR PROD 12:00 - 13:30 1.50 DRILL WIPR PROD 13:30 - 14:00 0.50 RIGMNT RSRV PROD 14:00 - 15:00 1.00 DRILL WIPR PROD 15:00 - 15:30 0.50 DRILL CIRC PROD 15:30 - 00:00 8.50 DRILL DRLG PROD 12/17/2001 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 06:30 2.50 DRILL CIRC PROD 06:30 - 10:30 4.00 DRILL WIPR PROD 10:30 - 12:00 1.50 RIGMNT RSRV PROD 12:00 - 16:30 4.50 DRILL WIPR PROD 16:30 - 22:30 6.00 DRILL CIRC PROD 22:30 - 00:00 12/18/2001 00:00 - 04:30 04:30 - 06:00 06:00 - 09:00 1.50 DRILL TRIP PROD 4.50 DRILL TRIP PROD 1.50 DRILL TRIP PROD 3.00 DRILL PULD PROD 12/19/2001 09:00 - 10:30 10:30 - 11 :30 11 :30 - 13:00 13:00 - 15:00 15:00 - 16:30 16:30 - 18:30 18:30 - 19:00 19:00 - 21 :00 21 :00 - 21 :30 21 :30 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 07:00 07:00 - 11 :00 1.50 WELCTL NUND PROD 1.00 WELCTL BOPE PROD 1.50 CASE RURD PROD 2.00 CASE RUNC PROD 1.50 CASE RURD PROD 2.00 CASE RUNC PROD 0.50 CASE CIRC PROD 2.00 CASE RUNC PROD 0.50 CASE CIRC PROD 2.00 CASE RUNC PROD 0.50 CASE CIRC PROD 3.00 CASE RUNC PROD 4.00 CEMENTCIRC PROD 4.00 CEMENT RURD PROD Spud Date: 12/8/2001 End: 12/20/2001 Group: Start: 12/6/2001 Rig Release: 12/20/2001 Rig Number: 141 Description of Operations Dir Drlg & Slide 5340' to 6225' MD ( 4395' T VD) ART 9.2 hrs , AST 1.2 hrs Dir Drlg & Slide 6225' to 7052' MD (4883' T VD) ART 6.2 hrs , AST 1.0 hrs Circu & Condition - Pump Wt/Hi Vis Sweep f ollowed by Hi Vis only sweep - Circu hole cl ean ( 2+ BUs) Recip & Rotate DP @ 110 rp ms at all times Start Wiper Trip to 4900' ( Past last WT poi n t) Con't Wiper Trip to 4900' - Drag 25-30K - N 0 excess tight hole - Fill correct Service Rig & Top Drive TIH - Wash 90' to Bttm - No fill CBU to minimize ECDs - Circu clean after W T Dir Drlg & Slide 7052' to 7675' MD ( 5253' TV D) ART 5.5 hrs AST 0.7 hrs Dir Drlg & Slide 8775' to 8974' MD (6002' T VD) ART 2.5 hrs , AST 0.0 hrs Pump tandum Hi Vis sweeps - Circu hole cle an - Recip & Rotate @ 110 RPMs to maximiz e hole cleaning Pump Dry job - TOH - Monitor well & hole fil I per Phillips trip policy Cut drill line - Service Rig & Top Drive - Ck & service brake linkage & draw works TIH - Fill pipe & break circu every 20 stds Circu & Condition Mud - Properties @ start Out/in Wt 9.8/9.6, Vis 56/45 , PV 22/18 , YP 20/18 . After condt Wt 9.6/9.6 Vis 45/ 44 , PV 14114 ,YP 16/16 - Spot 20 bbl lub e pill on Bttm - Monitor well Static TOH TOH to HWDP - No excess drag - No swab POOH LID HWDP LID DC's, down load MWD, LID MWD and mot or Change pipe rams for running casing Test Pipe rams 250 psi low, 3000 psi high R/U to run 4 1/2" casing Run 42 jts of 4 1/2" 12.6# L-80 IBT casing R/U to run 7" casing P/U Baker SBE and run 7" casing to 2900' Circ. bottoms up Run 7" casing to 4947' Circ. bottoms up, no mud losses Run 7" casing to 6948' Circ. bottoms up, no mud losses Run 7" casing f/6948' to 8966' Circ. and cond mud for cement job R/U cement head, hold pre-job safety meetin g, attempt to batch mix spacers and cement, Printed: 1/18/2002 4:24:56 PM /~þ TjTfI ~~ Page 5 of 5 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-429 2P-429 ROT - DRILLING Doyon Doyon 141 Date Sub From - To Hours Code Code Phase 12/19/2001 07:00 - 11 :00 4.00 CEMENT RURD PROD 11 :00 - 13:00 2.00 CEMENT PUMP PROD 13:00 - 14:00 1.00 WELCTL NUND PROD 14:00 - 16:30 2.50 WELCTL NUND PROD 16:30 - 18:00 1.50 CMPL TN RURD CMPL TN 18:00 - 00:00 6.00 CMPL TN RUNT CMPL TN 12/20/2001 00:00 - 03:00 3.00 CMPL TN RUNT CMPL TN 03:00 - 06:00 3.00 CMPLTN CIRC CMPL TN 06:00 - 08:00 2.00 CMPL TN SOHO CMPL TN 08:00 - 10:00 2.00 CMPL TN DEQT CMPL TN 10:00 - 12:00 2.00 WELCTL NUND CMPL TN 12:00 - 14:30 2.50 WELCTL NUND CMPL TN 14:30 - 22:00 7.50 DRILL PULD PROD 22:00 - 00:00 2.00 DRILL RIRD PROD Spud Date: 12/8/2001 End: 12/20/2001 Group: Start: 12/6/2001 Rig Release: 12/20/2001 Rig Number: 141 Description of Operations having freezing problems, mixing went very slow, circ hole with rig pump while this op eration is going on Pump 10 bbls CW100, test lines to 3500 psi, pump 80 bbls CW100, pump 50 bbls 12 ppg. MudPush, pump 30 bbls 13 ppg lead cement , pump 107 bbls 15.8 ppg tail cement, drop t op plug, pump 27 bbls 9.8 ppg KCL water an d displace with rig pump with 9.6 ppg mud, bump plug with calculated strokes, check flo ats and floats held. Reciprocate pipe throug h out cement job. Land casing in wellhead, remove landing jt., set packott and test to 5000 psi. Change pipe rams and test. R/U to run 4 1/2" completion tubing RIH with seal assembly and completion equi pment on 4 1/2" 12.6# L-80 IBTC tubing to 5 610' Run 4 1/2" tubing to top of SBE Reverse circ mud out of hole with clean 8.4 ppg fresh water, circ until hole was clean Space out and land seals in SBE, left 2' of space out from locators Pressure test 4 1/2 x 7" annulus to 3000 psi , shear valve in GLM during bleed down of a nnulus pressure as stated in procedure. N/D BOP's N/U tree and test to 5000 psi LID 7500' of 5" drill pipe out of derrick Per form annular injection test on 7" x 9 5/8" ca sings Freeze protect well Change out TDS 5" saver sub and grabbers t 0 4" Printed: 1/18/2002 4:24:56 PM Date 01/06/02 01/07/02 01/09/02 01/13/02 01/14/02 ( ( 2P-429 Event History Comment REPLACE 111 SOV @ 7500' RKB WTH DV.TBG & CSG TESTED GOOD TO 3000 PSI.TAG OBSTRUCTION IN 4.5" LINER @ 7728' SLM. [GLV, TAG, PTTBG-CSG] PULLED OBSTRUCTION FROM 7730' SLM TO GLM @ 7500' RKB; TOOLS PULLED FREE FROM FISH. DRIFTED W/22' X 2.511 DUMMY GUN TO 87351 SLM, NO OBSTRUCTION ENCOUNTERED. [FISH, TAG] STATIC @ 8340' & 84901 RKB [PRESSURE DATA] RUN SCMT-BB TOOL, DID NOT TAG TO, LOGGED VERY GOOD QUALITY CEMENT FROM 8700' UP TO LINER TOP @ 7617', POOH, CHANGE TO 2.5" HSD 6 SPF GUNS AND PERFORATED (84951-8505'), (8386'- - 84351), (83251-8350') IN 4 RUNS, POOH, CHANGE HEAD & LAY DOWN. PERFORATED 83001-8325, 81761-8240' IN 4 RUNS, LOGGED STATIC BHP=2365 PSI AND BHT =143 @ 8341' LOG 2ND STATION @ 81061, POOH, RDMO, LEFT WELL SI AND TESTED, NOTIFY DSO OF STATUS & DEPARTURE. [PERF] Page 1 of 1 1/21/2002 .~..~~.", ',";',ijif:::",';'1f:' dr~'ê~,lt:.< ;:u~ 10-Jan-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 2P-429 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 8,974.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 1 2002 Alæka Oil & Gas Cons. Commission Anchorage . DEFNITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 2P, Slot 2P-429 2P-429 Job No. AKMM11208, Surveyed: 17 December, 2001 SURVEY REPORT 10 January, 2002 Your Ref: API 501032037800 Surface Coordinates: 5868943.80 N, 443913.05 E (70003' 09.3430" N, 150026' 55.8224" W) Surface Coordinates relative to Project H Reference: 868943.80 N, 56086.95 W (Grid) Surface Coordinates relative to Structure: 65.06 S, 272.36 W (True) Kelly Bushing: 251. 10ft above Mean Sea Level ,..-., '"spa"""r'Y-5UI! DRILL.fNG "'seRVICEs A Halliburton Company Survey Ref: svy9798 Sperry-Sun Drilling Services . Survey Report for 2P-429 Your Ref: AP/501032037BOO Job No. AKMM1120B, Surveyed: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -251.10 0.00 O.OON 0.00 E 5868943.80 N 443913.05 E 0.00 MWD Magnetic 110.00 0.000 0.000 -141.10 110.00 O.OON 0.00 E 5868943.80 N 443913.05 E 0.000 0.00 207.68 0.370 68.640 -43.42 207.68 0.11 N 0.29 E 5868943.91 N 443913.34 E 0.379 -0.06 ~ 290.46 0.560 102.950 39.36 290.46 0.12 N 0.94E 5868943.91 N 443913.99 E 0.397 0.05 383.42 1.640 144.450 132.30 383.40 1.068 2.15 E 5868942.72 N 443915.20 E 1.372 1.43 473.87 3.440 155.840 222.66 473.76 4.59S 4.02 E 5868939.18 N 443917.03 E 2.057 5.24 565.17 5.440 160.160 313.68 564.78 11.168 6.61 E 5868932.59 N 443919.57 E 2.219 12.17 655.18 8.200 162.540 403.04 654.14 21.30 8 9.98 E 5868922.43 N 443922.87 E 3.082 22.75 745.72 10.390 166.810 492.39 743.49 35.41 8 13.78 E 5868908.29 N 443926.57 E 2.534 37.31 835.96 11.900 167.450 580.93 832.03 52.42 8 17.66 E 5868891.25 N 443930.32 E 1.679 54.74 927.14 14.330 170.000 669.72 920.82 72.71 8 21.66 E 5868870.93 N 443934.18 E 2.739 75.42 1016.96 17.810 172.090 756.02 1007.12 97.27 S 25.49 E 5868846.35 N 443937.82 E 3.927 100.27 1108.60 22.300 169.540 842.08 1 093.18 128.268 30.57 E 5868815.31 N 443942.68 E 4.991 131.67 1199.40 25.190 168.870 925.19 1176.29 164.17 8 37.43 E 5868779.36 N 443949.27 E 3.197 168.23 1293.19 26.230 168.500 1009.69 1260.79 204.07 S 45.42 E 5868739.40 N 443956.96 E 1.122 208.91 1383.32 28.030 169.990 1089.90 1341.00 244.44 S 53.07 E 5868698.97 N 443964.32 E 2.135 250.00 1474.04 30.930 169.510 1168.87 1419.97 288.37 8 61.02 E 5868654.99 N 443971.95 E 3.207 294.64 1565.46 33.250 169.660 1246.32 1497.42 336.13 S 69.80 E 5868607.16 N 443980.37 E 2.539 343.21 1659.78 35.550 170.440 1324.13 1575.23 388.62 S 79.00 E 5868554.61 N 443989.18 E 2.483 396.49 1751.49 37.310 171 .550 1397.92 1649.02 442.41 S 87.51 E 5868500.76 N 443997.30 E 2.049 450.93 .~. 1845.10 39.720 171.020 1471.16 1722.26 500.02 S 96.35 E 5868443.08 N 444005.71 E 2.599 509.20 1938.29 42.010 170.650 1541.63 1792.73 560.21 8 106.06 E 5868382.83 N 444014.98 E 2.471 570.15 2030.39 43.820 171.570 1609.08 1860.18 622.168 115.74 E 5868320.80 N 444024.21 E 2.080 632.84 2122.86 48.180 171.080 1673.30 1924.40 687.90 S 125.79 E 5868254.99 N 444033.77 E 4.730 699.31 2216.37 51.890 170.670 1733.35 1984.45 758.65 8 137.16E 5868184.16 N 444044.62 E 3.982 770.95 2309.20 52.630 170.240 1790.17 2041.27 831.04 8 149.33 E 5868111.68 N 444056.26 E 0.877 844.35 2401.96 53.440 170.240 1845.95 2097.05 904.09 S 161.89 E 5868038.55 N 444068.28 E 0.873 918.46 2495.92 53.450 170.820 1901.91 2153.01 978.53 8 174.31 E 5867964.01 N 444080.15 E 0.496 993.93 2588.80 52.820 170.840 1957.63 2208.73 1051.898 186.15 E 5867890.57 N 444091.45 E 0.679 1 068.22 2682.44 53.390 168.380 2013.86 2264.96 1125.548 199.66 E 5867816.82 N 444104.42 E 2.187 1143.1 0 10 January, 2002 - 15:31 Page2of6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 2P-429 Your Ref: API 501032037800 Job No. AKMM11208, Surveyed: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2774.88 53.740 167.790 2068.76 2319.86 1198.31 S 215.02 E 5867743.94 N 444119.24 E 0.638 1217.44 2869.38 53.020 167.620 2125.13 2376.23 1272.42 S 231.17E 5867669.72 N 444134.84 E 0.775 1293.24 2900.33 52.550 168.590 2143.85 2394.95 1296.53 S 236.25 E 5867645.56 N 444139.75 E 2.922 1317.88 2987.63 52.320 168.050 2197.07 2448.17 1364.30 S 250.26 E 5867577.69 N 444153.26 E 0.557 1387.06 3081.56 51.820 168.970 2254.81 2505.91 1436.90 S 265.02 E 5867504.99 N 444167.48 E 0.938 1461.13 3174.46 51.670 168.440 2312.33 2563.43 1508.44 S 279.31 E 5867433.35 N 444181.24 E 0.476 1534.08 3267.06 51.640 168.090 2369.78 2620.88 1579.55 S 294.08 E 5867362.13 N 444195.49 E 0.298 1606.68 3360.26 53.310 168.570 2426.54 2677.64 1651.93 S 309.03 E 5867289.64 N 444209.90 E 1.838 1680.57 3453.01 54.040 169.630 2481.49 2732.59 1725.31 S 323.15 E 5867216.16 N 444223.49 E 1.211 1755.29 3545.63 54.080 170.340 2535.85 2786.95 1799.15 S 336.19 E 5867142.22 N 444235.99 E 0.622 1830.28 3639.61 54.000 170.540 2591.04 2842.14 1874.17 S 348.83 E 5867067.12 N 444248.07 E 0.192 1906.34 3732.68 53.740 170.070 2645.91 2897.01 1948.26 S 36).-.49 E 5866992.93 N 444260.18 E 0.494 1981.51 3825.61 53.700 171.010 2700.90 2952.00 2022.16 S 373.80 E 5866918.95 N 444271.95 E 0.817 2056.41 3918.47 53.740 170.920 2755.85 3006.95 2096.09 S 385.55 E 5866844.93 N 444283.16 E 0.089 2131.25 4011.47 53.370 169.760 2811.10 3062.20 2169.83 S 398.10 E 5866771.09 N 444295.17 E 1.079 2206.05 4102.31 53.230 169.940 2865.39 3116.49 2241.53 S 410.94 E 5866699.31 N 444307.47 E 0.221 2278.88 4195.89 52.840 170.700 2921.66 3172.76 2315.23 S 423.51 E 5866625.51 N 444319.50 E 0.771 2353.65 4289.30 52.490 171.110 2978.31 3229.41 2388.57 S 435.25 E 5866552.09 N 444330.70 E 0.512 2427.90 4381.51 51.910 171.690 3034.83 3285.93 2460.61 S 446.15 E 5866479.97 N 444341.07 E 0.802 2500.73 4472.76 51.110 171.870 3091.62 3342.72 2531.30 S 456.36 E 5866409.21 N 444350.76 E 0.890 2572.1 0 ~. 4566.26 52.860 171.320 3149.20 3400.30 2604.17 S 467.13 E 5866336.26 N 444360.99 E 1.928 2645.71 4659.57 53.090 171.470 3205.39 3456.49 2677.82 S 478.28 E 5866262.53 N 444371.60 E 0.278 2720.18 4752.68 54.330 171.160 3260.50 3511.60 2752.01 S 489.61 E 5866188.26 N 444382.39 E 1.359 2795.19 4845.63 54.010 169.400 3314.91 3566.01 2826.28 S 502.33 E 5866113.89 N 444394.56 E 1.573 2870.54 4935.34 53.270 171.730 3368.10 3619.20 2897.54 S 514.18 E 5866042.55 N 444405.88 E 2.248 2942.77 5031.84 53.300 169.070 3425.80 3676.90 2973.80 S 527.08 E 5865966.20 N 444418.22 E 2.210 3020.10 5125.01 52.550 167.790 3481.97 3733.07 3046.62 S 541.99 E 5865893.27 N 444432.59 E 1.360 3094.42 5216.76 53.540 168.170 3537.13 3788.23 3118.33 S 557.25 E 5865821.45 N 444447.32 E 1.129 3167.71 5309.57 52.910 167.240 3592.69 3843.79 3190.97 S 573.08 E 5865748.70 N 444462.62 E 1.051 3242.00 5401.83 52.450 167.550 3648.62 3899.72 3262.57 S 589.09 E 5865676.98 N 444478.10 E 0.566 3315.32 10 January, 2002 - 15:31 Page 3 of6 DrlllQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 2P-429 Your Ref: AP/501032037BOO Job No. AKMM1120B, Surveyed: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (It) (ft) (ft) (ft) (ft) (It) (0/100ft) 5494.40 51.690 167.760 3705.53 3956.63 3333.908 604.70 E 5865605.54 N 444493.19 E 0.840 3388.29 5587.21 53.030 167.140 3762.20 4013.30 3405.63 S 620.68 E 5865533.69 N 444508.63 E 1.538 3461.73 5680.72 54.300 167.670 3817.61 4068.71 3479.158 637.10 E 5865460.06 N 444524.51 E 1.433 3537.00 5773.32 53.660 167.790 3872.06 4123.16 3552.33 S 653.02 E 5865386.76 N 444539.89 E 0.699 3611.85 ~ 5866.22 53.340 167.430 3927.32 4178.42 3625.27 S 669.04 E 5865313.70 N 444555.37 E 0.464 3686.48 5959.98 52.890 169.210 3983.60 4234.70 3698.70 8 684.22 E 5865240.16 N 444570.02 E 1.592 3761.45 6052.77 52.450 169.150 4039.87 4290.97 3771.17 8 698. 07 E 5865167.59 N 444583.33 E 0.477 3835.23 6144.59 53.920 169.440 4094.89 4345.99 3843.40 S 711.73 E 5865095.26 N 444596.45 E 1.621 3908.74 6238.61 53.840 171.200 4150.31 4401.41 3918.26 S 724.50 E 5865020.31 N 444608.67 E 1.514 3984.67 6331.29 54.850 169.340 4204.34 4455.44 3992.48 8 737.23 E 5864946.00 N 444620.86 E 1.961 4059.97 6424.28 54.230 169.030 4258.29 4509.39 4066.87 8 751.44 E 5864871 .50 N 444634.52 E 0.720 4135.71 6516.89 53.380 168.780 4312.98 4564.08 4140.21 8 765.82 E 5864798.06 N 444648.36 E 0.943 4210.44 6609.80 52.690 168.770 4368.84 4619.94 4213.038 780.27 E 5864725.14 N 444662.28 E 0.743 4284.67 6702.67 52.010 168.460 4425.57 4676.67 4285.11 8 794.79 E 5864652.95 N 444676.26 E 0.778 4358.18 6796.15 53.070 169.060 4482.43 4733.53 4357.898 809.25 E 5864580.07 N 444690.18 E 1.243 4432.38 6888.97 55.050 168.190 4536.91 4788.01 4431.56 S 824.07 E 5864506.29 N 444704.47 E 2.264 4507.51 6981.11 54.260 167.820 4590.21 4841.31 4505.07 S 839.69 E 5864432.66 N 444719.55 E 0.918 4582.64 7073.63 53.920 171.090 4644.48 4895.58 4578.738 853.41 E 5864358.91 N 444732.72 E 2.886 4657.55 7166.93 53.480 169.980 4699.72 4950.82 4652.89 S 865.77 E 5864284.66 N 444744.53 E 1.069 4732.74 7259.75 52.750 171.480 4755.43 5006.53 4726.168 877.73 E 5864211.30 N 444755.96 E 1.513 4806.96 7351. 62 53.860 171.610 4810.33 5061.43 4799.02 8 888.56 E 5864138.36 N 444766.25 E 1.214 4880.58 7444.74 53.750 172.190 4865.32 5116.42 4873.42 8 899.15 E 5864063.89 N 444776.29 E 0.516 4955.67 7539.23 53.350 171.410 4921.46 5172.56 4948.65 8 909.99 E 5863988.58 N 444786.58 E 0.787 5031.62 7631.81 52.770 170.730 4977.10 5228.20 5021.75 S 921.48 E 5863915.40 N 444797.52 E 0.859 5105.59 7724.75 52.370 171.200 5033.58 5284.68 5094.63 8 933.07 E 5863842.43 N 444808.58 E 0.589 5179.37 7816.61 53.370 171.440 5089.03 5340.13 5167.038 944.12 E 5863769.96 N 444819.09 E 1.1 08 5252.58 7906.21 54.350 171.980 5141.87 5392.97 5238.63 S 954.55 E 5863698.28 N 444829.00 E 1.197 5324.89 8003.10 54.320 171.520 5198.37 5449.47 5316.548 965.84 E 5863620.30 N 444839.72 E 0.387 5403.55 8096.16 54.760 169.780 5252.36 5503.46 5391.32 8 978.16 E 5863545.42 N 444851 .48 E 1.595 5479.33 8189.46 54.900 171.090 5306.10 5557.20 5466.53 S 990.83 E 5863470.12 N 444863.60 E 1.158 5555.59 10 January, 2002 - 15:31 Page 4 of 6 DrillQuest 2.00.09.003 . . Sperry-Sun Drilling Services . Survey Report for 2P-429 Your Ref: AP/501032037BOO Job No. AKMM1120B, Surveyed: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8282.71 54.870 170.620 5359.74 5610.84 5541.84 S 1002.96 E 5863394.73 N 444875.17 E 0.414 5631.85 8375.59 55.010 169.840 5413.09 5664.19 5616.76 S 1015.86 E 5863319.71 N 444887.52 E 0.704 5707.87 8468.70 55.200 171 .200 5466.36 5717.46 5692.08 S 1028.43 E 5863244.30 N 444899.54 E 1.215 5784.23 .~ 8561.36 55.550 171.040 5519.01 5770.11 5767.42 S 1040.21 E 5863168.88 N 444910.76 E 0.404 5860.45 8654.19 55.720 171.950 5571 .41 5822.51 5843.20 S 1051.54 E 5863093.01 N 444921.53 E 0.830 5937.04 8745.19 55.880 171.570 5622.56 5873.66 5917.69 S 1062.32 E 5863018.45 N 444931.77 E 0.388 6012.25 8840.00 56.000 171 .480 5675.66 5926.76 5995.38 S 1073.90 E 5862940.68 N 444942.77 E 0.149 6090.75 8902.57 56.090 173.500 5710.61 5961.71 6046.83 S 1080.68 E 5862889.18 N 444949.18 E 2.682 6142.58 8974.00 56.090 173.500 5750.46 6001.56 6105.73 S 1087.39 E 5862830.23 N 444955.45 E 0.000 6201.73 Project Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.368° (07-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 169.630° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8974.00ft., The Bottom Hole Displacement is 6201.80ft., in the Direction of 169.902° (True). Comments ~, Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8974.00 6001.56 6105.73 S 1087.39 E Project Survey 10 January, 2002 - 15:31 PageS of6 DrlllQuest 2.00.09.003 . ~ ~ <f!t Kuparuk River Unit Survey tool program for 2P-429 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 10 January, 2002 - 15:31 To Measured Vertical Depth Depth (ft) (ft) 8974.00 Sperry-Sun Drilling Services Survey Report for 2P-429 Your Ref: API501032037BOO Job No. AKMM1120B, Surveyed: 17 December, 2001 . North Slope, Alaska Kuparuk 2P Survey Tool Description 6001.56 MWD Magnetic ~. Page60f6 DrillQuest 2.00.09.003 Individual Well Report Subject Date 2P-417 1/15/2002 Start Time i8:10:01 AM 18:14:31 AM I End Time Category IComPletion Report ¡Phone Sharon Allsup-Drake of Phillips about apparent discrepancy in surface location for IKRU 2P-417 well between surface location recorded on the permit to drill application and the location reported on the Completion Report.. I Description Notes Sharon: Their surveyors, Lounsbury, noticed a "shift" in the Isurface locations of the wells on the KRU 2P-Pad. She will fax me the revised locations and will find out the cause of this "shift" in locations from Lounsbury. 9:10AM: received fax containing well locations from Sharon. Follow-Up Tasks Phone Sharon Allsup-Drake. Find out what caused the "shift" in the surface locations for the KRU 2P-Pad. Primary File Path Primary File Name Secondary File Path Secondary File Name TUeSday,. .J,. ~n.........a.....ry....l.5....'. 2002 ~} " ..//".... . - Page 1 ofl ~ SENT BY: 1-15- 2 ; 9:09AM ; PHILLIPS AK INC-~ ;# 1/ 2 Phone: 263-4612 ARca Alaska, Inci Fax u.;eJ) J;þ¿ J ;)0 ( -- \ 0 ~ To: Mr. Steve Davies Ftom: Shar~n AII~up-Drak~ Fax: 9-907-276-7542 D."; January 15, 2002 . . Phone: 793-1224 P8gøs: 1 He: 2PJ~~~._!?œtion~ cc: D U'1l.nt 0 For Review 0 PI_. Comment [J P'esse Reply tJ PI..ee Recyeht -Comments: Mr. Davies: Here. is the surface locations for the Mettwater wells as requested. If you have any ques1ions, plea$e feel free to call me at 263-4612. Thank$, Sharon RECE\VEO ¡¡1 r.;.? . ~.".¡¡ Ge ~ GØ1.-r' ~Oit&~. SENT BY: REV' . OME ay .. Co!< ,~r~ 1 I'J Ie /~.I MRT GG 1-15- 2 ; 9:09AM ; APP f' OESCRÏP!lQN .'~RA( ..'CR KØ11fl2ACS . . -~.~ . ,.-. N.OlES 1. COORDJNATES SHOWN ARE AI ASKA S fA rE PLANE, NAO 27. ZONE 4. . 2. ALL ELEVATIONS Si IOWN ARt BRITISH PETROLfUM MEAN seA lEVEL 3. ALL D1STANCrs ARE lRUE". 4. GEOGRAPHIC COORDJNA TF. $ SHOWN ARE NAb 27, 5. DRIll SIlC 2P' NOIHH IS ROTATED 1.5.øø'øø" WEST FROM GRID NUt-< I~I, . 6. OATE OF SUR'vE..Y. 11/8/Ø1, Fß Lf1I-63. Pp. /Ø-21. I. REFFRENCE DRAWING CEA-D2PX-6216D<1 Fon WEll CONDUCTORS 415. 417, 420, 4/4, 427, 429. 434, 4,38, -14.7, &: 449. PHILLIPS AK INC~ RËV . ..OA"I'E BY ( . APÞ'" ;# 2/ 2 '¡"'~~.P\ïÕÑ - .~=-=- . $URV~'yO~/S ÇERTlf/CI\ TE I HfREBY CERTIFY THAT I AM PROPERL Y R(fiIST£R£/) AND LICENSED TO PRACTICE LAND SURV£Y''''G IN THE SiATE OF ALASKA ANO THAT THIS PLAT REPRêSENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL OIMcN$IONS AND OTHER DéTAILS ARE CORk~CT AS OF NOVEMB£" 10, 2001. ~~_.""-., ..~ \é. CF A¿ --, .~ ~\ "".""'''''.'. 4. () '.~ . I; "\. r ~..,.. ..... 0L-.. " 0.~.'0" .\:1' t.. .-"t... ..~..' : ~f 49th \~, # ........ . . fM'Ie._. i ill .--... '-II".!"..-II --~~ .æ(ll 1,'"21 .." N J. ROOKUS l ~ III ;ro 'to ~. ~ ~ " LS ~. 5 ...- . t.:~. ........)~ 'J..'.~~ ~.' . ., ,l~i ~~ .. ~-.., -t~, rON~L ';.,.... .-.,~,..c , Sec. 17. T.8N'j R.7E.; U.M.; AK. . Well No. 'y' A.S.P.s 'X' LA TITUDE .---1.-'" --~._' -_..,- -... 415 ' -Þ,~69.ØØ6~" 4~,4,185.88: ,.. -;Ø" ~.~' Ø9.9~J", LONGITUDE SEC. stC.-' PAD' ,cO.G. ~'ã, ~~~... ELEV. ELEV, .F.N.L F. W.L ..-"".. -"._.'~- . ,,-". .-.'" .... u 15~: 26' 4'7.976" ~69' 22~.~:~ 224.0~'..z1É.:1L~ ,1.17 5,~S8.997..91. ' 44+,146.~L. "!ø. ø.3''''-~9,892''... 15Ø'''2~' 49.Ø9~" ä78'.. 218'7' ?24.Q(2J~:~r. 1,50' 26' '.~~:77BH' . .ë šF"2i 28' 224~:Ø' 216.7','. ,420 ., 5,868,984.:3Ø ". 4:41.øà8.4~ 7Ø' 01' '''9''~5~H , ,of ',...-'"' .""'.-' -."., n.._"" ...-"", _:42.~ 5,a~8.966.26~¡4.Ø1Ø"~ ..'70' ø~' ~9.571~ ,"- 1Sø<)e' 53.Ø22"" 910'., 2flJsë;" 224.S" 216.7' . " ""'~ 7~., 03' Ø9,.:434" - 'j 5Ø. .26' ~4.1Ø1"'., 924'" ",1.992' . 2~4.Ø 216~~~.~ 427 ". 5,868.~5~. 7B ' 4.~3,952,Ø,~ .429 ~t~68,943.~Ø 443,S13.Ø5 ",.. ¡eO Ø3' '09.3<43" 15Ø~ 26' 55.822" 934' 1953'- 224.i~ .21.7.2'" ... -.-f~1, 51868~9J4. 79 , - 44J,a?~~~ 70' Ø3 Ø9"252" '150"' 26' 5S:943H '-g¡J' 1914' . 22-4-.I/J' 217.6' ..1,34. 5,8~8,921.42.. 443,81?42 irr øJ.: ~9, 116".,' - 15'" 2a' 56.6.3ØÌt 957' 1a55'.'j~<4,.ø' 1~_~.2 ..----" 438. 5;a6~~~fJ3.23 '~3Ii3?66 ., _7O,: 8.3" Ø~:9J1"- -...-'... ""-"--.. .,. ..._~.._..,. .- ,,,...-..., 15Ø."Z1' 00.666"'. 975'" 17i8'-~24.Ø".'-?J8.:5' ... ....'--'-' 447. 5,86~la62.91 '-, 443.56~.37 ...".. ----n=-øj' 08,522" '~---;S'". 27' JZl5.9ør ~i' 16ØJ". 224.Ø' 219,5"- '., 44a 5.868.858.45 44J,542.95 7Ø. øJ' Øð.~77" . 151' 27' 06.466" 1122' 1583'" 224.e" 219.5' "449 ", ),a68.8SJ.67 44~t?23.29. .,." 7Ø~, øJ' 08.428". 1'5~~. 2.7ï' Ø7.Ø~J" . !Ø~6' ï'~....,~ 22"'.:!!-21à:6" I .. INDJCA TES CONDUCTORS AS-BUlL T THIS SURVEY. .., " . , . " . I: IÙs ~. . . . ' " AREA; 2P fd ru!;~~!~LI~I!!-~~~, r.!D~y MOOULE: xxxx DS2P WELL CONDUCTOR ASBUIL T LOCATIONS CEA--D2PX-6216D25 J sHm:"2 ~'~"'~'REV:'"~""'" -. .... . .- - '".01 .."..."-,",.."",...".",~,:,,..,-,... ."", CAOD FILE No. LK621 ~d25 11/18 /81 I ÖR~WI"G.. NO: . \JÑIT:'-02" ( 1.111 fl..11 WELL: 2P-429 DATE: 12/11/01 1 OF 1 PAGES LENGTH DEPTH TOPS Casing Detail 9 5/8" surface casinq PHilliPS Alaska, Inc. ( I ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 141 RT to LDS = 28.40' Above Rotary 6.80' RKB to LR 9 5/8" Landing Joint (35.20 total) Hanger 9 5/8" FMC GEN IV FLUTED MANDREL HANGER Jts 49-72 9 5/811, 40# L -80 STCM Port Collar Jts 3-48 9 5/8", 40# L -80 STCM Gemeco Float Collar Jts 1-2 95/8",40# L-80 STCM Gemeco Float Shoe BTM OF SHOE @-----»»> TD 12 1/411 Hole CSg Hanger goes in the top of Joint # 72 ( 12 TOTAL, Gemeco Bow Spring Centralizers - 3 Stop Rings 3- Centralizers in center of jts.1, 2 & 3 over stop rings 9 - Centralizers over collars of jts,4-12 ** Fill using "Franks" fill tool - Remove tool after Circu & Condition ** Baker Lok all connections from the Top of FC down *Monitor returns closely.MUSH HAVE FULL RETURNS-Stop if NOT ** Remove air from slips for first 10 jts II Torque first 10 and average-Torque to AVG - Watch Diamonds 28.40 1.23 977.30 2.93 1875.92 1.53 75.76 1.72 29721 28.40 29.63 1006.93 1009.86 2885.78 2887.31 2963.07 2964.79 ( Remarks: String Weights with Blocks: 135k Up, 75k On, 34k TO & Blocks. Ran 72 joints of casing. Drifted casing with 8.679" plastic rabbit. Use Jet Lube Lead free thread compound on all connections. Doyon 141 Drilling Supervisor: Dearl W. Gladden ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,965 (ft) 12/11/2001 Surface Casing 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: Spud Date: 12/8/2001 1 Report Date: 12/11/2001 12/6/2001 End: 12/20/2001 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Don Zierke Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: Reciprocating Rot Time Start: : Time End:: RPM: Init Torque: (ft-Ibf) Rec Time Start: 1 0:00 Time End: 23:58 SPM: 60 Stroke Length: 5.0 (ft) ( Type: Cement Casing Volume Excess %: 450.00 Meas. From: Time Circ Prior To Cementing: 10.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 80 (psi) Avg Torque: (ft-Ibf) Drag Up: 135 (Ibs) Stage No: 1 of 1 Start Mix Cmt: 21 :32 Start Slurry Displ: : Start Displ: 01 :00 End Pumping: 01 :30 End Pump Date: 12/12/2001 Top Plug: Y Bottom Plug: Y Type: KCL Polymer Density: 9.7 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature:70 (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Rig Tank Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 474 (psi) 383 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: 75 (Ibs) Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: 145.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: PVNP: 13 (cp)/15 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 215.90 (bbl) Mud Data Stage No: 1 Slurry No: 1 of 2 Description: AS Lite Class: G To: 1,525.00 (ft) Cmt Vol: 443.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Slurry Vol561 (sk) Water Vol: 276.0 (bbl) Other Vol: 0 Purpose: Mix Water: (gal) Foam Job: N Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) ( Temperature:72 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/9/2003 12:04:56 PM ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/8/2001 1 Report Date: 12/11/2001 12/6/2001 End: 12/20/2001 Stage No: 1 Slurry No: 1. of 2- Additives Trade Name Type Concentration 1.50 1.50 0.60 0.50 50.00 30.00 Units Liquid Conc. Units D079 S001 D046 D065 D124 D053 Stage No: 1 Slurry No: 2 of 2 Slurry Data Fluid Type: TAIL Description: LiteCRETE Class: Slurry Interval: 1,525.00 (ft}To: 2,465.00 (ft) Cmt Vol: 134.4 (bbl) Density: 11.60 (ppg) Yield: 2.39 (ft3/sk) Water Source: Rig Tank Slurry Vol:303 (sk) Water Vol: 58.0 (bbl) Other Vol: 0 Purpose: Mix Water: 8.12 (gal) Foam Job: N ( Test Data Thickening Time: 5.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: 72 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: 12.10 Compressive Strength 2: 15.00 Temp 72 (OF) 72 (OF) Pressure 500 (psi) 1 ,400 (psi) (OF) Stage No: 1 Slurry No: 2 of 2 - Additives Trade Name Type Concentration Units Liquid Conc. Units 0046 S001 0.20 1.00 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) H rs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ( Printed: 6/9/2003 12:04:56 PM ( ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/8/2001 1 Report Date: 12/11/2001 12/6/2001 End: 12/20/2001 Remarks Could only recip csg 5' . Drained stack to ck if hanger was centered. It appeared "OK". After measuring and looking things over it is suppected that the collar on Jt #3 was hanging up on the end of the conductor. Informed eng & Team leader. Also could never get Tail CMT up th weight. Was planned for 12.0# and it could only be mixed to 11.6 or 11.7 and then would flobber(turn to non-fluid)in the tub. After talking to Dowell lab tech (Perry)& well eng(Pat. R)& Team leader( Randy T), it was decided to go ahead and complete the CMT job. ( ( Printed: 6/9/2003 12:04: 56 PM 24 HR FORECAST N/U & Test BOPs - P/U BHA #2 - TIH - Drlg Out LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 12/10/2001 2,900.33 52.550 168.590 (in) @ (ft) DENSITY(ppg) I 9.70 I.pp I I EeD I I MUD DAtA I DÀILvCOST I FV PVNP GELS WUHTHP FCmSOL OILJWAT O/oSsÏ'ldlMBT Ph/pM 41 13/15 5/7 7.51 / / 18.5 9.31 ( WELL NAME 2P-429 SUPERVISOR I RIG NAME & NO. Dearl W. Gladden Doyon 141 CURRENT STATUS N/U BOPs FROM TO 00:00 03:00 03:00 04:30 04:30 10:00 HOURS 3.00 1.50 5.50 CODE DRILL P CASE P CASE P TROUBLE SUB PULD RURD RUNC 10:00 20:00 10.00 CEMENT Nf))H CIRC ( 20:00 21 :00 1.00 CEMENT P SFTY 21 :00 21 :30 0.50 CEMENT P 21 :30 00:00 2.50 CEMENT P CIRC PUMP CODE 124 HRS PROG ODR I FIELD NAME I OCS NO. Meltwater ACCIDENTS LAST 24 HRS.? TMD I TVD I DFS 2,972.0 2,438.0 5.00 AUTH MD I DAILY TAN~ DAILY INT W/O MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 12/11/2001 306,047 LEAKOFF AFE AK0187 I NEXT CASING 9.625 (in) @ 2,965.0 (ft) 0 ¡CUM cosrl 0 PflMf CI Cs H2S LIME ES / NO. 6 ¡CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 890,843 1/2001 AUTH. 2,661,570 LAST BOP PRES TEST OPERA1lBNSSUMMARY PHA$E , SURFAC UD BHA #1 - SIB HWDP SURFAC R/U to Run 9 5/8" 40# L-80 BTCM Csg SURFAC Run 9 5/8" Csg per well plan - Ran 72 jts - Shoe @ 2965' MD (2435' TVD) Tight f I 2160' - 2365' SURFAC Circu & Condition Mud for CMT - Staged circu up to 6 bpm - No losses- Running 40 BPH water - Condition Mud per well plan specs - Properties at start: Wt 9.9+ppg, Vis 54 , PV 18 , YP 28 , Gels 10/20/21 Final properties: Wt 9.7ppg , Vis 41 , PV 13, YP 15 , Gels 5/7/9 **Note** Only able to recip 5' - We drained diverter and made sure csg hanger was centered "OK" It was- After checking figures it appears Csg collar on #3 jt hanging up on bttm of conductor. SURFAC PJSM with Rig Crew & all contractors - CIO Franks fill tool- M/U Dowell CMT head SURFAC Re-establish circu wI CMT head SURFAC CMT per well plan - Pump 5 bbl CW1 00 - Test CMT lines to 3500 psi - Con't pump 35 bbls CW1 00 @ 8.4ppg , Drop Bttm plug, pump 50 bbl MudPUSH @ 10.2ppg, pumped 443 bbls Lead CMT (561 sxs), 128 bbls Tail CMT @ 11.5 to 11.7 ppg, Drop Top plug, pump 10 bbl wash up, Turn over to rig. Rig will displace w/2071 stks(Calulated) **NOTE** We were unable to mix the Tail to pre posed 12.0ppg ,it Avg'd 11.6ppg . Talked to Dowell eng & Team Leader. It was decided to con't and complete the CMT pumping. Dowell lab engineer(Perry) advised that the loss on compressive strength would be minimal. 24 HR SUMMARY: Run 9 5/8" Csg- Circu & Condition - CMT Csg COMPANY Phillips Doyon SERVICE ITEM UNITS bbls bbls USAGE 1,441 1,025 ( Fuel Water, Drilling PERSONNEL DATA NO. HOURS COMPANY 1 Misc Personnel 31 Service Personnel SERVICE NO. HOURS 5 12 MATERIALS I CONSUMPTION ON HAND ITEM 4,673 Water, Potable 160 UNITS bbls USAGE 100 ON HAND 132 Printed: 6/9/2003 12:22:56 PM ( WELL NAME TYPE 2P-438 3R-11 RESERVOIR NAME 2P-438 3R-11 DS 4 G&I ( ( 2P-429 NO. 673 2P-429 2P-429 2P-429 2P-429 2P-429 ( I JOB NUMBER REMARKS SUPPORT CRAFT TYPE DS 4 G&I 2P-429 NO. REMARKS RESERVOIR AND INTERVAL. DATA ZONE TOP BASE. 673 2.5 900-1050 0 0 COMMENTS Printed: 6/9/2003 12:22:56 PM TMD I DFS 2,972.0 2,438.0 6.00 AUTH MD IDAlLYTAN~ DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 12/12/2001 87,726 I LEAKOFF AFE AUTH. AK0187 2,661,570 I NEXT CASING LAST BOP PRES TEST 7.000 (in) @ 8,821.0 (ft) 12/12/2001 0 I>CUMëoST I 0 PfIMf CI Ca H2S LIME. ES I ( Phillips Alaska, Inc. WELL NAME 2P-429 SUPERVISOR I RIG NAME & NO. Dearl W. Gladden Doyon 141 CURRENT STATUS Dir Orlg & Slide @ 3265' 24 HR FORECAST Drlg - WiperTrip as needed - Drlg LITHOLOGY I JAR HRS OF SERVICE ¡BHA HRS SINCE INSP LAST SURVEY; DATE TMD INC AZIM I LAST CASING 12/10/2001 2,900.33 52.550 168.590 9.625 (in) @ 2,965.0 (ft) . DENSITY(ppg) ~ 9.60 Ipp I ECD I MOD D.ATAIDAII-rë()STj FV ÞVNp. GELS WLlHTHP FClT.SOL OILlWAT %SandlMBT Ph/pM 42 13/15 6124 9.0/ / I 18.5 12.01 BHANO. 2 BHA WT. BELOW JARS 51 BHA I HOLE CONDITIONS STRING WT. ON STRING WT. ROT 100 98 NO JTS LENGTH 0.75 1.15 31.55 5.15 27.49 9.02 23.52 11.88 30.45 30.85 30.82 2.16 90.65 32.32 785.60 STRING WT. UP 110 ITEM DESCRIPTION ( Bit STB Turbo Back Navidrill 1 XL Stabilizer - Non Mag MWD MWO MWD Neutron sub Sub - Hang Off 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 BIT I RUN 21 BITS TYPE SERIAL NO. JETS OR TFA S88HPX JS4314 12/12/12/12/12/11 2 SIZE MANUF. 8.500 SMITH I REPT ~O. I CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 978,569 0.0. 8.500 8.560 6.750 6.000 6.750 6.690 6.750 6.810 6.500 6.560 6.560 6.500 6.500 6.500 6.500 TORQUE I UNITS 6,500 ft-Ibf 1.0. I BIT NO. I 2 BHALENGTH 1,113.36 CONN SIZE CONN TYPE 1.750 2.750 1.920 1.920 1.920 2.750 2.750 2.750 2.750 3.000 2.250 3.000 DEPTH IN DATE IN I-O-D-L-B-G-O-R 2,972.0 12/12/2001 2-1-CT-N-D--EC-TD BIT I RUN WOB BIT OPERATIONS RPM I GPM PRESS I P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01 :30 1.50 CEMENT P DISP SURFAC Con't to displace CMT - Bump plug @ 2039 stks (Calculated 2071 stks) Fits held - CI P 01 :30 hrs (For CMT & pump detail see Report #6 12/11/01) 01 :30 03:00 1.50 CEMENT P PULD SURFAC RID CMT Equip - UD LJ 03:00 05:00 2.00 WELCTL P NUND SURFAC N/D Diverter System 05:00 06:00 1.00 WELCTL P NUND PROD N/U Csg Head & Test to 1000 psi - hold 10 min 06:00 10:00 4.00 WELCTL P NUND PROD N/U 135/8" 5K BOPs - Change bttm pipe rams to 5" -( 31/2" X 6" VBRs in Top Rams) ( 10:00 11:00 1.00 WELCTL P NUNO PROD Remove equip from floor - C/O TD bails 11:00 12:00 1.00 WELCTL P BOPE PROD R/U to test BOPs Printed: 6/9/2003 12:23:29 PM ( ( WELL NAME 2P-429 TMD 2,972.0 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 12:00 15:30 3.50 WELCTL P BOPE PROD DESCRIPTION Test BOPs & Choke Manif 250psi 10 & 3000 psi High. Ea. test held 5 Min. No failures Pull test plug - Set wear bushing - Blow dn choke manifold P/U BHA #2 tools to Rig floor - PJSM on RA scorces M/U BHA #2 - P/U Bit, TurboBack Stb, re-configure to 1.0 AKO & Scribe M/U Sperry Tools - Program MWD - Load RA Scorces P/U 3 NMDCs & TIH - Rotate Slowly thru port collar @ 1006' - Tag up @ 2884' R/U to test Csg - Circu air from system - Test Csg to 2500' psi - Pump 12 stks - Hold on Chart 30 min - (Loss 35 psi) Drlg Plugs, FC , CMT & Drilling on FS 24 HR SUMMARY: Finish CMT displ- NID N/U - Test BOPs - P/U BHA - TIH - Drlg out 15:30 16:00 0.50 WELCTL P BOPE PROD 16:00 17:00 1.00 DRILL P PULD PROD 17:00 18:00 1.00 DRILL P PULD PROD 18:00 20:00 2.00 DRILL P PULD PROD 20:00 21 :30 1.50 DRILL P PULD PROD 21 :30 22:30 1.00 WELLSR P DEQT PROD 22:30 00:00 1.50 DRILL P DRLG PROD COMPANY Phillips Doyon SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 Misc Personnel 30 Service Personnel SERVICE NO. 5 9 HOURS ITEM , UNITS bbls bbls USAGE 1,338 645 . MATERIALSJC0NSUMP"f10N . Ø:NHAND. ' ITEM . .. . . 3,335 Water, Potable 315 UNITS bbls USAGE 100 ON HAND 132 ( Fuel Water, Drilling 2P-438 3R-11 1 ,228 2P-429 2P-429 DS 4 G&I 2P-429 RESERVOIR NAME 2P-438 3R-11 DS 4 G&I 2P-429 2P-429 2P-429 RESERVOIR AND INTERVAL DATA WNE rop BAæ 1228 3 1000 0 0 COMMENTS ( Printed: 6/9/2003 12:23:29 PM (' Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS I REPT NO. I DATE 2P-429 ODR 1,728.0 4,700.0 3,481.0 7.00 8 12/13/2001 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANGO I CUM. TANGO Dear W. Gladden Doyon 141 Meltwater CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD Wiper Trip to Shoe - Serv Rig & TD (TD 5009' MD) 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Complete WT - Drlg t/ 7000'- - WT 12/13/2001 116,971 1,095,541 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOF~ 6.01 AFE AK0187 AUTH. 2,661,570 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 12/13/2001 4,566.26 52.860 171.320 9.625 (in) @ 2,965.0 (ft) 7.000 (in) @ 8,821.0 (ft) 12/12/2001 DENSITY(Ppg)] 9.60 I PP I IECD IMUD DATAl DAILY COST I 0 I CUM COST I 0 FV PVNP GELS WUHTHP FCIT.SOL OIUWAT %SandlMBT Ph/pM PflMf CI Ca H2S UME ES 48 15/18 6/20 4.2/ / / /8.0 9.3/ / WELL NAME BHANO. I 2 BHA WT. BELOW JARS 15 BHA I HOLE CONDITIONS STRING WT. ON STRING WT. ROT 98 112 NO JTS LENGTH 0.75 1.15 31.55 5.15 27.49 9.02 23.52 11.88 30.45 30.85 30.82 2.16 90.65 32.32 785.60 STRING WT. UP 132 ITEM DESCRIPTION Bit STB Turbo Back Navidrill 1 XL Stabilizer - NonMag MWD MWD MWD Neutron sub Sub - Hang Off 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 BIT / RUN 2/ BITS TYPE SERIAL NO. JETS OR TFA S88HPX JS4314 12/12/12/12/12/11 2 SIZE MANUF. 8.500 SMITH BIT / RUN 2/ BIT OPERATIONS PRESS P BIT HRS 1,750 388 15.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 1,728.0 115.20 15.00 1,728.0 115.20 WOB 5/20 RPM GPM 60 1100 550 2 M.D. 2,987.63 3,081.56 3,174.46 3,267.06 3,360.26 3,453.02 3,545.63 3,639.61 3,732.68 SURVEY DATA T.V.D. NIS CUM EN[ CUM SECTION M.D. 2,448.17 -1,364.3 250.26 1,387.07 3,825.61 2,505.90 -1,436.9 265.02 1,461.14 3,918.47 2,563.43 -1,508.4 279.31 1,534.08 4,011.47 2,620.87 -1,579.5 294.08 1,606.69 4,102.31 2,677.64 -1,651.9 309.03 1,680.58 4,195.89 2,732.59 -1,725.3 323.16 1,755.31 4,289.30 2,786.95 -1,799.1 336.20 1,830.29 4,381.51 2,842.13 -1,874.1 348.83 1,906.35 4,472.76 2,897.01 -1,948.2 361.49 1,981.52 4,566.26 INCL. 53.700 53.740 53.370 53.230 52.840 52.490 51.910 51.110 52.860 INCL. 52.320 51.820 51.670 51.640 53.310 54.040 54.080 54.000 53.740 AZIMUTH 168.050 168.970 168.440 168.090 168.570 169.630 170.340 170.540 170.070 0.0. 8.500 8.560 6.750 6.000 6.750 6.690 6.750 6.810 6.500 6.560 6.560 6.500 6.500 6.500 6.500 TORQUE/UNITS 6,000 ft-Ibf 1.0. ! BIT NO. I 2 BHALENGTH 1,113.36 CONN SIZE CONN TYPE 1.750 2.750 1.920 1.920 1.920 2.750 2.750 2.750 2.750 3.000 2.250 3.000 DEPTH IN DATE IN I-O-O-L-B-G-Q-R 2,972.0 12/12/2001 2-1-CT-N-D-I-EC-TD AZIMUTH T.V.D. N/S CUM EN[ CUM SECTION 171.010 2,952.00 -2,022.1 373.80 2,056.42 170.920 3,006.95 -2,096.0 385.56 2,131.26 169.760 3,062.20 -2,169.8 398.11 2,206.06 169.940 3,116.48 -2,241.5 410.94 2,278.89 170.700 3,172.76 -2,315.2 423.52 2,353.66 171.110 3,229.41 -2,388.5 435.26 2,427.91 171.690 3,285.92 -2,460.6 446.15 2,500.73 171.870 3,342.72 -2,531.3 456.37 2,572.11 171.320 3,400.30 -2,604.1 467.14 2,645.72 Printed: 11/7/2003 1:44:46 PM Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 1,728.0 4,700.0 WELL NAME 2P-429 Page 2 of 2 I TVD I DFS I REPT NO. I DATE 3,481.0 7.00 8 12/13/2001 NO. 1 2 PUMP I HYDRAUUC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 12.000 6.000 65 274.96 1,820 549.92 12.000 6.000 65 274.96 1,820 549.92 KILL SPM I PRESSURE 45 380 MAKE OF PUMP Emsco Emsco OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 00:00 00:30 0.50 DRILL P DRLG PROD 00:30 01 :30 1.00 DRILL P CIRC PROD 01 :30 02:00 0.50 DRILL P LOT PROD 02:00 05:00 3.00 DRILL P DRLG PROD 05:00 06:00 1.00 DRILL P OTHR PROD 06:00 12:00 6.00 DRILL P DRLG PROD 12:00 00:00 12.00 DRILL P DRLG PROD 24 HR SUMMARY: Dir Drlg & Slide DESCRIPTION Drlg FC & 30' new hole to 3002' Circu hole clean - Displace New conditioned 9.6 ppg mud into system.(Blended the last 278 bbls of new mud into our system) Pull back to shoe - Preform LOT to 16 EMW - (818 psi @ surface, 2458'TVD w/ 9.6ppg Mud) PSI loss to 670 psi after 10 min Dir Drlg & Slide 3002' to 3246' MD Sperry Sun Preform & record PWD Base line test - ECD hardline 11.7 @ 3200 to 11.9ppg @ 9000' Dir Drlg & Slide 3246' to 3860' MD (2972' TVD) ART 6.2 hrs , AST 0.5 hrs Dir Drlg & Slide 3860' to 4700' MD (3481' TVD) ART 8.3 hrs , AST 0.5 hrs COMPANY ConocoPhillips Company Doyon PERSONNEL DATA NO. HOURS COMPANY 1 Misc Personnel 31 Service Personnel NO. 5 8 SERVICE SERVICE HOURS ITEM USAGE 1,558 860 MATERIALS I CONSUMPTION ON HAND ITEM 1,777 Water, Potable 255 ON HAND 112 UNITS bbls bbls Fuel Water, Drilling TYPE 2P-438 3R-11 NO. 1,061 2P-429 2P-429 REMARKS UNITS bbls USAGE 120 SUPPORT CRAFT TYPE DS 4 G&I NO. REMARKS 2P-429 RESERVOIR NAME 2P-438 3R-11 DS 4 G&I RESERVOIR AND INTERVAL DATA ZONE TOP BASE 1061 2.5 850 - 1000 0 0 2P-429 2P-429 2P-429 COMMENTS Printed: 11nt2003 1:44:46 PM ~, ~ -~ ConocoPhillips Alaska Casing Report Page 1 of 2 Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: 2 Start: 12/6/2001 Spud Date: 12/8/2001 Report Date: 12/18/2001 End: 12/20/2001 General Information String Type: Production Casing Hole TVD; 6,002.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 4.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Rotary Table 0.00 (ft) (ft) (bbl) Hole Size: Water TMD; Liner Overlap: KB to Cutoff: 8.500 (in) (ft) (ft) 25.55 (ft) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 8,974.0 (ft) 190,000 (Ibs) 54.00 (°) 12.00 (days) Casing Flange I Wellhead Manufacturer: Hanger Model: FMC Model: Packoff Model: Gen 4/5 Top Hub/Flange: (in) / 5,000 (psi) BTM Hub/Flange: (in) / 5,000 (psi) Actual TMD Set: 8,966.17 (ft) Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer Model Condo Max OD Min ID Compo Name (in.) (Ib/ft) (in) (ft) (ft) (ft-Ibf) (in) (in) Casing Hanger w/pup 7.000 6.151 1 1.78 25.55 FMC Gen. 5 NEW 6.276 7" CASING - PRODUCTI 7.000 26.00 L-80 6.151 BTC Mod 179 7,580.47 27.33 Local NEW 7.658 6.276 7" CASING - PUP JT 7.000 26.00 L-80 6.151 BTC Mod 1 9.73 7,607.80 Local NEW 7.656 6.276 CROSS OVER - locator 7.000 4.750 BTC Mod 1 1.03 7,617.53 BAKER NEW 7.656 4.750 SEAL BORE EXTENSIO 7.000 4.750 1 19.23 7,618.56 BAKER NEW 7.000 4.750 4.5" CASING - PUP JT 4.500 12.60 L-80 3.833 IBTM 3 15.86 7,637.79 Local NEW 5.200 3.958 4.5" CASING - PRODUC 4.500 12.60 L-80 3.833 IBTM 3 91.13 7,653.65 Local NEW 5.200 3.958 4.5" CASING - PUP JT 4.500 12.60 L-80 3.833 IBTM 1 9.92 7,744.78 Local NEW 5.200 3.958 4.5" CASING - PRODUC 4.500 12.60 L-80 3.833 IBTM 36 1,115.32 7,754.70 Local NEW 5.200 3.958 FLOAT COLLAR 4.500 IBTM 1 1.42 8,870.02 Y WEATHERFORD NEW 5.200 4.5" CASING - PRODUC 4.500 12.60 L-80 3.833 IBTM 3 93.11 8,871.44 Y Local NEW 5.200 3.958 FLOAT SHOE 4.500 IBTM 1 1.62 8,964.55 Y WEATHERFORD NEW 5.200 Non-Integral Casing Accessories Accessory Manufacturer Number Spacing Interval How Fixed (ft) Top (ft) Bottom (ft) Bowspring Centralizer WEATHERFORD 34 7,800.0 8,966.0 Set Screws Bowspring Centralizer WEATHERFORD 8 7,260.0 7,600.0 OverCollar Printed: 6/9/2003 12:05:21 PM ,~, Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Accessory Centering Guides PESI Ran 179 jts 7" 26# L-80 BTC M casing Ran 42 jts 41/2" 12.6# L-80 IBTM casing Displaced 41/2" casing with 9.8 ppg KCL water Manufacturer ~, ConocoPhillips Alaska Casing Report Report #: 2 Start: 12/6/2001 Non-Integral Casing Accessories Number 24 Remarks Spacing (ft) Spud Date: 12/8/2001 Report Date: 12/18/2001 End: 12/20/2001 Interval Top (ft) 2,950.0 Bottom (ft) 100.0 Floating ~ Page 2 of 2 How Fixed Printed: 6/9/2003 12:05:21 PM (' Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 8,966 (ft) 12/19/2001 Production Casing (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: : Time End: : ( Type: Cement Casing Volume Excess %: 75.00 Meas. From: Time Circ Prior To Cementing: 8.00 Mud Circ Rate: 250 (gpm) Mud Circ Press: 600 (psi) Report #: Start: Spud Date: 12/8/2001 2 Report Date: 12/19/2001 12/6/2001 End: 12/20/2001 Cement Job Type: Primary Squeeze Open Hole Hole Size: SO TMD: (ft) SO Date: SO Type: Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cementer: Kevin Anderson Pipe Movement: RPM: SPM: Pipe Movement Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 1 of 1 Start Mix Cmt: 11 :00 Start Slurry Displ: 12:05 Start Displ: 12:05 End Pumping: 13:00 End Pump Date: 12/19/2001 Top Plug: Y Bottom Plug: N Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 47 (s/qt) Bottom Hole Circulating Temperature:80 (OF) Displacement Fluid Type:Mud Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 700 (psi) 1,200 (psi) 1,200 (min) Y Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Mud Data Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: scale PV/yP: 15 (cp)/15 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 14 (lb/100ft2) Bottom Hole Static Temperature: 80 (OF) Density: 9.6 (ppg) Volume: 284.00 (bbl) Stage No: 1 Slurry No: 1 of 2 Slurry Data Fluid Type: LEAD Description: AS Lite Slurry Interval: 7,200.00 (ftJTo: 7,700.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: Slurry Vol:84 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) ( Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 13.00 (ppg) Yield: 1.99 (ft3/sk) Water Vol: 22.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/9/2003 12:05: 1 0 PM ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/8/2001 2 Report Date: 12/19/2001 12/6/2001 End: 12/20/2001 Stage No: 1. SlurryNo:2of 2 Slurry Data Fluid Type: TAIL Description: ARCTIC SET Class: G Slurry Interval: 7,700.00 (ftJro: 8,966.00 (ft) Cmt Vol: 107.0 (bbl) Density: 15.80 (ppg) Yield: 1.20 (ft3/sk) Water Source: Slurry VolSOO (sk) Water Vol: 63.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: ( Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ( Printed: 6/9/2003 12:05:10 PM CODE 124 HRS PROG ODR 6,002.0 13.00 I FIELD NAME I OCS NO. I DAILY TANG Meltwater 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD Circ. clean water in well 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Space out, hang off, test annulus, NID BOP, N.U tree, fro pr 12/19/2001 75,983 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.01 AK0187 2,661,570 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 12/17/2001 8,974.00 56.090 173.500 9.625 (in) @ 2,965.0 (ft) 7.000 (in) @ 8,821.0 (ft) 12/12/2001 DENSITY(ppg) ¡ 9.60 PP IEce IMUDQATAIDAllYCOST I 0 CUMCOST I 0 FV PVIYPGELS WLJHTHP FClT.SOL OILJWAT %SaridIMBT Ph/pM PflMf CI Ca H2S LIME ES 42 14/15 5/14 4.41 / /7.5 9.5/ I ( WELL NAME I JOB NUMBER 2P-429 I RIG NAME & NO. Doyon 141 SUPERVISOR D. Presnell CURRENT STATUS FROM TO ,HOURS CObE TROUBLE SUB 00:00 03:00 3.00 CASE P RUNC 03:00 07:00 4.00 CEMENT P CIRC 07:00 11:00 4.00 CEMENT P RURD 11 :00 13:00 2.00 CEMENT P PUMP ( 13:00 14:00 1.00 WELCTL P NUND 14:00 16:30 2.50 WELCTL P NUND 16:30 18:00 1.50 CMPL TN P RURD 18:00 00:00 6.00 CMPL TN P RUNT I REPT NO. DATE 14 12/19/2001 I CUM. TANGO CUM INT ANG WI MUD 0 CUM COST WI MUD 1,748,103 'OPERA7FIONS SUMMARY , PHASE PROD PROD PROD DESCRIPTION Run 7" casing f/6948' to 8966' Circ. and cond mud for cement job R/U cement head, hold pre-job safety meeting, attempt to batch mix spacers and cement, having freezing problems, mixing went very slow, circ hole with rig pump while this operation is going on PROD Pump 10 bbls CW100, test lines to 3500 psi, pump 80 bbls CW100, pump 50 bbls 12 ppg. MudPush, pump 30 bbls 13 ppg lead cement, pump 107 bbls 15.8 ppg tail cement, drop top plug, pump 27 bbls 9.8 ppg KCL water and displace with rig pump with 9.6 ppg mud, bump plug with calculated strokes, check floats and floats held. Reciprocate pipe through out cement job. PROD Land casing in wellhead, remove landing jt., set packoff and test to 5000 psi. PROD Change pipe rams and test. CMPL TN R/U to run 41/2" completion tubing CMPLTN RIH with seal assembly and completion equipment on 41/2" 12.6# L-80 IBTC tubing to 5610' 24 HR SUMMARY: Run 7" casing, Circ and condo mud, cmt as program, run packoff and test, change pipe rams and test, R/U and run 41/2" tubing COMPANY Phillips Doyon SERVICE ITEM UNITS bbls bbls USAGE 2,397 880 Fuel Water, Drilling TYPE 2P-438 3R-11 NO. 1 ,797 2P-429 2P-429 REMARKS ( PERSONNEL DATA NO. HOURS COMPANY 1 Misc Personnel 29 Service Personnel SERVICE NO. HOURS 5 12 MATERIALS I CONSUMPTION ON HAND ITEM 2,845 Water, Potable 445 UNITS bbls USAGE 100 ON HAND 106 SUPPORT CRAFT TYPE DS 4 G&I NO. REMARKS 2P-429 Printed: 6/9/2003 12:24:55 PM ( 2P-429 I JOB NUMBER CODE 124 HRS PROG ODR I TMD I TVD I DFS I REPT NO. I DATE 8,974.0 6,002.0 13.00 14 12/19/2001 WELL NAME RESERVOIR NAME 2P-438 3R-11 OS 4 G&I 2P-429 2P-429 2P-429 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 1797 2.75 700-11 00 0 0 COMMENTS ( ( Printed: 6/9/2003 12:24:55 PM Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS 2P-429 ODR 8,974.0 6,002.0 14.00 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANGO Doyon 141 Meltwater ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD Moving rig to 2P-448 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Rig up, P/U 4" DP, hold spud meeting, spud well 12/20/2001 505,140 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.01 AK0187 2,661,570 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 12/17/2001 8,974.00 56.090 173.500 9.625 (in) @ 2,965.0 (ft) 7.000 (in) @ 8,821.0 (ft) 12/12/2001 DENSITY(ppg) I 8.40 I PP I IECD IMUD DATAl DAILY COST I 0 I CUM COST I 0 FV PVNP GELS WUHTHP FCIT.SOL OIUWAT %SandlMBT Ph/pM PflMf CI Ca H2S LIME ES 26 18/20 / / / 7.0/ / WELL NAME SUPERVISOR Don Presnell CURRENT STATUS Page 1 of 1 I REPT NO. I DATE 15 12/20/2001 I CUM. TANGO CUM INT ANG WI MUD 0 CUM COST WI MUD 2,253,243 OPERATIONS SUMMARY PHASE CMPL TN Run 41/2" tubing to top of SBE CMPL TN Reverse circ mud out of hole with clean 8.4 ppg fresh water, circ until hole was clean CMPL TN Space out and land seals in SBE, left 2' of space out from locators CMPL TN Pressure test 4112 x 7" annulus to 3000 psi, shear valve in GLM during bleed down of annulus pressure as stated in procedure. CMPL TN N/D BOP's CMPL TN N/U tree and test to 5000 psi PROD UD 7500' of 5" drill pipe out of derrick Perform annular injection test on 7" x 9 5/8" casings Freeze protect well PROD Change out TDS 5" saver sub and grabbers to 4" 24 HR SUMMARY: Finish RIH w/4.5" tbg, circ. mud out of hole, space out and land seals, pressure test annulus, NID BOP, N/U tree&test, UD DP, change saver sub on TDS FROM TO HOURS CODE TROUBLE SUB 00:00 03:00 3.00 CMPLTN P RUNT 03:00 06:00 3.00 CMPL TN P CIRC 06:00 08:00 2.00 CMPL TN P SOHO 08:00 10:00 2.00 CMPL TN P DEQT 10:00 12:00 2.00 WELCTL P NUND 12:00 14:30 2.50 WELCTL P NUND 14:30 22:00 7.50 DRILL P PULD 22:00 00:00 2.00 DRILL P RIRD COMPANY ConocoPhillips Company Doyon SERVICE ITEM UNITS bbls bbls USAGE 2,200 900 Fuel Water, Drilling TYPE 2P-438 3R-11 NO. 1,267 2P-429 2P-429 DESCRIPTION PERSONNEL DATA NO. HOURS COMPANY 1 Misc Personnel 29 Service Personnel SERVICE NO. 5 14 HOURS MATERIALS I CONSUMPTION ON HAND ITEM 645 Water, Potable 345 UNITS bbls USAGE 90 ON HAND 96 REMARKS SUPPORT CRAFT TYPE DS 4 G&I 2P-429 NO. REMARKS RESERVOIR NAME 2P-438 3R-11 DS 4 G&I RESERVOIR AND INTERVAL DATA ZONE TOP BASE 1267 2 800 - 1150 0 0 2P-429 2P-429 2P-429 COMMENTS Printed: 11/7/2003 2:28:21 PM ~, CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: 12/12/2001 Supervisor: Dearl W. Gladden 2P-429 0 Initial Casing Shoe Test Reason(s) for test: D Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/811 40# L-80 STCM Casing Setting Depth: 2,965' TMD Hole Depth: 3,002' TMD 2,435' TVD 2,458' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 371 EMW= Leak-off Press. + Mud Weight = 818 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,458' EMW for open hole section = 16.0 ppg Pump output = 0.1010 bps Fluid Pumped = 1.0 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi W 1,900 psi a: 1,800 psi m 1,700 psi () 1,600 psi W 1,500 psi a: 1,400 psi a. 1,300 psi 1,200 psi 1,100psi 1,000 psi :gg~~:-~¡a "w.w,.. 700 pSI' ^ ¥""l;.w .,." .ø'w,~. - -.:;::r.-:;'.;>:>-..è-:::~'$ 600 psi ' 500 psi l 400 psi 300 psi 200 psi 10g ~~: tr - 0 ~ 00 ro m ~ I~ ~ ~6:lM~~NtT~K5 11= I I I I -e- LEAK-OFF TEST ---CASING TEST ~~*~". LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME - ~ 0> '" i\! .. 0 t .. '" en I\) en 0> 0> 0 0> .. I\) .. I\) '" k! '" 0> STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA ~ CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE r---------------'----Õ-stks---!----4ÕI;-sr---lr---------------T--Õ-stks---1-----4Õ-ps¡----1 1----------------r--2"stks---t----12Õ-pSr--î ----------------t---2-štks---r--4šõ-risl---1 I----------------"t---------------t-------------';--~ 'Kß----------,---------------1--------------:'---1 L__-__---_____-l---~-~!~~-_-1---~~Q..P_~!_-~ Jku-----------~---~-~-~~~___L__~!Q-P..~}-_.J L.-------------.l---~-~!~~---1---~QQ..P~!_-~f,þ\tj-----------L--~-~-~~---L!!~~.Q_e~~.J !----------------t--1~õ~f~š--t---¡~i~~~--? \r¡~----------t--1~õ~s\~~--i--~~fã~-~~}:~ I----------------"'---------------T-----------------~ ..----------------~---------------~---------------: 1 : : 1 1 1 12 stks 1 2,500 pSI 1----------------+---------------+-----------------+1'----------------~---------------+-----------------, I I I I I I I I I I I I I I t I I----------------+---------------t-----------------i ~----------------~---------------i------------------i I I I I I I I I I I I I I I . I I----------------+---------------t-----------------it-----------------~---------------i-----------------1 1 I 1 I 1 I 1 1 1 I 1 1 1 1 I 1 1----------------""'---------------"'-----------------01 ~----------------"---------------oI-----------------'" I 1 1 1 1 I 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 I I----------------"'---------------+-----------------~"----------------..---------------ot-----------------" 1 1 1 1 I I . I 1 1 1 1 I . I . 1 I 1 1 I J . I 1----------------"'----------------1'-----------------11-----------------~---------------..-----------------... 1 I I 1 I J 1 I 1 1 1 I J I I I 1 1 1 1 I I I I I----------------..,----------------T-----------------' ...---------------- 1"'---------------"-----------------' 1 1 1 1 1 I 1 1 I 1 1 1 1 1 1 I----------------+---------------~-----------------~:---------------------------------~-----------------~ I I 1 I I 1 1 !----------------+---------------+-----------------~ !.---------------- '._____----------~-----------------~ I I I I 1 1 I 1 !----------------+---------------t-----------------i~----------------~---------------i------------------i 1 I 1 I I 1 I I 1 I I I I 1 1 I I----------------T---------------f-----------------i:-----------------~---------------1-----------------1 1 1 I I 1 I 1 I 1 1 I 1 1 I I I I----------------""'---------------"'-----------------"~----------------,,"---------------01-----------------'" 1 1 I I I I I I 1 1 I I I I I I 1 1 I I I 1 I I I----------------"'---------------+-----------------~"----------------,,---------------001-----------------'" 1 1 I 1 I 1 1 1 1 1 I 1 1 1 I I 1 I 1 1 1 1 I I 1----------------""'---------------1'-----------------1 1 1 1 1 ¡----------------¡---------------¡-----------------~ 1 1 I I 1 I 1 I I----------------+---------------~-----------------~ I I I I 1----------------1 1 I I 1 1 1 i : ! ! I SHUT IN TIME 1 SHUT IN PRESSURE 1______----------.---------------------------------- L__Q:9-_rn!~___1______---______1____~_!!!J?~!__J L---!:9-.rn!~---l---------------L--~QQ.'p~!_-j L--~:9-_rn!~---l---------------L--!.!.Q..p~!_-.l ! 3.0 min ! ! 730 psi! r--4~õ-rñiñ---r-------------1---72Õ-psi---l I----------------+---------------~-----------------~ 1 5.0 min 1 1 700 psi 1 1-----------,;,----+---------------+-------------,;---+ 1 6.0 mln : 1 695 pSI 1 I-----------,;,-----i----------------+-------------,;---i L_Z:9-_rn!~___L______--______l___~!!?_.P~!___l L_~:9-.rn!~-_.1_--------______1___~!!?_'p~!_--j ! 9.0 min ! ! 680 psi! !~~~iQ~~~~~!~~~I~~~~~~~~~~~~~~~!~~~~!.~j?~!~~~j ! SHUT IN TIME! SHUT IN PRESSURE r--õ~õ-miñ---r-------------T-I5õõpšTl ..----------------~---------------~-----------------., 1 1 .0 min 1 1 2,495 psi I :------------.-----~---------------+---------------:-~J-", 1 2.0 mln I 1 2,495 pSI '-----------------~---------------i---------------- ! 3.0 min 1 1 2,490 psi I L______----------~---------------"-----------------" ! 4.0 min : ! 2,490 psi! r---5~Õ-ITliñ--T------____m-r2:¡ãš-psrl r--6~õ-ñiiñ--1--------------1--2;4ãš-psrl r--fÕ-m-iñ---r---------------r-2:¡ãš-psrl r--ã~Õ-m-iñ--T--------------r-2:¡ãö-psrl ~----------------~---------------~-----------------~ 1 9.0 min I 1 2,480 psi: :-------------:.----~---------------~---------------;"-~ 1 10.0 mln 1 1 2,480 pSI 1 ~------------:.----~---------------i---------------;"--i 1 15.0 mln 1 I 2,475 pSI I r--2õ~õrñlñ--t---------------r2:¡7ö-psr1 r--2š~õ-ñilñ-T-----_m__---r2:¡7ö-psrl ...----------------..---------------..-----------------... L.9..9.:2_~J!.!_.L__._.__..._._L~z~~-~.p.!~.J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ._~..' CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-429 Date: 12/12/2001 Supervisor: Dearl W. Gladden 0 Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/811 40# L-80 STCM Casing Setting Depth: 2,9651 TMD Hole Depth: 3,0021 TMD 2,4351 TVD 2,4581 TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 37' EMW= Leak-off Press. + Mud Weight = 818 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,458' EMW for open hole section = 16.0 ppg Pump output = 0.1010 bps Fluid Pumped = 1.0 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,81)0 pSI 2,701) ~,SI 2,£00 p51 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi W 1,900 psi a: 1,800 psi ~ 1,700 psi (/) 1,600 psi W 1,500 psi a: 1 ,400 psi CL 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi -----i. BOO psi ~ 700P.Si I.~ ..~~~~ 600 psi 500 psi l 400 psi 300 psi ~J 200 psi .I' 100 psi f1""" 0 psi ~ /...-... .. .. .. ... .LI. - ""." ............... ?- ~~,~lM~~lET'~K5 I~ I I I I ""'LEAK-OFF TEST "'-CASING TEST -+-LOT SHUT IN TIME --a\¡-CASING TEST SHUT IN TIME - t ro '" 0 ~ '" ... '" '" k! '" () ... 0 t t '" '" '" () () 0 () ... () '" .... '" STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r---------------'----õ-štkš---ì---4Ô psi' 1 ,---------------......--- - -----t----- --- , 1 ¡ ! 2 stks I 120 psi I r--------------I---;r stkš--¡--260 psi -- i C~~~~~~~~~~~~~~L-~~ ~!~~-J-- - ~ÕO psi i ¡ ¡ 8 stks ¡ 690 psi ¡ ,----------------.,.---- --~ :::.:::-ï I----------------¡--~_~_~!ks---!-_~!J!~ psi I I I . I ¡----------------~-------------" - f---- -. '---f 1 'I I . I 1-------------------- "-" lu -------I I . . . I I I t I--------------+-------------f------ u ---_a_of I I I 1 . . . . 1------------.; -.---- -----t"" -- -- "" ....--; 1 I I ' 1----------------------- .----_u__u_-,---l ¡ I ¡ ! '--------------"-----------""--------1 ¡ I ¡ I .--------------,----------..,--------..--, , I . . I---------------+-------------~-----U" - --1 , I I , I----------------+----------+------------f . , I , I-------------'--------------t---- - _on, i . It. !-------------+---------------+- _u- ------1 : " I I :-------------T--------------t----------1 . I I I I . I t .----------------....--------- ...... ------~ I I I . I I I : '----------------...-------------.-------_.. -.- --.. . . . . I I I I [~~~~~=~~~~~~~~I===~~~]~~~=~-~--~.J I I I I 1-----------------1 I I I I . . I ¡I! I SHUT IN TIME I SHUT IN PRESSURE '______----------""---------------'-¡-- --- -- . L_.2:Q._'!!!~__l______---_u 1 . 818 psi _..l ! 1.0 min I ! 800 psi! :-----------':'----:---------- 1"'-- . . 1 !---~:2. m I ~_...!.-------------!--- 77.!JJ?~!_-...! ! 3.0 min ! ! 730 psi! .--------------.,..-------------.,---- ..-...--- , ¡---~: 0 rT]!~---¡---- ---- 1- 720 J?:»t J I 5.0 min I I 700 psi I 1------------+-----------+- - ., !---~:2._'!!!~-t--------- .t--- 6~5 psi I , 7.0 min I I 695 psi I I______--------",----_u---- __.1__- ~ L_~:2._'!!!~-_.l_-------______L_~85 psi __I I 9.0 min ! i 680 psi! [~i~~~~~~~~I~~~=~~=~~~~~~L"~7~J?si ] .-~ '\ CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE L.. ! 0 stks 40 psi 1 ! m-I 2 stks 480 psi J r U H ì 4 stks 910 psi ¡ I ! 6 stks 1,430 psi i ¡ r . 8 stks r 1,800 psi 1 ~,_u -- u - [.10 stks . 2,180 psi i .-.. ~.. -+ 1~ stks ~ ~,5~ psi ~ I. -- -I - i i ~ _0 1 1 Ln_- -- I J 1 . . t, I , I ! j f - --- 'f - -1 -I I ~ ~ i í==~--' j , f - ¡ I j I ~ - u I ¡- -~,~ i j t - .- , , ~, om --l J J , ! i ¡ i SHUT IN TIME i SHUT IN PRESSURE l_Q.:Q_rnin L i 2,500 pSi] ~-- ~:O m~n ~ .1 2,495 p~~ ~ ! - _2.:~_~~n ~- 2,495 ~S~ ~~. I 3.0 mln I 2,490 pSI J L 4:0-~Jn-_J I 2,490 psi! 'I 5.0 min II j 2 485 Psi ¡ ,. - ,,-- " I L 6.0 min - L- --- j ~,485 psi j ¡ 7.0 min ! L 2,485 psi I [ 8.0 _~in - [--- ¡ 2,480 psi ì I 9.0 min I 2,480 psi l' o ... I 10.0 mln I I 2,480 psi ¡ t:-15.0 "]jn. r -I 2,475 psi ~ ! 20.0 min 1 1 2,470 psi .1 r 25.Õ min r - -- -r 2,470 psi 1 [ _30:~ m~ñ L_, L 2,465_psi ] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY MINUTES FOR LOT STROKES PRESSURE ,----------------¡----------------T-----------------' I I 0 stks I 0 psi I 1----------------""---------------"-----------------1 "",--«_._~' ¡ ¡ 5 stks ! 150 psi I Hole Depth: /i,117' TMD f--------------I--rõšiks--r-'2õö-psr-1 ( 4 921' TVD .J¡----------------r--rS-Šiks--¡---'2sõ-p-sr-ï , ~I I I I "--....--- r--------------I--2"õ-šiks-l---'2sö-psr--l Length of Open Hole Section: 4,152' r---------------r-2"S-šiks-1---32S-psr-l I----------------""---------------~-----------------~ I I 30 stks I 375 psi I I----------------+---------------f-----------------~ I I 35 stks I 400 psi I :----------------+---------------t------------------I : : 40 stks I 450 psi: 1----------------r--4s-šiks--t---sõõ-psi---1 r--------------I--sõ-šiks-I---s25psi--1 r--------------I--ss-šiks-¡---s7s-psi--l r--------------I--6õšiks-l---sõö-psr-l r---------------T--6s-šiks--I---ssö-psr-l I----------------""---------------T-----------------~ : : 70 stks I 675 psi: :----------------+---------------f-----------------i I I 80 stks I 700 psi I :----------------+---------------t-----------------i : : 85 stks I 710 psi: 1----------------""---------------"-----------------1 ! ¡ 90 stks ! 725 psi: r---------------r-9s-šiks--r--7SÖ-psr--t r--------------I-;¡õõ-šiksl---75õ-psr-l r--------------1-7iös-šiks-I---7sö-psr-l r---------------r1-rõ-šiks-1---7SÕ-psr--ì :----------------+---------------~-----------------~ I I 115 stks: 750 psi I 1---------------- I . : I I 120 stks I 750 psi I I I . . : SHUT IN TIME I SHUT IN PRESSURE 1______----------""---------------------------------- L_.Q:9-~i!:1___1______---______L__'?~Q_[>-~!_--j L-_~:9-D~!!:1_-.l--------------j-----------------1 L-~:9--~!!:1---1---------------1-----------------l ! 3.0min ¡ ! ¡ ,----------------""---------------T-----------------' I 4.0min I I I I----------------+---------------~-----------------~ I 5.0min I I I I-----------,;,----+---------------f-----------------i I 6.0 mln I : : I-----------,;,----+---------------t-----------------i I 7.0 mln I I I I______----------""'---------------"'-----------------~ ! 8.0min ! ! ¡ 1----------------""'---------------"-----------------" ! 9.0min ! ! ¡ 1----------------",,---------------.-----------------01 L_!2:9__~!~-_L--____--______L______--------_.J CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-429 Date: 12/20/2001 Supervisor: Don Presnell D Initial Casing Shoe Test Reason(s) for test: [2] Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 711 x 9 5/811 Casing Setting Depth: 2,965' TMD 2,435' TVD Mud Weight: 9.6 ppg EMW= Leak.off Press. + Mud Weight = 750 J?6!:.."+',*.9.6 ppg 0.052 x TVD 0.052 ~ . EMW for open hole section = 12.5 ppg J '-\5<6 Pump output = 0.0295 bps Fluid Pumped = 3.5 bbl ....... 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 pSI. u 2,500 pSI ---.-.-.-.- 2,400 pSI - --. - 2,300 psi 2,200 psi 2,100 psi 2,000 psi W 1,900 psi a: 1,800 psi ~ 1,700 psi en 1,600 psi W 1,500 psi a: 1,400 psi D. 1,300 psi 1,200 psi 1,100 psi 1,000 psi ClIJIJ ['~i ----.---- -- -- / ~TIME LINE _._n lONE MINUTE TICKS 111111111 -+- LEAK-OFF TEST ---CASING TEST LOT SHUT IN TIME -rk-CASING TEST SHUT IN TIME - -+- TIME LINE .---------- - - -- -- .-- -.-- ---- - - - - -- ------ ---- --._U"--'U'.... ",(,(, ~,;, h --- - - ---- . III HI III ttl 111111111 tlllIHH Ûliïf 111111 Will III ;,.".'~", - ---- -, -. -. .. ...:.. J :.. Ð .C--'-~ 9 - - (--.-.--. --.-- ~¿¿~~; ---- ; ~;-~~. 400 psi . ~ 300 psi ~..- 200 psi /'" . 100 psi 0 psi ~ ~ ~ 00 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ m m ~ ~ ~ m m ~ ~ g ~ ~ ~ ~ § ~ ~ ¡ ~ ; ~ i ~ ~ § m m ~ ~ § ffi STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ._---------------r---------------,-----------------¡ L_-------------j---Q-~-~~~___L___~_e~~___J I I : I I I I I ..----------------~---------------..---_..._-----------... I I I I I I , I I I I I ,,----------------10---------------"'-----------------" I I I I I I I I I I I I ..----------------to---------------"-----------------" I I I I I I I I I I I I r----------------r---------------,-----------------' I : I ~ :-----------------~---------------~----------------,' 1 1 1 1 1 1 :-----------------~---------------~-----------------"I I I I I I I I I :-----------------~---------------i-----------------i I I I I I I I I 1----------------t---------------1-----------------1 L______----______L______--------_J_---------------_J I I I I I I I I I I I I ,,----------------,,---------------04------------------1 I I I I I I I I I I I I ..----------------to---------------"-----------------'" I I I I I I I I I I I I ..----------------r---------------,-----------------' I I I I :-----------------~---------------~-----------------~ ~----------------~---------------~-----------------~ 1 1 I 1 ~----------------~---------------i-----------------i I . I I I I I I ~----------------~---------------i-----------------1 I I I I I I I I ..----------------,,---------------..-----------------.. I I I I I I I I I I I I ,,----------------,,---------------04-----------------" I I I I I I I I 1 1 I 1 ! SHUT IN TIME! SHUT IN PRESSURE ~~~~g~Q~~~ñ~~~~~~~~~~~~~~~~~~~~I~~~~~~g~Ë~J~~~~~~ 1 1.0 mln 1 1 I------------.-----~---------------' -----------------j......,. I 2.0 mln : I .. t---iÕ-mlñ---r---------------":----------------' I r---4~õ-mlñ---t---------------l----------------1 1-----------------"---------------"-----------------" ! 5.0min ¡ ! ! ,,----------------,,---------------04-----------------" ! 6.0min ! ¡ ! ..----------------,.---------------..-----------------... ! 7.0min ! ¡ ! [~~~~~Q~~Jñ~~~[~~~~~~~~~~~~~~~]~~~~~~~~~~~~~~~~~] : 9.0min I I I I------------~----~---------------~-----------------~ I 10.0 mln I I I t--15~õ-ñilñ--t--------------_. -----------------1 r--2õ~õ-ñilñ--t--------------:-----------------1 1-----------------10---------------- -----------------.. ! 25.0 min i ! i ,,----------------,,---------------04------------------1 L_~9.:.Q_~J!!__L__._-__.._---_J.---_.._-------_.J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY 4:2.7.. - ~ CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-429 Date: 12/20/2001 Supervisor: Don Presnell 0 Initial Casing Shoe Test Reason(s) tor test: 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7" x 9 5/8" Casing Setting Depth: 2,9651 TMD 2,4351 TVD Hole Depth: 7,117' TMD ,J.1t~ """"1 TVD Mud Weight: Length of Open Hole Section: 9.6 ppg 4,152' -~ EMW = Leak-oft Press. + Mud Weight 0.052 x TVD Pump output = 0.0295 bps 750 psi + 9.6 ppg 0.052 x~1' .? -.. :2'4$0 EMW for open hole section = 1".~ 1'1~g 51 L¡ Fluid Pumped = 3.5 bbl = ''''''''-'' 3,200 ps¡ 3.100 psi 3.000 psi 2,900 psi 2,800 psi 2.700 psi 2.600 psi 2.500 psi 2,400 p$J 2,300 psi 2,200 psi 2.100 psi 2,000 psi UJ 1,900 psi a: 1,800 psi ~ 1,700psl en 1,600 psi UJ 1.soo psi a: 1,400 psi CL 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi SOOpsi 400 psi 300 psi 200 psi 100psl .' ops¡/ - V' CD ~ ~ ~ ~ ~ ~ ~ ~ ~ t ~ ~ !! g; m (j ::1 ~ ~ ~ ~ ~ § ~ ~ ~ ~ § ~ œ ~ ~ ; ~ ~ ~ ~ ~ ~ m ~ 8 ~ ~ / ¡TIME L.IÑE ONE MINUTE TICKS 111111111 ---LEAK-OFF TEST """'CASING TEST -.,~- LOT SHUT IN TIME -4..-CASING TEST SHUT IN TIME - -f- TIME LINE 11 1111111111111111111111111 111111111111111111111 HI III 1 @: ,I . STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ,----------------...----------------,----------------, 1 1 0 stks 1 0 psi I '----------------"'----------------t-----------------.. ! ! 5 stks I 150 psi ¡ r---------------¡--1-Õ-stks--r--"2õõ-psr--1 r---------------T--~fŠ-stks-T--"25õ-psr-l ¡----------------T--2Õ-štks--r--2SÕ-pšr--l r--------------T--2Š-stks-1---32Š--pš¡--1 ,----------------+--------------~-----------------4 I 1 30 stks 1 375 psi 1 I----------------t------------i------ -- --- - -i !---------------+--~?_~!~!_-i---~~Q..P-~!---4 1 1 40 stks 1 450 psi I .----------------+---------------..-----------------.. ¡ 1 45 stks ¡ 500 psi ¡ ¡----------------T--sõ-Siks--r--S2S-ps¡--1 r--------------1--šŠ-Siks--r--S7Š--psr-l ¡----------------T--Š-õšiks-l---sõõ-psr--l ¡----------------T--Š-Š-štks-T--S5Õ-ps¡--1 1----------------+---------------~-----------------4 I I 70 stks : 675 psi 1 I----------------+---------------+-----------------i : : 80 stks I 700 psi I I---------------+---------------i-----------------i : I 85 stks 1 710 psi I :----------------+---------------t----------------_.. : I 90 stks 1 725 psi! r---------------¡--9š-siks--¡---75Õ-pšr-, r---------------Y-"1öõ-šiï<šT--75õ-psr-l ¡---------------¡-1ÕŠ-šikš--r--75Õ-psr--l I----------------T---------------T-----------------.. 1 , 110 stks: 750 psi 1 :----------------+---------------~-----------------4 1 1 115 stks 1 750 psi 1 /-----------------1 I . 1 ¡ ! 120 stks! 750 PSI! ¡ SHUT IN TIME i SHUT IN PRESSURE '_---------------"'----------------T------------------ L_.Q:9._f!Jl!.1__.l__------______L--'?~Q.P_~!_.J ¡ 1.0 min ¡ ¡ ¡ :------------:----;----------------1------------"'----1 I 2.0 mm I I I r--3~Õ-mïñ--r--------------r----------------l I---------------'----------------T-----------------' I 4.0min : I 1 :----------------+--------------~-----------------4 1 5.0min 1 1 I -----------':'----+---------------+-----------------~ 1 6.0 mm 1 I 1 I-----------,:,----+---------------i-----------------i I 7.0 mm I I I I______----------.l..--------------"-----------------.J L_~:9._~l!.1___L______------_J._-------------_.J ¡ 9.0min ¡ ¡ i [~!2~9~~~!~~~I~~~~~~~~~~~~~~]~~~~~~~~~~~~~~~~] CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE [~~~~~:~~~~~~~~I~~~Q~~!~~~J~~~~=~~e~~~~~] I I I I I I I I I I I I ...----------------...--------------....-----------------"'" I . I I I . I I I . . I ...---------...------..---------------~-----------------... . I I I I I I I I I I . "----------------"---------------1-----------------; I I , I I I I . :.----------------:.---------------..:-----------------~ I I J I I . I I :-----------------I----------------~-----------------: I I I . I I I . ;'---------------~---------------------------------i I I I I ~----------------~---------------i----------------.{ I I I . I I I I t----------------t---------------i-----------------t I I , I I I I . &"----------------1.---------------..1-----------------'" . I I I I , I I I I I I ..----------------..---------------...-----------------.. I I I I I I I . I , I I "'----------------"'---------------'1-----------------"1 J I I I I . I I J I I . ,.----------------r---------------,-----------------.., , , I I . I I I 1-----------------1----------------~-----------------4 , I I I I I I J ;'----------------~---------------------------------i , , I . ~----------------~---------------i-----------------.{ I I I . I . I I ~----------------t---------------1-----------------i I I I I , . . I a..----------------I.--------------"'----------------'" I I . I I I I I ~----------------~---------------J-----------------.J I I I I I . , I I , I I i SHUT IN TIME! SHUT IN PRESSURE r---------------r---------------.,-----------------., ¡ 0.0 min ! ¡ 0 psi ¡ "'---------------r--------------,---------------.., I 1.0 min 1 1 1 ~---------~-----~---------------~----------------~ I 2.0 mrn 1 1 1 ------------.---------------------------------------..¡ 1 3.0 mrn I I : [~~~~Q~~]~~~~[~~~~~~~~~~~~~]~~~~~~~~~~~~~~~~] i 5.0min ¡ ! ¡ "----------------Þ---------------"'-----------------ooI ! 6.0min ! ¡ ¡ ..----------------~---------------...---------------... ! 7.0 min ¡ ¡ ! ...----------------r---------------.,-----------------... I 8.0min I I : 1----------------1----------------~-----------------4 1 9.0min 1 I 1 ~------------.---~---------------~-----------------~ : 10.0 mrn 1 I 1 ------------.--------------------i-----------------"¡ I 15.0 mm I I I L______----______L______--------_.J_---------------_.J t~~~~~~~~}g~~t~~~~~~~~~~~~~~~j~~~~~~~~~~~~~~~~~j L_?_g.:.Q-~j!!_J_-------------_J._------------_.J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ~ ConocoPhil!i~ ConocoPhillips Alaska, Inc. Structure: Drill Site 2P Field: Meltwater Well: 429 Location: North Slope, Alaska CreGted by bmIchod Date _eO, '-0.0-2003 Piol Rcfcn:ncc is WWD <0-8974'>. Coordinotes are in (eet. reference slot: #429. True Vertical Depths ore rd'~ RKB (Oaojcn 141). - -=- Scole 1 inch = 100 It 1300 1200 "00 1000 900 500 I I 1 I I 1 I I I I I I I I I I I I I I . I I I I I I .w.. 7 5/8 "" @ \r\\Ã.. \ East (feet) -> ~4 I I I I . . I I I I I I I I I 1 , I 1000 "00 1200 1300 1400 1500 1600 1700 I , I I I I I I I 1 I I " 500 g Õ ~ - :¡oo II 0 -200 0 ;::, - 100 - 100 VI 0 .1100 c:: :;: -1200 CD' .;. -1:500 I V -2300 -2500 ConocoPhillips Alaska, Inc. Drill Site 2P 429 slot #429 Meltwater North Slope, Alaska H 0 R I Z 0 N TAL P LAN E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: MWD <0-8974'> Our ref: svy6654 License: Date printed: 1-Dec-2003 Date created: 10-Dec-2001 Last revised: 27-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 9.340,w150 26 55.820 Slot Grid coordinates are N 5868943.497, E 443913.132 Slot local coordinates are 933.18 S 1956.25 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 1 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <847 - 8663'>,,448,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2966.0 2434.3 689.8S 1512.4W 290.5 1877.7 1591.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <4051 - 7593>,,448A,Dri11 Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2966.0 2434.3 689.8S 1512.4W 290.5 1877.7 1591.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0-6860'>,,420,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2436.8 2434.3 39.6N 169.5E 356.8 1388.5 1388.5 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 4 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0-5950'>,,451,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2529.5 2434.4 254.0S 1003.1W 311.2 1660.1 1633.5 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). (' ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 5 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0 - 7327'>,,441,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing 2965.0 2434.3 1346.8S 246.6E 2676.6 2434.4 820.6S 425.0W 308.1 8~f2 Horiz Min'm D i s.t:_.--Dá: s t 814.6 . ....--.---",~ ^ Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0-9224'>,,438,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2952.7 2434.3 1264.7S 582.1W 275.7 832.8 818.6 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 7 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0 - 9685'>,,431,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 3097.8 2434.4 1523.5S 127.8W 244.7 414.1 379.7 Coordinates All data is in feet unless otherwise stated. casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 8 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0-10402'>,,427,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 3153.0 2434.3 1516.0S 477.9E 126.2 286.6 202.7 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 9 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0 - 6008'>,,417,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2438.7 2434.3 55.8N 266.3E 0.8 1402.7 1402.5 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ftabove mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). (' ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 10 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wel1path Object we11path : MWD <0-8853'>,,422,Dri11 Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2946.6 2434.4 1031.2S 865.1E 63.0 694.3 690.9 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 11 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0 - 8848'>Depth Shifted,,422,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2941.6 2434.4 1031.2S 865.1E 63.0 694.3 690.9 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 12 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <2878 - 7310'>,,422A,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2939.2 2434.3 1028.9S 863.3E 62.7 693.8 690.9 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ( ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 13 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <0-???'>,,434,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2507.9 2434.3 245.0N 447.9W 336.4 1736.7 1625.0 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level) . ConocoPhillips Alaska, Inc. Drill Site 2P,429 Meltwater , North Slope, Alaska CLEARANCE LISTING Page 14 Your ref: MWD <0-8974'> Last revised: 27-Feb-2002 Reference wellpath Object wellpath : MWD <387 - ???'>,,432,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2965.0 2434.3 1346.8S 246.6E 2516.3 2434.3 486.2S 176.5W 333.8 958.9 919.8 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (251.70 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). TUBING (0-7617. 00:4500. ID:3,958) SURFACE (0-2965. 00,9,625. Wt40 00) ~ODUCTlOU (0-7617. OD:7,OOO, Wt26 00) SLEEVE (75..r.{). 755 1, 00'5562) tllP (7571-7572. OD 5,450) LOCATOR (7614-7615. OD 5,000) SEAL (7615-7616, 00:4,750) Perf (8176-8240) Perf (8300-8325) Perf (8325-æ50) Perf (8386-8411 ) Perf (8495-8505) ( ,CollocòPhllllpsAlasQ,lnö. i r ! ~ -- ~ ---- ;rD\-\°d- KRU 2P-429 2P.;429',:', ,:' , .' .. API: 501032037800 SSSV Type: Nipple ~: I '. . r . ~ :. ~ j: : ~:- . . .. , Well Type: INJ Orlg 12/20/2001 Completion: Annular Fluid: Last W/O: Reference Log: Ref Log Date: Last Tag: 8329 TD: 8974 ftKB Las~ Tag Date: 8/10~?~q~ ',' '" ",ME3J<,H,~le J\r1g~~:,~6 d.e9,~8~!4"""""" ",', "",', ' ',' '"',',""',, "," ",' ",,' - Cäšlh~' 8tH"g ..' AL!~~S)[c81NGS¡;:,,';(1;;i: :n;2;J§Bt:;;¥1;3'i!:B1jt;1!8:;i;;fh~B~:!i;;:;81;i;i2Ð!i!2;1r;jB.i;)iij~;2~B~~í~B;;m,¡jj;;'fgi!;i,;1J;1f;;Si(;ifg@!sil1;lioi;i&Bj Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 0.00 SURFACE 9.625 0 2965 2434 40.00 L-80 BTCM PRODUCTION 7.000 0 7617 5219 26.00 L-80 BTCM Tubing ,st~~~E_R TUØltjGk::[:;2;jj¡~;~~~~~g)j)J5.jjR¡j~~t11~jj~ð~~jjjjÈjBsï8~~~~0;;;jjji.j;jj;~~~~ìfjBjfmjk~~~~j;)~jjB~~~~(jÊì~~;(¡~;:~~¡ìBBi' Size I Top I Bottom I TVD I Wt I Grade I Thread 4.500 0 7617 5219 12.60 L-80 IBTM Perforations Summary , Interval TVD Zone Status Ft SPF Date 8176 - 8240 5549 - 5586 64 6 1/14/2002 Angle @ TS: deg @ Angle @ TD: 56 deg @ 8974 Rev Reason: TAG FILL Last Update: 8/31/2003 8300 - 8325 5621 - 5635 25 8325 - 8350 5635 - 5649 25 8386 - 8435 5670 - 5698 49 8495 - 8505 5732 - 5738 10 Type Comment IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 6 1/14/2002 IPERF '2.5" HSC. 2506 Power jet HMX Chgs, 60 deg phase 6 1/13/2002' IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 6 1/13/2002 IPERF 2.5" HSC, 2506 Power jet HMX Chgs, 60 deg phase 6 1/13/2002 IPERF 2.5" HSC, 2506 Power jet HMX 60 Gas Lift St MD TVD Man Man Mfr Type CAMCO KBG-2 V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt BTM 0.000 0 1/6/2002 DMY 1.0 1 7500 5149 Other ll>lugs, Depth TVD 517 517 7550 5179 7571 5192 7614 5217 7615 5218 Description CAMCO LANDING 'DB' NIPPLE BAKER CMU W/OTIS 'X' PROFILE CAMCO 'DB-6' NIPPLE BAKER G-22 LOCATOR BAKER G-22 SEAL ASSEMBLY ID 3.875 3.812 3.750 3.875 3.875 Type NIP SLEEVE NIP LOCATOR SEAL (. 111 fllll111 WELL: 2P-429 DATE: 12/11/01 1 OF 1 PAGES LENGTH DEPTH TOPS ( Casing Detail 9 518" surface casing PHILLIPS Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 141 RT to LOS = 28.40' Above Rotary 6.80' RKB to LR 9 5/811 Landing Joint (35.20 total) Hanger 9 5/811 FMC GEN IV FLUTED MANDREL HANGER Jts 49-72 95/8",40# L-80 STCM Port Collar Jts 3-48 95/8",40# L-80 STCM Gemeco Float Collar Jts 1-2 9 5/8", 40# L-80 STCM Gemeco Float Shoe BTM OF SHOE @-----»»> TO 12 1/4'1 Hole Csg Hanger goes in the top of Joint # 72 12 TOTAL, Gemeco Bow Spring Centralizers... 3 Stop Rings 3- Centralizers in center of jts.1, 2 & 3 over stop rings 9 ... Centralizers over collars of jts,4-12 ** Fill using "Franks" fill tool... Remove tool after Circu & Condition ** Baker Lok all connections from the Top of FC down *Monitor returns closely.MUSH HAVE FULL RETURNS-Stop if NOT ** Remove air from slips for first 10 jts II Torque first 10 and average-Torque to AVG... Watch Diamonds 28.40 1.23 977.30 2.93 1875.92 1.53 75.76 1.72 29721 28.40 29.63 1006.93 1009.86 2885.78 2887.31 2963.07 2964.79 Remarks: String Weights with Blocks: 135k Up, 75k On, 34k TO & Blocks. Ran 72 joints of casing. Drifted casing with 8.679" plastic rabbit. Use Jet Lube Lead free thread compound on all connections. Doyon 141 Drilling Supervisor: Dearl W. Gladden ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: Start: 1 12/6/2001 :;~1¡;t\'~¡;~~~~}~;ô' :'q;t~o :~'\'~'~~ueêze:~~1~0f~~'~:;' Þ~Î~~~¡ng Hole Size: 12.250 (in) Hole Size: Hole Size: TMD Set: 2,965 (ft) SO TMD: (ft) TMD Set: Date Set: 12/11/2001 SO Date: Date Set: Csg Type: Surface Casing SO Type: Csg Type: Csg Size: 9.625 (in.) SO TMD: SO Date: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Cmtd. Csg: "'.; '". . ;i,',. ~:", , Spud Date: 12/8/2001 Report Date: 12/11/2001 End: 12/20/2001 .- J: :.11 I ; - ~. ' ",:' '?,.,',',' !..~ ~,": :. '.~ '. ." '" ;1~] h,,: ;(;.H:,,:":. 'f." \ . , Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) '/..: Cementer: Don Zierke Pipe Movement: Reciprocating ....; .- :.' .:" '," .. ,~ !"."" -::,:'pjÞ-~:~~:9~~~~,ijt' Init Torque: (ft-Ibf) Stroke Length: 5.0 (ft) ! ,-',' Rot Time Start: : Time End:: RPM: Rec Time Start: 1 0:00 Time End: 23:58 SPM: 60 Avg Torque: (ft-Ibf) Drag Up: 135 (Ibs) Type: Cement Casing Volume Excess %: 450.00 Meas. From: Time Circ Prior To Cementing: 10.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 80 (psi) Start Mix Cmt: 21 :32 Start Slurry Displ: : Start Displ: 01 :00 End Pumping: 01 :30 End Pump Date: 12/12/2001 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 474 (psi) 383 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: 75 (Ibs) , : , - Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: 145.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Type: KCL Polymer Density: 9.7 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature:70 (OF) Displacement Fluid Type:Mud PV/yP: 13 (cp)/15 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 215.90 (bbl) Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Rig Tank Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: AS Lite To: 1,525.00 (ft) Cmt Vol: 443.0 (bbl) Slurry Vol561 (sk) Temperature: 72 (OF) Temperature: (OF) Temperature: eF) Class: G Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: 276.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/9/2003 12:04:56 PM Sk~ 'Z1t.ffü"'1;t~¡~~d.j\~:., i:'n' "';"1:::,].,''; ".' ~ ': ';":" '::J:'..,c~'::;'"'''' };'¡;";:fit,J': -'.I;~;¥~Ù",~~~~.t';' '. ~. ."'~ '.-: ;.1(;. 0'':'.' -:~;.':-. ,;I;;.J.';'J',;.. ' "J1 ~;;"';', ~ 'r:~,~"JJ.. ,Ii,.. It; it.~'" .¡~~'~' '.; ~"",," '.. I' . . ,,, ,i<1-',,,, ' . ','''''-" Cri'" .;".¡ 'C.".., 'I, ,..,..,' ',W, '. "'-Ïl''''"'' . Legal Well Name: 2P-429 Spud Date: 12/8/2001 Common Well Name: 2P-429 Report #: 1 Report Date: 12/11/2001 Event Name: ROT - DRILLING Start: 12/6/2001 End: 12/20/2001 ..:;~t,i:':;,.;ctj~i~:iLe::": :;f;'::.; "~"; ""':"~f.:.:~j~r~!i~t~~~;.~~~;\~tf¡;':".":,,,:: 'UqUiJ'~~. ", ,.,!,..~~~} ", .,.;'.. D079 S001 D046 D065 D124 D053 1.5C 1.5C 0.6C 0.5C 50.00 30.0C , Stage No: 1. Slurry NI):2. of 2 Slurry Data Fluid Type: TAIL Slurry Interval: 1,525.00 (ftJTo: Water Source: Rig Tank Description: LiteCRETE 2,465.00 (ft) Cmt Vol: 134.4 (bbl) Slurry Vol303 (sk) Class: Density: 11.60 (ppg) Yield: 2.39 (ft3/sk) Water Vol: 58.0 (bbl) Other Vol: 0 Purpose: Mix Water: 8.12 (gal) Foam Job: N Test Data Thickening Time: 5.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature:72 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: 12.1 0 Compressive Strength 2: 15.00 Temp 72 (OF) 72 (OF) Pressure 500 (psi) 1,400 (psi) (OF) ,.tÿpe' ': >CpndähthitiÒh~'r.' : 0.20 1.0C "Units' :.; ':'.,.-~~,t~g:~~'~Q,:';~.:';~~Ù~rYN~:,~.::~t~ ~.*~~i!i\fês;: D046 S001 Casing test. Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: ~:,;;ift~~~~~Y;E~ållJ~tí9~ '.'" CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: ~ I: .,ji:~t~~~r~f~~.i~~.:,$~:~:M~'?,. .: . " ,".¡ Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) Printed: 6/9/2003 12:04:56 PM ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: Start: 1 12/6/2001 Spud Date: 12/8/2001 Report Date: 12/11/2001 End: 12/20/2001 .-," ',- ,':,fif?tH;;,; {;(:,; : ~..,' ~ - ?: ~ ,3'/ ~ .:Y;6,~{:;,:,~e~~n(~>:Ùt "':'~:\ " :r'~r: " I' . -.> l.i_~:; ,. . " ~ .. ';\. , - , Could only recip csg 5' . Drained stack to ck if hanger was centered. It appeared -OK-. After measuring and looking things over it is suppected that the collar on Jt #3 was hanging up on the end of the conductor. Informed eng & Team leader. Also could never get Tail CMT up th weight. Was planned for 12.0# and it could only be mixed to 11.6 or 11.7 and then would flobber(turn to non-fluid)in the tub. After talking to Dowell lab tech (perry)& well eng(Pat. R)& Team leader( Randy T), it was decided to go ahead and complete the CMT job. Printed: 6/9/2003 12;04;56 PM ( I~;"~ !'o4~I."¡~!"rit;Y;..,, " .~. ~.,~, ~~~~1'fM"~ "3'.,¡.¡t,~,.".¡.tA'~.'~.;:ï' u.' 'J '.';:'>'f!,'ttfttr' . ;'\'. ',' ' .; 'f,~,t '¡":~"c",'"_'" ','1, '1" . ',. ',,' ",' " f " . ,: ,.)! ' "I'''''' ,':t.-), . ".. ,'" ¡'¡;"','.::t.¡...-. "', ,'I', ~ '. ,;;~¡,.:,,:t-ì~~'~'i \';~" ;;, '..': :,;" ' '~~IMf'~,~ifÞ,~~,~~%,'~>., ~:- G:'~~' ~~-:-..;-;,;:. "~',~"",:~~"i::;f~,,;;.,~j.t~J~(~,'." ,:'r~f,:~~ " ""I'Jri:J'i:;:rí;!~I'~:":"",~'/" ~~,t.{;~j{:J~ '~"ì;:i:".l~ ,.;:'~~'~r.:¡p=r¡, ;:.~q~f~.";"":'~(i:' .~ ~;~~ .~:~:"'.l!~~)Fffit'i'~ .c'~, ;~""~' r..,~rr;'-.~'~~:dr.~' :';,~,~~:, ,c" ., ,:.j:I.',,,"I./-, "-"'~'JI'" I'.. .~f ,..~"' " it1~~;'i" ~l:t~}"lt' ¡ ,::i::'t:~{~W~1?""X..::;~,il ~ . ;,.;" '," "." ,... : ~G~i<,';ê:;~\/:/:¡j :.:;.' ~j.':~;~~:');, .: 't:f~: ~,~~~~i;}..~,>,~:r. ';-~ ~ ~ j :,' ':,'.' ':,i~~jf/ \~~-'," :' ' :: ~ . \:):~r~.t.,;~~~.".! ,~': ,.L: J .;.~ '~f'.;?>~;~>' , '. "', " ~:,,: ',,:' ," ,t:...:,. ,,;,«(':~7:r " ,jt~ WELL NAME JOBNUMBER EVENTCODE 24HRSPROG TMD ITVD IDFS REPTNO. I DATE 2P-429 ODR 2,972.0 2,438.0 5.00 6 12/11/2001 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANG Dear1 W. Gladden Doyon 141 Meltwater 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD CUM INT ANG WI MUD N/U BOPs 0 0 DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD 12/11/2001 306,047 890,843 I LEAKOFF AFE AUTH. AK0187 2,661,570 I NEXT CASING LAST BOP PRES TEST 9.625 (in) @ 2,965.0 (ft) 0 I ,CUM c'OST I 0 PflMf . CI 'Ca " 'H2S LIME ES I 24 HR FORECAST N/U & Test BOPs - P/U BHA #2 - TIH - Drlg Out LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 12/10/2001 2,900.33 52.550 168.590 (In) @ (ft) '~~E.~~i1)t,(ppg) , I 9.70 I.' pp 1 I ECD, I I MllD:DATA !."DAIL Y,COST, I 'FV ¡ P,Vlyp ,:GELS WL1i-l11iP 'FCIT.SOL 'OILIWAT ' %$arìdiMST " Ph/pM 41 13/15 5/7 7.5/ I / 18.5 9.31 .. ,OPERA TIONSSÜM MARY 'PHASE ' " .. SURFAC UD SHA #1 - S/S HWDP SURFAC R/U to Run 9 5/8" 40# l-80 STCM Csg SURFAC Run 9 5/8" Csg per well plan - Ran 72 jts - Shoe @ 2965' MD (2435' 1VD) Tight f / 2160' - 2365' SURFAC Circu & Condition Mud for CMT - Staged circu up to 6 bpm - No losses- Running 40 BPH water - Condition Mud per well plan specs - Properties at start: Wt 9.9+ppg, Vis 54 , PV 18 , YP 28 , Gels 10/20/21 Final properties: Wt 9.7ppg , Vis 41 , PV 13 , YP 15 ,Gels 5/7/9 **Note** Only able to recip 5' - We drained diverter and made sure esg hanger was centered "OK" It was- After checking figures it appears Csg collar on #3 jt hanging up on bttm of conductor. SURFAC PJSM with Rig Crew & all contractors - C/O Franks fill tool- M/U Dowell CMT head SURFAC Re-establish circu wI CMT head SURFAC CMT per well plan - Pump 5 bbl CW100 - Test CMT lines to 3500 psi - Con't pump 35 bbls CW100 @ 8.4ppg , Drop Bttm plug, pump 50 bbl MudPUSH @ 10.2ppg, pumped 443 bbls Lead CMT (561 sxs), 128 bbls Tail CMT @ 11.5 to 11.7 ppg, Drop Top plug, pump 10 bbl wash up,Turn over to rig - Rig will displace wI 2071 stks(Calulated) **NOTE** We were unable to mix the Tail to preposed 12.0ppg ,it Avg'd 11.6ppg . Talked to Dowell eng & Team leader. It was decided to con't and complete the CMT pumping. Dowell lab engineer(Perry) advised that the loss on compressive strength would be minimal. FROM to 00:00 03:00 03:00 04:30 04:30 10:00 HOURS 3.00 1.50 5,50 TROUBLE' SUB PULD RURD RUNC , C()DE DRilL P CASE P CASE P 10:00 20:00 10.00 CEMENT N~H CIRC 20:00 21 :00 1.00 CEMENT P SFTY 21 :00 21 :30 0.50 CEMENT P 21 :30 00:00 2.50 CEMENT P CIRC PUMP DSSCRIPTION ¡, 24 HR SUMMARY: Run 9 5/8" Csg- Circu & Condition - CMT Csg . '"," . I,~ " :-f'-~.: . , ", " , :i;. C.q'MPÄNY ,- Phillips Doyon .. , , ;, ITE;" ,. .,O~,I~'. bbls bbls , VSA(,1E' 1,441 1,025 Fuel Water, Drilling '. :r:~~'..~l:~:U~~NE[~~~r~Ä~~',;:r" 1 Misc Personnel 31 Service Personnel ~ . ' , .: ::3~'",,~.~:.:.~'~ :':.'. :';~'}J()';:' ',r(Hb,Ø~~," 5 12 ~ÊijSl,q£}'> ,~':. .MAtËR1~lS;(~()NSd~f»t~~N':? .' . ¡ " OrHiÀNÞ ~ " , .1ftè;~V':' ' . 4,673 Water, Potable 160 .'.', '. ':oN:t*.:f.ÄNJ?, 132 Printed: 6/9/2003 12:22:56 PM ( ( WELL NAME - . -- ..'~",..I~;",..:,:¡:, ",,,:.....,::,,,;...., .'., ~', TYPE 2P-438 3R-11 .'1: -, " , . , I':',' ,- I .'- ~ ~ - . , Åt:S~RVOJR' N~E ' 2P-438 3R-11 DS 4 G&I 2P-429 Np.. 673 2P-429 2P-429 , ,- ' ~',ŠlfMöR.T'.ORÃ"- 'R-~MAR~S':' ~. ~ ' ,; ..\ ".. ';:: 1YPË DS 4 G&I 2P-429 -: . " 'NO. REMARKS . ...- 2P-429 2P-429 2P-429 . ..... ~Ô~~~èS~RYbl~~~.Q 1~!fER!I~\Jj)M A 673 2.5 900-1050 0 0 COMMENTS Printed: 6/9/2003 12:22:56 PM ( ( *'~\"~%~~í~~!t!~:t;~~~'I~:¿"lt;:t;~~~~{;¡.;!~!.:.¡.t¡:'i"~~~~1iC.:~¡~'~fI. . ~'7'" ,~: ,; ..,;,~i :' >";r~'t::.r.y/:' ~'~'~~;-'~'tTi~:li'fl'~"~:-»:r' ',:-' ;,:C' .,""';,:; " ", ,':;ì' "..~;~:~.,,!i~;;L \~~>',;'i'-;"; ¡f*~ '~""'Ii" .~"¡ '''''ì'~f' 1.y'¡';~~1~ ~',., ') ".", "," "i,,:>.1!, '1*""<" ¡.; " ';'1'" , ,...", '.., ,.,. "."C '~''';r'' .. '1'1' WELL NAME JOBNUMBER EVENT CODE 24HRSPROG TMD TVD DFS REPTNO. DATE 2P-429 ODR 2,972.0 2,438.0 6.00 7 12/12/2001 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANG Dearl W. Gladden Doyon 141 Meltwater 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD Dir Drlg & Slide @ 3265' 0 0 DATE OF LAST SAFETY MEETING DAIL Y TOTAL CUM COST WI MOD 12/12/2001 87,726 978,569 I LEAKOFF AFE AUTH. AK0187 2,661,570 I NEXT CASING LAST BOP PRES TEST 7.000 (in) @ 8,821.0 (ft) 12/12/2001 0 I CUM COST I 0 PflMf CI 'Oa H2S LiME ES / Drlg - WiperTrip as needed - Drlg LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM LAST CASING 12/10/2001 2,900.33 52.550 168.590 9.625 (in) @ 2,965.0 (ft) :~~~~fu'~,ppg)1 ,9.60 pp 1, !Ëcg 1:M,Ob~j)ÄtÄr DAILY,COST 'j ',' ï=V' , PVlYP GELS WUHTHP, , 'FcrroSOL OIUWAT '%SandIMBT Ph/I'M 42 13/15 6/24 9.0/ I / /8.5 12.0/ BHA,NO.I, 2 I , '" ::BHA I Ho.LECo.NDll10NS , BHA m.' EJELOW JA~S , STRING'WT. UP STRING WT. ON ' STRING WT. ROT 51 110 100 98 rTEM QEst¡:fífiúô,N. ':NÓJrS,' :~ENGfH ' 0.75 1.15 31.55 5.15 27.49 9.02 23.52 11.88 30.45 30.85 30.82 2.16 90.65 32.32 785.60 24 HR FORECAST Bit STB Turbo Back Navidrill 1 XL Stabilizer - Non Mag MWD MWD MWD Neutron sub Sub - Hang Off 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 W gt Jars Drill Pipe - Heavy W gt "(),D~ ", 8.500 8.560 6.750 6.000 6.750 6.690 6.750 6.810 6.500 6.560 6.560 6.500 6.500 6.500 6.500 TORQUE/UNITS 6,500 ft-Ibf , " "Ú). , I BrTNO. I 2 BHA lENGTH 1,113.36 þONN,$iiE'Ç' .~'çp'~.~ nR.E'. 1.750 2.750 1.920 1.920 1.920 2.750 2.750 2.750 2.750 3.000 2.250 3.000 :J;;;;~w'i~¿,~'~t:j:'~~¡Jf[:.è~~~~;,i{,j:~~~>"~å~i~J~~:~~1~"J~~ ~¡~~\i':;,"G~=t;:I~;¡¡~;ß'. ",'."./'. ',~~~¡.~~~¡~',..' 2 I 2 8.500 SMITH S88HPX JS4314 12/12/12/12/12/11 2,972.0 12/12/2001 2-1-CT-N-D-I-EC-TD ¡t;,,,;;~¡~~~l~;,~'¡~~&~":,í"j!;~~~i;;{.L~~~';:..I~k~~~~Jr~~ft~~~~~I'.!~i~f~t~;j;'~¡~:,~~;~~~~~~~~M~~~~~~~'~,'~~, i~~~""~;',"f~Þïi~~ ",..,i¡9jj~, . fìÍbû~~~/';~~~<,.,~~=rì~~,~~~MMÂRý:A"':'¡":,:;,i~~~;'~~~¡f/.;,¡'''¡Z:i:;r:i¡\~"j¡¡\::,;.;),: 00:00 01 :30 1.50 CEMENT P DISP SURFAC Con't to displace CMT- Bump plug @ 2039 stks (Calculated 2071 stks) Fits held - CI P 01 :30 hrs (For CMT & pump detail see Report #6 12/11/01 ) SURFAC RID CMT Equip - UD LJ SURFAC N/D Diverter System PROD N/U Csg Head & Test to 1000 psi - hold 10 min PROD N/U 135/8" 5K BOPs - Change bttm pipe rams to 5" -( 31/2" X 8M VBRs in Top Rams) NUND PROD Remove equip from floor - C/O TD bails BOPE PROD RlU to test BOPs 01 :30 03:00 03:00 05:00 05:00 06:00 06:00 10:00 1.50 2.00 1.00 4.00 CEMENT P WELCTL P WELCTL P WELCTL P PULD NUND NUND NUND 10:00 11:00 1.00 WELCTL P 11 :00 12:00 1,00 WELCTL P Printed: 6/9/2003 12:23:29 PM (' ( 2P-429 .F~bM: .to' ':~Ó~~~,;,;fÇ~b-~'.-": TRO:~B~E ".' '~~B~,..~=ff)~~.-:~U~~'~~~:.~.'; " ' "D~~CAiÞ.~N':-, , 12:00 15:30 3.50 WELCTL P BOPE PROD Test BOPs & Choke Manif 250psi 10 & 3000 psi High. Ea. test held 5 Min. No failures Pull test plug - Set wear bushing - Blow dn choke manifold P/U BHA #2 tools to Rig floor - PJSM on RA scorces M/U BHA #2 - P/U Bit, TurboBack Stb, re-configure to 1.0 AKO & Scribe M/U Sperry Tools - Program MWD - Load RA Scorces P/U 3 NMDCs & TIH - Rotate Slowly thru port collar @ 1006' - Tag up @ 2884' R/U to test Csg - Circu air from system - Test Csg to 2500' psi - Pump 12 stks - Hold on Chart 30 min - (Loss 35 psi) DRLG PROD Drlg Plugs, FC , CMT & Drilling on FS WELL NAME 15:30 16:00 16:00 17:00 17:00 18:00 18:00 20:00 20:00 21 :30 21 :30 22:30 0.50 1.00 1.00 2.00 1.50 1.00 WELCTL P DRILL P DRILL P DRILL P DRILL P WELLSR F 22:30 00:00 1.50 DRILL P BOPE PULD PULD PULD PULD DEaT PROD PROD PROD PROD PROD PROD 24 HR SUMMARY: Finish CMT displ - NID N/U - Test BOPs - P/U BHA - TIH - Drlg out " ::;."pêÁŠÒNNê['.DÄTA" ".,:'Nb.'::,' 'H.QIj~~> . ':~::;)cq.MrA.NY'" 1 Misc Personnel 30 Service Personnel ,¡:: CÒMPÂ~Y : Phillips Doyon . , '," ,~"O;:". ';~Ñ!::<,.:' Fuel Water, Drilling ,I.: ".TYPÈ :'-: 2P-438 3R-11 :'NO>' . H01.Jfís: 5 9 '.$~RVICE" . "ljS~$_e.,:;:~~~~~j~~~-:~~'L?ON$:~~M1~£%N. ' 1 ,338 3,335 Water, Potable 645 315 ': s; :. .PN.""~ '.- bbls bbls ".O'~'HÄNP 132 UNat$ .'. bbls ,',',':SUÞPORt:ÖRAFT ,', REM.(\Rlqr.:... ' . ': .::'/rVPE' DS 4 G&I ',NO.:" : 1 ,228 2P-429 2P-429 ." . ¡ . ~:.~ ,'. r.: ," " ' : . !.", J ~ . '.: .' ;:: '~E,~~BV.ÓIR:NAM~'\':,':' ',,: ~'~:':, . 2P-438 2P-429 3R-11 2P-429 DS 4 G&I 2P-429 NO. 2P-429 ...~Ó~E::~:~,~Ê~,r~.I,~b~~:~:J'~~;ERV~~~~~T~ " 1228 3 1000 0 0 , " -,", . .' '. '. ~ '.' , -:,. n. ',' .. " . . ":', :..~C'q~~~~c::'. Printed: 6/9/2003 12:23:29 PM . 'phIUI.Þs Alaska~ 1110'. . . . Dåily'Drilling '-',port I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS 2P-429 ODR 1,728.0 4,700.0 3,481.0 7.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAfL Y TANG Dear! W. Gladden Doyon 141 Meltwater 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAfLY INT WIO MUD Wiper Trip to Shoe - Serv Rig & TD (TD 5009' MD) 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAfL Y TOTAL Complete WT - Drlg t/ 7000'- - WT 12/13/2001 116,971 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.01 AK0187 2,661,570 LAST SURVEY: DATE TMD INC AZIM ¡LAST CASING ¡NEXT CASING LAST BOP PRES TEST 12/13/2001 4,566.26 52.860 171.320 9.625 (in) @ 2,965.0 (ft) 7.000 (in) @ 8,821.0 (ft) 12/12/2001 :DENS!li(ppg) I 9.60 I pp. I IECD I livlu.DDATA I. D!uLY COST I 0 I, C~M COST I 0 FV PVIYP' GELS WLlHTHP FCIT.SOL . OIL/WAT " "%SanCÍ/MBT . Ph/pM PfNlf CI Ca' H2S' . LIME ES 48 15/18 6/20 4.2/ / / /8.0 9.3/ I ( WELL NAME LITHOLOGY BHA~O. .'1 . 2 I BHA WT. BELOW JARS 15 ,BHA lHOLE ~CO~brrIONS: . , STRING WT. nN . STRING WT. ROT: 98 112 , NO JTs . LENGTH 0.75 1.15 31.55 5.15 27.49 9.02 23.52 11.88 30.45 30.85 30.82 2.16 90.65 32.32 785.60 STRI~G WT. UP 132 ITEM DESCRIPTION Bit STB Turbo Back Navidrill 1 XL Stabilizer - Non Mag MWD MWD MWD Neutron sub Sub - Hang Off 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 W gt Jars Drill Pipe - Heavy W gt BIT /.RUN:, . 2/ 2 , SIZE. MANUF. . 8.500 SMITH , ,BITS:' " "'TYPE $EFUALNO.: ".' JETS'ORTFA, S88HPX JS4314 12/12/12/12/12/11 ( , . Page 1 of 2 I REPT NO. I DATE 8 12/13/2001 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1,095,541 . TORQUE I UNITS ' 6,000 ft-Ibf I.D~ ',I BfTNO.:.J 2 . .' BHA LE~GTH 1,113.36 CONN SIZE. CC';>NN TYPE , '0.0. 8.500 8.560 6.750 6.000 6.750 6.690 6.750 6.810 6.500 6.560 6.560 6.500 6.500 6.500 6.500 1.750 2.750 1.920 1.920 1.920 2.750 2.750 2.750 2.750 3.000 2.250 3.000 DEPTH iN DATE' IN. , "" .1~O-D-L-8-p-O~R , 2,972.0 12/12/2001 2-1-CT-N-D-I-EC-TD , , B,IT I RUN' 2/ 2 "WOB' 5/20 , 'BITOPERA TIONS .: ,:RPM . . GPM' ;PRESS P BIT '. 'HRS . , 24Hr DIST : 24HrFIOP èUMHRS CÚMdE;PTH ;ÇUM ROP 60/100 550 1,750 388 15.00 1,728.0 115.20 15.00 1,728.0 115.20 'M;D.. .' 2,987.63 3,081.56 3,174.46 3,267.06 3,360.26 3,453.02 3,545.63 3,639.61 3,732.68 lNêL " 52.320 51.820 51.670 51.640 53.310 54.040 54.080 54.000 53.740 . " '. .SURVEY.DATA,' "AZIMUTH' T.V.D., NisCUMEIW CUM SeCTION M~D.: 168.050 2,448.17 -1,364.3 250.26 1,387.07 3,825.61 168.970 2,505.90 -1,436.9 265.02 1,461.14 3,918.47 168.440 2,563.43 -1,508.4 279.31 1,534.08 4,011.47 168.090 2,620.87 -1,579.5 294.08 1,606.69 4,102.31 168.570 2,677.64 -1,651.9 309.03 1,680.58 4,195.89 169.630 2,732.59 -1,725.3 323.16 1,755.31 4,289.30 170.340 2,786.95 -1,799.1 336.20 1,830.29 4,381.51 170.540 2,842.13 -1,874.1 348.83 1,906.35 4,472.76 170.070 2,897.01 -1,948.2 361.49 1,981.52 4,566.26 INCL~ 53.700 53.740 53.370 53.230 52.840 52.490 51.910 51.110 52.860 . . . . " . "",' . . AzIMUTHT~V.D. ' 'N/S'CÿM EIwC~M :~ECï1()N.,' 171.010 2,952.00 -2,022.1 373.80 2,056.42 170.920 3,006.95 -2,096.0 385.56 2,131.26 169.760 3,062.20 -2,169.8 398.11 2,206.06 169.940 3,116.48 -2,241.5 410.94 2,278.89 170.700 3,172.76 -2,315.2 423.52 2,353.66 171.110 3,229.41 -2,388.5 435.26 2,427.91 171.690 3,285.92 -2,460.6 446.15 2,500.73 171.870 3,342.72 -2,531.3 456.37 2,572.11 171.320 3,400.30 -2,604.1 467.14 2,645.72 Printed: 10/1/2003 2:38:49 PM ( ( .", 2P-429 Phllllp~ 'A'~~1öt(, ~hC. ' Daily.:lj)rllllng:'l~I.'þort . ~ .. . ~1 ".:.' . I JOB NUMBER I EVENT CODE \24 HRS PROG I TMD ODR 1,728.0 4,700.0 Pagë2.:of 2 WELL NAME ITVD IDFS REPTNO. I DATE 3,481.0 7.00 8 12/13/2001 NO. 1 2 MAKE OF PUMP PUMP I HYDRAULIC DATA STROKE(ln) UNER(ln) '. SI:'M Q(gpm} PRESS.(psl) TOTALQKILLSPM I PRESSURE 12.000 6.000 65 274.96 1,820 549.92 45 380 12.000 6.000 65 274.96 1,820 549.92 Emsco Emsco 01 :30 02:00 0.50 DRILL P LOT PROD 02:00 05:00 3.00 DRILL P DRLG PROD 05:00 06:00 1.00 DRILL P OTHR PROD 06:00 12:00 6.00 DRILL P DRLG PROD 12:00 00:00 12.00 DRILL P DRLG PROD 24 HR SUMMARY: Dir Drlg & Slide , . OP.E"R~TIONS;oSUMMAflY. FROM. TO .HOURS CObE :,.,TROUBLE SUB. PH~SE':' ". .'. . 00:00 00:30 0.50 DRILL P DRLG PROD Drlg FC & 30' new hole to 3002' 00:30 01 :30 1.00 DRILL P CIRC PROD Circu hole clean - Displace New conditioned 9.6 ppg mud into system.(Blended the last 278 bbls of new mud into our system) Pull back to shoe - Preform LOT to 16 EMW - (818 psi @ surface, 2458'TVD w/ 9.6ppg Mud) PSI loss to 670 psi after 10 min Dir Drlg & Slide 3002' to 3246' MD Sperry Sun Preform & record PWD Base line test - ECD hardline 11.7 @ 3200 to 11.9ppg @ 9000' Dir Drlg & Slide 3246' to 3860' MD (2972' TVD) ART 6.2 hrs , AST 0.5 hrs Dir Drlg & Slide 3860' to 4700' MD (3481 , 1VD) ART 8.3 hrs , AST 0.5 hrs 'DESCRIP110N ~ERVICE . P.ERSONNE.L"DATA' NO; . HOURS" . . . CÖMPANV . . 1 Misc Personnel 31 Service Personnel SERVICE HOURS' . '. C9MPANY ConocoPhillips Company Doyon NO. 5 8 '. ITEM . UNITS bbls bbls MATËRI~LS I CÖNSU~ÞTION USAGE. . . ON HAND '. ITEM 1,558 1,777 Water, Potable 860 255 . UNITS bbls USAGE" 120 ON HAND 112 Fuel Water, Drilling TYPE 2P-438 3R-11 NO;' . 1,061 2P-429 2P-429 . SUPPORT CRAFT REMARI<S " . "". . . 'TvPE" DS 4 G&I : NO. REMARKS 2P-429 . . RÊSERVOIRNAME . 2P-438 3R-11 DS 4 G&I 2P-429 2P-429 2P-429 . :R~SERVOIRAND"NTr:~VAL'DAiÀ' . ZONE. .. Tc,>P . :BASE' 1061 2.5 850 - 1000 0 0 . COMMENTS . Printed: 10/1/2003 2:38:49 PM \ Report #: 2 Start: 12/6/2001 . 'G~ri~r.åHi~f~},;~~~ion' ConocophiHî'ps';AlaSka' Casing,Re"port . Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING .. ".;.~.. :i..:":];.':j:/;;';;r'..r . .:"..~i .. String Type: Production Casing Hole TVD: 6,002.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 4.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Rotary Table 0.00 (ft) (ft) (bbl) Casing Flang'e I Wellhead Hole Size: Water TMD: Liner Overlap: KB to Cutoff: Manufacturer: Hanger Model: Actual TMD Set: 8,966.17 (ft) FMC Model: Packoff Model: Gen 4/5 8.500 (in) (ft) (ft) 25.55 (ft) Integral 'Casing. Detail MU Torq. TRD Manufacturer (ft-Ibf) Item Size . Weight Grade Drift Threads JTS Length . TO'p (in,) (I bitt) (in) (ft) (ft) Casing Hanger w/pup 7.000 6.151 1 1.78 25.55 7" CASING - PRODUCTI 7.000 26.00 L-80 6.151 BTC Mod 179 7,580.47 27.33 7" CASING - PUP JT 7.000 26.00 l-80 6.151 BTC Mod 1 9.73 7,607.80 CROSS OVER - locator 7,000 4.750 BTC Mod 1 1.03 7,617.53 SEAL BORE EXTENSIO 7.000 4.750 1 19.23 7,618.56 4.5" CASING - PUP JT 4.500 12.60 L -80 3.833 IBTM 3 15.86 7,637.79 4.5" CASING - PRODUC 4.500 12.60 L-80 3.833 IBTM 3 91.13 7,653.65 4.5" CASING - PUP JT 4.500 12.60 L -80 3.833 IBTM 1 9.92 7,744.78 4.5" CASING - PRODUC 4.500 12.60 l-80 3.833 IBTM 36 1 ,115.32 7,754.70 FLOAT COLLAR 4.500 IBTM 1 1.42 8,870.02 4.5" CASING - PRODUC 4.500 12.60 l-80 3.833 IBTM 3 93,11 8,871.44 FLOAT SHOE 4.500 IBTM 1 1.62 8,964.55 Non-Integral Casing Accessories Accessory Manufacturer Number Bowspring Centralizer Bowspring Centralizer WEATHERFORD WEATHERFORD 34 8 FMC Gen. 5 local local BAKER BAKER Local Local Local Local y WEATHERFORD Y Local y WEATHERFORD Spacing (ft) Top,(ft) - . - .'~. Spud Date: 12/8/2001 Report Date: 12/18/2001 End: 12/20/2001 . . . ..." -- ~ . -""'. ~.. ~..:. '~.i " ':,¥~:~~~.~~~~L~ Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 8,974.0 (ft) 190,000 (Ibs) 54.00 (°) 12.00 (days) ~ "':. """'." ';.~> ',' ".',' - '. -L.- .. ..'... ...::. ØG~~;II! - ,~--' ~. . ,r -~ .'~ Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) I 5,000 (psi) . Model<. .;'..'~i,.~~;;ill 'JEW 6.276 'JEW 7.658 6.276 'JEW 7.656 6.276 \JEW 7.656 4.750 'JEW 7.000 4.750 'JEW 5.200 3.958 'JEW 5.200 3.958 'JEW 5.200 3,958 'JEW 5.200 3.958 'JEW 5.200 \JEW 5.200 3.958 'JEW 5.200 .'-" , frifeniaJ Botton)--(ft) . . "'õ.,,;"':-.'.. - - . 7,800.0 7,260.0 8,966.0 Set Screws 7,600,0 OverCollar Printed: 6/9/2003 12:05:21 PM Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Accessory Centering Guides PESI Ran 179 jts 7" 26# L-80 BTC M casing Ran 42 jts 41/2" 12.6# L-80 IBTM casing Displaced 41/2" casing with 9.8 ppg KCL water Manufacturer ConocoPhîllips Alaska Casing :Re'port Report #: 2 Start: 12/6/2001 Non-Integral Casing Accessori'es Number 24 Remarks Spacing (ft) . . . ,.1.." --.:' :.'.~~.~~."' ".-'-~.~~.~.~'<:Y - - L. -' - -P" - - . ->.,/:, '-~~~;:'S'~~:0~,:~ , , Spud Date: 12/8/2001 Report Date: 12/18/2001 End: 12/20/2001 .. ., ~ir¡~¿~ . . . . ,,- of' ,. - .~' " 'JntéiV81 . Top (ft) . Bottom'(ft) 2,950.0 100.0 Floating . . ~. Printed: 61912003 12:05:21 PM (' ( .¡~"nì . ,I.:..'\'.,"~ -' , i'~";J ,t~,('~"j~'I) ,', , ~,:,:\!,~:;(>/."" ':. ". : ' " ' : . I ,~ Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING , ;, ;'.,;'.>' :\; , , : '~prirnäry 8.500 (in) 8,966 (ft) 12/19/2001 Production Casing (in.) Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: : Time End: : Report #: Start: 2 12/6/2001 . .' A)~",~~.¡~~~~~P!~ .PrllÎïlJ~ .. . "j, ..: . . I . I '. /'.' t. I,. I . ",Sque'éze-OpènHol~ ", " :,::;:;:(,j, .', :SqueežéCasln-g , Hole Size: Hole Size: SO TMD: (ft) TMD Set: SO Date: Date Set: SO Type: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cmtd. Csg: Cementer: Kevin Anderson :' <r~iþ'i{~~.Þ,~~~ØJ1t ~ Pipe Movement: . "":.' . Init Torque: (ft-Ibf) Stroke Length: (ft) ,,'.' "'.":~~~~'~~~~;~;}';1:o.~~":':' Type: Cement Casing Volume Excess %: 75.00 Meas. From: Time Circ Prior To Cementing: 8.00 Mud Circ Rate: 250 (gpm) Mud Circ Press: 600 (psi) RPM: SPM: Start Mix Cmt: 11 :00 Start Slurry Displ: 12:05 Start Displ: 12:05 End Pumping: 13:00 End Pump Date: 12/19/2001 Top Plug: Y Bottom Plug: N Avg Torque: (ft-Ibf) Drag Up: (Ibs) . . '. . f 1- " ~ - 'i.. ...: . .'. ' Spud Date: 12/8/2001 Report Date: 12/19/2001 End: 12/20/2001 ,Þiùg' Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled, Out: Cmtd. Csg: (ft) (ft) Max Torque: (ft-Ibf) Drag Down: (Ibs) ,,' Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 700 (psi) 1 ,200 (psi) 1,200 (min) Y Returns: Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: scale Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 47 (s/qt) Bottom Hole Circulating Temperature:80 (OF) Displacement Fluid Type:Mud PVNP: 15 (cp)/15 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 14 (lb/100ft2) Bottom Hole Static Temperature: 80 (OF) Density: 9.6 (ppg) Volume: 284.00 (bbl) .,è~9~'~¡¡~1,,~,~ii~Hk¡i~:~t~'T .' ',' ~, ~~~ .~ Slurry Data Fluid Type: LEAD Description: ASLite Slurry Interval: 7,200.00 (ft}To: 7,700.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: Slurry Vol:B4 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) T emperature:(OF) Temperature: (OF) , . ^ , " , - . " ~ . .",", " - . ~ ',\ Class: G Density: 13.00 (ppg) Yield: 1.99 (ft3/sk) Water Vol: 22.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: PRI MARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/9/2003 12:05: 1 0 PM ( Legal Well Name: 2P-429 Common Well Name: 2P-429 Event Name: ROT - DRILLING Report #: Start: 2 12/6/2001 Spud Date: 12/8/2001 Report Date: 12/19/2001 End: 12/20/2001 . . : , , ' - . ."' ,,:; .." ." :,'~" . '. '. I.~.r. r Stqgè~~:'4~$~.ur~¥~;~:ó: ;2: pllt I, t... -.:, ~ ,.;. , -,j- Slurry Data Fluid Type: TAIL Description: ARCTIC SET Slurry Interval: 7,700.00 (ft)To: 8,966.00 (ft) Cmt Vol: 107.0 (bbl) Density: 15.80 (ppg) Water Source: Slurry Vol:500 (sk) Water Vol: 63.0 (bbl) Class: G Yield: 1.20 (ft3/sk) Other Vol: () Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: eF) Temperature: (OF) Temperature: eF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) .. . , , . . . . .. ", I..inértöþ T~$t. - shriÈ!rèst Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: .: :,:-D.Þ9iSÞfveYE~~luatiÖh ---- '::-:I,rt,~tp.t~t~ii~r:$~~IT1,élry - - - CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: printed: 6/9/2003 12:05:10 PM E~~~W~~.': ,,;,,~i~r)~¡;{¡:~ì:"'~;..;JJ';~.;:iF}:lr~~~¡,~~il~~~'. :'~~~~,~r;Ù~~~~M~."'" .,.,,,.~. }~,\. 1~~l:~,fj~r:;}':c-J;:..~'t \¡,T:~,~ nii~t~Nr~~ Éa'~' <'~;.:.. . .i\:;,Rl;;:I.~'~ '.:;rtf~~;.!:~;v:~~1':~Îjr~~ WELL NAME I JOB NUMBER I EVENT CODE 24 HRS PROG TMD TVD I DFS I REPT NO. I DATE 2P-429 ODR 8',974.0 6,002.0 13.00 14 12/19/2001 RIGNAME & NO. FJELDNAME/OCSNO. AUTHMD I DAILY TANG ICUM.TANG Doyon 141 Meltwater 0 0 ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG WI MUD Circ. clean water in well 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAlL Y TOTAL CUM COST WI MUD Space out, hang off, test annulus, N/D BOP, N.U tree, fro pr 12/19/2001 75,983 1,748,103 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.01 AK0187 2,661,570 LAST SURVEY: DATE TMD INC AZIM LAST CASING I NEXT CASING LAST BOP PRES TEST 12/17/2001 8,974.00 56.090 173.500 9.625 (in) @ 2,965.0(ft) 7.000 (in) @ 8,821.0 (ft) 12/12/2001 "Ò~~srtv(pPŠ) I 9.60 I ,pp I lecp IriII'Utf"DÀtAI DAILV.CQ$T"I 0 ICU~,CÒ$T I 0 'Fv .. pvtYP GELS WLlHTHP Fcrr.SOl. OILlWAT' %SåiidIM.BT .Ph/pM PflMf ci Ca H2S . UME ES 42 14/15 5114 4.4/ / / /7.5 9.5/ / .OPERATIONS.SUMMARY pHASE PROD PROD PROD ( SUPERVISOR D. Presnell CURRENT STATUS FROM .to HOURS CODE TROUBLE .SUB 00:00 03:00 3.00 CASE P RUNC 03:00 07:00 4.00 CEMENT P CIRC 07:00 11:00 4.00 CEMENT P RURD 11:00 13:00 2.00 . CEMENT P PUMP 13:00 14:00 1.00 WElCTL P 14:00 16:30 2.50 WElCTL P 16:30 18:00 1.50 CMPl TN P 18:00 00:00 6.00 CMPLTN P NUND NUND RURD RUNT ( . DESCRIPTION Run 7" casing f/6948' to 8966' Circ. and cond mud for cement job R/U cement head, hold pre-job safety meeting, attempt to batch mix spacers and cement, having freezing problems, mixing went very slow, circ hole with rig pump while this operation is going on PROD Pump 10 bbls CW100, test lines to 3500 psi, pump 80 bbls CW100, pump 50 bbls 12 ppg. MudPush, pump 30 bbls 13 ppg lead cement, pump 107 bbls 15.8 ppg tail cement, drop top plug, pump 27 bbls 9.8 ppg KCl water and displace with rig pump with 9.6 ppg mud, bump plug with calculated strokes, check floats and floats held. Reciprocate pipe through out cement job. PROD land casing in wellhead, remove landing jt., set packoff and test to 5000 psi. PROD Change pipe rams and test. CMPl TN R/U to run 41/2" completion tubing CMPl TN RIH with seal assembly and completion equipment on 4 1/2" 12.6# L-80 ISTC tubing to 5610' 24 HR SUMMARY: Run 7" casing, Circ and condo mud, cmt as program, run packoff and test, change pipe rams and test, R/U and run 4 1/2" tubing ...US¡¡¡,~'..'~Ät~~¡~~y'~~~~sù~~õ~.',' 2,397 2,845 Water, Potable 880 445 .:~sUPPÖRìCRÄff ..: . AEMARKS,: . ,'TYPE 'I,'> . , . .. , ,. .' $~fivlc~ Phillips Doyon Fuel Water, Drilling . ,.TIP.E, ' 2P-438 3R-11 "N(:),: 1 ,797 2P-429 2P-429 . .. ',' . ..:-::--i'PEI:ì.Š,ONNELDATA:':},:: N9;i', :HÞii,R5':::;.~:: ;:;'.; :,'ç~~PÀ~V-. 1 ' Misc Personnel 29 Service Personnel 5 12 '>:':.~Ntt$:~,::::::'"> --;')~;~~~":i:;" "::;~~:?ö~l:~~~~.t:~~ bbls 100 106 .,',1 ::. '~',: ~ . ~~. . . - .' .: ::!foü'f.i~_:,', ~':: f,;' ~. . .. . .~,., :"::', . , ~ ' . ,:: /:':. ~:;r~:.X.:;ø~Àyj.p,~--. .. I, " :. . ~Ö'-"'. DS 4 G&I 2P-429 . Printed: 6/9/2003 12:24:55 PM - __1 r_o :! . ..,. IJOBNU~BER'I'~~E~~~~E .124~RS;R~~ . I-T~D .I~D' -'ID~~ . "IRE~NO~' I~ATE - 2P-429 ODR 8,974.0 6,002.Q 13.00 14 12/19/2001 RÉSE'R\iÒlff3ANè~N"'t!FUlÂ'L:DÃ'A');~--'" - ZONE TOP eASE - '. 1797 2.75 700-1100 0 0 . . ~ . ,rr'ih- '~,;.: t -If(:'~r . 1l1~f~:î!i~(:'. . ... ~ ""'"t:'. . '1'"¡;t"',-" ~ :\" ~~~<~.\\%~r:. . WELL NAME , : :~RESERVoiR NÃME 2P-438 3R-11 DS 4 G&I .:' :-cå~MËNTs. ., ,. ~ 2P-429 2P-429 2P-429 Printed: 6/9/2003 12:24:55 PM Re: Mbltwater 2P-429 , ). êAol- JO~ Subject: Re: Meltwater 2P-429 Date: Man, 17 Dec 2001 13:58:05 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Lamont C Frazer <Ifrazer@ppco.com> cc: Ryan L Stramp <rstramp@ppco.cam>, Thomas A Brockway <tbrockw@ppco.com>, Patrick Reilly <preilly@ppco.com>, Ronda C Wenger <rhuwa@ppco.com>, Steve Moothart <smootha@ppco.com>, Bob Crandall <bob_crandall@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us> Lamont et ai, Thank you far your note with regard to the desire to preserve the development potential of the Cairn zone located a -230' tvd above the Bermuda zone in the subject well. You are requesting a variance to the requirement of having the packer (or in your case CSR XO) not more than 200' md of the potential perforations. (n our discussion, it was indicated that where the Cairn is identified PPCo would propose to place the CSR XO about 100' md above that formation top and then would pump sufficient cement to have the TOC 500' above the Cairn formation top. In those wells permitted for injection service, a cement quality log would be run to assess the isolation achieved. Commission regulation 20 AAC 25.412 (b) specifies the 200' md distance mentioned above, but also allows the Commission to approve a different placement depth given the thickness and depth of the confining zone. Where the Cairn is present, some 230. tvd of confining zone (in this case) is present. With a successful cement job through this interval, more than sufficient isolation should be achieved. Your proposal to change the depth of the CSR XO in 2p..429 to -100' md above the Cairn formation is approved. Prior to initiating water injection into the well, the cement quality fog should be provided to Commission for review. Good tuck with the operations. Please call with any questions. Tom Maunder, PE AOGCC Lamont C Frazer wrote: > Tom t > The purpose of this emaH is ta summarize aur discussion today concerning > options to preserve Cairn development opportunities in Meltwater Well > 2p..429. > > Background > Phillips Alaska, Inc. (PAl) has encountered two neighboring hydrocarbon > bearing zones in Meltwater Well 2P-429: Bermuda and Cairn. (Depths for > zone are summarized below.) Preliminary estimates are the Bermuda interval > contains -73' of 011 pay while the Cairn interval contains -7' of gas pay. > Preserving the ability to access the Cairn is necessary to developing this > resource at a later date. To inexpensively preserve access to the Cairn > Interval with our existing completion design would require setting the > crossover -400' MD (230' TVD) above the Bermuda Interval. 2P-429 will > initially be used for Bermuda injection service; hence, preserving the > option to maximize Cairn resource development would exceed the 200' > measured depth guideline specified in 20 AA C 25.030. > > Interval > Depth (MD) Depth (SS TVD) 10f2 12/17/01 2:12 PN Re: Meltwater 2P-429 ¡, ,.þ ( > T4.1 (Cairn) 5047' > 7752' > T3 (Bermuda Top) 5278' > 8147' > T2 (Bermuda Base) 5489' > 8515' > > Action Plans > PAl wíll proceed to set 2P-429's crossover above the Cairn interval > contingent upon approval from the AOGCC. A positive response to this email > would confirm AOGCC approval. Bermuda injection would not be initiated > until evidence is obtained showing the zone is isolated. PAl will submit a > sundry detailing the above-mentioned changes. > > Future Meltwater wells that are suspected of having Cairn potential will > include plans to set the crossover above the Cairn in the permit > applications. If the Cairn interval is not present, the crossover would be > set deeper in the well. > > PAl will provide a synopsis detailing the reasons for setting the crossover > above the Cairn interval. The A OGCC may use this to help decide whether to > modify the Meltwater Injection Order. > > Best regards, > > Lamont Frazer > Meltwater Reservoir Engineer , ' Tom Maunder <tom maunder@admin.state.ak.us> I Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 20f2 12/17/01 2:12 PI\ ~J~71 :' J !Æ~!Æ~~~!Æ ATASIiA ORAND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR I 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 James Trantham Drilling Engineer Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 2P-429 Phillips Alaska, Inc. Permit No: 201-102 Sur Loc: 933' FNL, 1956' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 1610' FNL, 2256' FEL, Sec 20, T8N, R7E, UM Dear Mr. Trantham: 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 2P must comply with the requirements and limitations of20 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 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Kuparuk River Unit 2P-429 Permit to Drill No. 201-102 Page 2 of2 Commission to witness a test ofBOPE 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF WE COMMISSION DATED this 29'day of May 2001 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo 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 ~ Development Gas 0 Single Zone rnØ 5. Datum elevation (OF or KB) RKB = 102 feet AMSL 6. Property Designation ADL 389058 ALK 4998 6.,.3731/2- 7. Unit or property Name )}> Kuparuk River Unit 8. Well number 2P-429 20. Attachments Filing fee ~ Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program ~ Drilling fluid program ~ Time vs depth plot DRefraction analysis 0 Seabed report 0 20 MC 25.050 requirements ~ 21. I he by certify that the foregoing is true and correct to the best of my knowledge Questions? Call Pat Reilly 265-604. v)- ' J.- T,",,'h= J ( 1 a. Type of work: Drill b!J Redrill U Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 933' FNL, 1956' FWL, Sec. 17, T8N, R7E, UM At top of productive interval 1079' FNL, 2351' FEL, Sec. 20, T8N, R7E, UM At total depth 1610' FNL, 2256' FEL, Sec. 20, T8N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 2256' @ TD feet 2P-438 180' @ 100 16. To be completed for deviated wells i Kickoff depth: 300 MD 18. Casing program size Maximum hole angle 53.3 Hole Casing Weight 42" 16" 62.5# 12.25" 9.625" 40# 8.5" 7"x4.5" 26# Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 BTCM Length 80' 2960' 8139' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition 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 Q. ::}f1l~~ .~ . - ( ðMri 51z4Jol ~ 1;3 Development Oil U Multiple Zone 0 10. Field and Pool Kuparuk River Field Meltwater Oil Pool 11. Type Bond (see 20 MC 25.0251) Statewide Number #59-52-180 feet 9. Approximate spud date Amount May 25, 2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8821 ' MD I 5932' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1971 psig At total depth (TVD) 2591 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 30' 30' 110' 110' 9 cu yds High Early 30' 30' 2999' 2449' 350 sx AS III L & 300 sx LiteCRETE 30' 30' 8821' 5932' 470 sx Class G I Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEIVED MAY 2 3 2001 Alaska Oil & Gas Cons. Commissibn Anchorage Title: Drilling Engineering Supervisor I j Date ~3/ol I PreD~red bv Sh~ron AlIsuD-nr~k~ i Commission Use Onl} Permit Number I API numberø ~" I Approval date :',- ,n I ',e , :;2LJ1-/oz- 50-/03-2.ð310-(X) :)'í"'1,) Conditions of approval Samples required 0 Yes ~ No Mud log required Hydrogen sulfide measures 0 Yes J&t...NO Directional survey required ~ Yes Required working pressure for BOPE 0 2M; ~ 3M; 0 5M; 0 10M; 0 0 Other: Approved by :JRIGINAL SIGNED BY 0 Taylor Seamount Form 10-401 Rev. 12/1/85. I See cover letter for other requirements 0 Yes üa No 0 No Commissioner by order of c:: 1'), \ 0 \ the commission Date.) . J't '1 ' 0 J G N.: L Submit In triplicate APPlt ..,1"\ for Permit to Drill, Well 2P-429 , Saved: 23-May-01 Permit It - Meltwater 2P- 429 Application for Permit to Drill Document MoximizE We:11 Vglu~ 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. Casing 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. Dri II 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 10. Seism ic 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. Evidence of Bond i ng. ....... ......... .... ... ..... .............. ...... ....... .... ................. ....... ...... ...... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 OR GNAL 2P-429 PERMIT IT 5-22-01. doc Page 1 of 7 Printed: 23-May-01 ( APPlir """n for Permit to Drill, Well 2P-429 Saved: 23-May-01 13. Proposed Dri Iii 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. A tta c h men ts ............................................................................................................. 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 2P-429 PERMIT IT 5-22-01. doc Page 2 of 7 0:' G N A . Printed: 23.May.01 ( APPI~. ""n for Permit to Drill, We1l2P-429 Saved: 23-May-01 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b) For a well with multiple wel! branche~ each branch must similarly be identified by a unique name and API number bV adding a suffix to the name designated for the ¡/lell 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-429. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dríll must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the propertý's owners and showing (A)the coordinates of the proposed location of the well at the surface¡ at the top of each objective formation and at total depth referenced to governmental section Hnes. (8) the coordinates of the proposed location of the well at the surt'ace/ referenced to the state plane coordinate system for this state as ma¡i7tained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5868943.5 Eastings: 443913 935' FNL, 1955' FWL, Sec 17, T8N, R7E, UM RKB Elevation: 255.0 ft AMSL Pad Elevation: 225.0 ft AMSL Location at Top of Productive Interval (Bermuda Formation) NGS Coordinates Northings: 5863513 Easbngs: 444864 1079' FNL, 2351' FEL, Sec 20, T8N, R7E, UM Measured Depth (RKB feet): True Vertical Depth (55 feet): True Vertical Depth (RKB feet): 8146' 5275' 5529' Location at Total Depth NGS Coordinates Northings: 5862981 Easbngs: 444957 1703' FNL, 333' FEL, Sec 19, T8N, R7E, UM Measured Depth (RKB feet): 8820' True Vertical Depth (55 feet): 5678' True Vertical Depth (RKB feet): 5932' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a we!1 is to be intentionally deviated, the application for a Permit to Dríll (Form 10-40.1) must (1) include a plat drawn to a suitable scale, showing the path of the prop05-ed wellbore, induding a!! adjacent wel!bores within 200 feet of any pOftion of tile proposed well; Please see Attachment 2: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) fist the names of the operators of those well~ to the extent that those names are known or discoverable 1Ì7 public records, and show that each named operator has been furnished a copy of the appliœtion by certified mail,' or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 2P-429 PERMIT /T 5-22-01. doc OR G HAL Page30f7 . Printed: 23-May-01 APPI~ "'n for Permit to Drill, Well 2P-429 Saved: 23-May-01 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a PermIt to 01111 must be accompanied by each of the following Items; except for an item already on file with the commission and identified in the application: (3) a diagram and description of the bíowout prevention equ~Dr17ent (BOPE) as required by 20 AAC 25.03~ 20 AAC 25.036- or 20 MC 25.03~ as applicable,. Please refer to Doyon Rig 141 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PermIt to Dnll must be accompanied by each of the following Items; except for an item already on tlle with the commission and identified in the application: (4) information on drilllÌJg hazard5; including (A) the maximum down/Jole pressure that may be encountered; criteria used to determine it and maximum potential surface pressure based on a methane gradien(; The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.46 psi/ft, or 8.5 to 8.9 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. 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 1971 psi, calculated as follows: MPSP =(5633 ft)(0.46 - 0.11 psi/ft) =1971 psi Assuming a leak off of 15.9 ppg (0.83 psi/ft) based on open hole LOT results from offset Meltwater exploration wells, formation breakdown at the surface casing shoe (2999' TVD) can be expected to occur at 2489 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated above. (B) data on potential gas zones/ No potential gas zones have been identified along the planned 2P-438 well path. and (C) data concerning potential causes of hole problems :,ixh as abnofmally geo-pressured strata;, lost circulation zones; and zones that have '1 propensity for dìfferential 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 Permìt to Drill must be accompanied by each of the f..tjl/owing items, except for an item already on file with the commis"Sion and ìdentified in the application: (5) a descriptJ'on of the procedure for conducting formation integl1ty tests, as required under 20 AAC 25.030(t); 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 appliœtion f..tjr a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the appliœtion: (6) a complete proposed casing and cementing program as required by 20 AAC 25.03D., and a descri!)tion of any s10tted linet; pre- perforated linet; or screen to be instalJed/ OR. 'G 'NAI429 PERMIT IT 5-22-0 1. doc Page 4 of 7 Printed: 23-May-01 APP{ "rm for Permit to Drill, We1l2P-429 Saved: 23-May-01 Casing and Cementinq Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ibltt) Grade Connection (tt) (tt) (tt) Cement Program 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High Insulated Early 9-5/8 12-1/4 40.0 L-80 BTC,AB 2969 30 / 30 2999 / 2449 350 sx 10.7 Modified ppg AS3 Lead, 300 sx 12.0 ppg LiteCrete Tail Planned Top of Cement: Surface 7 8-1/2 26.0 L-80 BTC,AB 8116 30 / 30 8146/5529 470 sx 15.8 Modified ppg Class 'G' 4-1/2 8-1/2 12.6 L-80 IBT, AB 675 8169 / 5294 8821/5932 Planned Top of Mod Cement: 7547' MD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Perrmt to Drill must be accompanied by each of the following l'tems~ except for an item already on file with the commis.sion and identifled in the application: (7) a diagram and description of the díverter system as required by 20 MC 25.035; unless t!lis requirement Is ¡r.¡aíved by the commission under 20 AAC 25.035(h)(2)/ ' Please refer Doyon Rig 141 Diverter Schematic currently on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application f..0r a Permit to Drill must be accompanied by eacli of the following item~ except for an item already on file with the r:;vmmis.c;ion and ¡dentifled in the application: (8) a drilling f7uid programl including a diagram and description of the dJilling flUId system, as required by 20 MC25.033/ Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be built and maintained to the following specifications: Spud to 9-5/8" Drill Out to Top Bermuda Surface Casing Top Bermuda To Well TD Initial Value Final Value Initial Value Final Value Initial Value Final Value Density (ppg) 9.6 9.8 9.4 9.8 9.8 9.8 Funnel Viscosity 80 100 50 65 50 65 (seconds) Yield Point 35 45 10 25 20 30 (cP) Plastic Viscostiy 13 21 6 14 6 14 (lb1100 sf) 10 second Gel 10 15 2 6 4 7 Strength (lb1100 sf) 10 minute Gel 15 40 4 8 4 8 Strength (lb1100 sf) pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5 API Filtrate(cc) <15 <15 <6 <6 8-10 8-10 2P-429 PERMIT IT 5-22-01.doc 0 ) 'G . Page50f7 . 1. . . N A - Printed: 23.May.OI (' APP~ "')n for Permit to Drill, We1l2P-429 Saved: 23-May-01 Please refer to Doyon Rig 141 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an explorator¡ or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25~033(f); Not applicable: Application is not for an exploratory of stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dlill must be accompanied by eaäì of the following items, except for an item already on file with the commi.'ision and identified in the application: (10) for an exploratorv or stratigraphic test v,¡el¿ a seismic refraction or reflection analys"is as required by 20AAC 25,061{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 applícation for a Pelmlt to Dn!/ must be accompanied by each of the fo//ov'/ing Items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an off:,71ore platform, mobile bottom-founded structure, jaí.:1<-up rig, or floatliìg drillfÌìg vessel an analysis of seabed conditions as required by 20 AAC 25. 061 (b )/' Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dn!1 must be accompanied by each of the tollowing Items¡ except for an item already on file ¡flith the commission and identifìed in the application: (12) evidence showing that the requìrements of 20 AAC 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 far a PermIt to Drtll mllst be accompanied by each of the following items¡ except for an item already on file with the commiss"ion and identified in the application: 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 conductor. 2. Move in / rig up Doyon 141. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/- 2999 MD') according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM 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 up BOPE and test to 5000 psi. Record results. 0 R 'G NA 2P-429 PERMIT IT 5-22-01,doc Page 6 of 7 Printed: 23-May-01 .8 APP~' :on for Permit to Drill, Well 2P-429 Saved: 23-May-01 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. 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 8-1/2" hole to well total depth (+/- 8820' MD) according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. Circulate and condition hole. POOH. 9. Run open hole e-line or drill pipe conveyed logs as needed. 10. Run and cement 7/1 26.0# L-80 BTCM x 4-1/2 12.6# L-80 BTCM tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top perforation. 11. Run and land 4-1/2" tubing. Displace well to completion brine. 12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 13. Freeze protect well. Set BPV. 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 as per AOGCC regulations. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applIcatIon for a Permit to DIi// mU::.7:C be accompanIed by each of the fo/lowfi7g ItemSr exæpt for an Item already on file wIth the commission and identified in the application: (14) a general descrIption of how the operator plans to dispo!:>'"e of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 2S.080 for an annular disposal operation in the wel!,/' Waste fluids generated during the drilling process will be injected down a permitted annulus on 2P pad or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection 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 0 'j . G" þ V ' L2P-429 PERMIT IT Sp;~~;.~~~ 1 .,. Printed: 23-May-01 Phillips Alaska, Inc. Drill Site 2P 429 slot #429 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2P-429 Version#2 Our ref: prop4521 License: Date printed: 22-May-2001 Date created: 25-Feb-2001 Last revised: 22-May-2001 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 9.340,w150 26 55.820 Slot Grid coordinates are N 5868943.497, E 443913 .132 Slot local coordinates are 933,18 S 1956,25 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North O~ G NA- Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,429 Your ref: 2P-429 Version#2 Meltwater,North Slope, Alaska Last revised: 22-May-2001 Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 0.00 0.00 0.00 0.00 0,00 N 0.00 E 0.00 0,00 100.00 0.00 169.63 100.00 0,00 N 0.00 E 0.00 0.00 200.00 0.00 169.63 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 169,63 300.00 0,00 N 0.00 E 0,00 0 . 00 KOP 400.00 2.00 169.63 399.98 1.72 S 0.31 E 2.00 1. 75 500.00 4,00 169.63 499,84 6,86 S 1. 26 E 2,00 6,98 600.00 6.00 169,63 599,45 15,44 S 2.82 E 2,00 15.69 700.00 8.00 169.63 698.70 27.42 S 5.02 E 2.00 27.88 800.00 10.00 169.63 797.47 42,81 S 7,83 E 2.00 43,52 BId 3/100 866.67 12.00 169.63 862,90 55,32 S 10.12 E 3.00 56,24 966,67 15,00 169,63 960,13 78.28 S 14.32 E 3.00 79.58 1066,67 18,00 169,63 1056,00 106.22 S 19.43 E 3.00 107.98 1166,67 21. 00 169,63 1150,25 139,05 S 25.44 E 3.00 141,36 1266.67 24.00 169.63 1242,63 176,69 S 32.33 E 3,00 179,62 1366.67 27.00 169.63 1332,88 219,03 S 40.07 E 3.00 222,67 1466.67 30.00 169,63 1420.75 265.97 S 48.66 E 3.00 270,38 1505,29 31.16 169.63 1454.00 285.29 S 52,20 E 3.00 290,03 Base Permafrost 1566.67 33.00 169.63 1506,01 317 ,36 S 58,06 E 3,00 322,62 1666.67 36.00 169.63 1588.41 373,07 S 68,26 E 3,00 379.26 1766.67 39.00 169.63 1667,74 432.94 S 79.21 E 3.00 440.13 1866,67 42,00 169,63 1743.77 496.82 S 90.90 E 3.00 505,06 1966.67 45.00 169.63 1816,30 564.52 S 103,29 E 3.00 573,89 2042.74 47.28 169.63 1869,00 618,47 S 113 .16 E 3,00 628.74 Base West Sak 2066.67 48.00 169,63 1885.12 635.87 S 116.34 E 3.00 646.42 2166.67 51. 00 169,63 1950.06 710.66 S 130.02 E 3.00 722,45 2241.80 53.25 169.63 1996,18 768,99 S 140,70 E 3,00 781. 76 EOC 2500.00 53.25 169.63 2150,66 972,51 S 177.93 E 0.00 988.65 3000.00 53,25 169,63 2449,79 1366.61 S 250.04 E 0.00 1389.30 3107,32 53,25 169,63 2514.00 1451.21 S 265.52 E 0.00 1475,30 C-80 3500.00 53.25 169,63 2748.93 1760.72 S 322.15 E 0.00 1789,95 3949,75 53.25 169.63 3018.00 2115.22 S 387,01 E 0,00 2150,33 C-50 4000,00 53,25 169.63 3048,06 2154,82 S 394.26 E 0,00 2190.59 4500.00 53.25 169.63 3347.20 2548.93 S 466.36 E 0.00 2591.24 4554.83 53.25 169,63 3380.00 2592.15 S 474,27 E 0.00 2635.18 C-40 4874.09 53,25 169,63 3571.00 2843.79 S 520.31 E 0,00 2891. 00 C-37 5000.00 53.25 169.63 3646.33 2943.03 S 538.47 E 0,00 2991.89 5500.00 53.25 169.63 3945.46 3337.14 S 610.58 E 0,00 3392.54 6000.00 53.25 169.63 4244.60 3731.25 S 682.69 E 0.00 3793.18 6500.00 53.25 169.63 4543.73 4125.35 S 754,79 E 0.00 4193.83 7000.00 53.25 169,63 4842.87 4519.46 S 826.90 E 0.00 4594,48 7500.00 53.25 169.63 5142.00 4913.56 S 899.01 E 0.00 4995,13 8000.00 53,25 169,63 5441.14 5307.67 S 971,12 E 0,00 5395,78 8146,86 53.25 169.63 5529,00 5423,42 S 992.30 E 0.00 5513.45 T3 (Top Bermuda) 8320,67 53.25 169.63 5632.99 5560.42 S 1017,36 E 0.00 5652.73 Target - BermudaMidPt 8320,69 53.25 169,63 5633.00 5560,44 S 1017.36 E 0.00 5652.75 MW (H) Rvsd 15-May-01 8500.00 53.25 169,63 5740.27 5701. 77 S 1043.22 E 0.00 5796,42 8736.90 53,25 169.63 5882.00 5888.50 S 1077.39 E 0.00 5986,25 C-35 (Top Albian) 8820.69 53.25 169,63 5932.13 5954.54 S 1089.47 E 0.00 6053.39 TD - Csg pt All data is in feet unless otherwise stated, Coordinates from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea Bottom hole distance is 6053.39 on azimuth 169.63 degrees from wellhead. Total Dogleg for wellpath is 53.25 degrees. Vertical section is from wellhead on azimuth 169,63 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ level) . 01.G¡AA- ( Phillips Alaska, Inc. Drill 5ite 2P,429 Meltwater,North 5lope, Alaska PROP05AL LI5TING Page 2 Your ref: 2P-429 Version#2 Last revised: 22-May-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300,00 300,00 0,00 N 0.00 E KOP 800.00 797,47 42,81 5 7,83 E BId 3/100 1505.29 1454.00 285,29 5 52,20 E Base Permafrost 2042.74 1869.00 618.47 5 113 .16 E Base West 5ak 2241.80 1996,18 768,99 5 140.70 E EOC 3107,32 2514.00 1451,21 5 265,52 E C-80 3949.75 3018.00 2115,22 5 387.01 E C-50 4554.83 3380.00 2592,15 5 474.27 E C-40 4874.09 3571,00 2843.79 5 520.31 E C-37 8146.86 5529.00 5423.42 5 992.30 E T3 (Top Bermuda) 8320.67 5632.99 5560,42 5 1017,36 E Target - BermudaMidPt 8320,69 5633.00 5560.44 5 1017,36 E MW (H) Rvsd 15-May-01 8736,90 5882.00 5888.50 5 1077.39 E C-35 (Top Albian) 8820.69 5932,13 5954.54 5 1089.47 E TD - Csg pt Casing positions in string 'A' -- - - - --- -- - - -- -- - - - - - -- - ---- -- ---- - -- - -- - - -- --- - - - - - - - - --- -- TOP MD TOp TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords, Casing ----------------------------------------------------------------------------------------------------------- 0,00 0,00 0.00 0,00 O.OON O.OON O,OOE 8820,69 5932.13 O,OOE 2998.68 2449.00 5954.545 1365.575 1089.47E 7" Casing 249.85E 9 5/8" Casing Targets associated with this wellpath -- -- - - - -- - - - - - -- - - -- --- - - ---- - - - - -- -- --- - - - - -- -- -- - -- - - - - - -- - - - --- --- - - - -- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW (H) Rvsd 15-May-0 444888.000,5863376.000,999.00 5633,00 5560,445 1017,36E 22-Feb-2001 OR. G.^A~ Phillips Alaska, Inc. Drill Site 2P 429 slot #429 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2P-429 Version#2 Our ref: prop452l License: Date printed: 22-May-200l Date created: 25-Feb-2001 Last revised: 22-May-2001 Field is centred on 441964,235,5869891.466,999,OOOOO,N Structure is centred on 441964.235,5869891. 466,999,00000, N Slot location is n70 3 9,340,w150 26 55.820 Slot Grid coordinates are N 5868943,497, E 443913 ,132 Slot local coordinates are 933.18 S 1956.25 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North nlJ'~I^,A ,\~ Phillips Alaska, Inc. PROP05AL LI5TING Page 1 Drill 5ite 2P,429 Your ref: 2P-429 version#2 Me1twater,North 51ope, Alaska Last revised: 22-May-2001 Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D 5 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 443913.13 5868943.50 n70 3 09,34 w150 26 55.82 100.00 0.00 169.63 100.00 O.OON O.OOE 443913.13 5868943.50 n70 3 09,34 w150 26 55.82 200.00 0,00 169.63 200.00 O.OON O.OOE 443913.13 5868943.50 n70 3 09.34 w150 26 55.82 300.00 0,00 169,63 300.00 O.OON O,OOE 443913.13 5868943.50 n70 3 09,34 w150 26 55.82 400,00 2,00 169,63 399.98 1.725 O,31E 443913.43 5868941,78 n70 3 09.32 w150 26 55,81 500.00 4.00 169,63 499.84 6.865 1. 26E 443914.34 5868936,62 n70 3 09.27 w150 26 55,78 600.00 6,00 169.63 599.45 15,445 2, 82E 443915.84 5868928.04 n70 3 09.19 w150 26 55.74 700,00 8.00 169.63 698.70 27.425 5,02E 443917.94 5868916.04 n70 3 09,07 w150 26 55,68 800.00 10.00 169.63 797,47 42,815 7,83E 443920.64 5868900,63 n70 3 08.92 w150 26 55.59 866.67 12.00 169.63 862.90 55.325 10,12E 443922.83 5868888,10 n70 3 08.80 w150 26 55,53 966.67 15.00 169.63 960,13 78,285 14. 32E 443926,86 5868865.11 n70 3 08,57 w150 26 55.41 1066,67 18,00 169.63 1056.00 106.225 19, 43E 443931.75 5868837.14 n70 3 08,30 w150 26 55,26 1166.67 21. 00 169.63 1150.25 139.055 25. 44E 443937.51 5868804,27 n70 3 07,97 w150 26 55.09 1266,67 24,00 169,63 1242,63 176.695 32.33E 443944,11 5868766,58 n70 3 07.60 w150 26 54,89 1366.67 27.00 169.63 1332.88 219.035 40.07E 443951. 53 5868724,19 n70 3 07.19 w150 26 54.67 1466.67 30.00 169.63 1420,75 265.975 48,66E 443959.76 5868677.19 n70 3 06,72 w150 26 54,42 1505,29 31.16 169.63 1454.00 285.295 52.20E 443963.15 5868657,84 n70 3 06,53 w150 26 54,32 1566.67 33.00 169.63 1506,01 317.365 58. 06E 443968.77 5868625,74 n70 3 06,22 w150 26 54.15 1666.67 36.00 169.63 1588.41 373.075 68.26E 443978 , 54 5868569.96 n70 3 05.67 w150 26 53.86 1766.67 39.00 169.63 1667.74 432.945 79.21E 443989.04 5868510.01 n70 3 05.08 w150 26 53.54 1866,67 42.00 169,63 1743.77 496.825 90,90E 444000.23 5868446.05 n70 3 04,45 w150 26 53,21 1966.67 45,00 169.63 1816.30 564.525 103.29E 444012,10 5868378,26 n70 3 03.79 w150 26 52,85 2042.74 47.28 169,63 1869.00 618.475 113 ,16E 444021,56 5868324,24 n70 3 03,26 w150 26 52,57 2066,67 48.00 169.63 1885.12 635.875 116.34E 444024,61 5868306,82 n70 3 03.09 w150 26 52.47 2166,67 51. 00 169.63 1950.06 710.665 130,02E 444037.72 5868231.94 n70 3 02,35 w150 26 52.08 2241.80 53.25 169.63 1996.18 768,995 140, 70E 444047.95 5868173,53 n70 3 01. 78 w150 26 51,77 2500.00 53.25 169.63 2150.66 972.515 177,93E 444083,63 5867969,75 n70 2 59.77 w150 26 50.70 3000,00 53,25 169.63 2449.79 1366.615 250.04E 444152.73 5867575.15 n70 2 55.90 w150 26 48,63 3107,32 53.25 169.63 2514,00 1451.215 265.52E 444167.56 5867490.45 n70 2 55.07 w150 26 48.18 3500,00 53.25 169.63 2748,93 1760,725 322,15E 444221.82 5867180.54 n70 2 52,02 w150 26 46.56 3949.75 53.25 169.63 3018.00 2115.225 387,OlE 444283,98 5866825,59 n70 2 48,54 w150 26 44,69 4000.00 53.25 169.63 3048.06 2154.825 394,26E 444290,92 5866785,94 n70 2 48.15 w150 26 44,48 4500.00 53,25 169,63 3347.20 2548.935 466.36E 444360.02 5866391.33 n70 2 44.27 w150 26 42,41 4554,83 53.25 169,63 3380.00 2592 ,155 474.27E 444367.59 5866348.06 n70 2 43.84 w150 26 42.18 4874.09 53.25 169.63 3571.00 2843,795 520.31E 444411.71 5866096 .10 n70 2 41.37 w150 26 40.86 5000.00 53.25 169.63 3646,33 2943.035 538.47E 444429,11 5865996,73 n70 2 40.39 w150 26 40,34 5500.00 53.25 169.63 3945,46 3337.145 610.58E 444498,21 5865602.12 n70 2 36.52 w150 26 38.26 6000.00 53.25 169.63 4244,60 3731.255 682.69E 444567,30 5865207,52 n70 2 32.64 w150 26 36.19 6500,00 53,25 169,63 4543.73 4125.355 754.79E 444636,40 5864812,91 n70 2 28.76 w150 26 34.12 7000.00 53,25 169.63 4842.87 4519.465 826.90E 444705.49 5864418.31 n70 2 24.89 w150 26 32.05 7500.00 53.25 169.63 5142 ,00 4913,565 899, OlE 444774,59 5864023.70 n70 2 21. 01 w150 26 29.98 8000.00 53.25 169.63 5441,14 5307.675 971,12E 444843.68 5863629.10 n70 2 17.13 w150 26 27,90 8146,86 53.25 169.63 5529.00 5423.425 992,30E 444863,98 5863513,19 n70 2 16,00 w150 26 27,30 8320.67 53.25 169.63 5632.99 5560.425 1017.36E 444888.00 5863376.02 n70 2 14,65 w150 26 26,58 8320.69 53.25 169.63 5633.00 5560.445 1017.36E 444888.00 5863376.00 n70 2 14.65 w150 26 26.58 8500,00 53,25 169,63 5740.27 5701.775 1043. 22E 444912.78 5863234.49 n70 2 13 ,26 w150 26 25.83 8736.90 53,25 169,63 5882.00 5888.505 1077,39E 444945.52 5863047.53 n70 2 11,42 w150 26 24.85 8820.69 53.25 169,63 5932.13 5954,545 1089,47E 444957.09 5862981.40 n70 2 10,77 w150 26 24.51 All data in feet unless otherwise stated. Calculation uses minimum curvature method, Coordinates from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level) . Bottom hole distance is 6053.39 on azimuth 169.63 degrees from wellhead. Total Dogleg for wel1path is 53.25 degrees. Vertical section is from wellhead on azimuth 169.63 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ nøl~f^,A ~'""!II Phillips Alaska, Inc. Drill 5ite 2P,429 Meltwater,North 51ope, Alaska PROP05AL LI5TING Page 2 Your ref: 2P-429 Version#2 Last revised: 22-May-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300,00 O.OON O,OOE KOP 800.00 797.47 42,815 7.83E Bld 3/100 1505.29 1454.00 285.295 52. 20E Base Permafrost 2042,74 1869.00 618,475 113 .16E Base West 5ak 2241.80 1996,18 768,995 140.70E EOC 3107.32 2514,00 1451.215 265,52E C-80 3949.75 3018,00 2115.225 387,01E C-50 4554.83 3380.00 2592 .155 474.27E C-40 4874.09 3571.00 2843.795 520.31E C-37 8146.86 5529.00 5423.425 992.30E T3 (Top Bermuda) 8320,67 5632,99 5560.425 1017,36E Target - BermudaMidPt 8320,69 5633,00 5560,445 1017,36E MW (H) Rvsd 15-May-01 8736,90 5882.00 5888.505 1077 ,39E C-35 (Top Albian) 8820.69 5932.13 5954.545 1089,47E TD - Csg pt Casing positions in string 'A' - - - --- - ----- - --- ----- --- ---- - - - - -- - - - --- -- - --- - -- - - -- - - - - - - - Top MD Top TVD Rectangular Coords, Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0,00 0,00 0.00 0,00 O.OON O.OON O.OOE 8820.69 5932.13 O.OOE 2998.68 2449.00 5954.545 1365.575 1089.47E 7" Casing 249.85E 9 5/8" Casing Targets associated with this we11path - - - - - - - -- -- ----- - - - - - - --- -- - - - - - - - - -- - - - - - - - -- -- ----- -- - - - - - -- - - - - - - - - - - -- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW (H) Rvsd 15-May-0 444888,000,5863376,000,999.00 5633,00 5560.445 1017.36E 22-Feb-2001 nQ'~'MA~ Phillips Alaska, Inc, Drill Site 2P 429 slot #429 Meltwater North Slope, Alaska 3-D M I N I MUM D I S TAN C E C LEA RAN C ERE P 0 R T INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 2P-429 Version#2 Our ref: prop4521 License: Date printed: 22-May-2001 Date created: 25-Feb-2001 La~t revised: 22-May-2001 Field is centred on 441964.235,5869891,466,999,OOOOO,N Structure is centred on 441964.235,5869891.466,999.00000, N Slot location is n70 3 9.340,w150 26 55.820 Slot Grid coordinates are N 5868943.497, E 443913.132 Slot local coordinates are 933,18 S 1956.25 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet proximi ties will incorporate ellipses - when survey tools are defined for both wells, Ellipse separation in reverse brackets, e. g. ) 10.2 (, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e. g, 487.4 * Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M,D. Diverging from M,D. 21-May-2001 )239.6( 100.0 100,0 21-May-2001 )179.0( 325.0 325.0 6-Mar-2001 )40825,4 8820.7 8820.7 26-Feb-2001 )2909.2( 3700.0 3700.0 26-Feb-2001 )1172,6( 8820,7 8820,7 PMSS <0-6008'>,,417,Drill Site 2P PMSS <O-???'>, ,438,Drill Site 2P PMSS <0-8935'>"MWSouth1,Meltwater South #1 PMSS <2212-7349'>, ,MWN#2A, Meltwater North #2 PMSS <0-6122'>, ,MWN#l , Meltwater North #1 OR GVJ - Phillips Alaska, Inc. CLEARANCE LI5TING Page 1 Drill 5ite 2P,429 Your ref: 2P-429 Version#2 Mel twater ,North 51ope, Alaska Last revised: 22-May-2001 Reference wellpath Object wellpath : PM55 <0-6008' >, ,417, Drill 5ite 2P Horiz Min 'm Ellipse M.D, T.V.D. Rect Coordinates M,D. T.V,D. Rect Coordinates Bearing Dist 5ep'n 0.0 0.0 O.ON O.OE 0,0 0,0 56. ON 233,3E 76.5 239.9 N/A 100.0 100.0 O.ON O.OE 98,7 98,7 56.4N 233.4E 76,4 240.1 )239,6( 200,0 200,0 O.ON O.OE 198.1 198,1 57. 5N 233.7E 76,2 240.7 ) 239.7 ( 300,0 300,0 O.ON O,OE 298.0 297,9 59,3N 234,lE 75,8 241. 6 )240.0( 312.5 312.5 0.05 O.OE 310,5 310.4 59,6N 234,2E 75.7 241.7 )240,O( 325.0 325.0 0.15 O.OE 322.9 322.9 59.8N 234.2E 75,7 241. 8 )240.1( 337,5 337,5 0.25 O,OE 335,6 335,5 60,ON 234.3E 75,6 241. 9 )240.1( 350,0 350.0 0.45 O.lE 348,1 348.0 60.3N 234.3E 75.5 242.0 )240.2( 362.5 362.5 0.75 O.lE 360,5 360.5 60.5N 234.4E 75,4 242.1 )240.2 ( 375.0 375.0 1.05 0.2E 373.0 373.0 60.8N 234. 4E 75.2 242.3 ) 240,3 ( 387,5 387,5 1.35 O,2E 385.7 385.6 61. ON 234,5E 75.1 242.4 )240,3 ( 400.0 400,0 1. 75 O,3E 398,1 398.1 61. 3N 234.5E 74.9 242.5 ) 240.4 ( 412.5 412.5 2.25 0.4E 410,6 410.6 61. 5N 234.5E 74,8 242.6 )240,5( 425.0 425.0 2.75 0.5E 423.5 423.5 61. 8N 234.6E 74.6 242.8 )240,5( 437.5 437.4 3.28 O,6E 436.0 436.0 62,ON 234,6E 74.4 242.9 )240.6( 450,0 449.9 3.95 0, 7E 448,5 448.4 62,2N 234.6E 74.2 243,1 ) 240,7 ( 462,5 462.4 4,55 0.8E 461. 0 460.9 62.4N 234.6E 74.0 243.2 )240,7( 475.0 474.9 5.35 1.0E 474.2 474.2 62.6N 234. 6E 73.8 243.3 )240.8( 487.5 487.4 6.08 1.1E 486.7 486.6 62,7N 234,7E 73.6 243,5 )240.9( 500.0 499,8 6.95 1.3E 499.1 499.1 62. 8N 234.7E 73.4 243,6 )240.9( 512,5 512,3 7.75 1.4E 511. 6 511. 5 62.9N 234.7E 73.2 243.7 ) 241. 0 ( 525.0 524.8 8.75 1.6E 524.6 524.5 62.9N 234. 7E 72.9 243.8 )241.0( 537,5 537.2 9.78 1.8E 537.0 537.0 62,9N 234.7E 72.7 244,0 )241.1( 550.0 549.7 10.78 2,OE 549.5 549.4 63.0N 234,7E 72.4 244,1 )241.1( 562.5 562.1 11. 85 2,2E 562,1 562.1 63,ON 234, 7E 72.2 244,3 )241.2( 575,0 574.6 13 .05 2.4E 574,6 574.5 63.0N 234.7E 71.9 244.4 )241.3( 587,5 587.0 14.25 2.6E 587.0 586.9 62.9N 234. 7E 71.6 244.6 )241.4( 600.0 599.5 15.45 2.8E 599.4 599.4 62,9N 234.7E 71.3 244,8 )241.5( 612.5 611. 9 16.75 3,lE 612.1 612.0 62.9N 234,7E 71.0 245,0 )241.6( 625.0 624,3 18,15 3,3E 624,5 624.4 62.8N 234,8E 70,7 245.2 )241.7 ( 637,5 636,7 19.55 3.6E 636.9 636.8 62,8N 234.8E 70.4 245.4 )241.8( 650.0 649,1 21. 05 3.8E 649,3 649,3 62.8N 234.8E 70.1 245,6 )242,O( 662,5 661.5 22.58 4.1E 661. 9 661,8 62.7N 234,8E 69.7 245,9 ) 242.2 ( 675.0 673.9 24.15 4,4E 674.3 674.2 62.7N 234.8E 69,3 246.2 )242.3 ( 687.5 686.3 25,75 4, 7E 686.7 686.6 62.7N 234.8E 69.0 246.5 )242,5( 700.0 698.7 27.45 5.0E 699.1 699.0 62.7N 234. 7E 68.6 246.8 )242.7( 712,5 711. 1 29.28 5.3E 711.4 711. 4 62. 7N 234.7E 68.2 247,1 ) 243.0 ( 725,0 723,4 31.08 5. 7E 723.8 723.7 62.6N 234,7E 67.8 247,4 )243.2( 737,5 735.8 32.85 6,OE 736.2 736.1 62.6N 234.7E 67,3 247,8 ) 243.5 ( 750.0 748.2 34.75 6,3E 748,4 748.4 62.6N 234. 7E 66,9 248,2 )243,8( 762.5 760.5 36.65 6. 7E 760,8 760.7 62.6N 234. 7E 66.5 248.7 )244.1( 775.0 772,8 38.65 7.1E 773.1 773.0 62.6N 234. 7E 66.0 249.1 )244.5( 787,5 785,2 40.75 7.4E 785.5 785,4 62.7N 234,7E 65.5 249.6 ) 244.9 ( 800,0 797.5 42.85 7. 8E 797.8 797,8 62.7N 234.6E 65.1 250,1 ) 245.3 ( 811,1 808.4 44.75 8.2E 808.8 808.7 62.7N 234.6E 64.6 250,6 ) 245.7 ( 822,2 819.3 46.75 8.6E 819.7 819.6 62.7N 234. 6E 64.2 251.1 )246,1( 833.3 830,2 48.85 8.9E 830.6 830.5 62. 7N 234. 6E 63.7 251.7 )246,6( 844.4 841.1 50.95 9.3E 841. 5 841.4 62. 7N 234. 6E 63.2 252.3 )247.1( 855.6 852,0 53,15 9,7E 852,4 852,3 62.7N 234,6E 62.8 252.9 )247.6( 866.7 862,9 55.35 10.lE 863.2 863.2 62.7N 234.5E 62.3 253.6 )248.1( 877,8 873,8 57.65 10.5E 874.1 874.0 62.7N 234,5E 61. 8 254.3 ) 248.7 ( Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (254,00 Ft above mean Vertical section is from wellhead on azimuth 169,63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). J ~. G Nr- Phillips Alaska, Inc, CLEARANCE LI5TING Page 2 Drill 5ite 2P,429 Your ref: 2P-429 Version#2 Meltwater ,North 5lope, Alaska Last revised: 22-May-200l Reference wellpath Object wellpath : PM55 <0-6008'>, ,417,Drill 5ite 2P Horiz Min'm Ellipse M.D. T.V,D, Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 5ep'n 888.9 884,6 60,05 11.0E 885,3 885.2 62.7N 234, 5E 61.2 255.0 ) 249.3 ( 900.0 895.4 62,45 11.4E 896.1 896,1 62.7N 234.5E 60,7 255.8 )250,O( 911.1 906.3 64.95 11.9E 906.9 906,9 62,7N 234.5E 60.2 256.6 )250,7 ( 922,2 917.1 67.55 12,3E 917.7 917,7 62, 7N 234. 4E 59.6 257.4 )25L4( 933.3 927,9 70.15 12.8E 928.5 928.5 62. 7N 234. 4E 59,1 258,3 ) 252.2 ( 944.4 938.6 72 ,85 13 ,3E 939.3 939,2 62.7N 234.4E 58,5 259.3 ) 253.0 ( 955,6 949.4 75.55 13 .8E 950,1 950.0 62,7N 234,4E 57.9 260.2 )253.9( 966,7 960.1 78.35 14.3E 960.8 960.7 62.6N 234.3E 57.4 261.3 ) 254.8 ( 977.8 970,9 81.15 14.8E 971.9 971.9 62.6N 234.3E 56,8 262,4 ) 255.8 ( 988.9 981.6 84.15 15.4E 982.7 982.6 62.6N 234.3E 56,2 263.5 )256,8( 1000.0 992.3 87,05 15.9E 993,3 993.3 62.6N 234,2E 55.6 264,7 )257.9( 1011,1 1002,9 90.15 16.5E 1004,0 1004.0 62.6N 234. 2E 54.9 265.9 )259.0( 1022.2 1013 .6 93.25 17.1E 1014.7 1014.6 62.6N 234.1E 54,3 267.2 ) 260,2 ( 1033.3 1024.2 96.45 17,6E 1025.3 1025.2 62.6N 234.1E 53,7 268.6 )26L4( 1044.4 1034.8 99.65 18.2E 1035.9 1035.9 62.6N 234,OE 53.1 270.0 ) 262.7 ( 1055,6 1045.4 102.95 18.8E 1046,5 1046,5 62.6N 234.0E 52.4 271.4 )264.0( 1066,7 1056,0 106.25 19.4E 1057.1 1057,0 62,6N 234.0E 51.8 273.0 )265,5( 1077.8 1066,6 109.65 20,lE 1068.2 1068.2 62.6N 233,9E 51.2 274.6 )266,9( 1088.9 1077.1 113.15 20.7E 1078.8 1078 . 7 62.5N 233,9E 50.5 276,2 )268.4 ( 1100.0 1087.6 116.65 21.3E 1089,3 1089,2 62.5N 233.8E 49.9 277.9 ) 270.0 ( 1111. 1 1098,1 120.25 22.0E 1099.8 1099,7 62,5N 233. 7E 49.2 279.7 )27L7( 1122 ,2 1108.6 123.95 22.7E 1110.3 1110.2 62.5N 233,7E 48.6 281.5 )273,4( 1133.3 1119.0 127.65 23.3E 1120.7 1120.7 62.4N 233,6E 47,9 283,4 )275.2( 1144.4 1129.5 131.35 24.0E 1131.2 1131.1 62.4N 233,6E 47.2 285,4 )277.0( 1155.6 1139 , 9 135,25 24.7E 1141,6 1141. 5 62.3N 233. 5E 46.6 287.4 )278.9( 1166,7 1150,3 13 9 . 15 25.4E 1152.0 1151. 9 62.3N 233,5E 45,9 289,5 )280,9( 1177,8 1160,6 143.05 26.2E 1162.7 1162.6 62.3N 233,4E 45,3 291,7 )283.0( 1188,9 1171,0 147.05 26,9E 1173,0 1173.0 62.2N 233. 4E 44.6 293,9 )285,1( 1200.0 1181.3 151. 15 27.6E 1183,3 1183,3 62.2N 233. 3E 44.0 296.3 ) 287.3 ( 1211.1 1191.6 155,25 28.4E 1193.7 1193.6 62.1N 233, 2E 43.3 298.7 )289.5( 1222.2 1201. 8 159.45 29,2E 1203.9 1203.9 62.1N 233,2E 42.7 301,1 )29L9( 1233,3 1212,1 163.65 29,9E 1214.2 1214.1 62.0N 233.2E 42.0 303,7 ) 294.3 ( 1244.4 1222,3 167,95 30. 7E 1224.4 1224.3 62.0N 233.1E 41.4 306,3 )296,8( 1255.6 1232 . 5 172.35 3L5E 1234.6 1234.6 6L9N 233.1E 40.7 309.0 )299.4( 1266.7 1242.6 176,75 32.3E 1244.8 1244,7 6L9N 233.0E 40,1 311.8 )302.1( 1277.8 1252,8 181.25 33,lE 1255.2 1255.1 6L8N 233,OE 39.4 314.6 )304,8( 1288.9 1262,9 185.75 34,OE 1265.3 1265.3 6L7N 233,OE 38.8 317,5 )307,6( 13 00,0 1273,0 190.35 34.8E 1275.5 1275,4 61,7N 232, 9E 38,2 320,5 )310,5( 1311.1 1283.0 194,95 35.7E 1285,5 1285 , 5 6L6N 232. 9E 37.6 323,6 )313.4 ( 1322,2 1293 .0 199,65 36.5E 1295.6 1295.5 6L5N 232.9E 36.9 326.8 )316.5( 1333.3 1303.0 204.45 37.4E 1305.6 1305.6 6L5N 232,8E 36,3 330.0 )319,6( 1344.4 1313,0 209.25 38,3E 1315.6 1315.6 6L4N 232, 8E 35.7 333,3 )322,8( 1355.6 1323.0 214.15 39.2E 1325.6 1325.6 6L3N 232, 8E 35.1 336.7 )326,1( 1366,7 1332,9 219.05 40.1E 1335.6 1335.5 6L2N 232. 8E 34.5 340,1 )329.4( 1377,8 1342 .8 224,05 4LOE 1345,7 1345,7 61,lN 232. 7E 33.9 343,6 )332.8( 13 88.9 1352.6 229,15 4L9E 1355.6 1355.6 6L1N 232.7E 33.3 347.3 )336.3( 1400.0 13 62.4 234.25 42.8E 1365.5 1365.4 6LON 232. 7E 32.7 350.9 )339.9( 1411. 1 1372.2 239.35 43,8E 1375.3 1375.3 60.9N 232.6E 32.2 354,7 )343.6( 1422.2 1382,0 244.55 44, 7E 1385.1 1385.1 60.8N 232. 6E 31.6 358,5 )347,3( 1433.3 1391. 7 249.85 45,7E 1394.9 1394.8 60, 7N 232, 6E 31.0 362,5 )35L1( 1444,4 1401. 4 255.15 46.7E 1404.7 1404.6 60. 7N 232.5E 30.5 366.5 )355.0( Coordinates All data is in feet unless otherwise stated, Casing dimensions are not included, from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). OR G NA- (" Phillips Alaska, Inc, CLEARANCE LI5TING Page 3 Drill 5ite 2P,429 Your ref: 2P-429 Version#2 Mel twater ,North 5lope, Alaska Last revised: 22-May-2001 Reference wellpath Object wellpath : PM55 <0-6008' >, ,417, Drill 5i te 2P Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V,D. Rect Coordinates Bearing Dist 5ep'n 1455.6 1411.1 260.55 47.7E 1414.4 1414.3 60.6N 232. 5E 29.9 370.5 )359.0( 1466.7 1420.8 266.05 48. 7E 1424.0 1424.0 60.5N 232. 5E 29.4 374.7 )363.0( 1476.3 1429.1 270.75 49,5E 1432.4 1432,4 60,4N 232. 5E 28.9 378,3 )366,6( 1486,0 1437,4 275.55 50.4E 1440.4 1440,4 60,4N 232, 4E 28,5 382.1 ) 370.2 ( 1495.6 1445,7 280,45 51. 3E 1448,8 1448,7 60.3N 232,4E 28.0 385.9 ) 373.9 ( 1500,0 1449,5 282.65 51,7E 1452,5 1452,5 60.3N 232, 4E 27.8 387.6 )375,6( 1505,3 1454.0 285.35 52.2E 1457.1 1457,0 60,2N 232, 4E 27,5 389.7 )377.7( 1515.5 1462.7 290,55 53.2E 1465.8 1465.8 60.2N 232. 4E 27,1 393.8 )381.7( 1525.7 1471.5 295.85 54.1E 1474.6 1474,5 60.1N 232.4E 26.6 398,0 )385.9( 1536.0 1480.1 301.15 55.1E 1483.3 1483,2 60.0N 232. 3E 26.1 402,3 ) 390.0 ( 1546.2 1488.8 306.55 56,lE 1492.0 1491. 9 60.0N 232.3E 25,7 406.6 ) 394.3 ( 1556,4 1497.4 311.95 57,lE 1500.7 1500.6 59.9N 232.3E 25,2 411. 0 ) 398.6 ( 1566.7 1506.0 317.45 58,lE 1509.3 1509.2 59.8N 232. 3E 24,8 415.5 ) 403.0 ( 1577.8 1515,3 323.35 59.2E 1518.6 1518.6 59.8N 232. 3E 24.3 420.4 )407,8( 1588.9 1524,6 329,45 60.3E 1528.0 1527,9 59.7N 232.2E 23.8 425,4 )412,7( 1600.0 1533.8 335.55 61. 4E 1537.0 1537,0 59.6N 232, 2E 23,4 430.5 ) 417.7 ( 1611.1 1543 .0 341.65 62,5E 1546.3 1546.2 59,6N 232, 2E 22.9 435.6 )422.7( 1622.2 1552.2 347.85 63.6E 1555.5 1555.4 59.5N 232. 2E 22.5 440.8 ) 427.8 ( 1633.3 1561,3 354.05 64.8E 1564.6 1564.6 59.4N 232. 2E 22.0 446,1 ) 433.0 ( 1644.4 1570.4 360,35 65.9E 1573,7 1573.7 59.4N 232.2E 21.6 451. 4 ) 438.3 ( 1655.6 1579.4 366,75 67.1E 1583.2 1583,2 59,3N 232,lE 21.2 456.9 ) 443.6 ( 1666,7 1588.4 373.15 68.3E 1592.3 1592.2 59.2N 232.1E 20.8 462.3 )449.0( 1677,8 1597.4 379.55 69,4E 1601. 3 1601. 2 59.2N 232.1E 20,3 467.9 )454.5( 1688.9 1606.3 386.05 70,6E 1610.3 1610.2 59.1N 232.0E 19.9 473,5 ) 460.0 ( 1700.0 1615.2 392.65 71,8E 1619.2 1619.1 59. ON 232.0E 19.5 479,2 ) 465.6 ( 1711.1 1624.1 399,25 73.0E 1628.1 1628.0 59,ON 232,OE 19,1 485.0 ) 471.3 ( 1722 .2 1632.9 405,85 74.3E 1636.9 1636,9 58.9N 231.9E 18.7 490.8 ) 477.0 ( 1733,3 1641. 6 412,55 75.5E 1645.7 1645.7 58.8N 231. 9E 18.4 496.7 )482.9( 1744,4 1650.4 419.35 76,7E 1654.5 1654.5 58.8N 231.9E 18.0 502,6 ) 488.7 ( 1755.6 1659.1 426.15 78,OE 1663.3 1663.2 58.7N 231.9E 17.6 508.7 ) 494.7 ( Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (254,00 Ft above mean Vertical section is from wellhead on azimuth 169.63 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ sea level). OR G,^A- Phillips Alaska, Inc. CLEARANCE LI5TING Page 4 Drill 5ite 2P, 429 Your ref: 2P-429 Version#2 Meltwater,North 51ope, Alaska Last revised: 22-May-2001 Reference wellpath Object wellpath : PM55 <O-???'>, ,438,Drill 5ite 2P Horiz Min'm Ellipse M,D. T.V.D, Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 5ep'n 0.0 0,0 O,ON O,OE 0.0 0.0 41,75 175,3W 256.6 180.2 N/A 100,0 100,0 Q,ON O.OE 100.0 100,0 41,75 175, 3W 256,6 180.2 ) 179.7 ( 200.0 200.0 O.ON O,OE 199.6 199.6 41. 45 175 . 5W 256.7 180.3 ) 179.2 ( 300.0 300.0 O.ON O.OE 299.0 299,0 40.65 176 . OW 257.0 180.6 ) 179.0 ( 312,5 312.5 0.05 O,OE 311. 5 311.5 40.55 17 6 , OW 257.0 180,7 ) 179.0 ( 325.0 325.0 0.15 O,OE 324,0 324.0 40.45 176.1W 257.1 180.7 ) 179.0 ( 337.5 337,5 0.25 O,OE 336.5 336.5 40.45 176. 2W 257.2 180,8 ) 179.0 ( 350.0 350.0 0.45 O.lE 348,6 348.6 40.35 176.3W 257.3 180.9 ) 179,0 ( 362.5 362.5 0.75 O.lE 361.1 361.1 40.25 176.4W 257.4 180,9 ) 179.0 ( 375.0 375.0 1.05 0.2E 373.6 373,6 40,25 176. 6W 257,5 181. 0 )179.1( 387.5 387,5 1.35 O,2E 385,3 385,3 40,15 176 . 7W 257.6 181.1 )179.1( 400.0 400.0 1. 75 0.3E 397.8 397,8 40.15 176 . 8W 257.8 181.2 )179,2( 412.5 412.5 2.25 0.4E 410.3 410.3 40.15 177. OW 257.9 181. 4 ) 179,2 ( 425.0 425.0 2,75 0.5E 421.7 421. 7 40,15 177.1W 258.1 181. 6 ) 179.3 ( 437.5 437.4 3.25 0.6E 434.2 434.2 40.25 177 .3W 258.3 181. 8 )179.5( 450,0 449.9 3.95 O,7E 445,7 445.7 40.35 177. 6W 258.5 182.0 )179,6( 462,5 462,4 4.55 O,8E 458,2 458.1 40.45 177, 8W 258.7 182.3 )179,8( 475.0 474,9 5.35 1.0E 470,6 470,6 40.55 178,lW 258.9 182.5 ) 180,0 ( 487.5 487.4 6.05 1.1E 482.3 482,2 40.75 178, 4W 259.1 182,9 ) 180,3 ( 500.0 499.8 6.95 1.3E 494.8 494.7 41. 05 178 . 7W 259,3 183.2 )180.6( 512,5 512.3 7.75 1.4E 506.6 506.6 41. 45 179 . OW 259.4 183.6 )180.8( 525,0 524,8 8,75 1.6E 519,1 519.0 41. 95 179.3W 259.6 184.0 ) 181.2 ( 537,5 537.2 9.75 1.8E 530.9 530.9 42.55 179,6W 259.7 184,4 )181.5( 550.0 549.7 10,75 2.0E 542.8 542,7 43.35 179.8W 259,8 184,8 )181.9( 562,5 562.1 11,85 2.2E 555.3 555,2 44.25 180, 2W 259,9 185.3 ) 182.2 ( 575.0 574,6 13 .05 2,4E 567,1 566.9 45,15 180. 4W 260,0 185.8 )182,6( 587,5 587.0 14.25 2,6E 579,6 579.3 46.35 180. 8W 260.1 186.3 )183,1( 600.0 599.5 15.45 2,8E 591.2 590.9 47.45 181,lW 260.1 186,8 )183,5( 612.5 611.9 16.75 3.1E 603.7 603.3 48,75 181. 4W 260.2 187,4 )184.0( 625.0 624.3 18,15 3.3E 615.3 614.9 50.05 181.7W 260,2 188.0 ) 184.5 ( 637.5 636,7 19.55 3,6E 627.8 627.3 51. 65 182.1W 260.2 188.7 ) 185.0 ( 650.0 649,1 21. 05 3,8E 639,5 638.8 53.15 182. 4W 260.2 189,3 )185,6( 662.5 661. 5 22.55 4,lE 651. 9 651. 2 54.85 182, 8W 260.2 190,0 )186.1( 675,0 673.9 24.15 4.4E 663.2 662.3 56.45 183, 2W 260.2 190,7 )186,8( 687,5 686.3 25.75 4.7E 675.7 674.6 58.35 183, 6W 260.2 191. 5 )187.4( 700.0 698.7 27,45 5.0E 686.5 685,3 60,05 184. OW 260.2 192.3 )188.1( 712.5 711.1 29,25 5.3E 699.0 697,6 62,05 184. 5W 260,2 193.1 )188.8( 725.0 723.4 31.05 5. 7E 711.5 709,9 64.05 185,lW 260,2 194,0 ) 189.6 ( 737.5 735.8 32.85 6.0E 722,3 720.6 65.85 185. 5W 260.2 195.0 )190,4( 750.0 748,2 34.75 6,3E 734,8 732.9 68.05 186.1W 260.2 195.9 ) 191.2 ( 762.5 760.5 36.65 6.7E 746,1 744.0 70.05 186, 7W 260,2 196.9 )192.1( 775,0 772.8 38.65 7.1E 758,6 756.2 72.35 187. 3W 260.2 198.0 )193.0( 787,5 785.2 40.75 7.4E 771.0 768.5 74,65 188. OW 260.1 199.0 )193.9( 800.0 797.5 42,85 7.8E 783.5 780.7 77.05 188. 6W 260.1 200.1 ) 194.8 ( 811.1 808.4 44.75 8.2E 794.0 790.9 78.95 189.1W 260.2 201. 0 ) 195.6 ( 822.2 819.3 46.75 8.6E 805,0 801. 8 81. 05 189. 7W 260.2 202,0 )196.4( 833.3 830.2 48,85 8.9E 816,1 812,6 83.25 190. 3W 260.2 203.0 )197.2( 844.4 841.1 50.95 9.3E 827.2 823.5 85.35 190, 9W 260.2 203.9 )198.0( 855.6 852.0 53.15 9.7E 837.4 833.5 87.35 191.5W 260,3 204.9 ) 198.9 ( 866.7 862.9 55.35 10.lE 848.5 844.4 89.55 192.1W 260.4 205,9 )199.7( 877.8 873.8 57,65 10.5E 859.6 855.2 91.75 192. 7W 260,5 206.9 )200.6( Coordinates All data is in feet unless otherwise stated, Casing dimensions are not included, from slot *429 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 169,63 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ sea level). OR G NA. Phillips Alaska, Inc. CLEARANCE LI5TING Page 5 Drill 5ite 2P, 429 Your ref: 2P-429 Version#2 Meltwater,North 51ope, Alaska Last revised: 22-May-2001 Reference wellpath Object wellpath : PM55 <O-???'>, ,438,Drill 5ite 2P Horiz Min'm Ellipse M.D, T.V,D. Rect Coordinates M.D, T,V.D, Rect Coordinates Bear ing Dist 5ep'n 888.9 884,6 60.05 11.0E 870,6 866.0 93.95 193.3W 260,6 207.9 )201.4( 900.0 895.4 62.45 l1,4E 881.7 876,8 96 ,15 193, 9W 260.7 208,9 )202.3 ( 911,1 906.3 64,95 11.9E 891. 8 886.7 98.25 194. 5W 260,9 210.0 ) 203,1 ( 922.2 917,1 67.55 12.3E 902.8 897.5 100.45 195.2W 261. 0 211.0 )204.0( 933.3 927,9 70.15 12.8E 913,9 908.3 102.65 195.8W 261,1 212.1 )204,9( 944.4 938.6 72,85 13 ,3E 924.9 919,1 104.95 196. 5W 261.3 213,2 )205,8( 955,6 949,4 75.55 13,8E 934.9 928.8 106.95 197 .1W 261. 5 214.2 ) 206.7 ( 966,7 960.1 78 .35 14.3E 945.9 939.6 109.25 197. 8W 261.7 215.3 ) 207.7 ( 977,8 970.9 81.15 14.8E 956,9 950,3 111,55 198. 5W 261,9 216.5 )208,6( 988,9 981. 6 84.15 15.4E 967,9 961.1 113 .85 199. 2W 262.1 217,6 )209,5( 1000,0 992,3 87.05 15.9E 977.8 970.7 115.95 199. 9W 262.4 218.8 )210.5( 1011,1 1002,9 90.15 16.5E 988,8 981. 4 118.25 200. 6W 262,6 219.9 )211.5 ( 1022,2 1013 ,6 93.25 17.1E 999.8 992,2 120.55 201.4W 262,9 221.1 )212.5( 1033.3 1024.2 96.45 17,6E 1010,8 1002.9 122.95 202.1W 263.1 222,4 ) 213.5 ( 1044,4 1034.8 99,65 18,2E 1021. 8 1013 .6 125.35 202. 9W 263.4 223,6 )214.6( 1055,6 1045,4 102.95 18.8E 1031. 7 1023,3 127.45 203, 6W 263,7 224.9 )215.6 ( 1066.7 1056.0 106.25 19.4E 1042.7 1033.9 129,85 204,4W 264,0 226.1 )216,7( 1077 . 8 1066.6 109.65 20.1E 1052.8 1043.8 132,15 205.1W 264.3 227.4 )217,8( 1088.9 1077.1 113 .15 20,7E 1063.8 1054.4 134.65 205. 9W 264.6 228.8 )218,9( 1100,0 1087.6 116.65 21. 3E 1074.8 1065.1 13 7 . 15 206,8W 264.9 230.1 ) 220,0 ( 1111.1 1098,1 120.25 22.0E 1084,9 1074,9 139.55 207. 5W 265.2 231. 5 )221.2 ( 1122,2 1108,6 123.95 22.7E 1095.8 1085,5 142,05 208,4W 265,5 232,9 ) 222,3 ( 1133,3 1119.0 127.65 23,3E 1106.8 1096.1 144.75 209.2W 265.8 234,3 )223,5( 1144,4 1129.5 131.35 24.0E 1116.8 1105.7 147.15 210 , OW 266.2 235.8 )224.8( 1155,6 1139.9 135.25 24.7E 1127,7 1116.3 149.85 210. 9W 266,5 237.3 )226.0( 1166.7 1150.3 13 9,15 25.4E 1138.6 1126,9 152,55 211 . 8W 266,8 238.8 )227,3 ( 1177,8 1160.6 143,05 26,2E 1148,6 1136.4 155.05 212. 6W 267.1 240.3 )228,6( 1188.9 1171.0 147.05 26.9E 1159.5 1146.9 157.85 213 .6W 267,4 241. 9 )229.9( 1200.0 1181.3 151.15 27.6E 1170,4 1157.4 160,75 214,5W 267,7 243,5 )231.2( 1211.1 1191.6 155.25 28.4E 1180,3 1167.0 163,35 215,3W 268,1 245,1 ) 232.6 ( 1222.2 1201. 8 159,45 29.2E 1191.2 1177.4 166.35 216.3W 268.4 246.8 )234,O( 1233.3 1212.1 163.65 29.9E 1202.1 1187.8 169.35 217.2W 268.7 248.4 )235.4( 1244,4 1222.3 167.95 30.7E 1212.4 1197.6 172 . 15 218,2W 269.0 250,1 )236.8( 1255.6 1232.5 172.35 31.5E 1223.3 1208,0 175,25 219.1W 269,3 251. 9 ) 238.3 ( 1266,7 1242.6 176.75 32.3E 1234,1 1218,4 178.45 220.1W 269.6 253,6 ) 239.7 ( 1277.8 1252,8 181.25 33.1E 1244.7 1228.4 181. 55 221.1W 269.9 255.4 )241.2( 1288.9 1262.9 185,75 34,OE 1255.6 1238.8 184,85 222.0W 270.2 257.2 ) 242.7 ( 1300.0 1273.0 190.35 34.8E 1266.5 1249.1 188.15 223,OW 270,5 259.0 )244.2( 1311.1 1283.0 194.95 35. 7E 1277,1 1259.1 191,45 224.0W 270.8 260,8 ) 245.7 ( 1322.2 1293.0 199.65 36.5E 1287.9 1269.4 194,85 225.0W 271.1 262.6 )247.3 ( 1333.3 13 03.0 204.45 37,4E 1298.1 1279.0 198.15 225. 9W 271.4 264.5 )248,8( 1344.4 1313,0 209.25 38.3E 1309.0 1289.2 201,75 226.9W 271.6 266.4 )250.4( 1355.6 1323.0 214.15 39.2E 1319.9 1299.4 205.35 227, 9W 271.9 268.3 )252.0( 1366.7 1332,9 219.05 40.1E 1329.6 1308.5 208.65 228,9W 272.2 270.2 )253.7( 1377.8 1342,8 224.05 41. OE 1340.4 1318,7 212.35 229.9W 272.5 272.2 ) 255.3 ( 1388.9 13 52.6 229.15 41. 9E 1351.3 1328,8 216,05 231.0W 272.7 274.2 )257.0( 1400.0 13 62 . 4 234.25 42,8E 13 61.0 1337.9 219,45 231.9W 273.1 276.3 ) 258.7 ( 1411.1 1372.2 239.35 43.8E 1371.9 1348.0 223.25 233. OW 273.3 278.4 )260.5( 1422.2 1382,0 244.55 44. 7E 1382.7 1358.0 227.05 234,lW 273.6 280,5 ) 262.3 ( 1433.3 1391.7 249.85 45,7E 1392.6 1367.2 230.65 235. 2W 273,9 282,6 )264.1( 1444.4 1401. 4 255,15 46, 7E 1403.5 1377,2 234.65 236.3W 274,2 284.8 ) 265.9 ( Coordinates All data is in feet unless otherwise stated, Casing dimensions are not included, from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 169,63 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). O,1JGlivl. Phillips Alaska, Inc. CLEARANCE LI5TING Page 6 Drill 5ite 2P,429 Your ref: 2P-429 Version#2 Meltwater,North 5lope, Alaska Last revised: 22-May-2001 Reference wellpath Object wellpath : PM55 <O-???' >, ,438, Drill 5ite 2P Horiz Min'm Ellipse M,D. T.V,D, Rect Coordinates M.D. T,V.D, Rect Coordinates Bearing Dist 5ep'n 1455.6 1411,1 260.55 47. 7E 1414.3 13 87.2 238.65 237.5W 274.4 287.0 )267,8( 1466.7 1420.8 266.05 48, 7E 1424.4 1396.5 242.45 238.5W 274.7 289,2 )269.7( 1476.3 1429,1 270.75 49,5E 1433,8 1405,2 246,05 239. 6W 274.9 291.1 )271.3( 1486.0 1437.4 275,55 50.4E 1442.5 1413 .2 249.35 240, 5W 275.1 293.1 ) 273,0 ( 1495.6 1445.7 280.45 51. 3E 1451.9 1421.7 253,05 241. 6W 275.3 295.1 ) 274,7 ( 1500.0 1449,5 282.65 51. 7E 1456.2 1425.6 254,75 242, OW 275.4 296.0 )275,4( 1505.3 1454.0 285.35 52.2E 1461. 3 1430.3 256.75 242.6W 275.5 297.1 )276.4( 1515.5 1462.7 290.55 53,2E 1470.6 1438,8 260,55 243, 7W 275.8 299,3 )278.2( 1525.7 1471. 5 295.85 54. IE 1480.5 1447,8 264.55 244, 8W 276.0 301.5 )280,1( 1536.0 1480.1 301.15 55.1E 1488.7 1455.1 267.85 245. 8W 276,3 303.7 )282.0( 1546.2 1488.8 306.55 56. IE 1498.6 1464,1 271.95 246, 9W 276.5 306.0 )283.9( 1556,4 1497.4 311.95 57. IE 1508.5 1473.0 276.15 248. 2W 276.7 308.3 )285.8( 1566,7 1506.0 317,45 58.1E 1515.4 1479.2 279.15 249. OW 277.1 310.6 )287.9( 1577.8 1515.3 323.35 59,2E 1526,2 1488.8 283.75 250. 5W 277.3 313.3 )290.1( 1588.9 1524.6 329.45 60.3E 1533,9 1495.6 287.15 251. 5W 277.7 316.0 )292,5( 1600.0 1533.8 335.55 61,4E 1544 ,6 1505.1 291. 85 253, OW 277.9 318.7 )294.8( 1611.1 1543.0 341. 65 62,5E 1555,3 1514.6 296.65 254, 6W 278,1 321. 5 ) 297.3 ( 1622.2 1552.2 347.85 63, 6E 1563,0 1521.3 300.15 255. 7W 278,5 324.4 )299,8( 1633,3 1561. 3 354,05 64.8E 1573.6 1530.6 305,05 257. 4W 278.7 327.3 ) 302.3 ( 1644.4 1570.4 360.35 65,9E 1581,4 1537,4 308,65 258, 6W 279.1 330.3 ) 305.0 ( 1655,6 1579,4 366,75 67.1E 1592.0 1546.6 313.55 260.3W 279,2 333,3 )307,6( 1666,7 1588.4 373,15 68.3E 1602,6 1555.8 318,55 262,lW 279.4 336.4 )310.2( 1677,8 1597.4 379.55 69,4E 1610,4 1562.5 322.25 263.4W 279.8 339.5 ) 313.0 ( 1688,9 1606.3 386.05 70.6E 1621. 0 1571.7 327.35 265. 2W 279.9 342,7 )315.8( 1700,0 1615.2 392,65 71,8E 1631. 6 1580.8 332,45 267, OW 280.1 345,9 )318.5( 1711.1 1624.1 399.25 73,OE 1639,3 1587.4 336.15 268. 4W 280.5 349.1 )321.4( 1722.2 1632.9 405.85 74.3E 1649,8 1596.4 341.25 270.3W 280.6 352,4 ) 324.3 ( 1733,3 1641,6 412,55 75.5E 1660,4 1605.4 346.45 272 .2W 280.8 355.8 ) 327,2 ( 1744.4 1650.4 419.35 76, 7E 1669.4 1613,0 350.95 273. 9W 281. 0 359.2 )330.2( 1755,6 1659.1 426.15 78 .OE 1680.0 1622.0 356.25 275. 9W 281.2 362,6 )333,2( 1766,7 1667,7 432,95 79.2E 1690.5 1630,8 361.45 277. 8W 281. 3 366.0 )336.2( 1777,8 1676.3 439.85 80,5E 1701.0 1639,7 366.85 279. 8W 281. 5 369.5 )339.2( 1788.9 1684.9 446.85 81. 7E 1711. 5 1648.5 372.15 281. 8W 281. 6 372,9 )342,2( 1800.0 1693.5 453,85 83.0E 1722,0 1657.3 377,55 283, 8W 281. 8 376.4 ) 345.2 ( 1811,1 1701.9 460,85 84.3E 1732.5 1666.1 382.95 285. 8W 281. 9 379.9 ) 348.3 ( 1822.2 1710.4 467.95 85.6E 1743,0 1674.8 388,45 287. 8W 282,0 383,4 )351.3( 1833 .3 1718.8 475.15 86.9E 1753,5 1683.5 393,85 289, 8W 282.2 387.0 ) 354,4 ( 1844.4 1727.2 482.35 88.2E 1763 ,8 1692,0 399.25 291. 7W 282.3 390.5 )357.5( 1855,6 1735.5 489.55 89,6E 1774.2 1700,7 404.85 293. 7W 282.5 394.1 )360.6( 1866.7 1743.8 496.85 90,9E 1784.7 1709.3 410.45 295. 8W 282,6 397,7 )363.7( 1877 . 8 1752.0 504.25 92 .2E 1794.7 1717.5 415.75 297, 7W 282.8 401.3 )366.9( 1888,9 1760.2 511,55 93.6E 1805.1 1726.0 421.45 299. 7W 282.9 405.0 ) 370.0 ( 1900.0 1768.3 519,05 95.0E 1815.5 1734.5 427.15 301.8W 283,0 408,6 )373.2( 1911.1 1776.4 526.45 96.3E 1825.6 1742.7 432.65 303.8W 283.2 412,3 )376.4( 1922.2 1784.5 534.05 97. 7E 1836.0 1751.1 438.45 305, 8W 283.3 416.0 )379.7 ( 1933.3 1792.5 541,55 99.1E 1846.4 1759.5 444.25 307.9W 283,5 419.8 )382,9( 1944,4 1800.5 549,25 100. 5E 1856.0 1767.1 449.65 309, 8W 283,6 423.5 ) 386,2 ( 1955.6 1808.4 556.85 101. 9E 1866.3 1775.4 455,55 311. 9W 283.8 427.3 )389.5( 1966.7 1816.3 564.55 103, 3E 1876.7 1783.7 461.45 314. OW 283.9 431.1 )392.8( 1977.5 1824,0 572 .15 104. 7E 1885.6 1790.7 466.55 315, 8W 284.1 434.8 )396.1( 1988.4 1831.6 579.75 106.1E 1895.7 1798,7 472.45 318,OW 284.2 438,6 )399,3( Coordinates All data is in feet unless otherwise stated, Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 169,63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). O~' 1IU,,~AL (' Phillips Alaska, Inc. CLEARANCE LISTING Page 7 Drill Site 2P,429 Your ref: 2P-429 Version#2 Meltwater, North Slope, Alaska Last revised: 22-May-2001 Reference wellpath Object wellpath : PMSS <0-???'>,,438,Drill Site 2P Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M,D, T.V.D. Rect Coordinates Bearing Dist Sep'n 1999,3 1839.2 587,4S 107,5E 1904.6 1805.6 477.6S 319, 8W 284.4 442.4 ) 402.7 ( 2000.0 1839.7 587.9S 107.6E 1905,3 1806.1 478.0S 320. OW 284,4 442.7 )402.9( 2010.1 1846.7 595.1S 108.9E 1914.7 1813 .5 483.6S 322. OW 284.5 446.3 )406.0( 2021. 0 1854.2 602,8S 110. 3E 1923 .5 1820.3 488,8S 323.9W 284.7 450,2 )409.5( 2031. 9 1861. 6 610,68 111. 7E 1933.6 1828.1 494,9S 326. OW 284.8 454.1 )412.8( 2042,7 1869.0 618,5S 113, 2E 1943.7 1835.8 501. OS 328, 3W 284,9 458.0 ) 416.3 ( 2050.7 1874.4 624, 2S 114, 2E 1949.4 1840,2 504.4S 329, 5W 285.1 460.9 )418,9( 2058.7 1879,8 630,OS 115. 3E 1956.8 1845.8 508. 9S 331.1W 285.2 463.8 ) 421. 4 ( 2066,7 1885.1 635.9S 116. 3E 1964.2 1851. 4 513 .5S 332,8W 285.2 466.7 )424,O( 2077 , 8 1892.5 644.08 11 7 , 8E 1972 .2 1857.5 518. 4S 334, 6W 285,5 470.9 )427.6( 2088.9 1899.9 652.2S 119. 3E 1982.5 1865.2 524. 8S 337 , OW 285.6 475.0 )431.2( 2100,0 1907,2 660.4S 120. 8E 1992 .7 1872 . 8 531.2S 339.4W 285.7 479,2 )434.9( 2111.1 1914.5 668.78 122. 3E 2000,7 1878.7 536,2S 341.2W 285.9 483,5 )438.7( 2122.2 1921.7 677.0S 123 .9E 2010,9 1886.3 542.7S 343. 7W 286.0 487,7 )442.4( 2133.3 1928.9 685,4S 125. 4E 2018,9 1892.1 547,7S 345. 6W 286.3 492.0 ) 446.3 ( 2144.4 1936.0 693.78 126,9E 2029.1 1899,6 554,2S 348. OW 286.4 496.4 )450,1( 2155,6 1943.0 702,2S 128,5E 2039.3 1906.9 560.7S 350. 5W 286.5 500,8 ) 453.9 ( 2166.7 1950.1 710,78 130, OE 2049.6 1914,4 567,4S 353,lW 286,5 505.2 )457,7( 2177.4 1956.8 718,98 131. 5E 2059.4 1921. 5 573.88 355, 5W 286.6 509.4 )461.4( 2188.1 1963.5 727.1S 133, OE 2071.9 1930.4 582,18 358, 6W 286.4 513.6 )464.9( 2198.9 1970,1 735.48 134,6E 2081.8 1937.3 588.68 360, 9W 286.5 517,9 )468,6( 2200.0 1970.8 736.38 134. 7E 2082,8 1938.1 589,38 361.2W 286.5 518.3 )469.0( 2209.6 1976,7 743.88 136,lE 2094.4 1946.2 597.08 364. OW 286.4 522,1 ) 472,1 ( 2220.3 1983.2 752.18 137,6E 2104,2 1953.1 603.68 366,4W 286.4 526,3 )475.8( 2231.1 1989,7 760,58 139,2E 2116,9 1961.8 612.28 369,4W 286.3 530,5 ) 479.3 ( 2241. 8 1996,2 769.08 140. 7E 2126.7 1968.6 619,08 371. 7W 286,3 534,6 )482.9( Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 169,63 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level), OR I l:4 IIVl '. ( Phillips Alaska, Inc. Drill Site 2P 429 slot #429 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 2P-429 Version#2 Our ref: prop452l License: Date printed: 22-May-200l Date created: 25-Feb-200l Last revised: 22-May-200l Field is centred on 441964,235,5869891,466,999,00000, N Structure is centred on 44l964,235,5869891.466,999.00000,N Slot location is n70 3 9,340, w150 26 55.820 Slot Grid coordinates are N 5868943.497, E 443913,132 Slot local coordinates are 933.18 S 1956.25 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North OHlullvAL Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,429 Your ref: 2P-429 Version#2 Mel twater , North Slope, Alaska Last revised: 22-May-200l 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. 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 0,00 169,63 100.00 0.00 N 0.00 E 0.00 0,26 0.26 0.15 N/A 200,00 0,00 169.63 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0,30 N/A 300.00 0,00 169.63 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400,00 2,00 169,63 399,98 1.72 S 0.31 E 1.75 1.05 1.05 0.60 N/A 500.00 4.00 169.63 499.84 6,86 S 1.26 E 6.98 1.36 1.31 0.75 349,63 600.00 6,00 169.63 599,45 15.44 S 2.82 E 15,69 1.73 1.58 0.90 349.63 700,00 8.00 169.63 698,70 27.42 S 5.02 E 27.88 2.20 1.86 1.05 349,63 800.00 10.00 169.63 797.47 42,81 S 7.83 E 43.52 2.77 2.16 1.21 349.63 866.67 12,00 169.63 862,90 55.32 S 10.12 E 56.24 3.23 2.36 1.31 349,63 966.67 15.00 169.63 960.13 78.28 S 14.32 E 79.58 4.09 2.69 1.48 349.63 1066.67 18,00 169.63 1056.00 106,22 S 19.43 E 107.98 5.13 3,05 1.65 349.63 1166.67 21.00 169.63 1150.25 139.05 S 25.44 E 141.36 6.35 3.43 1.84 349,63 1266.67 24.00 169.63 1242.63 176.69 S 32.33 E 179.62 7,75 3,84 2.05 349.63 1366.67 27,00 169.63 1332.88 219.03 S 40.07 E 222.67 9.33 4,29 2.28 349,63 1466.67 30,00 169.63 1420.75 265.97 S 48,66 E 270.38 11.09 4.75 2.55 349.63 1505.29 31.16 169.63 1454,00 285,29 S 52.20 E 290,03 11.83 4,94 2,67 349,63 1566.67 33,00 169,63 1506,01 317 ,36 S 58.06 E 322,62 13 .02 5.24 2.86 349,63 1666.67 36.00 169,63 1588,41 373,07 S 68.26 E 379.26 15.11 5.75 3.21 349,63 1766,67 39.00 169,63 1667.74 432,94 S 79.21 E 440.13 17,37 6.28 3,62 349.63 1866,67 42.00 169.63 1743,77 496.82 S 90.90 E 505.06 19.78 6.82 4,07 349.63 1966,67 45,00 169.63 1816,30 564.52 S 103.29 E 573.89 22.35 7.36 4.58 349.63 2042.74 47.28 169.63 1869.00 618.47 S 113 .16 E 628.74 24.41 7,77 5.01 349.63 2066,67 48,00 169.63 1885.12 635,87 S 116.34 E 646.42 25.06 7.90 5,15 349.63 2166,67 51.00 169.63 1950.06 710.66 S 130.02 E 722.45 27,91 8.43 5.78 349.63 2241.80 53.25 169.63 1996 .18 768.99 S 140,70 E 781,76 30,13 8,83 6.28 349.63 2500.00 53.25 169,63 2150.66 972.51 S 177.93 E 988,65 37,77 10,20 8.04 349.63 3000.00 53,25 169.63 2449,79 1366.61 S 250.04 E 1389,30 52.62 12.86 11.52 349,63 3107,32 53.25 169.63 2514.00 1451.21 S 265.52 E 1475.30 55.81 13 ,44 12.27 349,63 3500,00 53.25 169.63 2748.93 1760,72 S 322.15 E 1789,95 67.50 15,54 15.03 349,63 3949,75 53.25 169.63 3018.00 2115.22 S 387,01 E 2150,33 80,90 17.95 18,20 349,63 4000,00 53,25 169,63 3048.06 2154.82 S 394.26 E 2190.59 82,39 18.22 18,55 349,63 4500,00 53.25 169.63 3347.20 2548.93 S 466.36 E 2591,24 97,30 20,91 22,09 349,63 4554.83 53.25 169,63 3380.00 2592.15 S 474.27 E 2635,18 98.93 21.20 22.47 349,63 4874.09 53.25 169,63 3571.00 2843,79 S 520.31 E 2891. 00 108.45 22.92 24.73 349,63 5000,00 53.25 169.63 3646.33 2943.03 S 538.47 E 2991. 89 112.20 23.59 25,62 349.63 5500.00 53.25 169,63 3945.46 3337.14 S 610.58 E 3392.54 127.11 26.28 29.16 349,63 6000.00 53,25 169.63 4244.60 3731.25 S 682.69 E 3793.18 142.03 28.97 32.70 349,63 6500.00 53.25 169,63 4543,73 4125.35 S 754.79 E 4193.83 156,94 31.67 36.25 349.63 7000.00 53,25 169,63 4842.87 4519.46 S 826.90 E 4594.48 171.86 34.36 39,79 349.63 7500,00 53.25 169.63 5142.00 4913 .56 S 899.01 E 4995.13 186.77 37.05 43.34 349.63 8000.00 53.25 169,63 5441,14 5307,67 S 971 . 12 E 5395.78 201.69 39.74 46.88 349,63 8146.86 53.25 169,63 5529.00 5423.42 S 992.30 E 5513.45 206.07 40.53 47.92 349.63 8320.67 53.25 169.63 5632,99 5560,42 S 1017.36 E 5652.73 211. 26 41.47 49,15 349.63 8320,69 53.25 169,63 5633,00 5560.44 S 1017.36 E 5652.75 211.26 41.47 49,16 349.63 8500,00 53.25 169.63 5740.27 5701,77 S 1043.22 E 5796,42 216.61 42.44 50.43 349,63 8736,90 53.25 169.63 5882.00 5888.50 S 1077.39 E 5986.25 223 .67 43.71 52.11 349,63 8820.69 53.25 169,63 5932.13 5954.54 S 1089.47 E 6053,39 226.17 44.16 52.70 349,63 All data is in feet unless otherwise stated. Coordinates from slot #429 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea Bottom hole distance is 6053.39 on azimuth 169,63 degrees from wellhead. Vertical section is from wellhead on azimuth 169.63 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . 011bllVAL Phillips Alaska, Inc, Drill Site 2P,429 Meltwater, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-429 Version#2 Last revised: 22-May-2001 POSITION UNCERTAINTY SUMMARY -- - ---- --- - ---.... - ----- ---- -- --- - - -- --- -- -- - --.... - ---- - -- -- - - --- Depth From position Uncertainty Major Minor Vert. To Survey Tool Error Model ---------------------------------------------------------------------------------------------------- 8821 ARCO (H.A) Mag) User specified 44,16 226.17 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, Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300,00 0.00 N 0.00 E KOP 800.00 797.47 42.81 S 7.83 E Bld 3/100 1505.29 1454.00 285,29 S 52.20 E Base Permafrost 2042.74 1869.00 618,47 S 113.16 E Base West Sak 2241.80 1996 .18 768,99 S 140,70 E EOC 3107,32 2514,00 1451. 21 5 265.52 E C-80 3949.75 3018,00 2115,22 S 387.01 E C-50 4554.83 3380.00 2592,15 S 474.27 E C-40 4874,09 3571,00 2843,79 S 520.31 E C-37 8146,86 5529,00 5423.42 S 992.30 E T3 (Top Bermuda) 8320.67 5632.99 5560.42 S 1017 .36 E Target - BermudaMidPt 8320.69 5633,00 5560.44 S 1017 .36 E MW (H) Rvsd 15-May-01 8736.90 5882.00 5888.50 S 1077.39 E C-35 (Top Albian) 8820.69 5932.13 5954.54 S 1089.47 E TD - Csg pt Casing positions in string 'A' - - - -- - -- - - -- -- - - - - - -- -.... -.... -- - - - - - --- -- -- -........ -- - - -.... - - - - - -- -- - -- TOP MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords, Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OOE 8820.69 5932.13 O.OOE 2998.68 2449.00 1089.47E 7" Casing 249,85E 9 5/8" Casing O.OON O.OON 5954.545 1365,57S Targets associated with this wellpath ----- - - - -- - - - - - - - - - -- - - -- -- - - - - - - - --- -- --- - - - -- - --- - - ---- - - --- --- - - - - - ---- Target name Geographic Location Rectangular Coordinates Revised T.V,D. ----------------------------------------------------------------------------------------------------------- MW (H) Rvsd 15-May-0 444888.000,5863376,000,999,00 5633.00 1017.36E 22-Feb-2001 5560.44S 52.70 UHI~IIVAL Phillips Alaska, Inc. Drill Site 2P 429 slot #429 Meltwater North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 2P-429 Version#2 Our ref: prop452l License: Date printed: 22-May-2001 Date created: 25-Feb-2001 Last revised: 22-May-2001 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 9,340, w150 26 55.820 Slot Grid coordinates are N 5868943.497, E 443913 .132 Slot local coordinates are 933.18 S 1956.25 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. 21-May-2001 239.9 0.0 0.0 21-May-2001 180.2 100.0 100.0 6-Mar-2001 41005.8 8820.7 8820.7 26-Feb-2001 3042,1 3600,0 3600.0 26-Feb-2001 1397.6 8820,7 8820.7 PMSS <0-6008'>,,417,Drill Site 2P PMSS <O-???'>, ,438,Drill Site 2P PMSS <0-8935'>"MWSouth1,Meltwater South #1 PMSS <2212-7349'>, ,MWN#2A,Meltwater North #2 PMSS <0-6122' >, ,MWN*l ,Meltwater North #1 0 1 "GIIVA . Created by bmichael For: T Dote p'atted : 22-Moy-2DOI Plot Reference is 2P-429 Versionfl2. Coordinates are in feet re(erence slot 1429. Vertical Depths are reference RKB (Doyon ~:= ~ !,...! ,LI_' 169.63 AZIMUTH 5653' (TO TARGET) ***Plane of Proposal*** ~ r @ tl ~7.¡¡ TRUE Phillips Alaska, Structure: Drill Site 2P Well: 429 Field: Meltwater Location: North Slope, 300 East Ueetì -> 300 60ð 960 1200 0 AS-STAKED SURFACE LOCATION: 934' FNL, 1953' FWL SEC. 17, T8N, R7E Casing TARGET LOCATION: 1215' FNL, 2329' FEL SEC, 20, T8N, R7E Target TO LOCATION: 1609' FNL, 2258' FEL SEC. 20, T8N, R7E Inc. 1500 1800 300 - 0 - 300 - 600 - 900 - 1200 - 1500 - 1800 - 2100 - 2400 (J) 0 c - 2700 -+- :r ,..--.,. -+. - 3000 CD CD -+- '--'" - 3300 I V - 3600 - 3900 - 4200 - 4500 - 4800 - 5100 - 5400 - 5700 \ IC-35 (Top Albian) - ¿\ "'-TO - Csg pt - 6000 ........ ~.......,¡¡¡¡,. ;-~~"'!:ii.. (PHILLIPS) = ¡ I , ( ) ,-Î ~ 0. )G< "ìN '.' 1 . ~- For: T Dote p'otted : 22-l.1oy-2001 Plot Reference is 2P-429 Version#2. ( Phillips Alaska, Structure: Drill Site 2P Coordinates ore in feet reference slot 1429. True Vertical Depths ore reference RI<8 (Doyon ~;i~ =m iiŸGi'&S ji'liTi':q 0 - I Estimated RKB Elevation: 254' 400 - 800 - 1200 - 1600 - "......." -+- Q) 2000 - Q) '+- '--" ...c 2400 - -+- 0.. Q) 0 2800 - 0 ü += 3200 - L Q) > Q) 3600 - :J L I- I 4000 - V 4400 - 4800 - 5200 - 5600 - 6000 - KOP ,. 2,00 ,. 4,00 6,00 8,00 Bid 3/100 15,00 18,00 21,00 24,00 27,00 3~'2,~OBase Permafrost 39,00 0 DLS: 2,00 deg per 100 ft DLS: 3.00 deg per 100 It 45,00 Bose West Sak 51,OOEOC TANGENT ANGLE 53.25 DEG 400 800 1200 1600 Well: 429 Field: Meltwater Location: North Slope, 169.63 AZIMUTH 5653' (TO TARGET) ***Plane 01 Proposal*** 9 5/8 Casing C-80 C-50 C-40 C-37 Inc. ~ ..... - - /' _::- . . ---=--'- , PHllllp:)r . . . . . . - . . . I \ I I .. . ~ -----' 2000 2400 2800 3200 3600 T3 (Top Bermuda) Target - BermudaMidpt C-35 (Top Albion) TD- CS9 pt 4000 4400 4800 Vertical Section (feet) -> Azimuth 169.63 with reference 0.00 N, 0.00 E from slot #429 5200 5600 6000 6400 ORr;IIVAL ( Philli ps Alaska, Inc. ¡-ë;;~;~~.;;;;;;;'i~~;--For:-T-Br-oëkway Structure: Drill Site 2P Well: 429 Dote ploUed : 22-lw1oy-2001 Plot Reference is 2P-429 Versionl2. Field: Meltwater Location: North Slope, Coordinates orc in feet reference slot 1429. :True Vertical Deptl'1s ore reference RKB (Doyon 141).: ~.. ~ P'';TEQ TRUE NORTH ~ ~ c:=:J 350 0 10 340 20 330 210 30 320 40 50~ 310 300 60 290 70 280 80 30 270 0 30° 90 30 100 250 1 10 240 120 230 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ! OR "GIIVA~ Phillips Alaska, Inc. .... ....., ..... ~'PHILLIPS' Created by bmichael For: T Brockway Date plotted: 22-May-2001 Structure: Drill Site 2P Well: 429 Plot Reference is 2P-429 Version#2. Field: Meltwater Location: North Slope, ~ .,. ....;.... Coordinates are in feet reference slot #429. Vertical Depths are reference RKB (Doyon liiiiíiig IIAKm HUGHES INTRQ ==== PROF~LE COMMENT DATA ===== "'-"', ----- Point ----- MO Inc Oir TVO North East V, Sect Oeg/100 KOP 300.00 0.00 1 69.63 300.00 0.00 0.00 0.00 0,00 Bid 3/100 800.00 10.00 169.63 797.4 7 -42.81 7.83 43.52 2,00 Bose Permafrost 1505.29 31.16 169.63 1454.00 -285.29 52.20 290.03 3,00 Bose West Sak 2042.74 47.28 169.63 1869.00 -618.47 113.16 628.74 3.00 EOC 2241.80 53.25 169.63 1996.18 - 768.99 140.70 781 .76 3,00 C-80 3107.32 53.25 169.63 2514,00 -1451.21 265.52 1475.30 0,00 C-50 3949.75 53.25 1 69.63 3018.00 -211 5.22 387.01 2150.33 0,00 .~ C-40 4554.83 53.25 169.63 3380.00 -2592.15 474.27 2635.18 0,00 C-37 4874.09 53.25 1 69.63 3571.00 - 2843. 79 520.31 2891 .00 0.00 <:::) T3 (Top Bermuda) 8146.86 53.25 169.63 5529.00 -5423.42 992.30 5513.45 0.00 ::0 ......... 5652.73 0,00 ~ Target - BermudaMidP 8320.67 53.25 1 69.63 5632,99 -5560.42 1017.36 ........ IC-35 (Top Albion) 1077.39 5986.25 0.00 :æ 8736.90 53.25 169.63 5882.00 -5888.50 ~ ¡TO - Csa pt 8820,69 53.25 169.63 5932,13 -5954.54 1089.47 r-- by bmichoel For: T Dote p'otted , 22-Moy-2001 Plot Reference is 2~-429 VersionH2. Coordinates are in feet reference slot 1429. Vertical Depths ore reference RKB (Doyon ¡gîAÏ!!i ~ :NT[Q 2800 2400 2000 1600 ~ 4300 ",' 4500 '! 4700 'If 4900 f 5100 'If 5300 i 5500 ~ 5700 1f: 4100 ( Phillips Alaska, Structure: Drill Site 2P 1200 800 400 300. 1100J 1500j 1700¡ 1900¡' í 21 001 í 2300j 1438Í >I> 2500 .: 2700 '" 2900 'Ii: 3100 '" 3300 .: 3500 '" 3700 .: 3900 Field: Meltwater Location: North Slope, East (feet) -> 400 800 1200 if5003¡2.~.ETIJ .1100 .1300 ,1500 .1700 \ . 1900 \ \ .2100 \ \ . 2300 \ \ . 2500 \ \ . 2700 \ \ . 2900 \ \ .3100 \ \ .\. 3300 \ \ , 3500 \ , 3700 , 3900 \ ,4100 \ , 4300 \ , 4500 \ ,4700 \ , 4900 \ ,5100 \ , 5300 \ t 5500 \ ,5700 \ f, 5910 429 r4°0 ~ Inc. Well: 429 1600 2000 2400 2800 3200 3600 4000 400 ~" ~if,4900 ""'- 4 700 " ',*,¿500 '",,- 4300 .... "JI<,~ 1 00 "JI<,3900 """-.,3700 '",,- 3500 "if,3300 """'Ö2900 - 30 ''If - 0 - 400 - 800 -1200 - 1600 - 2000 - 2400 - 2800 U) 0 C -+ - 3200 ::J ..---.. -+. CD - 3600 CD -+ ........., I - 4000 V - 4400 - 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 OHlü/IVAL ( ( 2P-429 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) 12-1/411 Hole /9-5/8" CasinQ Interval Event Conductor Broach Well Collision Gravel and sand sloughing Shaker/Trough Cuttings System Overflow Permafrost Hydrates Shoe Fracture/Lost Returns during cement job I Risk Level Low Low Low Low Low Low I MitiCiation StrateCiY Monitor cellar continuously during interval. Careful well planning and surveying, adherence to anti-collision policy Elevated mud viscosity from spud; Hi dens sweeps; contingent 13-3/8" casing string. Controlled ROP Controlled drilling, reduced pump rates, higher mud weights, lower viscosities, and lecithin additions as needed Reduced pump rates, and lightweight tail cement 8-1/2" Hole /7" x 4-1/2" CasinQ Interval Event Hole Stability through CaD interval Lost Circulation in Bermuda interval High ECD and swabbing if higher MW is required Hole stability during e- line runs I Risk Level Moderate Moderate Low Moderate I M itiCiation StrateCiY Maintain mud weight at 9.8-10.0 ppg and keep all other mud properties within specifications. Good drilling practices. Good drilling practices. LCM as needed. Stay within ECD hardlines Pumping and rotating out on all trips to reduce swab and barite sag potential. Emphasis on maintaining mud properties. Clean out runs as needed. Good drilling practices 2P-429 Drilling Hazards Summary. doc prepared by Thomas A. Brockway OS/23/01 Page 1 of 1 ~a1rGIÏVAL ~ PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Meltwater 2P-42t Proposed Completion Schematic Big Bore Base Case - 4-1/211 Completion String 30" X 16" 62.6# @ +1- 110' MD (Insulated) II JI Depths are based on Doyon 141 RKB Surface csg. 9-5/8" 40.0# L-80 BTCM +1- 2999' MD I 2449' TVD Intermediate csg. 7" 26.0# L-80 STCM run CSR to surface +/- 8047' MD / 5469' TVD Future Perforations Production csg 4-1/2" 12.6# L-80 1ST TD to CSR +1- 8821' MD I 5932' TVD .. -- ~ I i I ¡ ... ... .- I 5 ~ .~ ]1 r ~ 4-1/2" FMC Gen 5 Tubing Hanger, 4-1/2" L-80 1ST pin down 4-1/2" 12.6# L-80 1ST Spaceout Pups as Required 4-1/2" 12.6# L-80 1ST Tubing to Surface 4-1/2" Cameo 'DB' nipple wI 3.875" No-Go Profile. 4-1/2" x 6' L-80 handling pups installed above and below, 1ST set at +1- 500' MD 4-1/2" 12.6# L-80 1ST tubing to landing nipple 4-1/2" X 1" Cameo 'KBG-2' mandrel wI DCK-2 shear valve and SEK latch (Max. 005.985", 103.833"), 1ST pin x pin, pinned for 3000 psi shear (casing to tubing differential), 4-1/2" x 6' L-80 1ST box x box handling pup installed above, 4-1/2" x 6' L-80 1ST box x pin handling pup installed below 1 jt 4-1/2" 12.6# L-80 1ST tubing 4-1/2" Cameo 'DB' nipple wI 3.75" No-Go profile. 4-1/2" x 16' L-80 ISTspacaeout pup installed above, 4-1/2" x 6' handling pup installed below 1 jt 4-1/2" 12.6# L-80 1ST tubing 4-1/2" Baker 80-47 GBH-22 casing seal assembly wI 15' stroke, 4-1/2" L-80 1ST box up, 4-1/2" x 6' L-80 1ST handling pup installed on top Saker Casing Seal Receptacle, 194-47,7" STCM x 4-1/2" 1ST Saker 7" (Max) 00 x 4-3/4" 10 17' Seal Sore Extension CSR set at +1- 100' above top perforation O~'G'Vj~ PJR, 5/10/00 ~ PHILLlPS( .laska, Inc. I~ A Subsidiary ot PHilLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 May 23,2001 FrSCSIVI2D M4y 2 Alaska Q. 3 '00 'Ì/&G, <I! asC, AnChOr. Ot]s. ~ age flrJiSSiOt] Alaska Oil and Gas Conservation Commission Camille Taylor, Commissioner 333 West th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2P-429 Surface Location: Target Location: Bottom Hole Location: 933'FNL, 1956' FWL,Sec. 17,T8N,R7E 1079'FNL,2351'FEL,Sec.20,T8N,R7E 1610'FNL,2256'FEL,Sec.20,T8N,R7E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-429. Subject to AOGCC approval, fluids and cuttings generated from drilling 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 or James Trantham at (907) 265-6434. Sincerely, ~~:~ James Trantham J Drilling Engineering Supervisor Tí~ RECEIVED MAY 2 3 2001 Alaska Oil & Gas C A ons. Commission nchorage American Express~ Cash'Advance Draft DATE HI ~~YD:~~;E S)a+¿ of/f{as&.¡ ftoScc ~ó~ ~~I-ß~ck~ a-//~!rOÞ 135 b3/2t:o( 82-40/1021 I slloo.oO DO LlARS Issued by Integrated Payment System. Inc. . Englewood. Colorado NOT V AUD FOR AMOUNT OVER $1000 Payable at NolWest Bank of Grand Junction - Downtown. NA st:;- SHAR!~tt. LSj);:t;. Grand Junction. Colorado PERIOD ENDING ~ llÀC\ ¿;h.. (- I: .0 2 . 0 0 ~ POI: :i 5 III 0 . 7 5 000 5 :i b III 0 . :l 5 , ,,!:íetZ / WELL PERMIT CHECKLIST COMPANY ¡1..//1rjc'5 WELL NAME 2¡?..<l21 PROGRAM: exp - dev - redrll- 5erv / wellbore sag ~ann. disposal para req - FIELD & POOLt/7()(') ~':) INIT CLASS ~ 6:¡eUIc£ l~ tJlk¡/4 GEOL AREA S'f() UNIT# / ! I (é/) ON/OFFSHORE n/'1 ADMINISTRA TIOH 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . N /' Iz ,', d / /' . I ( 2. Lease number appropriate. . . . . . . . . . . . . , . . . . . N <::5i.-C.-r-~z/~'<~ ~ ~~ Ù<-, .ÇIÐC 3 '~~ 1/2: ) -rc; r rÓd-U ~'h~?-t"\:=f<-d/O<- 3. Unique well name and number. .. . . . . . . . . . , . . . . . N ¿U,va- ' ,",~ rl-DL .3&,/osg. ,/,;)t:.'> , 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 platincluded.. . . . . . . . . . . .. . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N AP~ RATE --( 12. Permit ca~'be issued without administrative approval.. . . . . N /J j/ f:. . 23 .0, 13. Can permit be approved before 15-day wait.. . .' . . . . . . . N ENGINEERING 14. Conductor string provided . . .. . ., ' ,. . . " . ., . . . . .. . ~ N ' 15. Surface casing protects all known USDWs. . . . . .. . . . . N ~ 16. CMT vol adequate to circulate on conductor &, surf csg. . . . . -~ ~ ' \ \ \ \ \ \ 17. CMT vol adequate to tie-in long string to surf csg. . . . . .. . " y <JY <J. ~~~ 'c...('- 0\"'S.~(J~<). ,\,) \ .. ........ú... \.c 1 V ~ '''~ 18. CMT will cover all known productive horizons. . . . .'. . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 'Y 'N , 20. Adequatetankage or reserve pit.. . . . . . . . . . . . . . . . Y N e'1:-:~~~'-~' \, ~ ~~~~<t. C,~ ' 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ~ -.J J \ 22. Adequate weilbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling ,fluid program schematic & equip list adequate. . ~ . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 1. ~ ~ \\.1 .. '11, ~~AA ~~;" , 26. BOPE press rating appropriate; test to - 3t)CJO psig. N M~CS1? ~~~ ~~d ~ \ "''\.\ O~ \ lJ"ì-':{J1{ :::J/ - ./ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N '\ 28., Work will occur without operation shutdöwn. . . . . . . . . . . N 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . .. gy <tD GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . .0 Y 31. Data presented on potential overpressure zones. . . . . .. ,1\' N , 32. Seismic analysis of shallow gas zones. . . . . . . . ~. ... f/t' Y N AP@ft DATE 33. Seabed condition survey (if off-shore). . . . . . . . . .. .' Y N ßJ..J _5: 23,D ( 34. Contact name/phone for weekly progress reports [expl tory only] Y N "" ANNULAR DISPOSAL35. W~h proper cementing records. this plan . ð>v" \'û~ \ ~ \Q.."'.-.L'¿) \" \.:::. "-'-"-. <::q:>~~..ro <:>.t--~ \ '" ':> <:f. \-.c. ,Ù -\è <:.,~ l:L" (A) will contain waste in a suitable receiving zone; . . . . . . . Y N ~1" ~~ f ~ 'WJ P1 D - APP /..-1 CA 1, 0 N... \)J '^ , (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular C~ION: Commentsllnstructions: ~Þ8 4Ø~ ~-Q?rr¡ ~..,~M 9~~ ...)AA\J 6[24ID~ 2. pAØ- tIO. R:0 I1a.n1L Î5 '¿pi q5~\~\~~~-\:, ~~\ APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -I ~ ;U -I m -' Z -I :J: en ). ;U m » Well History File APPENDIX Infonnation of detailed nature that is not particularly gennane to the Well Pennitting Process' but is part of the history file. To improve the readability of the Well History file and to simpltfy finding infonnation, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically. . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 20 20:40:15 2002 Reel Header Service name..... ........LISTPE Date.....................02/03/2(1 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOTtJN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name.............LISTPE Date.....................02/03/20 Origin...................STS Tape Name................ UNK"NOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record T.i\PE HEimER Kuparuk River Unit M'ViD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPi\NY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AKMMl1208 B. ZIEMKE D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHI P: Ri\NGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROH KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: HSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 2 P-4 2 9 501032037800 PHILLIPS Alaska, Inc. Sperry Sun 20-MAR-02 MWD RUN 2 AKMM112 08 B. ZIEMKE D. GLADDEN 17 8N 7E 934 1953 .00 251.10 224.00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 110.0 9.625 2965.0 12.250 # REHARKS: 1. ALL DEPTHS ARE HEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. aOI-/od 101<05 3. HWD RUN 2 IS DIRECTIONAL WITH DUAL GAHM.Þ.. RAY (DGR) UTILIZING GEIGER HUELLER TUBE DETECTORS, ELECTRO~ffiGNETIC WAVE RESISTIVITY PHASE 4 (EI'JR4), COMPENSATED NEUTRON POROSITY (CNP), l,,-ND STABILIZED LITHO-DENSITY (SLD). 4. GPJ"J]vlP, R.Ä.Y (SGRC) IS LOGGED BEHIND CASING FRO!'-1 :2 902' MD, 2396' TVD TO 2965' HD, 2434' TVD. 5. MWD DATA IS CONSIDERED PDC PER THE E-HAIL FROH D. SCH~JARTZ OF PHILLIPS ALASKA, INC. m\TED 01/04/02. AUTHORIZED BY GKA GEOSIENCE GROU ALL ~~D LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. HWD RUNS 1 - 2 REPRESENT WELL 2P-249 WITH API # 50-103-20378-00. THIS WELL REACHED A TOTAL DEPTH OF 8974' MD, 6002' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY SGRC = SMOOTHED GAMMA RAY COHBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SHOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FOR~~TION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = ABSORPTION CTFA RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC FACTOR (L01i'if-COUNT BIN) SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE M~TRIX, FIXED HOLE SIZE) SMOOTHED AVER.~GE OF FAR DETECTOR'S COUNT SPSF = ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DA'.L'A: HOLE SIZE: 8.5" HUD HEIGHT: 9.75 PPG MUD FILTR~TE SALINITY: PPM CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: G/CC VL~TRIX DENSITY: 9.60 - 28,000 - 32,000 22,727 PPM CHLORIDES 1. 00 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number:-......... ..1.0.0 Date of Generation.......02/03/20 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FI LE NUlv1BER: ~DITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMM.1:'uqy PBU TOOL CODE GR ROP NCNT FCNT 1 and clipped curves; all bit runs merged. .5000 START DEPTH 28.0 110.0 2955.0 STOP DEPTH 8932.5 8974.5 8880.5 2955..0 8880.5 8880.5 8925.0 8925.0 8925.0 8925.0 8925.0 8889.5 8889.5 8889.5 NPHI FET RPD RP~1 RPS RPX DRHO RHOB PEF $ 2955.0 2955.0 2955.0 2955.0 2955.0 2955.0 2963.5 2963.5 2963.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT m\TA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # IvlERGED PBU IvlWD ]\f[rifD $ DATA SOURCE TOOL CODE 2 2972.5 MERGE BASE 2972.0 8974.5 BIT RUN NO IvlERGE TOP 1 28.0 # RE.MARKS: IvlERGED .MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.......... ...Undefined .7\bsent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR M1i'VD API 4 1 68 8 3 RPX Mtl'ÌD OHMM 4 1 68 12 4 RPS M~"JD OHMM 4 1 68 16 5 RPM IvlíriJD OHMJl.I 4 1 68 20 6 RPD M1i"JD OHMM 4 1 68 24 7 FET Mí"JD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB HWD G/CH 4 1 68 44 12 DRHO ]\f[rifD G/CH 4 1 68 48 13 PEF MíriJD B/E 4 1 68 52 14 First Last Name Service Unit Mill. Hax Mean Nsam Reading Reading DEPT FT 28 8974.5 4501.25 17894 28 8974.5 ROP M1i'W FT/H 6.88 423.6 118.013 17730 110 8974.5 GR HWD API 49.54 243.38 135.5 17810 28 8932.5 RP}C IvfwD om,1M 0.28 1801.47 5.42551 11941 2955 8925 RPS NWD OHHH 0.34 1181. 46 5.59568 11941 2955 8925 RPH lvIT'JD OHHM: 0.35 2000 5.97424 11941 2955 8925 RPD MirilD OHHN 0.59 2000 6.60966 11941 2955 8925 FET MiiJD HR 0.27 64.83 1.02386 11941 2955 8925 NPHI Ì"fifVD PU-S 16.65 69.36 39.7576 11852 2955 8880.5 FCNT lvIWD CP30 464.73 1071.38 706.888 11852 2955 8880.5 NCNT HliJD CP30 2296 3790.04 2803.17 11852 2955 8880.5 RHOB H1-vD G ¡ Cr-! 2.02 ¿. i.5 2.41849 11853 2963.5 8889.5 DRHO lvIWD GICM -0.02 0.43 0.068818 11853 2963.5 8889.5 PEF IvfwD B/E 2.27 7.32 3.53996 11853 2963.5 8889.5 First Reading For Entire File..........28 Last Reading For Entire File...........8974.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......02/03/20 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03120 Haximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW JvIWD Curves and log BIT RUN NUHBER: DEPTH INCREHENT: # FILE SUHMARY VENDOR TOOL CODE START DEPTH GR 28.0 ROP 110.0 $ 2 header data for each bit run in separate files. 1 .5000 STOP DEPTH 2902.5 2972.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (HEHORY OR REAL-TIHE) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERV~L (FT): BIT ROTATING SPEED (RPH): HOLE INCLINATION (DEG MINIHUM ANGLE: MAXIHUH ANGLE: 10-DEC-01 Insite 4.05.5 3.30 Nemory 2972.0 .4 53.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUR~L GAMMA PROBE $ TOOL NUMBER 010 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 2965.0 ( # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): HUD PH: HUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (HT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTR~TE AT MT: t-1U D CAKE A'T t-1'l': EZ-MUD 9.60 60.0 9.3 27000 5.4 .000 .000 .000 .0 87.0 .0 .0 .000 # NEUTRON TOOL MATRIX: lvlATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REM.~RKS : $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP Ivß'm010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 28 2972 1500 5889 28 2972 ROP MWD010 FT/H 6.88 423.6 110.333 5725 110 2972 GR MWD010 API 49.54 186.76 121.141 5750 28 2902.5 First Reading For Entire File..........28 Last Reading For Entire File...........2972 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/20 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/20 Maximum Physical Record..65535 Fi 1 e Type................ LO ( Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RA~'J HllJD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 3 .5000 header data for each bit run in separate files. ") ;i FILE SUMMARY VENDOR TOOL CODE START DEPTH GR NCNT FCNT NPHI FET RPD RPM RPS RPX DRHO RHOB PEF ROP $ 2903.0 2955.0 2955.0 2955.0 2955.0 2955.0 2955.0 2955.0 2955.0 2963.5 2963.5 2963.5 2972.5 # LOG HKA.DER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTW.A.RE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG HINIMUM ANGLE: M.A.XIHUM ANGLE: # STOP DEPTH 8932.5 8880.5 8880.5 8880.S 8925.0 8925.0 8925.0 8925.0 8925.0 8889.5 8889.5 8889.5 8974.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CNP $ BOTTOH) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMPENSATED NEUTRON # BOREHOLE ,~D 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: HUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL I'1ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 17-DEC-01 Insite 4.05.5 66.37 Memory 8974.0 51.1 56.6 TOOL NUMBER PB02334HWRG6 PB02334HWRG6 PB02077NL6 PB02077NL6 8.500 EZ-MUD 9.60 48.0 9.2 28000 4.3 .180 .100 .100 .350 68.0 127.4 68.0 68.0 .,. Data Format Specification Recorè Data Record T~lpe.................................... Data Specification Block Type.....Ci Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -99~ Depth Uni"Cs....................... Datum Specification Block sub-ty~e...ù Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP H~IJD020 FT/H 4 1 68 4 2 GR MlrJD020 API 4 1 68 8 3 RPX MWD020 OHMlv! 4 1 68 12 4 RPS !vIWD020 0 Hl'4M 4 1 68 16 5 RPH !vIWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CP30 4 1 68 36 10 NCNT MWD020 CP30 4 1 68 40 11 RHOB MWD020 GICM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 B/E 4 1 68 52 14 First: Last Name Service Unit Min Hax Hean Nsam Reading Reading DEPT FT 2903 8974.5 5938.75 12144 2903 8974.5 ROP MWD020 FT/H 7.21 344.17 121. 675 12005 2972.5 8974.5 GR MiÑD020 API 60.87 243.38 142.346 12060 2903 8932.5 RPX HWD020 OH¡V1N 0.28 1801.47 5.42551 11941 2955 8925 RPS MWD020 OHMN 0.34 1181.46 5.59568 11941 2955 8925 RPH HhTD020 OHMM 0.35 2000 5.97424 11941 2955 8925 RPD t--1WD020 OH!vIM 0.59 2000 6.60966 11941 2955 8925 FET MltiJD020 HR 0.27 64.83 1.02386 11941 2955 8925 NPHI MWD020 PU-S 16.65 69.36 39.7576 11852 2955 8880.5 FCNT MVIJD020 CP30 464.73 1071.38 706.888 11852 2955 8880.5 NCNT HWD020 CP30 2296 3790.04 2803.17 11852 2955 8880.5 RHOB MírJD020 GICN 2.02 2. 3 2.41849 11853 2963.5 8889.5 DRHO MWD020 GICM -0.02 0.43 0.068818 11853 2963.5 8889.5 PEF HWD020 B/E 2.27 7.32 3.53996 11853 2963.5 8889.5 First Reading For Entire File..........2903 Last Reading For Entire File...........8974.5 File Trailer Service name..... ........STSLIB.003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/03/20 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO4 Physical EOF Tape Trailer Service name.............LISTPE Date.....................02/03/20 Origin. . . . . . . . . . . . . . . . . .. STS T ape Name................ UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWl\f Comments.................STS LIS liifri ting Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................02/03/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNK'NŒ'iN Continuation Number......Ol Next Reel Name.. - . . . . . - . . UNK'NŒ'JN Cornrnents. . . . . . . . . . . . . . . . . STS LIS Physical EOF Phjlsical EOF End Of LIS File IlIJri ting Library. Scientific Technical Services