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Home My WebLink About202-0671. 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 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): 7310' None Casing Collapse Structural Conductor Surface Intermediate Production Kill String 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-422A 5984' 26' 26' 26', 575', 1808', 2305', 2387', 2870', 2920', 4759', 6646', 6759' 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): 6399' MD and 5196' TVD N/A Leslie Manning STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst 6401' MD MD 120' 2388' 120' 2858' 5958'7280' 16" 7-5/8" 85' 2823' 6785-6903' below cement 7254' 5-1/2" 5528-5630' below cement 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 12/31/2025 2300'2274' 3-1/2" 2073' Packer: Baker GBH-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 W ell Alteer Casing Extend Suspension Date 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): None g Collapse al or e ate on g 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/RWO Engineer KRU 2P-422A 5984'26'26' 26', 575', 1808', 2305', 2387', 2870', 2920', 4759', 6646', 6759' 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): 6399' MD and 5196' TVD N/A Leslie Manning ADL0373112, ADL0389058 202-067 360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended s Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst 6401'MD MD 120' 2388' 120' 2858' 5958'7280' 16" 7-5/8" 85' 2823' low cement 7254' 5-1/2" 5528-5630' below cement 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 12/31/2025 2300'2274' 3-1/2" 2073' Packer: Baker GBH-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 326-012 By Grace Christianson at 9:17 am, Jan 09, 2026 SFD VTL 1/21/26 March 1, 2026 X DSR-1/22/26 10-407 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-422A (PTD# 202-067). 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: RKB 2,387.0 2P-422A 9/27/2025 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated cement top from SL tag 2P-422A 10/17/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: DUMP BAILED 9.35 FT OF SAND AND 3 FT OF BISN BEADS ON CEMENT. 9/25/2025 rmoore22 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD 5.5" Cement String T/ 565' 5 1/2 4.95 25.6 565.0 564.3 15.50 L-80 BTC PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 2,845.0 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,152.0 Set Depth 6,401.5 Set Depth 5,197.6 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.5 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.7 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 575.0 574.2 6.11 CIBP K-1, CIBP Baker 12/13/2025 0.000 2,915.0 2,421.8 52.92 CUT MSC on rig 2/9/2025 4.950 2,920.0 2,424.9 52.72 CIBP CIBP 2/9/2025 0.000 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 3,257.0 6,400.0 2,644.1 5,196.3 Cement Casing Annular flow after cement job (Y/N): NMethod used for mixing cement in this stage: BatchReturns (pct): 0Time cementing mixing started: 13:00 4/21/2002 2,387.0 2,838.0 2,121.7 2,376.5 Plug Plug Back / Abandonment Plug Pumped 35 bbl 15.8 ppg cement w IsoGuard.Tagged at 2,387' RKB w/ SL on 9/27 5/20/2025 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2,400.0 2,920.0 2,128.9 2,424.9 Cement Plug Pumped 28 bbls 15.8# balanced plug. Good returns throughout job. Est. 8 bbls returns to tank during circ. out Milled down to 2870' on 05/19/2025 2/12/2025 2,305.0 2,387.0 2,075.8 2,121.7 Plug Plug Back / Abandonment Plug 15.8 PPG CEMENT W/ ISOGUARD AND MICROBOND. 10/14/2025 1,808.0 2,305.0 1,728.5 2,075.8 Plug & Abandonment HES pump 10 Bbls of fresh water @ 3 BPM, 210 PSI. Pump 23 Bbls of 16.0 PPG PTA cement @ 3 BPM, 580 PSI. Pump 1.5 Bbls of fresh water @ 3 BPM, 310 PSI. Displace w/ 9 Bbls of seawater @ 3 BPM, 210 PSI. POOH T/ 1445'. Circ well clean. Tag witnessed by AOGCC rep ??????????????????????????????????????? 12/11/2025 2P-422A, 1/7/2026 3:43:47 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Casing; 3,257.0 ftKB Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.8-2,857.8 Cement Plug; 2,400.0 ftKB Plug Plug Back / Abandonment Plug; 2,387.0 ftKB Plug Plug Back / Abandonment Plug; 2,305.0 ftKB Plug & Abandonment; 1,808.0 ftKB CIBP; 575.0 5.5" Cement String T/ 565'; 25.6- 565.0 CONDUCTOR; 35.0-120.0 Plug & Abandonment; 25.6 ftKB KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 25.6 575.0 25.6 574.2 Plug & Abandonment Pump 30 Bbls of Surf Wash @ 3 BPM, 180 PSI. Pump 41 Bbls 15.8 PPG PTA cement @ 3 BPM, 206 PSI. 5 Bbls 15.8 PPG retruned to surface. 12/13/2025 2P-422A, 1/7/2026 3:43:48 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Casing; 3,257.0 ftKB Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.8-2,857.8 Cement Plug; 2,400.0 ftKB Plug Plug Back / Abandonment Plug; 2,387.0 ftKB Plug Plug Back / Abandonment Plug; 2,305.0 ftKB Plug & Abandonment; 1,808.0 ftKB CIBP; 575.0 5.5" Cement String T/ 565'; 25.6- 565.0 CONDUCTOR; 35.0-120.0 Plug & Abandonment; 25.6 ftKB KUP PROD 2P-422A ... WELLNAME WELLBORE2P-422A 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 2, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2P-422A KUPARUK RIV U MELT 2P-422A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/02/2026 2P-422A 50-103-20400-01-00 202-067-0 N SPT 6399 2020670 1600 180 1770 1690 1640 0 20 20 20 OTHER F Guy Cook 11/8/2025 MIT for resevoir plug for P&A. TOC was already confirmed previously so no cement tag was performed. Previous MIT fail was on 10/17/25. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U MELT 2P-422A Inspection Date: Tubing OA Packer Depth 180 1770 1690 1640IA 1600 20 45 Min 1600 60 Min Rel Insp Num: Insp Num:mitGDC251109161545 BBL Pumped:0.9 BBL Returned:0.4 Friday, January 2, 2026 Page 1 of 1           Well is a Suspended 1-Oil producer that is being P&A'd; this is a plug verification; jbr Test did not meet the pressure loss criteria; jbr   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 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): 7310' None Casing Collapse Structural Conductor Surface Intermediate Production Kill String 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) 265-6049 CTD/RWO Engineer KRU 2P-422A 5984' 2387' 2122' 2252', 2277', 2408', 2657', 2920', 4759', 6646', 6759' 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: Cy.Eller@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6399' MD and 5196' TVD N/A Cy Eller STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned TVD Burst 6401' MD MD 120' 2388' 120' 2858' 5958'7280' 16" 7-5/8" 85' 2823' 6785-6903' below cement 7254' 5-1/2" 5528-5630' below cement 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 12/8/2025 2300'2274' 3-1/2" 2073' Packer: Baker GBH-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 325-717 By Grace Christianson at 7:51 am, Nov 21, 2025 X X BOP test to 2500 psig Annular preventer test to 2500 psig 10-407X VTL 11/24/2025 12/31/2025 TS 11/25/25 DSR-11/21/25 X JLC 11/25/2025 11/26/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 20, 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-422A (PTD # 202-067). This Sundry application is intended to replace Sundry #s 325-595, 325-526, and 325-229. 2P-422A was a producer 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 attempts to pressure test the plug have failed. Multiple attempts have been made to remediate the surface shoe cement plug using coiled tubing, but were also unsuccessful. To complete the abandonment of this well, CPAI is requesting approval to mill out cement inside of the 5-1/2 kill string, then cut and pull the kill string from above the top of cement in the kill string x surface casing annulus, then wash over and fish the remaining the section of the kill string. After removing the kill string, we plan to mill cement from the 7-5/8 surface 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-422A P&A Procedure PTD #202-067 Page 2 of 4 Pre-Rig Work Remaining 1. Prepare well for rig arrival Rig Work MIRU 1. MIRU Nabors 7ES on 2P-422A. 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. Bleed pressures to zero and complete 30-minute NFT. Verify well is dead. a. Seawater can not be circulated at this step, since cement is in kill string at ~2,252 RKB preventing kill string x SC circulation. 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 four cement plugs. Retrieve Kill String 4. MU 4-3/4 tri-cone milling BHA. RIH and remove cement from kill string. 5. Attempt to pull and lay down kill string. a. If kill string has cement on backside and will not pull free, MU MSC, RIH and cut 5-1/2 kill string at ~2,235 RKB, pull and lay down 5-1/2 kill string from cut then wash and burn over 5-1/2 kill string and PU fishing BHA and jar remaining section free. Remove Cement from 7-5/8 Casing 6. MU cement milling BHA. 7. PU DP, RIH to top of cement in 7-5/8 casing. a. Anticipated top of cement will be ~2,300 RKB once kill string is removed. 8. Mill cement from 7-5/8 casing until injectivity is achieved. 9. TOOH LD milling BHA. Set Cement Retainer 10. MU and RIH with cement retainer for 7-5/8 casing. Set retainer. a. 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. 2P-422A P&A Procedure PTD #202-067 Page 3 of 4 a. Cement volume will be determined by the depth that the surface shoe plug is tagged. RDMO 18. Perform NFT. ND BOPE. NU dry hole tree. a. This step may be performed before pumping final abandonment plug for operational efficiency. 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-422A c. PTD# 202-067 d. API# 50-103-20400-01-00 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: 12/8/2025 Current Operations: Suspended Well Type: Producer Wellhead Type: FMC Gen V. 11 5M casing head top flange. 11 5M tubing head top flange. 7- 1/16 5M dry hole tree. Scope of Work: Mill cement from kill string. Remove kill string. Mill cement from 7-5/8 casing until injectivity is achieved. Set cement retainer in 7-5/8 casing and pump 2P-422A P&A Procedure PTD #202-067 Page 4 of 4 cement through retainer. Run 5-1/2 kill string and circulate cement to surface. Execute final abandonment. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Well Data: Meltwater Formation: Reservoir pressure 8/10/2020 = 1071 psi @ 5515 TVD MASP = 520 psi / 0 psi (Cemented) C-80 Formation: OA Pressure = 410 psi (11/24/22) (diesel fluid level at 384 TVD) MASP = 971 psi / 0 psi (Cemented) TOC in kill string = 2,252 RKB Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Intervention Engineer: Erica Livingston 2P-422A Current Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 120 120 16 15.06 62.5 H-40 Welded Surface Casing 2858 2388.1 7 5/8 6.87 29.7 L-80 BTC-M Kill String 2300 2072.9 5 1/2 4.95 15.5 L-80 BTC-M Production Casing (5.5" Section) Top - 2915 Btm - 6402 Top - 2422 Btm - 5198 5 1/2 4.95 15.5 L-80 BTC-M Production Casing (3.5" Section) Top - 6402 Btm - 7280 Top - 5198 Btm - 5958 3 1/2 2.99 9.3 L-80 EUE-M Tubing Top - 3152 Btm- 6402 Top - 2574 Btm - 5198 3 1/2 2.99 9.3 L-80 EUE-M Surface Casing 2858' RKB Production Casing 7280' RKB Conductor Plug #1 -Reservoir TOC 6,646' RKB CIBP 6,759' RKB Tubing Cut: 3,152' RKB CIBP 2920' RKB Production Casing Cut: 2,915' RKB Production Casing Calculated TOC: 3,650' RKB Surface Casing TOC: Surface CIBP Plug #2 - Intermediate TOC 4,759' RKB BOC 6,630' RKB Surface Shoe Cement Plug Date Placed: 2/12/2025 TOC: 2,408' RKB 2nd Surface Shoe Cement Plug Date Placed: 10/14/2025 Slickline Tagged TOC: 2,252' RKB 2P-422A Proposed P&A Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 120 120 16 15.06 62.5 H-40 Welded Surface Casing 2858 2388.1 7 5/8 6.87 29.7 L-80 BTC-M Proposed Kill String ~2300 ~2073 5 1/2 4.95 15.5 L-80 BTC-M Production Casing (5.5" Section) Top - 2915 Btm - 6402 Top - 2422 Btm - 5198 5 1/2 4.95 15.5 L-80 BTC-M Production Casing (3.5" Section) Top - 6402 Btm - 7280 Top - 5198 Btm - 5958 3 1/2 2.99 9.3 L-80 EUE-M Tubing Top - 3152 Btm- 6402 Top - 2574 Btm - 5198 3 1/2 2.99 9.3 L-80 EUE-M Surface Casing 2858' RKB Production Casing 7280' RKB Conductor Plug #1 -Reservoir TOC 6,646' RKB CIBP 6,759' RKB Tubing Cut: 3,152' RKB CIBP 2920' RKB Production Casing Cut: 2,915' RKB Production Casing Calculated TOC: 3,650' RKB Surface Casing TOC: Surface CIBP Plug #2 - Intermediate TOC 4,759' RKB BOC 6,630' RKB Surface Shoe Cement Plug Date Placed: 2/12/2025 TOC: 2,408' RKB Cmt Retainer Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 2,387.0 2P-422A 9/27/2025 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated cement top from SL tag 2P-422A 10/17/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: DUMP BAILED 9.35 FT OF SAND AND 3 FT OF BISN BEADS ON CEMENT. 9/25/2025 rmoore22 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD 5.5" Kill String T/ 2,300' 5 1/2 4.95 25.6 2,300.0 2,072.9 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 2,845.0 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,152.0 Set Depth 6,401.5 Set Depth 5,197.6 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.5 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.7 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,915.0 2,421.8 52.92 CUT MSC on rig 2/9/2025 4.950 2,920.0 2,424.9 52.72 CIBP CIBP 2/9/2025 0.000 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.5 28.5 0.00 PRODUCTION 5.500 4.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,657.0 3,257.0 2,271.4 2,644.1 Kick-Off Plug (#3 Annular flow after cement job (Y/N): NPressure before cementing (psi): 950Bbls cmt to surf: RKB 3/6/2002 7,653.0 8,853.0 Abandonment Plug #2 Annular flow after cement job (Y/N): NPressure before cementing (psi): 950Bbls cmt to surf: RKB 32.14Returns (pct): Full 3/5/2002 8,253.0 8,853.0 Abandonment Plug #1 Annular flow after cement job (Y/N): NPressure before cementing (psi): 950Hours circulated between stages: 3Method used to measure density: MikroMethod used for mixing cement in this stage: On flyReturns (pct): Full 3/5/2002 3,257.0 6,400.0 2,644.1 5,196.3 Cement Casing Annular flow after cement job (Y/N): NMethod used for mixing cement in this stage: BatchReturns (pct): 0Time cementing mixing started: 13:00 4/21/2002 2,252.0 2,838.0 2,045.0 2,376.5 Plug Plug Back / Abandonment Plug PUMPED 15.8 PPG CEMENT W/ IsoGaurd from 2838'-2370' 5/20/2025 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2P-422A, 10/18/2025 3:36:59 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Casing; 3,257.0 ftKB Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.8-2,857.8 Kick-Off Plug (#3 ; 2,657.0 ftKB Cement Plug; 2,408.0 ftKB 5.5" Kill String T/ 2,300'; 25.6- 2,300.0 Plug Plug Back / Abandonment Plug; 2,277.0 ftKB Plug Plug Back / Abandonment Plug; 2,252.0 ftKB CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,408.0 2,915.0 2,133.3 2,421.8 Cement Plug Pumped 28 bbls 15.8# balanced plug. Good returns throughout job. Est. 8 bbls returns to tank during circ. out 2/12/2025 2,277.0 2,387.0 2,059.7 2,121.7 Plug Plug Back / Abandonment Plug 15.8 PPG CEMENT W/ ISOGUARD AND MICROBOND. 10/14/2025 2P-422A, 10/18/2025 3:36:59 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Casing; 3,257.0 ftKB Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.8-2,857.8 Kick-Off Plug (#3 ; 2,657.0 ftKB Cement Plug; 2,408.0 ftKB 5.5" Kill String T/ 2,300'; 25.6- 2,300.0 Plug Plug Back / Abandonment Plug; 2,277.0 ftKB Plug Plug Back / Abandonment Plug; 2,252.0 ftKB CONDUCTOR; 35.0-120.0 KUP PROD 2P-422A ... WELLNAME WELLBORE2P-422A 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:7310 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface:7 5/8"O.D. Shoe@ 2858 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:5.5"x3.5"O.D. Shoe@ 7280 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3.5"O.D. Tail@ 6401 Feet Tbg Cut@ 3152 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 2920 ft 2252 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1750 1600 1510 IA 1800 1650 1570 OA 20 16 15 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Halliburton wireline tagged cement at 2218 ft MD. With the wireline correction of 34 ft the cement was tagged at 2252 ft MD. The toolstring was approximately 250 pounds with a 4-ft drive down bailer fitted with a mule shoe with a flapper valve. The bailer sample was good cured cement. 0.6 bbl was pumped in the well for the MIT and 0.5 bbl was returned after the MIT was completed. October 17, 2025 Guy Cook Well Bore Plug & Abandonment KRU 2P-422A ConocoPhillips Alaska Inc. PTD 2020670; Sundry 325-595 None Test Data: F Casing Removal: John Hansen Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1017_Plug_Verification_KRU_2P-422A_gc                   Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE 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:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409812P-422A50-103-20400-01910312860Kuparuk RiverMulti Finger CaliperField & Processed23-Sep-250122P-422A50-103-20400-01910313140Kuparuk RiverMulti Finger CaliperField & Processed28-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 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): 7310'None Casing Collapse Structural Conductor Surface Intermediate Production Kill String 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 10/7/2025 2300'2274' 3-1/2" 2073' Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2823' 6785-6903' 7254' 5-1/2" 5528-5630' 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 120' 2858' 5958'7280' 16" 7-5/8" 85' 6401' MD MD 120' 2388' 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 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6399' MD and 5196' 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-422A 5984' 2387' 2122' 2387',2870', 2920', 4759', 6646', 6759' 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 1:55 pm, Oct 01, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.10.01 09:19:29 -08'00' 325-595 DSR-10/2/25A.Dewhurst 01OCT25 10-407 BJM 10/3/25 Conditions of approval on previous sundries 325-229 and 325-526 still apply. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.10.06 10:28:04 -08'00'10/06/25 RBDMS JSB 100625 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska September 30, 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-422A (PTD# 202-067). This 10-403 is being submitted to request procedure changes to the existing Sundry Approved P&A procedure (Sundry# 325-526). If you have any questions, please contact me at 263-4131. Sincerely, Jill Simek Staff Well Interventions Engineer 2P-422A Plug and Abandon Revised Procedure PTD #202-067 Sundry #325-526 Page 1 of 2 2P-422A is a suspended producer, idenƟĮed 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 aƩempted, on rig, to isolate the C80 from the wellbore; however, this plug has failed and requires remediaƟon. Under Sundries 325-229 and 325-526, two aƩempts have been made oī-rig to isolate the C80. This procedure shows steps to remediate the failed plugs by placing a 110Ō cement cap on the exisƟng plug. Once isolaƟon has been conĮrmed, the well will be cemented to surface then excavated and wellhead removed. 5/20/2025 C80 Cement Plug AƩempt (CTU): o RIH to 2828’, pump 35 bbls 15.8ppg premium cement w/ Isoguard o Lay in cement 1:1 up to 2464’; perform 2 hesitation squeezes o PUH pumping pipe displacement to 2301’; contaminate cement down to 2370’ RKB Result o Tag TOC at 2332’ RKB o Attempt to pressure test (1700psi). Failed; established LLR of 0.03gpm @ 1700psi 9/25- 9/28/2025 C80 Cement Plug AƩempt (BiSN): o Pump 120kg BiSN base beads down killstring o RIH with BiSN heater; tagged 11ft high o Slickline bailed BiSN beads, sand, contaminated cement; established new TOC tag at 2387’ RKB o Slickline caliper shows significant penetrations and projections at TOC, compromising BiSN plug placement o BiSN job aborted Revised Procedure Underream & Place New Cement (Coil) 1. MIRU. 2. RIH with coil and underream to TOC. 3. RIH with coil and place ~110ft cement plug, ~5bbls, leaving TOC ~2,277ft KB 4. RDMO. Wait on Cement. Tag and Pressure Test (Slickline) 5. Notify the AOGCC Inspector of timing for pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 6. MIRU. 7. RIH and tag TOC (witnessed). 8. Perform MIT to 1500psi on production casing (witnessed). 9. Perform DDT on production casing (witnessed). 10. RDMO. Surface Cement Plug (Eline/Pumping) 11. MIRU 12. RIH and punch killstring above TOC 13. Pump ~92bbls permafrost cement in kill string and surface casing. 14. RDMO. Wait on cement. Wellhead Excavation / Final P&A: 15. Confirm tubing and annulus pressures are at 0psi. 16. 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). 17. Remove the tree, in preparation for the excavation and casing cut. 18. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 19. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 20. Send the casing head w/ stub to materials shop . Photo document. 2P-422A Plug and Abandon Revised Procedure PTD #202-067 Sundry #325-526 Page 2 of 2 21. 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-422A PTD #: 202-067 API #: 50-103-20400-01-00 22. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 23. Obtain site clearance approval from AOGCC. RDMO. 5-½” Kill String set @ 2300' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A P&A Schematic - Current Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 Item Depth - tops (KB) 1 FMC Hanger 25.6' 2 Cast Iron Bridge Plug 2920' 3 Baker Sliding Sleeve 6,344.4' 4 Camco D Nipple 6,360.4' 5 Baker Locator 6,398.8' 6 Baker GBH-22 Seal Assembly 6,399.5' C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Shoe Cement TOC milled to ~2870' RKB BOC @ ±2920' RKB Plug #3 TOC @ 2387' RKB BOC ~2870' RKB 5-½” Kill String set @ 2300' RKB Plug #5 TOC @ Surface BOC ~2377' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A P&A Schematic - Proposed Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 Item Depth - tops (KB) 1 FMC Hanger 25.6' 2 Cast Iron Bridge Plug 2920' 3 Baker Sliding Sleeve 6,344.4' 4 Camco D Nipple 6,360.4' 5 Baker Locator 6,398.8' 6 Baker GBH-22 Seal Assembly 6,399.5' C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Shoe Cement TOC milled to ~2870' RKB BOC @ ±2920' RKB Plug #3 TOC @ 2387' RKB BOC ~2870' RKB Plug #4 TOC ~ 2377' RKB BOC @ 2387' 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:7310 ft MD Lease No.:ADL 0373112 Operator Rep:Suspend:NA P&A:X Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ NA Feet Surface:7-5/8"O.D. Shoe@ 2858 Feet Csg Cut@ NA Feet Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production:5-1/2"x3-1/2"O.D. Shoe@ 7280 Feet Csg Cut@ 2915 Feet Liner:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing:3-1/2"O.D. Tail@ 6401 Feet Tbg Cut@ 3152 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Open Hole Bridge plug 2920 ft 2332 ft 6.9 ppg N/A Initial 15 min 30 min 45 min Result Tubing IA OA 1630 1545 1500 Initial 15 min 30 min 45 min Result Tubing IA OA 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 @ 2300 ft MD. With production casing cut and pulled tubing, inner and outer annuli were in communication. They pumped into the inner annulus flange on the wellhead. Target pressure of 1500psi- fail. Operators optimistic attempt prior to committing to BisN bead plug. Plug failed MIT attempt in June 2025 (witnessed). No tag done. September 13, 2025 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-422A ConocoPhillips Alaska, Inc PTD 2020670; Sundry 325-229 none Test Data: F Casing Removal: Ryan Moore Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0913_Plug_Verification_KRU_2P-422A_am                   1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Extend Exp 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): 7310'None Casing Collapse Structural Conductor Surface Intermediate Production Kill String 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 2300'2274' 3-1/2" 2073' Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2823' 6785-6903' 7254' 5-1/2" 5528-5630' 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 120' 2858' 5958'7280' 16" 7-5/8" 85' 6401' MD MD 120' 2388' 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 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6399' MD and 5196' 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-422A 5984' 1603' 1554' 2332', 2408',2920', 4759', 6646', 6759' 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 09/10/2025 By Grace Christianson at 4:15 pm, Aug 28, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.08.28 16:02:38 -08'00' 325-526 10-407 All conditions on original approved sundry apply VTL 9/8/2025 No further extensions will be approved. DSR-9/9/24A.Dewhurst 02SEP25 X December 31, 2025 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 08:42:34 -08'00'09/10/25 RBDMS JSB 091125 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska August 27, 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-422A (PTD# 202-067). This 10-403 is being submitted to request procedure changes to the existing Sundry Approved P&A procedure (Sundry# 325-229), and to request an extension of the Sundry deadline, to December 31, 2025. If you have any questions, please contact me at 263-4131. Sincerely, Jill Simek Staff Well Interventions Engineer ! ! "# $ % & ' ( ((%)%' % *)+, -./ "#"#$ # %&#$!'("% ' 0 1. 2 1 3 42 5/% %% . %6%1 " 782 )*)+# ,+$#- 9:;""<73 (3" 6: -(0( 8 <$ &= >; 7#(<$ 74#<9?* # ''@77<9?* 1(4## 2A$ --9##7B(4## ./!!!0/1)230//&4/5/647//4' 5(3)+#( 4%)+#&)' ( C:9> 9:;,9(8#73?* 7 9:;D"4#?* 9:; D3##D7 E &=%'@D74#?* a. A Variance is requested to 20 AAC 25.112(a)(1)(A) requiring cement 100’ below hydrocarbon bearing zones. It is our intention to remove failed cement to ~50’ above existing CIBP, then to place ~500’ new cement from TOC into the surface casing. b. 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 mill out the cement plug once pumped. 3 9FC@, #&8' 8 +@G: 1 @G' , +A % 2 4 C:9> " 9:;'@1 2 H C:'(3## 1 2 (# FF' 1 2 (( 9FC@ 508&/9+$ ' ( C:9> (7 . '@77?* ( 9:; , -.' (3 , -. . (8 %, -. D3 8*)+4 36"I (4 9FC@9). Variance approved. VTL 9/8/2025 VTL 9/8/2025 Variance approved. #&8' (" +@G: 1 @G' , +A % 2 (H C:9> # 9:;, -.&27))%#' ( C:' &27))%#' (FF' &27))%#' : FF' & +###27))' 9FC@ ; )+# &+$ ' 3 C:9> 8 DH8 . 4 9FC@, 5" /< #=> 9- " # H +@G: . 1 @G' , +A % 2 7# 9%/% 7( 5/%% % 7 J KIL1 2&@G & 77 ) 6 7 ,MI.%1(8I@F2% @G, 9& )"$ ?@ - 6-!! 73 9%*. %6 *.% 78 @ %@G9FC@ 5-½” Kill String set @ 2300' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A P&A Schematic - Current Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 !" #$ % &'!'!( )%*** *+ ,! )%$* &- + )%#.. &/ '!01!2 )%## C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Shoe Cement TOC milled to ~2870' RKB BOC @ ±2920' RKB Plug #3 TOC @ 2332' RKB BOC ~2870' RKB 5-½” Kill String set @ 2300' RKB Plug #5 TOC @ Surface BOC ~2300' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A P&A Schematic - Proposed Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 !" #$ % &'!'!( )%*** *+ ,! )%$* &- + )%#.. &/ '!01!2 )%## C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Shoe Cement TOC milled to ~2870' RKB BOC @ ±2920' RKB Plug #3 TOC @ 2332' RKB BOC ~2870' RKB Plug #4 5ft BiSN Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 2,332.0 2P-422A 6/28/2025 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update TOC tag depth 2P-422A 6/28/2025 rogerba 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD 5.5" Kill String T/ 2,300' 5 1/2 4.95 25.6 2,300.0 2,072.9 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 2,845.0 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,152.0 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.5 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.7 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,915.0 2,421.8 52.92 CUT MSC on rig 2/9/2025 4.950 2,920.0 2,424.9 52.72 CIBP CIBP 2/9/2025 0.000 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.5 28.5 0.00 PRODUCTION 5.500 4.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,332.0 2,838.0 2,091.1 2,376.5 Plug – Plug Back / Abandonment Plug PUMPED 15.8 PPG CEMENT W/ IsoGaurd from 2838'-2370' 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2,408.0 2,915.0 2,133.3 2,421.8 Cement Plug Pumped 28 bbls 15.8# balanced plug. Good returns throughout job. Est. 8 bbls returns to tank during circ. out 2/12/2025 2P-422A, 8/27/2025 2:17:11 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.8-2,857.8 Cement Plug; 2,408.0 ftKB Plug – Plug Back / Abandonment Plug; 2,332.0 ftKB 5.5" Kill String T/ 2,300'; 25.6- 2,300.0 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE 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:Simek, Jill To:Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL]2P424A and 2P-422A P&As - proposed WBS Date:Monday, September 8, 2025 4:13:53 PM Attachments:2P-422A P&A Schematic - Current rev1.pdf 2P-422A P&A Schematic - Proposed rev1.pdf 2P-424A P&A Schematic with FISH rev1 - Current.pdf 2P-424A P&A Schematic with FISH rev1 - Proposed.pdf Hi Victoria, Amended WBS attached. For each well, I included “Current” and “Proposed”. Let me know if you have further questions. Jill From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, September 3, 2025 7:53 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]2P424A and 2P-422A P&As - proposed WBS 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. Jill, Could you please provide the updated WBS(proposed) that was included in the original sundries for both these P&As? Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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: 7310 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: X Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 7-5/8" O.D. Shoe@ 1858 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5-1/2 x 3-1/2" O.D. Shoe@ 7280 Feet Csg Cut@ 2915 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Surface Other 2870 ft 2336 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA 1690 1660 1630 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Tubing and production strings has been pulled and all testing was against casing. Same pressure loss every 15 minute test interval (30 psi). Plug was set on top of previous plug. June 28, 2025 Bob Noble Well Bore Plug & Abandonment KRU 2P-422A ConocoPhillips Alaska Inc. PTD 2020670; Sundry 325-229 none Test Data: F Casing Removal: Brent Rodgers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0628_Plug Verification_KRU_2P-422A_bn 9 9 9 9 9 999 9 9 9 9 9999 9 999 9gp Plug was set on top of previous plug. James B. Regg Digitally signed by James B. Regg Date: 2025.08.27 13:44:55 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-20_16033_KRU_2P-422A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16033 KRU 2P-422A 50-103-20400-01 Caliper Survey w/ Log Data 20-May-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 202-067 T40486 5/28/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.28 10:43:04 -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): 7310'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5/1/2025 3-1/2" Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2823' 6785-6903' 7254' 5528-5630' 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 120' 2858' 5958'7280' 16" 7-5/8" 85' 6401' MD MD 120' 2388' 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 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6399' MD and 5196' 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-422A 5984' 1603' 1554' 1603', 2408', 4759', 6646', 6759' 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 1:47 pm, Apr 15, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.04.14 16:54:50 -08'00' 325-229 10-407 SFD 4/18/2025 X SFD X 9/30/2025 DSR-4/17/25VTL 4/21/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.22 10:37:29 -08'00'04/22/25 RBDMS JSB 042225 ! "# $ % & ' "# () * + ,% %% ) %-% ! "# $! "../01" 2 3 4"2. % !&' ! 556 ##789., 556##7%'5.:;5 $ ; #"789.019;5. (01## *+ ) ( )*!) +,!" 0 <=8: 8=6;80>#?19. ? 8=6@"A#9. 8=6 @1##@? B &C%'5@?A#9. a. A Variance is requested to 20 AAC 25.112(a)(1)(A) requiring cement 100’ below hydrocarbon bearing zones. It is our intention to remove failed cement to ~50’ above existing CIBP, then to place ~500’ new cement from TOC into the surface casing. b. 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 mill out the cement plug once pumped. 1 83<5; $$$%!-!" > D52= ( 52' ; D+ % * A <=8: " 8=6'5( * 4 <='01## ( * 0# 33' ( * 00 83<5 %. ! " 0 <=8: 0? @4> ) 0 83<5; (/ 01 2 !34! 5# 01 # 0> D52= ) ( 52' ; D+ % * 0A 8%,% 0" E,%% % 04 F GHI( *&52 & # J - 0 ;KH)%(0>H53*% 52; 8& /!!$ 6 7 # 8#9: 8%.) %- .)% ? 5 %5283<5 5-½” Kill String set @ 2300' RKB WRP @ 1603.5' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A P&A Schematic - Current Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 !" #$ % &'!'!( )%*** * + ,! )%$* &- + )%#.. &/ '!01!2 )%## C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Shoe Plug TOC 2408' RKB (2133' TVD) BOC @ ±2920' RKB 5-½” Kill String set @ 2300' RKB Plug #4 TOC @ Surface BOC ~2370' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A P&A Schematic - Proposed Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 !" #$ % &'!'!( )%*** * + ,! )%$* &- + )%#.. &/ '!01!2 )%## C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Shoe Cement TOC milled to ~2870' RKB BOC @ ±2920' RKB Plug #3 TOC ~2370' RKB BOC ~2870' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,759.0 2P-422A 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update post RWO 2P-422A 3/7/2025 rogerba 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD 5.5" Kill String T/ 2,300' 5 1/2 4.95 25.6 2,300.0 2,072.9 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 2,845.0 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,152.0 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.5 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.7 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,603.5 1,554.3 28.52 WRP WRBP Unloader set for 3600#, Release set for 7600# YJOS WRBP 2/15/2025 0.000 2,915.0 2,421.8 52.92 CUT MSC on rig 2/9/2025 4.950 2,920.0 2,424.9 52.72 CIBP CIBP 2/9/2025 0.000 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.5 28.5 0.00 PRODUCTION 5.500 4.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2,408.0 2,915.0 2,133.3 2,421.8 Cement Plug Pumped 28 bbls 15.8# balanced plug. Good returns throughout job. Est. 8 bbls returns to tank during circ. out 2/12/2025 2P-422A, 4/14/2025 1:50:30 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 FRAC; 6,872.0 IPERF; 6,872.0-6,882.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.7-2,857.8 Cement Plug; 2,408.0 ftKB 5.5" Kill String T/ 2,300'; 25.6- 2,300.0 WRP; 1,603.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 120' 7.625" L-80 2388' 5.5" L-80 5214' 3.5" L-80 5958' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above6.75" TUBING RECORD 325 sx Class G6.75" 6401' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/16/2025 202-067/324-678 50-103-20400-01-00 KRU 2P-422A ADL 373112, ADL0389058 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM 921' FSL, 1855' FEL, Sec. 17, T8N, R7E, UM ALK 4/13/2002 7310' MD/ 5984' TVD 1603' MD/ 1554' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444049 5868975 1124' FSL, 1895' FEL, Sec. 17, T8N, R7E, UM 9. Ref Elevations: KB: 27' WT. PER FT.GRADE 4/19/2002 CEMENTING RECORD 5865711 1495' MD/ 1458' TVD SETTING DEPTH TVD 5865507 TOP HOLE SIZE AMOUNT PULLED 445331 445364 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 512'MD/ 511' TVD N/A PACKER SET (MD/TVD) 24" 9.875" 45 sx AS I 35'316 bbls AS3 Lite, 81 bbls LiteCrete 9.3# 35' 6421' 2858'35' 35' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 2408'- 2915' 28 bbls 15.8 ppg cement balanced plug Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 4759' (SW TOC) -6334' MD SUSPENDED 6785-6903' MD and 5528-5630' TVD (below cement plug) 6872-6882' MD and 5603-5612' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 31 bbls 15.8 ppg Class G cement 6421' SIZE DEPTH SET (MD) 7280' 26' 5214' 62.5# 29.7# 120' 26' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 1:24 pm, Mar 13, 2025 Suspended 2/16/2025 JSB RBDMS JSB 032525 xGDSR-4/7/25VTL 7/30/2025 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Digital Signature with Date:Contact Email: Shane.Germann@conocophillips.com Contact Phone:(907) 263-4597 Senior RWO/CTD Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS 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 Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this documentLocation: Date: 2025.03.13 09:29:40-08'00' Foxit PDF Editor Version: 13.0.0 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,759.0 2P-422A 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-422A 9/21/2024 bworthi1 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD 5.5" Kill String T/ 2,300' 5 1/2 4.95 25.6 2,300.0 2,072.9 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 2,845.0 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,152.0 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.5 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.7 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,603.5 1,554.3 28.52 WRP WRBP Unloader set for 3600#, Release set for 7600# YJOS WRBP 2/15/2025 0.000 2,915.0 2,421.8 52.92 CUT MSC on rig 2/9/2025 4.950 2,920.0 2,424.9 52.72 CIBP CIBP 2/9/2025 0.000 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.5 28.5 0.00 PRODUCTION 5.500 4.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2,408.0 2,915.0 2,133.3 2,421.8 Cement Plug Pumped 28 bbls 15.8# balanced plug. Good returns throughout job. Est. 8 bbls returns to tank during circ. out 2/12/2025 2P-422A, 3/7/2025 9:12:47 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 2,915.0-7,279.9 FRAC; 6,872.0 IPERF; 6,872.0-6,882.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 CIBP; 2,920.0 CUT; 2,915.0 SURFACE; 34.7-2,857.8 Cement Plug; 2,408.0 ftKB 5.5" Kill String T/ 2,300'; 25.6- 2,300.0 WRP; 1,603.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE 5-½” Kill String set @ 2300' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A Well Final P&A Schematic Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϵϮϬΖ ϯ ĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞϲ͕ϯϰϰ͘ϰΖ ϰ ĂŵĐŽEŝƉƉůĞ ϲ͕ϯϲϬ͘ϰΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϲ͕ϯϵϴ͘ϴΖ ϲ ĂŬĞƌ',ͲϮϮ^ĞĂůƐƐĞŵďůǇ ϲ͕ϯϵϵ͘ϱΖ C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6720' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Plug #3 – Surface Shoe TOC 2408' RKB (2133' TVD) BOC @ ±2920' RKB Page 1/8 2P-422 Report Printed: 3/10/2025 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) 2/8/2025 00:00 2/8/2025 01:00 1.00 MIRU, MOVE MOB P Warm up moving system hydraulics. Jack up rig. Back off 2P-424. Stage rig on pad. Unload old tree. Clean up area in front of well. Lay pit liner & T mats at 2P-422. 0.0 0.0 2/8/2025 01:00 2/8/2025 02:00 1.00 MIRU, MOVE MOB P Spot sub over 2P-422. Shim & berm rig. Center and level rig over well. 0.0 0.0 2/8/2025 02:00 2/8/2025 04:30 2.50 MIRU, MOVE MOB P Spot auxiliary equipment. Take initial RKB's and pressures. Initial Pressures (T/IA/OA) = 0 / 0 / 840 psi. RU bleed trailer to OA. Bleed off to ensure clear flow path and confirm initial pressure. Stage contingency wellhead equipment behind cellar (dry hole tree + DSA). Complete rig acceptance check list. Accept rig @ 04:30. 0.0 0.0 2/8/2025 04:30 2/8/2025 06:15 1.75 MIRU, WELCTL RURD P Load 9.8# brine into pits. Finish spotting in support equipment. RU hardline to kill tanks and cuttings tank. Build and warm up 35 bbl Deep Clean pill. 0.0 0.0 2/8/2025 06:15 2/8/2025 06:30 0.25 MIRU, WELCTL SFTY P PJSM on well kill. 0.0 0.0 2/8/2025 06:30 2/8/2025 06:45 0.25 MIRU, WELCTL PRTS P PT circ manifold & hard line T/ 2500 PSI. 0.0 0.0 2/8/2025 06:45 2/8/2025 07:30 0.75 MIRU, WELCTL KLWL P Pump 37 bbls warm Deep Clean. Chase with 83 Bbls 9.8# brine @ 4 BPM / ICP=700, FCP=1000. Circulate until have clean 9.8# brine around. 0.0 0.0 2/8/2025 07:30 2/8/2025 08:00 0.50 MIRU, WELCTL RURD P Blowdown lines. 0.0 0.0 2/8/2025 08:00 2/8/2025 08:30 0.50 MIRU, WELCTL OWFF P OWFF - 30 Min no flow. 0.0 0.0 2/8/2025 08:30 2/8/2025 10:15 1.75 MIRU, WHDBOP NUND P ND and hang old tree. Inspect hanger neck threads. Funtion LDS. 0.0 0.0 2/8/2025 10:15 2/8/2025 10:45 0.50 MIRU, WHDBOP MPSP P Set BPV w/ test dart. NU BOP. 0.0 0.0 2/8/2025 10:45 2/8/2025 13:15 2.50 MIRU, WHDBOP NUND P N/U BOP. Install flow niipple. M/U trip hose. 0.0 0.0 2/8/2025 13:15 2/8/2025 14:45 1.50 MIRU, WHDBOP RURD P R/U, testing equipment, Fill stack w/ fresh water. 0.0 0.0 2/8/2025 14:45 2/8/2025 15:30 0.75 MIRU, WHDBOP PRTS P Shelll test BOP. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 2/8 2P-422 Report Printed: 3/10/2025 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) 2/8/2025 15:30 2/8/2025 22:00 6.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/ 2 7/8" & 5 ½” test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Rest 2 7/8" Pac HT FOSV and IBOP. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3,000 PSI, after closure (drawdown) = 1,750 PSI, 200 PSI attained = 22 sec, full recovery attained = 106 sec. UVBR's = 5 sec, LVBR’s = N/A Annular = 20 sec. Simulated blinds = 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 1950 PSI. Test gas detectors, PVT and flow show. Test witnessed by AOGCC rep Guy Cook. 0.0 0.0 2/8/2025 22:00 2/8/2025 23:30 1.50 MIRU, WHDBOP RURD P RD testing equipment. Drain stack. Prep floor to pull 3 1/2" Tubing. 0.0 0.0 2/8/2025 23:30 2/9/2025 00:00 0.50 MIRU, WHDBOP MPSP P Pull BPV w/ test dart. 0.0 0.0 2/9/2025 00:00 2/9/2025 00:30 0.50 COMPZN, RPCOMP THGR P MU 3 1/2" EUE landing joint. Screw in TD. Set 10K down. BOLDS. Pull hanger to rig floor. Unseat @ 60K. Drag to floor @ 58K. 3,152.0 3,125.0 2/9/2025 00:30 2/9/2025 00:45 0.25 COMPZN, RPCOMP CIRC P Circ @ 4 BPM / 475 psi until clean. 3,125.0 3,125.0 2/9/2025 00:45 2/9/2025 01:00 0.25 COMPZN, RPCOMP OWFF P OWFF. 3,125.0 3,125.0 2/9/2025 01:00 2/9/2025 04:30 3.50 COMPZN, RPCOMP PULL P L/D landing joint and hanger w/ pup. Pull 3 1/2" EUE Tubing F/ pre-rig cut @ 3,152'. L/D in shed. Pull 98 full joints, pup joints, 1 DS nipple, 1 GLM, and 1 cut joint. Cut Joint Length = 27.70'. 3,125.0 0.0 2/9/2025 04:30 2/9/2025 06:00 1.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Prep pipe handling equipment to run 2 7/8" DP. Crew change out. 0.0 0.0 2/9/2025 06:00 2/9/2025 06:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #1 (5 1/2" CIBP) T/ 9' 0.0 9.0 2/9/2025 06:30 2/9/2025 07:30 1.00 COMPZN, RPCOMP TRIP P RIH F/9'' T/ 2921.5, PUW=52K, SOW=52K. Drop setting ball. 9.0 2,921.5 2/9/2025 07:30 2/9/2025 08:00 0.50 COMPZN, RPCOMP PACK P K/U. Pressure up T/ 1400 PSI hold for 5 Min. Pressure up T/ 2800 PSI. P/U T/ shear off CIBP. Set CIBP Top @ 2920'. Tag plug w/ 5K down. Good set. 2,921.5 2,920.0 2/9/2025 08:00 2/9/2025 08:30 0.50 COMPZN, RPCOMP OWFF P P/U T/ 2893', L/D working single. B/D TD. OWFF 2,920.0 2,893.0 2/9/2025 08:30 2/9/2025 09:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2893 T/ 9', PUW=52K. 2,893.0 9.0 2/9/2025 09:30 2/9/2025 09:45 0.25 COMPZN, RPCOMP BHAH P L/D BHA #1 9.0 0.0 2/9/2025 09:45 2/9/2025 10:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 MSC 0.0 8.0 2/9/2025 10:15 2/9/2025 11:45 1.50 COMPZN, RPCOMP TRIP P RIH F/ 8' T/ 2910', PUW=56K, SOW=53K. 8.0 2,910.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 3/8 2P-422 Report Printed: 3/10/2025 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) 2/9/2025 11:45 2/9/2025 12:00 0.25 COMPZN, RPCOMP WASH P Wash in hole F/ 2910' T/ 2920' @ .5 BPM, 100 PSI. Verify no collar at cut depth.. Tag plug top. P/U T/ 2915'. 2,910.0 2,915.0 2/9/2025 12:00 2/9/2025 12:30 0.50 COMPZN, RPCOMP CUTP P Cut 5 1/2" CSG @ 2915'. Rot @ 98 RPM, 1.2 K Free Tq. Circ @ 2 BPH, 1100 PSI. ROT=55K. Tq=1.5-2.5K, Freeze protect seen inside of 5 1/2". No PSI wrap around T/ OA 2,915.0 2,915.0 2/9/2025 12:30 2/9/2025 13:00 0.50 COMPZN, RPCOMP CIRC P P/U T/ 2893'. L/D single. B/D TD. M/U TIW. Close UPR. Open OA T/ cutting tank. Attempt to circ, PSI climbed to 310 PSI no fluid movement out OA. Open UPR. 2,915.0 2,893.0 2/9/2025 13:00 2/9/2025 13:15 0.25 COMPZN, RPCOMP TRIP P M/U single. Rack back stand T/ 2830. M/U single. 2,893.0 2,830.0 2/9/2025 13:15 2/9/2025 13:30 0.25 COMPZN, RPCOMP WASH P Wash in hole F/ 2830' T/ 2848' @ 1 BPM, 135 PSI. Locate collar @ 2848'. P/U T/ 2845' 2,830.0 2,845.0 2/9/2025 13:30 2/9/2025 13:45 0.25 COMPZN, RPCOMP CUTP P Cut 5 1/2" CSG @ 2845'. Rot @ 100 RPM, 1.2 K Free Tq. Circ @ 2 BPH, 1130 PSI. ROT=55K. Tq=1.5-2.5K, Fluid level fell out of sight in IA. 185 PSI wrap around on OA. Fill hole w/ charge pump through kill, 13 Bbls to bring fluid back T/ surface. 2,845.0 2,845.0 2/9/2025 13:45 2/9/2025 14:00 0.25 COMPZN, RPCOMP PULD P L/D working single T/ 3820'. B/D TD. M/U TIW. Close UPR. Open OA T/ cutting tank. 2,845.0 2,830.0 2/9/2025 14:00 2/9/2025 15:00 1.00 COMPZN, RPCOMP CIRC P Circ 87 Bbls hot deep clean pill around @ 3 BPM, 125 PSI. 2,830.0 2,830.0 2/9/2025 15:00 2/9/2025 15:30 0.50 COMPZN, RPCOMP OWFF P Open UPR OWFF. 2,830.0 2,830.0 2/9/2025 15:30 2/9/2025 18:30 3.00 COMPZN, RPCOMP SFTY P Safety stand up. Crew appreciation meal. 2,830.0 2,830.0 2/9/2025 18:30 2/9/2025 20:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #2 (MSC). 2,830.0 8.0 2/9/2025 20:00 2/9/2025 20:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #2 (MSC). Inspect blades 8.0 0.0 2/9/2025 20:45 2/9/2025 21:30 0.75 COMPZN, RPCOMP CIRC P Open OA to gauge. 20 psi on OA. Circ STS @ 4 BPM / 405 psi until have clean 9.8# brine around and OA dead before pulling pack-off. 0.0 0.0 2/9/2025 21:30 2/9/2025 22:00 0.50 COMPZN, RPCOMP WWSP P MU pack-off retrieval tool. J into pack- off. BOLDS. Pull pack-off. 0.0 0.0 2/9/2025 22:00 2/9/2025 22:30 0.50 COMPZN, RPCOMP PULL P MU 5 1/2" landing joint to hanger. Pull 5 1/2" hanger to rig floor. Unseat hanger @ 90K. Drag to floor @ 83K. 0.0 2,845.0 2/9/2025 22:30 2/9/2025 23:00 0.50 COMPZN, RPCOMP CIRC P Circ. until have clean 9.8# brine returns. 5 BPM @ 339 psi. SD pumps. 2,845.0 2,845.0 2/9/2025 23:00 2/10/2025 00:00 1.00 COMPZN, RPCOMP PULL P L/D 5 1/2" landing joint and hanger. BD Top drive. Pull 5 1/2" casing F/ cut @ 2,845' to midnight depth of 2,047' 2,845.0 2,047.0 2/10/2025 00:00 2/10/2025 02:00 2.00 COMPZN, RPCOMP PULL P Finish pulling 5 1/2" casing. Cut Joint = 41.63' long. Good cut. Pulled total of 65 Full Joint of 5 1/2" casing, 1 cut joint, and 23 centralizers. 2,047.0 0.0 2/10/2025 02:00 2/10/2025 03:00 1.00 COMPZN, RPCOMP RURD P Kick out 5 1/2" casing. C/O pipe handling equipment to 3 1/2" 0.0 0.0 2/10/2025 03:00 2/10/2025 04:30 1.50 COMPZN, RPCOMP BHAH P Load Yellow Jacket tools and 6 - 4 3/4" DC's. MU BHA #3 (Spear). Process 3 1/2" EUE Tubing. 0.0 228.0 2/10/2025 04:30 2/10/2025 06:30 2.00 COMPZN, RPCOMP TRIP P TIH F/ 229' T/ 2840', PUW=71K, SOW- =65K Saw ratty CSG starting @ 2833'. 228.0 2,840.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 4/8 2P-422 Report Printed: 3/10/2025 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) 2/10/2025 06:30 2/10/2025 09:30 3.00 COMPZN, RPCOMP FISH P Engage fish T/ 2853''. Set down 30K. Hit 25 licks @ 100K over, with 290K over straight pulls. Release from fish. Reengage fish. Hit 25 licks @ 100K over, with 325K over straight pulls. Release from fish. Rack stand back T/ 2758' 2,840.0 2,758.0 2/10/2025 09:30 2/10/2025 10:15 0.75 COMPZN, RPCOMP SFTY P Perform post jarring derrick inspection. OWFF 2,758.0 2,758.0 2/10/2025 10:15 2/10/2025 11:15 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2758 T/ 228', PUW=71K. 2,758.0 228.0 2/10/2025 11:15 2/10/2025 11:45 0.50 COMPZN, RPCOMP BHAH P Rack back DC's. L/D BHA #3. 228.0 0.0 2/10/2025 11:45 2/10/2025 12:15 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 2/10/2025 12:15 2/10/2025 12:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 MSC T/ 103' 0.0 103.0 2/10/2025 12:45 2/10/2025 14:15 1.50 COMPZN, RPCOMP TRIP P RIH F/ 103' T/ 2875, PUW=66K, SOW=64K. 103.0 2,875.0 2/10/2025 14:15 2/10/2025 14:45 0.50 COMPZN, RPCOMP WASH P Wash in hole verify no collars T/ 2979 @ 1 BPM, 150 PSI, 2,875.0 2,879.0 2/10/2025 14:45 2/10/2025 15:15 0.50 COMPZN, RPCOMP CUTP P Cut 5 1/2" CSG @ 2879'. Rot @ 100 RPM, 1.7K Free torque ROT=65K. Circ @ 2.5 BPM, 1600 PSI. 2.4-5.8K Tq. 2,879.0 2,879.0 2/10/2025 15:15 2/10/2025 16:15 1.00 COMPZN, RPCOMP CIRC P Circ BU @ 2 BPM, 940 PSI. Overboard contaminated fluid. 2,879.0 2,879.0 2/10/2025 16:15 2/10/2025 16:30 0.25 COMPZN, RPCOMP OWFF P Rack back stand T/ 2820'. B/D TD. OWFF 2,879.0 2,820.0 2/10/2025 16:30 2/10/2025 17:45 1.25 COMPZN, RPCOMP TRIP P POOH F/ 2820' T/ 103', PUW=66K. Crew change out. 2,820.0 103.0 2/10/2025 17:45 2/10/2025 18:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #4 103.0 0.0 2/10/2025 18:00 2/10/2025 19:15 1.25 COMPZN, RPCOMP BHAH P M/U BHA #6 spear T/ 230'. SOW=42K. 0.0 230.0 2/10/2025 19:15 2/10/2025 20:15 1.00 COMPZN, RPCOMP TRIP P RIH F/ 230' T/ 2818, PUW=70K, SOW=64K. 230.0 2,818.0 2/10/2025 20:15 2/10/2025 20:30 0.25 COMPZN, RPCOMP FISH P Engage fish T/ 2853''. Set down 10K. Bleed jars, , straight pull, pipe free @ 170K over. Drug @ 30K over for 5'. P/U T/ 2818' 2,818.0 2,818.0 2/10/2025 20:30 2/10/2025 21:00 0.50 COMPZN, RPCOMP CIRC P Circ BU @ 4 BPM, 500 PSI. Overboard contaminated fluid 2,818.0 2,818.0 2/10/2025 21:00 2/10/2025 21:15 0.25 COMPZN, RPCOMP OWFF P Rack back stand of DP. B/D TD. OWFF 2,818.0 2,818.0 2/10/2025 21:15 2/10/2025 22:30 1.25 COMPZN, RPCOMP TRIP P POOH F/ 2818' T/ 230', PUW=70K. 2,818.0 230.0 2/10/2025 22:30 2/11/2025 00:00 1.50 COMPZN, RPCOMP BHAH P Rack back DC's. L/D BHA #5 and 30.91' long fish. Good cut. 230.0 0.0 2/11/2025 00:00 2/11/2025 00:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #6 (Spear w/o pack-off). 0.0 226.0 2/11/2025 00:30 2/11/2025 01:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ spear to just above surface casing shoe @ 2,820'. PUW = 70K. SOW = 64K. 226.0 2,820.0 2/11/2025 01:30 2/11/2025 02:45 1.25 COMPZN, RPCOMP FISH P Wash down to fish top @ 1 BPM / 63 psi. See fish top @ 2,879'. Warm up jars. Hit 10 jar licks @ 75K over. His 40 jar licks @ 100K over (170K total). Straight pull to 250K over (325K total). No movement. 2,820.0 2,879.0 2/11/2025 02:45 2/11/2025 03:45 1.00 COMPZN, RPCOMP SFTY P Perform post jarring derrick inspection. 2,879.0 2,879.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 5/8 2P-422 Report Printed: 3/10/2025 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) 2/11/2025 03:45 2/11/2025 05:00 1.25 COMPZN, RPCOMP FISH P Continue jarring on fish. Hit 50 jar licks @ 100K over. Straight pull to 290K over (360K total). No movement. Release from fish. 2,879.0 2,879.0 2/11/2025 05:00 2/11/2025 06:30 1.50 COMPZN, RPCOMP SFTY P Perform post jarring derrick inspection. Crew C/O. 2,879.0 2,879.0 2/11/2025 06:30 2/11/2025 07:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #6 (Spear) 2,879.0 226.0 2/11/2025 07:30 2/11/2025 08:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #6 226.0 0.0 2/11/2025 08:00 2/11/2025 08:45 0.75 COMPZN, RPCOMP BHAH P PU BHA #7 (MSC) 0.0 103.0 2/11/2025 08:45 2/11/2025 09:45 1.00 COMPZN, RPCOMP TRIP P TIH to top of fish @ 2,879'. PUW = 71K. SOW = 62K. Access 5 1/2" stub. 103.0 2,879.0 2/11/2025 09:45 2/11/2025 10:45 1.00 COMPZN, RPCOMP CPBO P Cont. TIH. Calculated collar @ 2,890'. Obtain parameters. Free Torque = 1.5K @ 100 RPM. Bring pumps online @ 1 BPM / 213 psi. Set down 5K @ 2,896'. Unable to make it to 2,897'. Confirm clear of collars. Cut 5 1/2" CSG @ 2893'. Rot @ 100 RPM. Circ @ 2.0 BPM, 983 PSI. 1.7-2.7K torque during cut. Set down 5K on cut. All indications of a good cut. Torque fell off to 1.7K. 2,879.0 2,893.0 2/11/2025 10:45 2/11/2025 11:45 1.00 COMPZN, RPCOMP CIRC P Circ BU. 2 BPM @ 990 psi. SD Pumps. OWFF. 2,893.0 2,893.0 2/11/2025 11:45 2/11/2025 13:15 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #7 (MSC). 2,893.0 103.0 2/11/2025 13:15 2/11/2025 13:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #7. Inspect blades. 103.0 0.0 2/11/2025 13:45 2/11/2025 14:15 0.50 COMPZN, RPCOMP BHAH P MU BHA #8 (Spear w/o pack-off) 0.0 226.0 2/11/2025 14:15 2/11/2025 15:30 1.25 COMPZN, RPCOMP TRIP P TIH w/ spear to just above SC shoe @ 2,811'. Obtain parameters. PUW = 70K. SOW = 65K. 226.0 2,811.0 2/11/2025 15:30 2/11/2025 15:45 0.25 COMPZN, RPCOMP FISH P Wash down to fish top @ 1 BPM / 60 psi. Found top of 5 1/2" stub @ 2,879'. Cont. to 2,888' and fully no-go spear in fish. Set down 20K to confirm. PU 120K (50K over) to bleed off jars. Straight pull to 180K over (250K total). Fish came free. 2,811.0 2,888.0 2/11/2025 15:45 2/11/2025 16:00 0.25 COMPZN, RPCOMP OWFF P OWFF. 2,888.0 2,888.0 2/11/2025 16:00 2/11/2025 16:30 0.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #8 (Spear). 2,888.0 226.0 2/11/2025 16:30 2/11/2025 17:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #8 (Spear). Fish on the bank. Fish Length = 13.10'. 226.0 0.0 2/11/2025 17:30 2/11/2025 18:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #9 (Spear) 0.0 226.0 2/11/2025 18:00 2/11/2025 19:45 1.75 COMPZN, RPCOMP TRIP P TIH w/ spear to just above SC shoe @ x,xxx'. Obtain parameters. PUW = 70K. SOW = 68K. 226.0 2,982.0 2/11/2025 19:45 2/11/2025 20:30 0.75 COMPZN, RPCOMP FISH P Screw in TD. Wash down to top of fish @ 2,893' // Pump off attempt to engage fish, stack out @ 2,894' // Pump 2.5 bpm @ 270 psi wash into fish T/ 2,897' // Fish engaged Jar on fish. Hit 5 jar licks @ 100K over. Straight pull to 290K over (360K total) 2 times fish free . 2,982.0 2,980.0 2/11/2025 20:30 2/11/2025 21:15 0.75 COMPZN, RPCOMP CIRC P Circulate SxS @ 4 bpm 320 psi // OWFF blow down TD 2,980.0 2,980.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 6/8 2P-422 Report Printed: 3/10/2025 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) 2/11/2025 21:15 2/11/2025 22:45 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #9 (Spear). 2,880.0 226.0 2/11/2025 22:45 2/11/2025 23:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #9 (Spear). Fish on the bank. Fish Length = 24.70'. 226.0 0.0 2/11/2025 23:30 2/12/2025 00:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor for running 3.5" tubing 0.0 0.0 2/12/2025 00:00 2/12/2025 01:00 1.00 COMPZN, RPCOMP RURD P Prep floor to run 3 1/2" EUE tubing. 0.0 0.0 2/12/2025 01:00 2/12/2025 04:30 3.50 COMPZN, RPCOMP PUTB P Run 3 1/2" EUE cement string to 2,910'. Tag plug @ 2,915' Space out @ 2,910' 0.0 2,910.0 2/12/2025 04:30 2/12/2025 06:00 1.50 COMPZN, RPCOMP CIRC P Rig up head pin to cement hose, circulate while rigging up HAL. Finish RU HAL cementers. 2,910.0 2,910.0 2/12/2025 06:00 2/12/2025 08:30 2.50 COMPZN, RPCOMP CMNT P PJSM. Flood lines. Batch mix 30 bbls of cement. Cement wet @ 07:12. Flood lines. PT lines to 3,000 psi. Line up to pump cement job. Pump 22.3 bbls of 10# spacer ahead. Load 4" foam ball ahead. Pump 28 bbls of cement @ 2 BPM / 130 psi. SD pumps. Close UPR. Close isolation valve. RD head pin. Load 4" foam ball behind. Open UPR. Pump 5.7 bbls of 10# spacer behind. Displace with 12 bbls of 9.8# brine. Check vac at bleeder. On slight vac. Good displacement. RD cement manifold at rig floor. 2,910.0 2,910.0 2/12/2025 08:30 2/12/2025 09:30 1.00 COMPZN, RPCOMP TRIP P L/D Joint #93, pup joint, Joint #92, and Joint #91. Rack back 4 stands (#30-27). On Joint #77 set in slips @ 2,400'. 2,910.0 2,400.0 2/12/2025 09:30 2/12/2025 10:15 0.75 COMPZN, RPCOMP CIRC P RU head pin and circ hose. Circ out well with 9.8# brine until see clean 9.8# returns from OA. 3 BPM @ 106 psi. Spacer @ shakers @ 900 (52 bbls) strokes pumped. Swap to take OA returns to cutting tank. See cement returns @ 1400 strokes (81 bbls. Cleaned up @ 1550 strokes. Est. 8 bbls of cement returns. 2,400.0 2,400.0 2/12/2025 10:15 2/12/2025 10:30 0.25 COMPZN, RPCOMP TRIP P Rack back 2 stand of DP to position 3 1/2" tubing tail approx. 200' above TOC. 2,400.0 2,250.0 2/12/2025 10:30 2/12/2025 11:00 0.50 COMPZN, RPCOMP CIRC P Circ tubing volume @ 2 BPM. Kick out more dirty fluid until returns cleaned up. SD Pumps. 2,250.0 2,250.0 2/12/2025 11:00 2/13/2025 00:00 13.00 COMPZN, RPCOMP WOC P WOC for 500 psi compressive strength. 500 psi C.S @ 20 hours + 3 hr safety. If weather allows, plan for state witnessed Tag/Test @ 10:30 AM on 2/13. 2,250.0 2,250.0 2/13/2025 00:00 2/13/2025 10:30 10.50 COMPZN, RPCOMP WOC P WOC for 500 psi compressive strength. 500 psi C.S @ 20 hours + 3 hr safety. If weather allows, plan for state witnessed Tag/Test @ 10:30 AM on 2/13. Give AOGCC State Inspector (Josh Hunt) an update. Phase 1 conditions @ 05:00AM. Check refrigerated cement sample for hardness. 2,250.0 2,250.0 2/13/2025 10:30 2/13/2025 19:00 8.50 COMPZN, RPCOMP WAIT T Wait on Weather. Phase 2 called @ 07:00AM. State Inspector in Deadhorse. Cannot travel in Phase 2 conditions. 2,250.0 2,250.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 7/8 2P-422 Report Printed: 3/10/2025 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) 2/13/2025 19:00 2/13/2025 20:30 1.50 COMPZN, RPCOMP WASH P Screw in TD. Bring pumps online. PU singles and wash down (4 BPM / 40 psi) to clear contaminated cement. TOC tag @ 2,408' (2,133' TVD). Surface casing shoe = 2,858' TVD. TOC is approx. 450' inside surface casing shoe. Set 10K down. Mark pipe. Confirm Tag Depth with Tally. 2,250.0 2,408.0 2/13/2025 20:30 2/13/2025 21:30 1.00 COMPZN, RPCOMP CIRC P PUH 5' off tag. Pump 30 bbls hi-vis sweep. Chased out with 9.8# brine until clean. PumpedSxS @ 4 BPM / 150 psi. 2,400.0 2,400.0 2/13/2025 21:30 2/13/2025 22:00 0.50 COMPZN, RPCOMP RURD P Space out if needed to leave 4-5' of 3 1/2" EUE stickup at rig floor. RU pressure testing equipment (plug valves w/ double block, Tee w/ sensator, circ hose). 2,400.0 2,400.0 2/13/2025 22:00 2/13/2025 23:30 1.50 COMPZN, RPCOMP PRTS P Pressure test cement plug to 1,000 psi for 10-min. Bring pressure up to 1,500 psi for 30-min PT. Chart. Test fail // Pick up hanger and land to eliminate surface equipment, re-test test fail 2,400.0 2,400.0 2/13/2025 23:30 2/14/2025 00:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. KU TD. 2,400.0 2,400.0 2/14/2025 00:00 2/14/2025 02:15 2.25 COMPZN, RPCOMP PULL P Pull and lay down 3.5" Tubing 2,400.0 0.0 2/14/2025 02:15 2/14/2025 06:15 4.00 COMPZN, RPCOMP WAIT P Phase 2 conditions. Wait for YJ fishing hand to be escorted to rig from Deadhorse. // Load 5.5" casing into pipe shed for kill string 0.0 0.0 2/14/2025 06:15 2/14/2025 08:15 2.00 COMPZN, RPCOMP BHAH P Load Yellow Jacket tools. MU BHA #10 (Scraper/Test Packer Drift) 0.0 7.0 2/14/2025 08:15 2/14/2025 10:00 1.75 COMPZN, RPCOMP TRIP P TIH w/ BHA #10 and clear potential cement stringers down to TOC @ 2,408'. 7.0 2,408.0 2/14/2025 10:00 2/14/2025 11:30 1.50 COMPZN, RPCOMP CIRC P PU off TOC tag to 2,402'. Circ BU at high rate to clear green cement/debris from 7 5/8" casing. 5 BPM / 432 psi. 2,408.0 2,402.0 2/14/2025 11:30 2/14/2025 12:00 0.50 COMPZN, RPCOMP OWFF P OWFF 2,402.0 2,402.0 2/14/2025 12:00 2/14/2025 13:30 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #10 (Scraper/Drift) 2,402.0 7.0 2/14/2025 13:30 2/14/2025 14:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #10. 7.0 0.0 2/14/2025 14:00 2/14/2025 14:15 0.25 COMPZN, RPCOMP BHAH P MU BHA #11 (7 5/8" Test Packer) 0.0 15.0 2/14/2025 14:15 2/14/2025 16:00 1.75 COMPZN, RPCOMP TRIP P TIH to TOC @ 2,408'. Fix top drive lube oil error. PUH and set Test Packer @ 2,354'. 15.0 2,354.0 2/14/2025 16:00 2/14/2025 16:30 0.50 COMPZN, RPCOMP RURD P RU testing equipment w/ isolation valves and sensator. RU sensator to IA. 2,354.0 2,354.0 2/14/2025 16:30 2/14/2025 18:15 1.75 COMPZN, RPCOMP PRTS P PT 7 5/8" Casing to 1,500 psi. Bleed casing pressure to 500 psi. Keep needle down to monitor casing pressure during cement plug test. Chart. PT cement plug to 1,500 psi through DP. Chart. // Casing pass to 2360' cement fail pressure test 2,354.0 2,354.0 2/14/2025 18:15 2/14/2025 20:15 2.00 COMPZN, RPCOMP TRIP P TOOH to lay down test packer 2,354.0 0.0 2/14/2025 20:15 2/14/2025 21:15 1.00 COMPZN, RPCOMP RURD P Rig up to run 5.5" Kill string 0.0 0.0 2/14/2025 21:15 2/15/2025 00:00 2.75 COMPZN, RPCOMP PUTB P Pick up and run 5.5" BTC casing w/ Mule shoe T/ 2300' // Mule shoe length 41.57' w/ 52 jts 5.5" casing 0.0 2,300.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 Page 8/8 2P-422 Report Printed: 3/10/2025 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) 2/15/2025 00:00 2/15/2025 01:00 1.00 COMPZN, RPCOMP THGR P Pick up and land 5.5" casing hanger and packoff // Test packoff 3000 for 10 min good test 0.0 0.0 2/15/2025 01:00 2/15/2025 02:00 1.00 COMPZN, RPCOMP FRZP P Rig up LRS, PT lines // Pump 9 bbls LEPD down OA taking returns up casing // Freeze protect OA to 500' 0.0 0.0 2/15/2025 02:00 2/15/2025 03:00 1.00 COMPZN, RPCOMP CLEN P Jet stack // Lay down jetting tool 0.0 0.0 2/15/2025 03:00 2/15/2025 04:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA #2 (WRBP) , Unloader set for 3600# (2 screws), Release set for 7600# (3 screws). 0.0 13.5 2/15/2025 04:00 2/15/2025 05:45 1.75 COMPZN, RPCOMP TRIP P RIH w/ WRBP on 2-7/8" HT-Pac DP to set depth of 1,605' (COE). PUW = 45K. SOW = 45K. 13.5 1,608.0 2/15/2025 05:45 2/15/2025 06:15 0.50 COMPZN, RPCOMP MPSP P Drop ball. Set WRBP @ 1,605' COE (Top @ 1,630.5'). See 1st shear @ 1,600 psi. Hold 1900 psi for 5-min. Press. up to shear off @ 2,900 psi. 1,608.0 1,608.0 2/15/2025 06:15 2/15/2025 06:30 0.25 COMPZN, RPCOMP RURD P PUH to 1,583'. L/D single. BD Top Drive. RU PT equipment w/ sensator on 2 7/8" DP. Fluid pack. Close UPR. 1,608.0 1,583.0 2/15/2025 06:30 2/15/2025 07:00 0.50 COMPZN, RPCOMP PRTS P PT WRBP to 1500 psi for 10-min. 19 strokes to pressure up. Charted. 1,583.0 1,583.0 2/15/2025 07:00 2/15/2025 08:30 1.50 COMPZN, RPCOMP RURD P RD testing equipment. Fix leak on Eckels. 1,583.0 1,583.0 2/15/2025 08:30 2/15/2025 10:30 2.00 COMPZN, RPCOMP PULD P TOOH DRY L/D 2 7/8" DP. 1,583.0 135.0 2/15/2025 10:30 2/15/2025 11:00 0.50 COMPZN, RPCOMP BHAH P L/D WRBP setting tools. 13.5 0.0 2/15/2025 11:00 2/15/2025 14:00 3.00 COMPZN, RPCOMP PULD P L/D remaning 2 7/8" DP in derrick. 0.0 0.0 2/15/2025 14:00 2/15/2025 14:45 0.75 COMPZN, RPCOMP FRZP P RU test pump to IA. Top Fill 5 1/2" casing with 6 bbls of diesel FP. R/D test pump. 0.0 0.0 2/15/2025 14:45 2/15/2025 22:45 8.00 COMPZN, WHDBOP NUND P Drain stack. Open BOP rams and inspect. Clean out green cement/debris from ram cavities. ND BOP. NU 7 1/16" Dry Hole Tree with 7 1/16" x 11" DSA and Otis tree cap. RU bleed manifold on tree cap. RU test pump to IA. Fluid pack tree with diesel. Start offloading fluids from pits. 0.0 0.0 2/15/2025 22:45 2/15/2025 23:00 0.25 COMPZN, WHDBOP PRTS P PT dry hole tree with test pump to 2,500 psi for 10-min. 0.0 0.0 2/15/2025 23:00 2/16/2025 00:00 1.00 DEMOB, MOVE RURD P RD test pump. RD cellar hardline and hoses. Clean and clear cellar. Obtain final pressures. Rig Release @ 00:00 on 2/16/25. Prep for move to 2P-419. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 2/16/2025 DTTMSTART JOBTYP SUMMARYOPS 2/8/2025 RECOMPLETION Warm up moving system hydraulics. Prep rig to back off well. Back off 2P- 424. Stage rig. Clean up pad. Kick out old tree. Lay pit liner and T-mats. Pull sub over well. Shim & berm in rig. MIRU. Spot auxiliary equipment. Gather initial RKB's and pressures. Complete rig acceptance check list. Accept rig @ 04:30. Take on 9.8# NaCl to pits. RU and PT hardline. Kill well w/ 120 Bbls of 9.8 PPG brine. OWFF - 30 Min no flow. N/D tree & adaptor. Hang tree in cellar. Function LDS, inspect hanger neck threads. Install H BPV & test dart. N/U BOP. Shell test. Perform initial BOP test to 250/2500 psi (witnessed by Guy Cook). R/D testing equipment. Drain stack. Pull BPV w/ test dart. 2/9/2025 RECOMPLETION MU landing joint. Screw in TD. Set 10K down. BOLDS. Pull Tbg hanger to rig floor @ 58K. Circ BU. L/D landing joint and hanger. OWFF. Pull 3 1/2" Tbg from pre-rig cut @ 3,152'. Cut Joint = 27.70'. Good Jet Cut. Prep rig floor to run 2 7/8" DP. MU BHA #1 (5 1/2" CIBP). TIH w/ CIBP and set @ 2,920' (top). Tag top set 5k down. POOH, L/D BHA #1. M/U BHA #2 MSC. RIH T/ 2910. Wash in hole T/ plug top no collars. Cut CSG @ 2915'. No PSI wrap around to OA. Attempt to circ, pressure up T/ 300 PSI no fluid movement on OA. POOH T/ 2830'. Wash in hole locate collar @ 2848'. P/U T/ 2845' cut 5 1/2" CSG. 180 PSI wrap around on OA. Pull T/ 2830'. Circ 87 Bbls hot deep clean pill around out OA. OWFF. Safety stand up. OA = 20 psi. Close blinds. Circ out OA to balance well. OWFF. MU pack- off retrieval tool. BOLDS. Pull pack-off. MU landing joint. Pull 5 1/2" hanger to rig floor. Unseat @ 90K. Drag to floor @ 83K. Circ BU. OWFF. Pull 5 1/2" casing F/ cut @ 2,845' T/ midnight depth of 2,047'. 2/10/2025 RECOMPLETION Finish pulling 5 1/2" casing. Cut Joint = 41.63' long. Good cut. Clean and clear rig floor. C/O pipe handling equipment to 3 1/2". Load Yellow Jacket tools. MU BHA #3 (5 1/2" spear). TIH and engage fish top T/ 2853''. Confirm engaged. Work jar hits up T/ 100K over. Stage straight pull up T/ 325K over. Hit jars total of 50 times. No pipe movement. Release from fish. Perform post jarring derrick inspection. POOH, L/D BHA #4. M/U BHA #4 MSC. RIH T/ 2875'. Cut 5 1/2" @ 2879'. Circ BU. POOH, L/D BHA #4. M/U BHA #5 spear. RIH engage fish top T/ 2853'. Bleed jars. Straight pull, pipe free @ 170K. over. Circ BU. POOH, L/D BHA #5 and 31' fish. MU BHA #6 (Spear w/o pack-off). 2P-422A Rig Suspend Summary of Operations 2/11/2025 RECOMPLETION TIH w/ spear and engage fish @ 2,879'. Warm up jars. Hit 50K licks @ max 100K over, with straight pulls to 325K over (250K max). Perform derrick inspection. Continue jarring. Hit additional 50K licks @ 100K over, with straight pulls to 290K over. No movement. Release from fish. PU into cased hole. Circ BU. Perform derrick inspection. TOOH and L/D BHA #6 (spear). MU BHA #7 (MSC). TIH and cut 5 1/2" casing @ 2,893'. Circ BU. TOOH and L/D BHA #6 (MSC). Inspect blades. MU BHA #7 (Spear w/o pack-off). TIH. See top of fish @ 2,879'. Fully no-go spear @ 2,888'. Set 20K down. PU to bleed off jars. Pull to 180K over (250K total). Fish came free. OWFF. TOOH and L/D spear and 13.10' long fish. MU BHA #9 (Spear). TIH and engage fish @ 2,893', wash down to 2,897', ensure grapple worked into pipe, Jar 5 times 100k over, straight pull 290K over 2 times fish pull free, move up hole 40K over for 20' then free pick up, circulate SxS, OWFF, TOOH lay down BHA# 9 and xx.xx' fish, clean and clear rig floor for running 3.5" 2/12/2025 RECOMPLETION Prep floor to run 3 1/2" EUE tubing. Run 3 1/2" EUE cement string to 2,910'. Space out. RU HAL cementers and cement manifold at rig floor. Blow air through hardline and PT. Batch up cement. Cement wet @ 07:12. Pump cement plug as per HAL pump schedule. Displace with 12 bbls of 9.8# brine. Check vac. On slight vac. RD circ equipment. Pull tubing to 2,400'. Cement in place @ 09:20. RU head pin and circ hose. Circulate 9.8# brine until clean. Est. 8 bbls of cement returns. SD pumps. RD circ equipment. Rack back 2 stands of 3 1/2" Tubing to appox. 200' above TOC. Circ BU. WOC for 500 psi C.S (min 24 hours). 2/13/2025 RECOMPLETION WOC for 500 psi C.S (24 hours, approx. 10:30AM). Phase 2 called @ 07:00AM. Wait on Weather. AOGCC Inspector cannot travel from Deadhorse in Phase 2. Inspector on location 19:00 wash in hole tag TOC @ 2,408 15K WOB, space out circulate hole clean and get air out of system, rig up test equipment PT cement 1500 psi Fail, land hanger PT cement eliminate surface equipment 1500 psi Fail, blow down test equipment 2/14/2025 RECOMPLETION Pull and lay down 3.5" tubing. Wait on Yellow Jacket rep. Convoy due to Phase 2 conditions. MU BHA #10 (Scraper/Drift). TIH and drift for 7 5/8" test packer to TOC @ 2,408. Circ BU at 5 BPM / 432 psi. OWFF. TOOH and L/D BHA #10. MU BHA #11 (Test Packer). TIH and set test packer @ 2,354'. PT 7 5/8" casing to 1,500 psi. Chart. PT cement plug to 1,500 psi. Chart. PT Fail, pull test packer and lay down, pick up and run 52 jts 5.5" BTC casing kill string w/ 41.57' 5.5" casing mule shoe 2/15/2025 RECOMPLETION Land 5.5" hanger and packoff, Freeze protect OA w/ 9 bbls LEPD down to 500', pick up stack flushing tool, flush BOPs, Pick up WRBP, RIH on 2-7/8" DP. Set WRBP @ 1,605'. PT to 1,500 psi for 10-min. RU testing equipment. TOOH dry L/D 2 7/8" DP. L/D WRBP setting tool. L/D remaining 2 7/8" pipe in derrick. Top fill 5 1/2" with Diesel FP to 250' (6 bbls). Open up BOP rams. Clean out cement from cavities. ND BOP. NU Dry Hole Tree. PT tree to 2,500 psi for 10-min w/ test pump. RD test pump and cellar hoses/hardline. Obtain final pressures. Clean and clear cellar. Rig Release @ 00:00 2/16/25. Prep to move rig to 2P-419. 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: 26.90 ft RKB Total Depth: 7,310 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 7-5/8" O.D. Shoe@ 2858 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5-1/2x3-1/2" O.D. Shoe@ 7280 Feet Csg Cut@ 2915 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole Bridge plug 2960 ft 2408 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Final Attempt Tubing IA 1720 OA Remarks: Attachments: Got a break in the weather so traveled to location and met with Chase Erdman (CPAI). They had earlier run in the hole and got a good plug tag. I had them tag again and witnessed a solid tag at 2408 ft MD with 15K lbs on the plug. They next circulated the well and rigged up for a MIT. The first attempt started at 1720 psi and immeditaly bled down over 400 psi in roughly 8 minutes (FAIL). The 2nd attempt was better but still failed in under 10 minutes. Chase suggested putting the hanger on the tubing and setting the hanger, then testing against it to eliminate the BOP stack and lines. This helped but the test still failed by dropping below the 1500 psi in under 15 minutes with no apppearance of decreasing pressure loss. CPAI's plan is to run in with a test packer and attempt another test or locate the casing leak above the plug. February 14, 2025 Josh Hunt Well Bore Plug & Abandonment KRU 2P-422A ConocoPhillips Alaska Inc. PTD 2020670; Sundry 324-678 Test chart Test Data: F Casing Removal: Chase Erdman Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0214_Plug Verification_KRU_2P-422A_jh 9 9 99 99 9 9 9 9 9 9 9 999 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.03.26 14:57:47 -08'00' Plug Verification – KRU 2P-422A (PTD 2020670) Test Chart – 2/14/2025 &KDUWVKRZVVWDUWLQJSUHVVXUHDWSVL,QVSHFWRUUHSRUWHGSVL IURPUHDGLQJWHVWJDXJH7KHUHDVRQIRUWKHGLVFUHSDQF\EHWZHHQFKDUW UHFRUGHUDQGJDXJHLVXQFOHDUEXWGRHVQRWFKDQJHWKHIDFWWKDWSUHVVXUH WHVWVIDLO-5HJJ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U MELT 2P-422A JBR 03/19/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2 7/8" and 5.5" test joints used for testing. The third rams were 7" and they didn't test them as they planned on testing them at another time, before they ran 7" casing. BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold. Test Results TEST DATA Rig Rep:A. Hansen/N. WoodsOperator:ConocoPhillips Alaska, Inc.Operator Rep:K. Barr/Tyson Wiese Rig Owner/Rig No.:Nordic 3 PTD#:2020670 DATE:2/8/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC250209072200 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 901 Sundry No: 324-678 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 3 P Inside BOP 2 P FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5.5" V P #2 Rams 1 Blinds P #3 Rams 1 7" Solids NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 2 2 1/16" 5000 P System Pressure P3000 Pressure After Closure P1750 200 PSI Attained P22 Full Pressure Attained P106 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@1950 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P5 #2 Rams P5 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9999 9 9 9 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): 7310'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. 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 1/5/2025 3-1/2" Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2823' 6785-6903' 7254' 5528-5630' 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 120' 2858' 5958'7280' 16" 7-5/8" 85' 6401' MD MD 120' 2388' 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 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6399' MD and 5196' 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 CTD/RWO Engineer KRU 2P-422A 5984' 4759' 3799' 4759', 6646', 6759' 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): 901 By Grace Christianson at 3:44 pm, Dec 02, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.12.02 15:02:23-09'00' Foxit PDF Editor Version: 13.0.0 324-678 SFD 12/5/2024 DSR-12/16/24 AOGCC Witnessed BOP and Annular Test to 2500 psi. AOGCC Witnessed tag and PT TOC. See attached "Conditions of Approval" June 30, 2025 X X JJL 12/23/24 X 10-407 MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.23 13:57:04 -09'00'12/23/24 RBDMS JSB 122424 KRU 2P-422A Abandonment Conditions of Approval: 1. A variance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata. 2. A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. The plug must pass a State Witnessed pressure test and tag according to 20 AAC 25.112(g). 3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. 4. A failed pressure test of the surface casing shoe plug requires the submission of a new sundry (10-403) to cover the rigless abandonment scope if planned. Completion of workover operations under the original sundry will be complete and a 10-407 Well Completion or Recompletion Report and Log ϐ Commission within 30 days following the completion of workover operations. 5. If surface abandonment operations are not initiated within 30 days after the successful placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407 Well Completion or ϐ 30 days after the completion of workover operations to date. 6. Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. 7. AOGCC witness is required after the wellhead cutoff and prior to a top job. ϐ 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 8/10/2020 = 1071 psi @ 5515’ TVD x MASP = 520 psi C-80 Formation: x OAP = 410 psi (11/24/22) (diesel fluid level at 384’ TVD) x MASP = 901 psi Intermediate plug TOC = 4759’ MD Tubing cut depth = 3152’ MD Well Name Previous plug tag depth (RKB)PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-422A 4759' Pass 9/15/2024 0 psi 0 psi 675 psi 9/21/2024 Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A Well Suspension Schematic Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &DdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂŵĐŽ^EŝƉƉůĞ ϱϭϭ͘ϱΖ ϯ ĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞϲ͕ϯϰϰ͘ϰΖ ϰ ĂŵĐŽEŝƉƉůĞ ϲ͕ϯϲϬ͘ϰΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϲ͕ϯϵϴ͘ϴΖ ϲ ĂŬĞƌ',ͲϮϮ^ĞĂůƐƐĞŵďůǇ ϲ͕ϯϵϵ͘ϱΖ C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6720' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Surface Casing Plugs – Rig Date: 12-2-2024 Prepared by: Shane Germann Estimated Start Date: 1-5-2025 MIRU 1. MIRU on 2P-422A. 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 16 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 5-1/2” casing is 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 b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư- rig remediation. Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A Well Surface Shoe Cement Schematic Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϵϲϬΖ ϯ ĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞ ϲ͕ϯϰϰ͘ϰΖ ϰ ĂŵĐŽEŝƉƉůĞ ϲ͕ϯϲϬ͘ϰΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϲ͕ϯϵϴ͘ϴΖ ϲ ĂŬĞƌ',ͲϮϮ^ĞĂůƐƐĞŵďůǇ ϲ͕ϯϵϵ͘ϱΖ C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6720' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Plug #3 – Surface Shoe TOC 2597' RKB (2238' TVD) BOC @ ±2960' RKB Base of 5.5” Casing 300'-350' MD Inside Surface Shoe Execute Final Abandonment Plug 8. Land workstring in casing hanger proƱle. 9. Circulate cement surface to surface until full cement returns observed on surface. See table below for cement volumes. RDMO 10. ND BOPE. NU dry hole tree. a. Note: this step may be performed prior to pumping Ʊnal surface to surface abandonment plug. 11. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 2907 2957 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing Stub Included in BBL/FT calc 2857 2907 Open Hole 6.75 0.04426 2.2 2597 2857 Surface Casing 6.87 0.04585 11.9 16.0 Total Volume of Plug Surface Casing 23 2597 Surface Casing 6.87 0.04026 103.6 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-422A c. PTD #: 202-067 d. API #: 50-103-20400-01-00 21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground level. 22. Obtain site clearance approval from AOGCC. RDMO. 23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location condition after work is completed Plug #4 – Surface TOC 25' RKB BOC @ ±2597' RKB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 2P-422A Well Final P&A Schematic Conductor: 16" Conductor 120' KB 1 2 3 5 4Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB (2388' TVD) Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϵϲϬΖ ϯ ĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞ ϲ͕ϯϰϰ͘ϰΖ ϰ ĂŵĐŽEŝƉƉůĞ ϲ͕ϯϲϬ͘ϰΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϲ͕ϯϵϴ͘ϴΖ ϲ ĂŬĞƌ',ͲϮϮ^ĞĂůƐƐĞŵďůǇ ϲ͕ϯϵϵ͘ϱΖ C80 @ 3000' KB C80 @ 3000' KB Plug #1 – Reservoir TOC ±6720' RKB Plug #2 – Intermediate TOC ±4759' RKB BOC @ ±6330' RKB Plug #3 – Surface Shoe TOC 2597' RKB (2238' TVD) BOC @ ±2960' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,759.0 2P-422A 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-422A 9/21/2024 bworthi1 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 25.6 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.6 25.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.5 511.0 5.08 SAFETY VLV 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,047.8 1,911.9 45.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.6 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.8 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,047.8 1,911.9 45.13 1 GAS LIFT SOV INT 1 0.0 7/31/2024 2K, CSG to TBG 0.000 3,972.4 3,153.8 38.91 2 GAS LIFT DMY INT 1 0.0 7/29/2024 0.000 5,021.3 4,020.8 33.07 3 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 5,779.8 4,673.6 31.59 4 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 6,294.6 5,106.5 32.05 5 GAS LIFT DMY INT 1 0.0 6/13/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2P-422A, 12/2/2024 2:52:58 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 25.6-7,279.9 FRAC; 6,872.0 IPERF; 6,872.0-6,882.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 SURFACE; 34.7-2,857.8 GAS LIFT; 2,047.8 SAFETY VLV; 511.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE ϮWͲϰϮϮϭϯĂůĐƵůĂƚĞĚWdKΛϯϲϱϬ͛Z<^^ŚŽĞΛϮϴϱϳ͛Z</WΛϮϵϲϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϱϵϳ͛Z<WƵƚΛϮϵϬϳ͛Z<ϴϬdŽƉΛϯϬϬϬ͛Z<ϴϬĂƐĞΛϰϯϱϬ͛Z< CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Germann, Shane To:Davies, Stephen F (OGC) Cc:Loepp, Victoria T (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]KRU 2P-422A (Permit 202-067, Sundry 324-678) - Questions Date:Wednesday, December 4, 2024 8:06:47 AM Attachments:image001.png image002.png Hi Steve, It looks like the previous sundries had the C80 depth of 3140’ RKB listed in error (perhaps it was mistakenly carried over from the 424A). 3000’ RKB is the correct depth for top of C80 in 2P-422A. Proposed program in the sundry will remain the same. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 560, Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, December 3, 2024 8:21 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]KRU 2P-422A (Permit 202-067, Sundry 324-678) - Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Shane, I'm reviewing CPAI’s Sundry Application to abandon well KRU 2P-422A (PTD 202-067, Sundry 324-678) and I have a question. In this Sundry Application, the top of C80 is shown as 3000’ KB: but in CPAI’s two recent Sundry Applications for this same well (323-449 and 324-394), the C80 top is shown as 3140’ KB. Can you please discuss this 140-foot depth change and the impact it will have on CPAI’s planned abandonment program for this well? If significant changes to the proposed program are necessary, please provide a revised Sundry Application. Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 120' 7.625" L-80 2388' 5.5" L-80 5214' 3.5" L-80 5958' 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 6421' SIZE DEPTH SET (MD) 7280' 26' 5214' 62.5# 29.7# 120' 26' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 4759' (SW TOC) -6334' MD 31 bbls 15.8 ppg Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 6785-6903' MD and 5528-5630' TVD (below cement plug) 6872-6882' MD and 5603-5612' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 24" 9.875" 45 sx AS I 35'316 bbls AS3 Lite, 81 bbls LiteCrete 9.3# 35' 6421' 2858'35' 35' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 4/19/2002 CEMENTING RECORD 5865711 1495' MD/ 1458' TVD SETTING DEPTH TVD 5865507 TOP HOLE SIZE AMOUNT PULLED 445331 445364 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 512'MD/ 511' TVD 50-103-20400-01-00 KRU 2P-422A ADL 373112, ADL0389058 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM 921' FSL, 1855' FEL, Sec. 17, T8N, R7E, UM ALK 4/13/2002 7310' MD/ 5984' TVD 4759' MD/ 3799' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444049 5868975 1124' FSL, 1895' FEL, Sec. 17, T8N, R7E, UM 9. Ref Elevations: KB: 27' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 9/21/2024 202-067/324-394 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above6.75" TUBING RECORD 325 sx Class G6.75" 6401' MD3-1/2" CASING 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 9/21/2024 JSB RBDMS JSB 100924 xGDSR-10/14/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.10.02 13:43:44-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 4,759.0 2P-422A 9/15/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-422A 9/21/2024 bworthi1 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 25.6 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.6 25.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.5 511.0 5.08 SAFETY VLV 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,047.8 1,911.9 45.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.6 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.8 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,152.0 2,574.1 48.38 CUT JET CUT AT 3152' RKB 9/21/2024 2.992 6,330.0 5,136.6 31.69 TUBING PUNCH TUBING PUNCH, 4.5FT, 6 SPF, 0 DEGREE PHASE. 8/7/2024 2.992 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,047.8 1,911.9 45.13 1 GAS LIFT SOV INT 1 0.0 7/31/2024 2K, CSG to TBG 0.000 3,972.4 3,153.8 38.91 2 GAS LIFT DMY INT 1 0.0 7/29/2024 0.000 5,021.3 4,020.8 33.07 3 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 5,779.8 4,673.6 31.59 4 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 6,294.6 5,106.5 32.05 5 GAS LIFT DMY INT 1 0.0 6/13/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 4,759.0 6,334.5 3,799.0 5,140.5 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT (Tagged TOC @ 4759' SLM) 9/7/2024 2P-422A, 10/2/2024 9:34:20 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 25.6-7,279.9 FRAC; 6,872.0 IPERF; 6,872.0-6,882.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB TUBING PUNCH; 6,330.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 Cement Plug; 4,759.0 ftKB GAS LIFT; 3,972.4 CUT; 3,152.0 SURFACE; 34.7-2,857.8 GAS LIFT; 2,047.8 SAFETY VLV; 511.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 8/7/2024 CHANGE WELL TYPE RAN TUBING PUNCH. PUNCH INTERVAL: 6330' - 6334.5' WITH 4.5', 18 SHOT TUBING PUNCHES. PRESSURED UP TUBING TO CONFIRM GOOD COMMUNICATION. READY FOR INTERMEDIATE CEMENT PLUG. 8/29/2024 CHANGE WELL TYPE (P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASSED) T PPPOT (PASSED), FUNCTION TEST ALL IC LDS/GNS (COMPLETE), IC POT (PASSED) IC PPPOT (PASSED), 9/7/2024 SUPPORT OTHER OPERATIONS PUMP INTERMEDIATE BALANCED CEMENT PLUG.PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT & DISPLACED CEMENT w/41 BBLS OF 9.8 PPG. PLACING TOC IN TBG & IA @ ~4830' MD. 9/10/2024 SUPPORT OTHER OPERATIONS ATTEMPT TO SHEAR SOV. FREEZE PROTECT TxIA.PUMPED 50 BBL DSL INTO IA TAKING RETURNS UP TBG TO OPEN TANK. (SEE LOG) JOB COMPLETE 9/15/2024 SUPPORT OTHER OPERATIONS *** STATE WITNESSED (SEAN SULLIVAN)*** TAGGED TOC @ 4759' SLM, OBTAINED PASSING CMIT TO 1500 PSI. READY FOR TUBING CUT 9/21/2024 SUPPORT OTHER OPERATIONS CUT 3.5" TUBING AT 3152' RKB WITH 2.5" JET CUTTER. JOB COMPLETE, READY FOR RIG 2P-422A Intermediate Suspend Summary of Operations ORIGINAL TRANSMITTAL DATE: 9/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5076 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 5076 2P-422A 50103204000100 Tubing Cut Record 21-Sep-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-067 T39584 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.24 10:03:31 -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:7,310 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface:7-5/8"O.D. Shoe@ 2858 Feet Csg Cut@ Feet Intermediate:n/a O.D. Shoe@ n/a Feet Csg Cut@ Feet Production:5-1/2" x 3-1/2"O.D. Shoe@ 7280 Feet Csg Cut@ Feet Liner:n/a O.D. Shoe@ n/a Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 6401 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 6,330 ft 4,759 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result CMIT TxIA Tubing 1900 1825 1800 IA 1790 1720 1690 OA 672 672 672 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Traveled to KRU 2P pad for tag and test of intermediate balanced plug. Tag was good @ 4759ft MD and brought back a good sample in the bailer. Passing CMIT TxIA. September 15, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-422A ConocoPhillips Alaska Inc. PTD 2020670; Sundry 324-394 none Test Data: P Casing Removal: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0915_Plug_Verification_KRU_2P-422A_ss                       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-422A 50-103-2040-01-00 202-067 Kuparuk River WL Puncher FINAL FIELD 7-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 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 120' 7.625" L-80 2388' 5.5" L-80 5214' 3.5" L-80 5958' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above6.75" TUBING RECORD 325 sx Class G6.75" 6401' MD3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/5/2024 202-067/323-449 50-103-20400-01-00 KRU 2P-422A ADL 373112, ADL0389058 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM 921' FSL, 1855' FEL, Sec. 17, T8N, R7E, UM ALK 4/13/2002 7310' MD/ 5984' TVD 6646' MD/ 5408' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444049 5868975 1124' FSL, 1895' FEL, Sec. 17, T8N, R7E, UM 9. Ref Elevations: KB: 27' CASING WT. PER FT.GRADE 4/19/2002 CEMENTING RECORD 5865711 1495' MD/ 1458' TVD SETTING DEPTH TVD 5865507 TOP HOLE SIZE AMOUNT PULLED 445331 445364 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 N/A PACKER SET (MD/TVD) 24" 9.875" 45 sx AS I 35'316 bbls AS3 Lite, 81 bbls LiteCrete 9.3# 35' 6421' 2858'35' 35' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Kuparuk River Field/ Meltwater Oil Pool- Suspended Flow Tubing SUSPENDED 6785-6903' MD and 5528-5630' TVD (below cement plug) 6872-6882' MD and 5603-5612' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 15.5# 7280' 26' 5214' 62.5# 29.7# 120' 26' Sr Res EngSr Pet GeoSr Pet Eng 512'MD/ 511' TVD Oil-Bbl: Water-Bbl: 6646' (SW TOC) -6759' MD 0.26 bbls 15.8 ppg Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 6421' SIZE DEPTH SET (MD) Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 3:54 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 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 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: 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. N/A- Suspended INSTRUCTIONS 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 14:17:52-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,036.0 2P-422A 3/21/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement with SL 2P-422A 6/14/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/19/2010 haggea 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 25.6 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.6 25.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.5 511.0 5.08 SAFETY VLV 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,047.8 1,911.9 45.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.6 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.8 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,047.8 1,911.9 45.13 1 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 3,972.4 3,153.8 38.91 2 GAS LIFT GLV INT 1 1,962.0 11/24/2014 0.156 5,021.3 4,020.8 33.07 3 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 5,779.8 4,673.6 31.59 4 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 6,294.6 5,106.5 32.05 5 GAS LIFT OPEN 1 3/22/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 2P-422A, 7/10/2024 2:04:49 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 25.6-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 GAS LIFT; 3,972.4 SURFACE; 34.7-2,857.8 GAS LIFT; 2,047.8 SAFETY VLV; 511.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 3/21/2024 CHANGE WELL TYPE DRIFT 2.623" DUMMY CIBP TO TD @ 7036' SLM, JOB IN PROGRESS 3/22/2024 CHANGE WELL TYPE SET 2.78" AVA CATCHER IN 2.75" D NIPPLE @ 6360' RKB, PULL O.V FROM STA 5 @ 6294' RKB, PULL 2.78" CATCHER FROM 2.75" D NIPPLE @ 6360' RKB, READY FOR E- LINE 4/1/2024 CHANGE WELL TYPE LOAD TBG & IA WITH SEAWATER AND DIESEL FREEZE PROTECT. SET 3.5" CIBP AT 6760'. CMIT TxIA TO 2500 PSI (PASS) JOB COMPLETE, READY FOR SLICKLINE 6/13/2024 CHANGE WELL TYPE DRIFT W/ 2.5" BAILER 2.64" MULE SHOE BTM. TAGGED CIBP @ 6759' RKB. SET 1" BTM LATCH DMY IN ST#5 @ 6294' RKB.OBTAIN PASSING MIT-T TO 2500#. DUMP BAILED 14' OF CEMENT LAST TAG @ 6745' RKB. LFDN. JOB IN PROGRESS. 6/14/2024 CHANGE WELL TYPE DUMP BAILED 16' OF CEMENT. DRIFTED W/ 2.5" CENT TAGGED CEMENT @ 6694' RKB. LET CURE FOR 72 HOURS, THEN READY FOR SW TAG & TEST. 7/5/2024 CHANGE WELL TYPE TAG TOC @ 6646' SLM. MIT-T PASSED TO 1500 PSI. STATE WITNESSED BY BRIAN BIXBY. READY FOR NEXT CEMENTING PROCEDURE. 2P-422A 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): 7310'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Senior Well Interventions Engineer KRU 2P-422A 5984' 6646' 5408' 6759' 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): 6399' MD and 5196' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst 6401' MD MD 120' 2388' 120' 2858' 5958'7280' 16" 7-5/8" 85' 2823' 6785-6903' 7254' 5528-5630' 5-1/2"x 3-1/2" Perforation Depth TVD (ft): 7/22/2024 3-1/2" Packer: Baker GBH-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 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 15:00:40-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-394 By Grace Christianson at 3:38 pm, Jul 10, 2024 SFD DSR-7/10/24SFD 7/11/2024 Suspend VTL 7/17/2024 X 10-407X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.17 14:25:06 -08'00'07/17/24 RBDMS JSB 072324 2P-422A Intermediate Plug Date: 4-22-24 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-422A was a producer shut-in in late 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 8/10/2020 = 1071 at 5515’ TVD MASP = 520 psi CIBP set at 6759’ KB on 4/1/24, CMIT-TxIA passed to 2500 psi TOC in tubing 6646’ KB Procedure Wireline & Pumping 1. Punch tubing at ±6330’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±150 bbls 9.8 brine c. ±31 bbls cement d. ±42 bbls 9.8 brine displacement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 4830’ MD 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 5. Cut tubing at ±3150’ RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 6330 3.5" 9.3# 2.99" 0.0087 6330 55.0 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 6330 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 6330 75.3 84.0 from punch depth Tubing Cement 4830 6330 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 4830 6330 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 1071 at 5515’ TVD 2P-422A Well Schematic Conductor: 16" Conductor 120' KB Production Casing Cement: 69 bbls of 15.8# Class G Cement Calculated TOC @ 3,650' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 6,241' KB, 15.5# x 9.3#, L-80 BTC Mod Set @ 7,279.9’ KB T-3 Peforations: @ 6,785' – 6,882' KB (97') Surface Casing: 7-5/8", 29.7#, L-80 BTC Mod Set @ 2,857.8' KB Production Tubing: 3 ½”, 9.3# L-80 BTC Mod Set @ 6,401.5' KB 6 Item Depth - tops (KB) 1 FMC Tubing Hanger 25.6' 2 Camco DS Nipple 511.5' 3 Baker Sliding Sleeve 6,344.4' 4 Camco D Nipple 6,360.4' 5Baker Locator 6,398.8' 6 Baker GBH-22 Seal Assembly 6,399.5' C80 @ 3140' KB C80 @ 3140' KB Plug #1 – Reservoir TOC ±6646' RKB Plug #2 – Intermediate TOC ±4830' RKB BOC @ ±6330' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,036.0 2P-422A 3/21/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement with SL 2P-422A 6/14/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/19/2010 haggea 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 25.6 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 6,401.5 Set Depth … 5,197.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.6 25.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.5 511.0 5.08 SAFETY VLV 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,047.8 1,911.9 45.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.6 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.8 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,759.3 5,506.2 30.28 CIBP 2.63" CIBP (MID-ELEMENT AT 6760' RKB) OAL=1.39' TTS CIBP N/A 4/1/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,047.8 1,911.9 45.13 1 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 3,972.4 3,153.8 38.91 2 GAS LIFT GLV INT 1 1,962.0 11/24/2014 0.156 5,021.3 4,020.8 33.07 3 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 5,779.8 4,673.6 31.59 4 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 6,294.6 5,106.5 32.05 5 GAS LIFT OPEN 1 3/22/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,646.0 6,759.3 5,408.3 5,506.2 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 6694' RKB. 6/14/2024 2P-422A, 7/10/2024 2:04:49 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 25.6-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 CIBP; 6,759.3 Cement Plug; 6,646.0 ftKB GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 GAS LIFT; 3,972.4 SURFACE; 34.7-2,857.8 GAS LIFT; 2,047.8 SAFETY VLV; 511.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Rig Elevation: Total Depth: 7310 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 7 5/8" O.D. Shoe@ 2858 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2"x3 1/2" O.D. Shoe@ 7280 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 6401 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 6759 ft 6650 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1690 1595 1565 IA 134 141 138 OA 718 718 718 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Pre-test pressures Tbg = 0 / IA = 28 / OA 718 July 5th 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-422A ConocoPhillips Alaska Inc. PTD 2020670; Sundry 323-449 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-422A_bb 9 9 9 9 99 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.14 14:43:49 -08'00' 202-067 T38912 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 14:53:45 -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): 7310'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. 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 9/20/2023 3-1/2" Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2823' 6785-6903' 7254' 5528-5630' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 120' 2858' 5958'7280' 16" 7-5/8" 85' 6401' MD Plugs (MD): 120' 2388' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20400-01-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6399' MD and 5196' 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-422A 5984' 7072' 5776' 520 None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:33 pm, Aug 08, 2023 323-449 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU =Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.08.08 14:25:14-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor X 10-407 VTL 8/11/2023 X DSR-8/14/23MDG 8/23/2023 12/31/2024 *&:JLC 8/24/2023 08/24/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.08.24 12:23:37 -08'00' RBDMS JSB 082923 2P-422A Suspension Date Wrien: 13 June 2023 Execuon Date: Sept 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-422A was a producer shut-in in late 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 8/10/2020 = 1071 at 5515’ TVD MASP = 520 psi Last tag 7042’ RKB on 8/10/2020 with gauges Procedure Wireline & Pumping 1. Tag TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 2. Fluid pack tubing with KWF and freeze protect 3. Set CIBP @ ±6,750’ RKB (must be set within 50’ of the top of perforations) 4. Perform MIT-T to 2500 psi, record results 5. Dump bail at least 30’ of cement on top of CIBP 6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 7. RIH and tag TOC, approx. 6720’ RKB (MUST BE AOGCC WITNESSED) 8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 9. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,072.0 2P-422A 8/10/2020 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag 2P-422A fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/19/2010 haggea 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 35.0 120.0 120.0 62.60 WELDED SURFACE 7 5/8 6.87 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 6421' 5 1/2 4.95 25.6 7,279.9 5,957.6 15.50 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.6 Set Depth … 6,401.5 Set Depth … 5,197.6 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.6 25.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.5 511.0 5.08 SAFETY VLV 4.550 CAMCO DS NIPPLE CAMCO DS 2.875 2,047.8 1,911.9 45.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 3,972.4 3,153.8 38.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,021.3 4,020.8 33.07 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 5,779.8 4,673.6 31.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,294.6 5,106.5 32.05 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.867 6,344.4 5,148.9 31.61 SLEEVE-C 4.500 BAKER SLIDING SLEEVE BAKER 2.813 6,360.4 5,162.5 31.52 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,398.8 5,195.2 31.31 LOCATOR 4.000 BAKER LOCATOR BAKER GBH-22 3.000 6,399.5 5,195.9 31.30 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY BAKER 3.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,047.8 1,911.9 45.13 1 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 3,972.4 3,153.8 38.91 2 GAS LIFT GLV INT 1 1,962.0 11/24/2014 0.156 5,021.3 4,020.8 33.07 3 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 5,779.8 4,673.6 31.59 4 GAS LIFT DMY INT 1 0.0 4/22/2002 0.000 6,294.6 5,106.5 32.05 5 GAS LIFT OV INT 1 0.0 11/18/2014 0.156 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,785.0 6,903.0 5,528.4 5,629.9 T-3, 2P-422 8/17/2015 6.0 APERF 2.5" 6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3, 2P-422 5/4/2002 6.0 IPERF 2.5" HSD HJ Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,872.0 6,882.0 1 FRAC 5/5/2002 0.0 0.00 0.00 2P-422A, 8/7/2023 3:02:03 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6421'; 25.6-7,279.9 IPERF; 6,872.0-6,882.0 FRAC; 6,872.0 APERF; 6,785.0-6,903.0 GAS LIFT; 6,294.5 GAS LIFT; 5,779.8 GAS LIFT; 5,021.3 GAS LIFT; 3,972.4 SURFACE; 34.7-2,857.8 GAS LIFT; 2,047.8 SAFETY VLV; 511.5 CONDUCTOR; 35.0-120.0 KUP PROD KB-Grd (ft) 37.30 RR Date 3/6/2002 Other Elev… 2P-422A ... TD Act Btm (ftKB) 7,310.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032040001 Wellbore Status PROD Max Angle & MD Incl (°) 56.55 MD (ftKB) 2,390.91 WELLNAME WELLBORE2P-422A Annotation Last WO: End DateH2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE • WELL LOG TRANSMITTAL DATA LOGGED c1,2BENDER To: Alaska Oil and Gas Conservation Comm. September 14, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 'SLIP 2 2 RE: Perforation Record: 2P-422A Run Date: 8/15/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2P-422A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20400-01 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC @halliburton.com (1/).A.42.4zec.,17) Date: Signed: STATE OF ALASKA ' ALA,OIL AND GAS CONSERVATION COMINSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon rl Rug Perforations fl Fracture Stimulate r Pull Tubing r Operations Shutdow n Performed: Suspend fl Perforate F Other Stimulate r Alter Casing rChange Approved Program Rug for Redrill r Perforate New Pool r Repair Well rrRe-enter Susp Well rOther: 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 202-067 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20400-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 373112 KRU 2P-422A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Meltwater Oil Pool 11.Present Well Condition Summary: Total Depth measured 7310 feet Plugs(measured) none true vertical 5984 feet Junk(measured) none Effective Depth measured 7185 feet Packer(measured) no packer true vertical 5875 feet (true vertical) no packer Casing Length Size MD ND Burst Collapse CONDUCTOR 85 16 1 120 120 SURFACE 2823 7.625 J 2858 2388 PRODUCTION 7254 5.5 7280 5958 RECEIVED SEP 01 2015 Perforation depth: Measured depth: 6785-6903' CANNE i'\d 1 1 2 0 j True Vertical Depth: 5528'-5630' AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,6402 MD, 5198 TVD Packers&SSSV(type,MD,and ND) no Packer SAFETY VLV-CAMCO DS NIPPLE @ 512 MD and 511 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 69 737 48 -- 278 Subsequent to operation 168 3255 105 -- 292 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F7 Exploratory l Development Kr. Service r Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas r WDSPL Printed and Rectronic Fracture Stimulation Data r GSTOR r WINJ r WAG fl GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O.Exempt: none Contact Tyson Wieseta7 263-4250 Email Tyson.M.Wieseconocophillips.com Printed Name Tyson iese Title Sr. Wells Engineer Signature Phone:263-4250 Date A `1 — 1)-015 VIL 4,,,00 / 0/ /� RBDMS �," / P 0 1 2015 Form 10-404 Revised 5/2015 Submit Original Only P-422A WELL WORK SUMMARY • DATE SUMMARY 8/3/2015 N2 FCO. Late start due to N2 Pumpers being stuck behind rig move at the Kupauk River bridges for 2.5 hours. After N2 Pumpers rigged up, cooled down N2, conditioned N2 and pressure tested, a fitting broke off on the high pressure side of their pump. Unable to continue with pump and unable to get one out of Deadhorse in a timely manner to re-start job. Job postponed until morning. Well freeze protected and location secured for the night. *****Job in Progress**** 8/4/2015 N2 FCO. Unable to get any better than 55% returns after trying numerous pump rates for both fluid and N2.Eventually lost all fluids as well went on a very strong vac. Ended up doing a Fluff n' Stuff from TOF @ 6,896' down to 7,167'. Well freeze protected and ready for slicklne. *****Job in Progress***** 8/12/2015 TAGGED D NIPPLE @ 6360' RKB. ENCOUNTERED OBSTRUCTION @ 6862' SLM W/ DUMMY PERF DRIFT (22.8'x 2.64"). SWAGED PROBLEM AREA @ 6862' SLM W/2.71" DUMBELL SWAGES. RAN 13'x 2.5" DRIFT, TAGGED @ 7073' SLM. RE-RAN DUMMY PERF DRIFT, TAGGED @ 7073' SLM. READY FOR E-LINE. 8/15/2015 CORRELATED LOG TO BAKER MPRG LOG DATED APRIL 19 2002; GAMMA RAY PERFORATED 6883-6903'WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6875.5' WITH A 7.5' CCL TO TOP SHOT OFFSET. PERFORATED 6863-6883'WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6855.5'WITH A 7.5' CCL TO TOP SHOT OFFSET. 8/16/2015 CORRELATED LOG TO BAKER MPRG LOG DATED APRIL 19 2002; GAMMA RAY. PERFORATED 6843-6863'WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6835.5' WITH A 7.5' CCL TO TOP SHOT OFFSET. PERFORATED 6823-6843'WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6815.5'WITH A 7.5' CCL TO TOP SHOT OFFSET. PERFORATED 6808-6823' WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6800.5'WITH A 7.5' CCL TO TOP SHOT OFFSET. 8/17/2015 CORRELATED LOG TO BAKER MPRG LOG DATED APRIL 19 2002; GAMMA RAY. PERFORATED 6794-6808' WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6786.5'WITH A 7.5' CCL TO TOP SHOT OFFSET. PERFORATED 6785-6794'WITH A 2.5" HSC WITH 6 SPF AT 60 DEG PHASING. PERFORATED AT CCL STOP DEPTH OF 6777.5'WITH A 7.5' CCL TO TOP SHOT OFFSET. KUP PROD 40 2P-422A Conor PEt1IIips0 ' Well Attributes Max Angle&MD TD, Alaska,Inc Wellbore APIIUWI Field Name Wellbore Status nal(°) MD(15(8) Act Btm(ftKB) C ilk 501032040001 MELTWATER PROD 56.55 2,390.91 7,310.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2P-422A,8/17120152:41'46 PM SSSV:NIPPLE 50 11/2/2014 Last WO: 37.301 3/6/2002 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,030.0 8/12/2015 Rev Reason:TAG,PERFORATIONS lehallf 8/17/2015 HANGER;25.6 Casing Strings J.. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 120.0 120.0 62.60 WELDED 14 ICasing Descriphon OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ` SURFACE 7 5/8 6.875 34.7 2,857.8 2,388.1 29.70 L-80 BTC-MOD LA Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I. Grade Top Thread ;...._;,._.. ., , , lupe t auu.PRODUCTION 5.5"x3.5" 512 4.950 25.6 7,279.9 5,957.6 15.50 L-80 BTC-MOD @ 6421' Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 25.6 6401.5 5,197.6 9.30 L-80 BTC-MOD 1 CONDUUCTO�V5�0-1200 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inot(") Item Des Corn (in) SAFETY VLV;5115 "i 25.6 25.6 0.00 HANGER FMC TUBING HANGER 3.500 511.5 511.0 5.08 SAFETY VLV CAMCO DS NIPPLE 2.875 6,344.4 5,148.9 31.61 SLEEVE-C BAKER SLIDING SLEEVE 2.813 6,360.4 5,162.5 31.52 NIPPLE CAMCO D NIPPLE 2.750 6,398.8 5,195.2 31.31 LOCATOR BAKER LOCATOR 3.000 6,399.5 5,195.9 31.30 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.000 I Perforations&Slots g ��x�i�d4�_> �; GAS LIFT;2,047.8 Shot II Dens Top(ND) Btm(ND) (shotstt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I) Type Corn • 6 785.0 6,903.0 5,528.4 5,629.9 T-3,2P-422 8/17/2015 6.0 APERF 2.5"6SPF 60 DEG Millenium Charges 6,872.0 6,882.0 5,603.3 5,611.9 T-3,2P-422 5/4/2002 6.0 (PERF 2.5"HSD HJ Stimulations'&Treatments SURFACE;34.7-2.8578-. Min Top Max Btm Depth Depth Top(ND) Star(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn ill 6,872.0 6,882.0 5,603.3 5,611.9 FRAC 5/5/2002 INITIAL FRAC,285#PROPPANT,10 PPA ON II GAS LIFT;3,972.4 - PERFS Mandrel Inserts st ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Corn GAS LIFT;5,021.3 a 1 2,047.8 1,911.9 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 4/22/2002 9 �'. 2 3,972.4 3,153.8 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.156 1,962.0 11/24/2014 9 3 5,021.3 4,020.8 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 4/22/2002 9 GAS LIFT;5,779.8 4 5,779.8 4,673.6 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 4/22/2002 9 II 5 6,294.6 5,106.5 CAMCO KBG-2- 1 GAS LIFT OV INT 0.156 0.0 11/18/2014 9 Notes:General&Safety End Date Annotation GAS LIFT;6,294.5 ':. r 11/19/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 11 4: ' SLEEVE-C,63444 • ( NIPPLE;6,360.4 LOCATOR;6,398.7 SEAL ASSY;6,399.5 ;;M am.. JAPERF;6,785.06,903.0 FRAC;6,872.0 (PERF;6,872.06,882.0 r PRODUCTION 5.51,6 5.8� 6421';25.6-7,279.9 Image r-~oject Well History File Cover Pade XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;;;¡ Q;¡- 0 b7well History File Identifier ~)~~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:, -0ES - NO SEVERl Y ROBIN VINCENT SHERYlB WINDY DATE: 'D 17/ O+ISI V\1t P Organizing (done) RESCAN 0 Two~Sided DIGITAL DATA 0 Color items: Diskettes, No. 0 ,/ Grayscale items: 0 Other, NofType 0 Poor Quality Originals: Other: 0 NOTES: BY: BEVERLY ROBIN VINCENT S~"ERY~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY BY: ð x 30 = q:f}} w BEVERLY ROBIN VINCENT SHERYL~JNINDY Scanning Preparation Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: 0 Rescan Needed OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds ,01 Other DATE(P J.? DIfSI ntP DA~E6.~'6iþl mPr ~ .Jj + C = TOTAL PAGES 0,0 --.. ~/' .. ~...j -'- -. /. :i..:-,I-.- , ~. DATE:b ~~lþl nqj}.' , . ~ V ¡ÔD BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ISI (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS Due TO QUALITY. GRAYSCALE OR COLOR IMAGES) ReScanned (iltr.(i\.idl';¡1 ¡n(,l" [.r,f',)r;io1l ,~f10111io/J 5o(',..~lni¡¡g w¡r¡pfl'toci) RESCANNED BV: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: - YES - NO DATE: DA TE: ISI Quality Checked (d')l1c) 12/10/02Rev3NOTScanned.wpd • Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Thursday, January 27, 2011 9:09 AM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval Attachments: Kuparuk Gas Injector Flow back Volumes.xls Tom, Attached you will find the Kuparuk Gas Injector Flowback information per your request. Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. 44/NFU FEU 8 ki U 11 Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e -mail in error,_ lease notify the sender and delete this email immediately. From: Maunder, Thomas E (DOA) Lmailto _tom.maunder_ @alaska.gov] Sent: Tuesday, January 25, 2011 9:09 AM To: NSK Prod Engr & Optimization Supv Subject: RE: Request for Approval Gary/Denise, Following up on my brief conversation with Gary the other day, could one of you provide some information with regard to the flowback of these WAG injectors while TAPS was unavailable. Please copy everyoned as before with your response. Thanks in advance, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody 3 (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. 1/27/2011 Page 2 of 3 • Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv j mailto :n2046 @conocophillips.coml Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 L,J From: Maunder, Thomas E (DOA) [mailto_ tom .maunder_ @alaska,gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC I I From: NSK Prod Engr & Optimization Supv [ mailto :n2046©conocophillips.comJ Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D 1/27/2011 Page 3 of 3 Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. lowback Adjacent Estimated Prod PTD# PTD# i as Injector SI Producer (Mscfd) X-420 201 -182 2P -422A 202 -067 4,500 a4P -447 rk 203 -154 2P -448A 202 -005 2,000 au-o3 185 -006 2U -02 185 -005 3,500 '5S -09 202 -205 3S -08C 207 -163 7,500 3S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr &Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/27/2011 Page 2 of/S • • Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. will do not have the authority for this approval, but based on responses to others, the AOGCC wl I work with y ou to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 ©conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Importance: High ] NED Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ilowback Adjacent Estimated Prod ;as Injector PTD# SI Producer PTD# (Mscfd) ;P -420 201 -182 2P -422A 202 -06 4,500 ;P -447 203 -154 2P -448A 202 -005 2,000 U -03 185 -006 2U -02 185 -005 3,500 1S -09 202 -205 3S -08C 207 -163 7,500 1S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/11/2011 Page 1 of 1 • . Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval 1/11/2011 e Conoc~illips Alaska e t: ':k- I' 'I ,jÛL " f'" V g ') U)Oh L ' v P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 & Anchorage June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ~(ìA..~~\!EÐ tj 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. 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, \~~~~6 á~ C:>6/~ ù ItJ6 Attachment eo';) -O~1- # e e ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Initial top Vol. of cement Final top of Cement top Name PTD # of cement um ed cement off date ft bbls ft ) ConocóP'hiiii ps Alaska EC~ E;1 \\~~¡/!E: JU¡\\) . i..: " em :Î!t B JI£C;.(j¡ü'ij;1, ¡~J1¡¡;h0n]~® P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 dð~ -Ob 7 June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 5Ci\NNED JUN 2 11 2006 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfill404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took p lace and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05,2006. SchlumbergerWell Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached / spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. L ConocoPhillips Problem Well Supervisor Attachment ) ) ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off . ~ . . . '. . {::·'?2P~~·.·.= .': . 2P-415 f~~j2P;'¡it7: . ::f: . 2P-419 ~;"::~îP~Ð:::' '::) . ." 2P-422 r<~;~~4·'.-':· 2P-427 ,,.:.æ~9:.:'·· 2P-431 .' ·:2p:412:·',;·;:., ." 2P-434 '.' ~æ143à:~,\~':" 2P-441 '2P~~:'. ..: 2P-447 .': ~)?,M$:: 2P-449 , ;,2P~1·: Initial top of cement ft ',4'. .' 5.5 . 7~5" 1 . ·3:.'5.'·. 13.5 . ,.:';4~5· " 10 ~2: 13 ,8~5. 14 .s'·· 15 .,3~5· 2.5 " :"·1...5.: 3 .: :1-0.··· Vol. of cement pumped bbls -(to 0.0 ··Ô~7 0.0 ". , ..... ·;::diô··..:"·· '... :. 2.3 . . : ·,'O~().·.·· ",. 1.6 ~ . .' '··,o~b<·· '..' ,., 1.9 ,O~9. 2.0 '. '/'. '.' .~O;.ò'::> 2.0 ::G.O.: .' 0.0 ':"QQ" "';.. 0.0 ". . ~1 Kuparuk F'ield June 6,2006 Final top of Cement top cement off date ft ·;·4··.na· 5.5 na :. ":. 2~5 :. :', " ~. .5/112006. . 1 na ·:'·~'·3.5.· .' . '. '. F1S¡ "1 " 2.5 5/1/2006 ,"~4~5:.·" '. ·na··~.··< ,'.~ . 2.5 5/1/2006 2,:" ': ,:...Da...': 2.5 5/1/2006 ,_)2!.:S~· ..' :. .511'J2006;····{ 2.5 5/1/2006 ,:.·::is·,:·· ...nà'",.",. 2.5 5/1/2006 .. . '~.~.:~3~5.:,. : ..' ':Ï1ã:::' . ~ . 2.5 na .. ·:·1~5. '. . nä. ." .. 3 na :2.5'· 51112006 . RG2041 voi gal . :·5~:7. 7.1 ····:5~,7 . 6.7 '.' ·7~·1.··· 7.1 '5;'7..· 7.1 ':" '3';.:'8· : 7.1 . '.. '5.7.':'"- 5.7 --: . .<:5(1'.:· 7.1 ':' .8~7:: '.. . 9.5 .' ·9.5: . 5.7 '. . ·7¡t· Royfill404B vol. gal ':1'7'.1" . 30.9 "g',,:' . o 1,7.3,.. . 10.7 :t1J5:' : 13.7 . '5~:7·:. 10.1 .1:3.:8:.':' 6.2 "21-:.9.", 13.1 :'1'1".4" o . . 0 .' 11.5 . '6~5 . Corrosion inhibitor/ sealant date 5/19/2006 . MØ120fe:' : 5/19/2006 . ·.~5Aœt2ø.i?'.. < 5/18/2006 "I:,+ðt~" 6··.... :, ,·,W.I(I'QI."· ¡. ~ . . ",",: " ",' ..,.... 5/18/2006 : ··.·;-51'.81~6;:: .:. 5/18/2006 :. " ...:·.5t1ØJ2oœ-/:··::/ 5/18/2006 . . . t:,t!i,:Ü!f"i, .,.... . :.':~{~~QQ6';':::.::' 5/18/2006 . '. : .' :.:/5l¡'t812ømr'~ .:;.~ 5/18/2006 .' .' .·..511al2Ø06:<: 5/18/2006 . ' 5l...~a;mnrie:· , . ~'. . " . .,:l~~~ ".,':.: 5/31/2006 .' " . 5i~nY2006·· . e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _1nserts\Microfilm _ Marlœr.doc Previous totals (bbls): 2003 / 4th 28146 2004/1st 3614 2004 / 2nd 0 2004 / 3rd 0 Total Ending Volume (bbls): 31760 Signature: Printed Name: Form 10-423 Rev. 2/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GlNJ 0 WINJ D. WDSPI,.D 5a. Sundry number: 5b. Sundry approval date: D or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 303-305 / (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2003 Volume (bbls): Number of days disposal. occurred 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added 11. Attach: Disposal Performance Data: Pressure vs. Time D 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. '\ ~._~ I.l...-- 100 40* 40 0 28246 0 3714 0 0 0 0 100 0 0 200 32000 53 40 Step Rate Test 0 ~- Date: Randy Thomas Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 202-067 2P-422A 8. API Number: 50-103-20400-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 47 10/31/2003 12/31/2003 2P-432, 2P-434, 2P-447, 2P-424 6 1/1/2004 2P-424 1/6/2004 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 JAN 1 4 2005 l {-¡ (oS- Phone Number: (907) 265-6830 Submit in Duplicate - Previous totals (bbls): 2003 / 4th 28146 2004/1st 3614 2004 / 2nd 0 2004 / 3rd 0 '- Total Ending Volume 31760 (bbls): 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Signature: Printed Name: 1::'-....- --t n. AI')~ C_u 1')/l*'Jnf\A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service D Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ D WINJ 0 WDSPL D Sa. Sundry number: 5b. Sundry approval date: 0 or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 303-305 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2003 Volume (bbls): Number of days disposal occurred 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. '\ ~\L.,.. 40* 40 100 0 28246 47 100 0 3714 6 0 0 0 0 0 0 0 0 200 40 32000 53 Pressure vs. Time 0 Step Rate Test 0 Date: Randy Thomas Title: Kuparuk Drilling Team Leader 1r..ICTCIIt"TI('\r..IC ('\1\.1 CJ::\IJ::CC:J:: C::lnJ:: 6. Permit to Drill Number: 7. Well Name: 202-067 2P-422A 8. API Number: 50-103-20400-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 10/31/2003 12/31/2003 2P-432, 2P-434, 2P-447, 2P-424 1/1/2004 1/6/2004 2P-424 Report ;s 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 2004 \oft'=( (oy Phone Number: (907) 265-6830 Submit in Duolicate 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) 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 4th 2004/1st 2004 / 2nd 2004 / 3rd Total Ending Volume (bbls): 11. Attach: Signature: Printed Name: 0 or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 303-305 (h)(3) Other Commission approved substances (include descriptions in block 12) 1 0/22/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 202-067 2P-422A 8. API Number: 50-103-20400-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: -.-" 40* 40 0 28246 47 1 0/31/2003 12/31/2003 2P-432, 2P-434, 2P-447, 2P-424 0 3714 6 1/1/2004 1/6/2004 2P-424 0 0 0 28146 100 3614 100 0 0 31760 40 32000 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. ~\~. Randy Thomas 200 Step Rate Test 0 Date: Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE -' 53 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(.g(D1' Phone Number: (907) 265-6830 Submit in Duplicate 1JAN~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020670 Well Name/No. KUPARUK RIV U MELT 2P-422A Operator CONOCOPHILLlPS ALASKA INC MD 7310 ,-/ Completion Date 5/4/2002 .-~- TVD 5984-- Completion Status 1-01L Current Status 1-OIL - -- ------------- - -~-------- REQUIRED INFORMATION 5þ~~ IJ~ Àð~,,- API No. 50-103-20400-01-00 UIC N Mud Log No Samples No Directional Survey Yes ~--- -----"--- -- - _u---- --- ---- ------~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received fi5- .0 .C._Tf- CJ255 LIS Verification 1-3 2857 7310 Open 11/12/2003 :~ ,...,...LI S Verification 1-3 2857 7310 Open 11/12/2003 ED C ./Pdt ~255 I nduction/ResìstíVity 25 2878 7310 Open 11/12/2003 t.og--- I nduction/ResistíVity 25 Blu Mb 2878 7310 Open 11/12/2003 ~V;;h.,;- £D C "pdt ~255 Neutron 25 2878 7310 Open 11/12/2003 ~/ Neutron 25 Blu 2878 7310 Open 11/12/2003 [ED C /Pdt ,;(2255 Density 25 2878 7310 Open 11/12/2003 ~ Density 25 Blu 2878 7310 Open 11/12/2003 ---- .-._---------~ Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received -' Comments Multiple Propagation Resistivity, Gamma Ray - RWD Multiple Propagation Resistivity, Gamma Ray - RWD Caliper Corrected Neutron, Optimized Rotational Density - RWD Caliper Corrected Neutron, Optimized Rotational Density - RWD Caliper Corrected Neutron, Optimized Rotational Density - RWD Caliper Corrected Neutron, Optimized Rotational Density - RWD ~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020670 Operator CONOCOPHILLlPS ALASKA INC Well Name/No. KUPARUK RIV U MELT 2P-422A MD 7310 TVD 5984 Completion Status 1-01L Current Status 1-01L Completion Date 5/4/2002 ADDITIONAL INFORMATION Well Cored? Y I@) Chips Received? .~ Daily History Received? ~N (J IN Formation Tops Analysis Received? .Y-ßi- -- ----- --" ----~- - - - -----~---- Comments: .- -------- -------- ~ Date: ------- ~-------- Compliance Reviewed By: API No. 50-103-20400-01-00 UIC N ~ ~~ J~}J,~~ .---" STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 40* 40 28146 100 0 28246 47 10/31/2003 12/31/2003 2P-432, 2P-434, 2P-447, 2P-424 3614 100 0 3714 6 1/1/2004 1/6/2004 2P-424 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement -contami nated drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 0 or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 303-305 (h)(3) Other Commission approved substances (include descriptions in block 12) 1 0/22/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 14th 2004 11 st 2004 / 2nd 2004 / 3rd Total Ending Volume (bbls): 40 31760 200 32000 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 foregoin~ is true and correct to the be:t of my knowledge. Signature: l .2~. -l~- -- Printed Name: ~'-<:À; \ L.c '"""'... t" Title: Step Rate Test 0 Date: t:>.S \~~- L:..,J Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 202-067 2P-422A 8. API Number: 50-103-20400-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ,,~. 53 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. 'f / ( b /6 '7 26 S- 6-6 > 0 Phone Number: Submit in Duplicate RECEIVED JAN 2 8 2004 0'\ & Gal' Cons CommiSsion A\aska' o}. . (1 nchoraQe 202-067 2P-422A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 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. ~ \ ~ ,,\..-.C> . \<-CoI.." J.. >' ~~ -Ct. 3 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 Previous totals (bbls): 2003 14th 28146 100 YYYY 10# YYYY 10# YYYY 10# Total Ending Volume (bbls): 28146 100 Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-305 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2003 Volume (bbls): Number of days disposal occurred 40* 40 0 28246 40 28286 47 Step Rate Test D Date: Title: b(-t ttc0 te~-- { , -..-< INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 50-103-20400-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~/ 47 10/31/2003 12/31/2003 2P-432, 2P-434, 2P-447, 2P-424 ~ 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. t( 'L6(o y Phone Numbel~ US- 6-& 30 ~.- Submit in Duplicate ) ) f)OC)-00 f Transmittal Form '&1. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2P-422A Contains the following: 1 LDWG Compact Disc )!J(!)55 (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log 1 blueline - CCN-ORD TVD Log LAC Job#: 241701 Date: Oct 30, 2003 D REC:EtVED ate: NOV 1 2 2003 PLEASE ACKNOWLEDGE RECEIPT BY SIGN:r1IftI;a~~ OR FAXING YOUR COPY . . ' FAX: (907) 267-6623 Sent By: Glen Horel .. "-.::::: Received B~~~~ ,-~~/y~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~~~'"~ rT-~~:",~-:~~:=.=:~':._-"-j' ---------.....----.---...-..------- r~ ~"'''':~" ., :...~ :....,.~ .... .: ., "'~'. ....... "'" - . - :.... "'I" ...' . II;.'\II.'L" "."1 tOM- :--~. . -.. u-.,¡, : .-... .,...-..,... ....,......,..... ~~§._I ¡=..~ - .=,.. ."'\ - ::~ "~1:. I~~ . ;.:',''''-:';"'' .". ...~ i_~-=:- :~=~--_.~~---=-~ ~ ¡ - '1"""'-" '-_-'_h_'_" ~--_.._.".~ .....'........". ---. ... ".----..--.- "'~ IZ:-~."'- "-----.-.- -------< ') ) Note to File 2P-422A (202-067.. .303-305) 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 10 bbls of cement was circulated to surface. The net cement remaining in the surface hole according to the cement calculation sheet was 2550/0 XS of the calculated hole volume. Companion reports of other wells on 2P pad indicate that large cement volumes were left in several of the surface holes on that pad. --On the initial leak off test, 18.4 ppg EMW was reached rather quickly (8 strokes). During the observation period, the pressure declined with the open hole holding 17.8 EMW and 15.8 EMW. The well was not actively pumped into. --The casing test and leak off pressure plot do not overlay. It appears that the casing was not completely fluid packed when the casing pressure test was done. --CPA experienced some lost circulation while drilling the production hole section. It is not reported if circulation was lost while running the production casing, but it was not possible to establish circulation once on bottom and the well was cemented without returns. Comments in the report indicate that lift pressure was seen as the cement rose in the annulus throughout the cementing job. " ~ --A subsequent injectivity test was done down the 7-5/8" x 5.5" annulus. The pressure increases to 750 psi where it breaks. Approximately 3 bbls of mud were injected with a steady pressure near 730 psi. This is 15.6 EMW. On shut down, the pressure decreased to 560 psi in 1 minute and further decreased to 540 psi at 15 minutes. --CPA provided a listing of all surface casing shoes within % mile of 2P-422A. The records of the 3 wells within 1100' radius (nearest well 600' distant) were examined and no problems were identified that would preclude granting CPA's request for 2P-422A. Based on examination of the submitted ConocoPhillips' request for the subject well. ~Y'í)~? Tom Maunder, PE Sr. Petroleum Engineer October 22, 2003 information, I recommend approval of ~ ~E: 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) ?P-44~: 17.2 ppg. This "new calculated" pump in pressure is greater than the 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 rmailto:tom maunder(â>.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: ~~\> po~-\. t::)~ -\- "'" ~ J\ '=' , l. V~pp\ C\\' \>\~~""""\'(:)f'\ '- ~ ~ c;..\,.)~~, ~~' \Ctcc~ '> ð ~ ~ ,,~ ('. \I", \ \ '~ \t......~, ~ ~(: () ap-\.\,-\\, ~p-~~\ d?-~ dY-W '\ð~ \;:}'f, a?-"'dO . ~\'- L ...... -- \ \ \ '\ \ ""~ \<:1 ~\ ~ ~(( \ \ ~ ~ ~ ð ---: . \- c:J r ~\o)$)~~ \ D«.<ë. "" ~ ~\'\C) \;)(!: ~ ~ r~~c.. ~ "\-" ~ \ ~ \' f\ $. 1\..,e 'Sl:c.. ,,-\- --\-.0 -\. h ~ ~ <; ,"" ~\ \ () "" \)..J Co ~ \ \0 ~ ') 'Ñc>.. '( ö- 'U.::Ñ.. 'f P (: c -\- \ \,)~ \I.,) Cê \.\ ç \ \<t ~ ~ ¡;2~ t 1)/ -ò~ Id{) 10/22/2003 9:59 AM RE: 2P-422A Annular Disposal Application ') > files. This would have lead to two differeflf sets of data for these > wells and we felt this could be potentially more confusing. On the other > hand we recognise now that we should have brought this to your attention > in our initial correspondence. We will be sure to do so in the future. > > For well 2P-431 we have been unable to locate any record of a pump in > test after the initial leak off test was performed. We do know that this > annulus has been freeze protected and also that methanol has been pumped > down it to remove a hydrate plug but accurate pressure information is > lacking. However, due to its location, between wells 429 and 441 we are > confident that its behaviour with respect to a pump in test is similar > to these wells. > > I hope this note adequately addresses your comments and questions. If > there is anything else please let me know. > > Regards > > Philip > > -----Original Message----- > From: Tom Maunder (mailto:tom maunder@admin.state.ak.usl > Sent: Monday, October 20, 2003 9:07 AM > To: Hayden, Philip > Subject: Re: 2P-422A Annular Disposal Application > > Phil, > Here are my furlher comments/questions on the 2P-422A application. I > look > forward to your reply. > Thanks. > Tom Maunder, PE > AOGCC > > On the 2P-420 pump in test, the calculation has not been done. TVDs > have > not been entered. Using the 550 psi maximum pressure and the shoe tvd, >1 > calculate 14.2 EMW. The EMW of the sustained pump in pressure would be > slightly lower. > > On the pump in test of 2P-417, the calculation does not use the tvd of > the > rathole at the surface casing shoe. Using 2430' tvd, the EMW calculates > to > 14.2 which is in agreement with the calculation for 2P-420. > > Tom Maunder wrote: > > > Hi Phil, > > Welcome back. I was looking at the application and I have a couple of > > questions. Please note that I am not finished with my review of the > > packet. This first note will allow you to capture my eddress. ) 2 of 3 10/22/2003 9:59 AM KE: 2P-422A Annular Disposal Application ) ) » > > My questions/comments are: » > > On the pump in plot for 2P-422ST dated 4/22/02, the TVD used in the > > calculation is not the same as done on the initialleakoff dated > > 2/20/02. Why the difference?? » > > The TVDs on 2P-441 also are different. In particular the pump in TVD > is > > listed as the mid point between the top of cement and surface shoe. > All > > EMWs should be referenced to the surface shoe. » > > There is no pump in test for 2P-431. » > > You have made the appropriate tvd change on 2P-429. » > > Tom Maunder, PE > > AOGCC 3 of 3 10/22/20039:59 AM ) ConocóP'hillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Philip Hayden Phone (907) 265-6481 Fax: (907) 265-1336 Email: philip.hayden@conocophillips.com October 3, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilline Waste on well 2P-422A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that 2P-422A be pennitted 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-422A approximately November 1,2003. 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 10. Details on all wells within % mile of 2P-422A at the surface casing shoe (2P-441, 2P-431, 2P-429, 2P-427, 2P-420,2P-417). With reference to point (8) above, this deeper LOT occurred at a lower equivalent mud weight than the casing shoe test. Therefore we conclude 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. If you have any questions or require further information, please contact Philip Hayden at 265-6481, or Randy Thomas at 265-6830. Sincerely, ~,t ,ß,~ IL I p-~ Ph~ay~L- Drilling Engineer Cc: 2P422A Well File Randy Thomas Sharon Allsup-Drake """.~ :~ () .. .. ..... 6 " ATO-1576 ATO-1530 ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown 0 0 0 Perforation Depth MD (ft): 6872 - 6882 Packers and SSSV Type: Baker GB H 22 Seal ass. with receptacle, Cameo 'DS' nipple 12. Attachm ents: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 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): 5603 - 5612 Packers and SSSV MD (ft): Seal bore receptacle @ 6402', nipple @ 512' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GlNJ 0 ) 1. Type of Request: Suspend 0 Repair well 0 Pull Tubing 0 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Abandon P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' Above GL 8. Property Designation: ADL 32092 / ALK 373112 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7310 5984 7178 Casing Length Size Structural Conductor 80 16" Suriace 2830 7.625" Intermediate Production 7252 5 1/2" x 3 1/2" Liner 11/1/2003 Date: Printed Name ') J:W¡ .;;> :J Plug Perforations Perforate 0 Stimulate 0 Other 0 0 Time Extension 0 Variance Annular Dispos.0 Perforate New Pool Re-enter Suspended Well 0 5. Permit to Drill Number: 4. Current Well Class: Development 0 Exploratory D Stratigraphic 0 Service 0 202-067 6. API Number: 50-103-2040001 9. Well Name and Number: 2P-422A 10. Field/Pools(s): Kuparuk River Field / Meltwater Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 5868 MD TVD Burst Collapse 1081 1081 28581 23901 6890 4910 7280' 5958' 7000/10160 4980 / 10530 Tubing Size: 3.5" Tubing Grade: L-80 Tubing MD (ft): 6402 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact Philip Havden 265-6481 Signature R. Thomas Title Kuparuk Drilling Team Leader ~ \ ~ Phone 265-6830 COMMISSION USE ONLY Date i.. ò I"t.. (o 3 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 303-30~ Plug Integrity 0 Mechanical Integrity Test 0 BOP Test D Other: Location Clearance 0 ,.....-~ ,à ~ ~,~ -" ..r" V Subsequent Form Required: ~\'O\+ O~ C>. f'1'\J \.0. \~ \ S.ÇX) >C\.. \ Approved by: L.L; Æ - ... t!:....-~ COMMISSIONER --8Ft OCT 2' 2003 OR'GINA~ Form 1 0-403 Revised 2/2003 . < ¡ BY ORDER OF THE COMMISSION Date:/r'¿¥ OJ SUBMIT IN DUPLICATE Annulus Jsposal Transmittal Form - WL~P-422A AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: 2P-422A 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 drilling 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 lbs/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 showing 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 2,287 psi. See attached calculation page. See attached: cementing reports, LOT 1 FIT reports and casing reports. 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. NI 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 operat,or 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. See attached casing summary sheet and calculation pages. N/A 2P-432, 2P-434, 2P-424, 2P-447, 2P-443 N/A N/A Well Date ~ ~ ~ ~ bJ) = .~ U = = an .,) ) ') 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 2P-422A 10/3/2003 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 MW max 5,857 = ( 2,390 * 0.052 * MW roax ) + 1500 - (0.4525 * 2,390) 43.8 ppg 2,390 TVD Surface Casing String Size Weight Grade PburstlOO% Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure TOC Est. @ 5,920' MD 4,792' TVD 7.625 in 29.7 ppf L 80 6,890 psi 5,857 psi 2,390 ft 18.4 ppg 15.3 ppg 1,500 psi or 2,287 psi Maximum Fluid Densitv to Collapse 2nd Casing String P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader MW max 4,242 = ( 4,792 * 0.052 * MW roax ) + 1,500 - ( 0.1100 * 4,792) - 0 13.1 ppg = 3 1/2"Tbg 2nd Casing String 5,198 TVD Size 5.5 in Weight 15.5 ppf Grade L 80 Maximum Allowable Pressure at Surface Casing Shoe P collapse 100% 4,990 psi P collapse85% 4,242 psi P max allowable = Shoe TVD Depth * .052 * Shoe FIT /LOT Top of Cement 4,792 ft Gas Gradient 0.11 psi/ft P max allowable = ( 2,390 * .052 * 18.4 ) Max Surf. Pressu 1,500 psi Header Press 0 psi P max allowable = 2,287 psi '.-' ~ i~~'. .,';' " .. - -ConocoPhil,'iþ:s.~~~la~ka. . '~:Casb'g,:R~port , - ' "." ,--',.r;- . ,f;>~~:'~';'6':.t': Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - DRILLING Report #: Start: 1 1/21/2002 Spud Date: 1/25/2002 Report Date: 2/15/2002 End: -GeneraUrifòimation String Type: Surface Casing Hole TVD: 2,402.0 (ft) Ground Level: 225.00 (ft) Circ Hours: (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Average Pad Gmd Lvi 225.00 (ft) (ft) 5.0 (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: (in) (ft) (ft) 34.74 (ft) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 2,878.0 (ft) 85,000 (Ibs) 56.55 (°) 11.00 (days) '--- " , ~ - 'C!ising Flaiige/Wèllheaçl Manufacturer: Hanger Model: FMC Model: Packoff Model: GenV Top Hub/Flange: 11.000 (in) /5,000 (psi) BTM Hub/Flange: (in) / (psi) Actual TMD Set: 2,857.79 (ft) ilÍt~gral cas,iÍigCetaÍl ' 0". :~:~' "fo-. 0 , .' ~ . - cltem Síze ~~~~;: ',}~r~de_. - D'rïft Thrëàds' .JTS length Tòp~ - ..MUtörq. THO ManufactUrer -- Mqdel - Cònd:. Max OU.MinlD . Có,mp"Narne (in.) - :(irí) (ft) '(ft).. (fHbt)' -. (Îll). (in) Casing Hanger 7.625 29.70 L-80 6.750 BTC-MOD 2.57 34.74 FMC GenV t..JEW 8.500 6.875 Casing Hanger Casing 7.625 29.70 L-80 6.750 BTC-MOD 22 944.87 37.31 \JEW 8.500 6.875 75/8" 29.7# L-8 Port Collar 7.625 29.70 L-80 6.750 BTC-MOD 2.42 982.18 TAM NEW 8.500 6.875 Port Collar Casing 7,625 29.70 L-80 6.750 BTC-MOD 42 1,783.43 984.60 NEW 8.500 6.875 7 5/8" 29.7# L-8 Float Collar 7.625 29.70 L-80 6.750 BTC-MOD 1.33 2,768.03 Y WEATHERFORD \JEW 8.500 6.875 Float Collar Casing 7.625 29.70 L-80 6.750 BTC-MOD 2 86.91 2,769.36 Y "JEW 8.500 6.875 75/8" 29.7# L-8 -' '-- Float Shoe 7.625 29.70 L-80 6.750 BTC-MOD 1.52 2,856.27 Y WEATHERFORD NEW 8.500 6.875 Float Shoe , - - -e .NoJ'1~lntegral C~slngAccessóries. Accessory . . Màriufabturê-r - NOOiber . Spáèing (it) fnterväl . HþW:Ftxëd.' Bowspring Centralizer Bowspring Centralizer WEATHERFORD WEATHERFORD 9 3 Top' (ft}' 2,336.0 2,748.0 Bottom(ft) 2,748.0 OverCollar 2,836.0 Clamped Printed: 6/9/. 0:41 :33 AM Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - DRILLING String Type: Hole TVD: Ground Level: Circ Hours: Manufacturer: Hanger Model: Actual TMD Set: (ft) 225.00 (ft) (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: . éÓJi()eop~i¡(¡~è'Â~ska ... . ,Casit;t9./Rêp,Ørt' . Report #: Start: 2 1/21/2002 - ." -.' .General: hjt~tm;ation Average Pad Grnd Lvi 225.00 (ft) (ft) (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: . -,- ,.. . . '~ing.Flaftge¡Wellhead . Model: Packoff Model: (in) (ft) (ft) (ft) . . . '" "'--. .'..P~$,-~';qf.~;1.; Spud Date: 1/25/2002 Report Date: 2/16/2002 End: Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: (ft) (Ibs) (°) 12.00 (days) .~. Top Hub/Flange: (in) I (psi) BTM Hub/Flange: (in) / (psi) .----' Printed: 6/91 .0:41:42 AM ) . . .. . . . . . . .. '" .. , .. ConQbophinips: 'Ala$ka . . ,qérneMting' Report Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 9.875 (in) 2,858 (ft) 2/15/2002 Surface Casing 7.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ) '. Page " of 4' Report #: Start: Spud Date: 1/25/2002 1 Report Date: 2/15/2002 1/21/2002 End: . Cement Jòb Type:..Ptimary . . . .... .. . 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: sa Date: Cmtd. Csg: Cementer: Steve Doughten Pipe Movement Pipe Movement: Reciprocating Rot Time Start: : Time End:: RPM: Rec Time Start:11:38 Time End: 12:36 SPM: 3 Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: Mud Circ Rate: 252 (gpm) Mud Circ Press: 400 (psi) Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 85 (Ibs) Start Mix Cmt: Start Slurry Displ: : Start Displ: End Pumping: End Pump Date: 2/15/2002 Top Plug: N Bottom Plug: N Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: : ;, ~ Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No:.1.of 3 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) N (psi) (psi) (min) N .Plug. Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Mucf Data. Max Torque: (fHbf) Drag Down: 55 (Ibs) Ann Flow After: N Mixing Method: Density Meas By: D-S PV/yP: (cp)/ (lb/100ft2) Gels 10 see: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) .. . . . Stage,No: 1.Slurry No: 1 of 1. . To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.40 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/9/2003 10:41:11 AM . .'... ) Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - DRILLING Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: Mud Circ Rate: 252 (gpm) Mud Circ Press: 500 (psi) ) , .. . .: . .Öonc>C'oÞ'~ilHPsAI.aska . .Cementing.. Report ,.Page2 of 4' Report #: Start: Spud Date: 1/25/2002 1 Report Date: 2/15/2002 1/21/2002 End: . stage No: 2 013 Start Mix Cmt: Start Slurry Displ: : Start Displ: End Pumping: End Pump Date: 2/15/2002 Top Plug: Bottom Plug: Type: KCL Polymer Density: (ppg) Vise: (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Type: Cement Casing Volume Excess %: Meas. From: Time Circ Prior To Cementing: 3.50 Mud Circ Rate: 252 (gpm) Mud Circ Press: 600 (psi) Disp Avg Rate: (bbl/min) Disp Max Rate: (bbl/min) Bump Plug: Press Prior: (psi) Press Bumped: (psi) Press Held: (min) Float Held: Mud Data Returns: Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: Mixing Method: Density Meas By: PV/yP: (cp)/ (lb/100ft2) Gels 10 see: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Stage No: 2 Slurry No: 1 of 1 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.20 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Start Mix Cmt: 11 :30 Start Slurry Displ: : Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: Type: KCL Polymer Density: 9.9 (ppg) Vise: 65 (s/qt) Bottom Hole Circulating Temperature:50 (OF) Displacement Fluid Type: Mud Time Compressive Strength 1: Compressive Strength 2: 5t~ge No: 3. ()f3 . 14:06 2/15/2002 Y Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 4.50 (bbl/min) 4.50 (bbl/min) y 600 (psi) 1,100 (psi) 5 (min) y MUd Data Temp (OF) (OF) Pressure (psi) (psi) Returns: Good returns Total Mud Lost: (bbl) Cmt Vol to Surf: 10.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: PV/yP: 18 (cp)/32 (lb/100ft2) Gels 10 see: 10 (lb/100ft2) Gels 10 min: 20 (lb/100ft2) Bottom Hole Static Temperature: 520 (OF) Density: 9.9 (ppg) Volume: 117.90 (bbl) Printed: 6/9/2003 10:41: 11 AM ') ) . . , , . :,.CÒnocoPtiiUips:Alaska " , Cementing.RQP;Orf Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - DRILLING Slurry Data Fluid Type: LEAO Slurry Interval: (ft) Water Source: Rig tank Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Trade Name 0-46 0-65 0-79 0-124 0-53 S1 Slurry Data Fluid Type: TAIL Slurry Interval: 2,356.00 (ft)To: Water Source: Rig tank Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: : Trade Name 0-79 0-65 0-46 (OF) (OF) . Page:3 of 4, Report #: Start: Spud Date: 1/25/2002 1 Report Date: 2/15/2002 1/21/2002 End: t)tage No:3 Slurry No: ,1 of 2 , To: r--.'j Oescriptipn: AS,pte ! 2,357.00 (ft) Cmt vot 316.0 (b,~) Slurry yol:417 (s~) l// Temperature: 53 (OF) Temperature: (OF) Temperature: (OF) Class:,/G'" .1 Density: 1 0.60 (ppg) Yield.{ 4.26 (ft3(sk) I ../ Water Vol: (bbl) Othe\~~~:9/'/ Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 3 Slurry No:10f 2 - Additives Type DEFOAMER DISPERSANT EXTENDER FI LUTE GYPSUM ACCELERATOR Concentration Units Liquid Cone. 0.60 %BWOC 0.50 %BWOC 1.50 %BWOC 50.00 %BWOC 30.00 %BWOC 1.50 %BWOC Stag,e No: 3 Slurry No:20f2 Description: L¡té6R~) . Class: 2,856.00 (ft) Cmt voÿ~á1.0 (bbl) ill Density: 12.60 (ppg) Yield: 2.40 (ft3/sk) Slurry (01:190 (Sk~// Water Vol: (bbl) Other Vol: () . /'/ "'-..-- Time Temperature: (OF) Compressive Strength 1: Temperature: (OF) Compressive Strength 2: Temperature: (OF) Temp (OF) (OF) Stag,e.Nó: 3.Siurry.No:,2of2'- Additives ,type EXTENDER DISPERSANT DEFOAMER Liquid Cone. Concentration ' Units 0.75 %BWOC 1.0C %BWOC 0.6C %BWOC Purpose: FILLER CEM Mix Water: 18.66 (gal) Foam Job: N Pressure (psi) (psi) Units Purpose: SHOE INTEG Mix Water: 8.15 (gal) Foam Job: N Pressure (psi) (psi) Units Printed: 6/9/2003 10:41: 11 AM ') ) . . ". I,. . .. . . .... Conocóp:~iI'ipsAlaSkâ.. : ',Cementing'F1eporf ' Page 4 of4' Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - DRILLING Report #: Start: Spud Date: 1/25/2002 1 Report Date: 2/15/2002 1/21/2002 End: qasing 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: : . ... .. ,. Good returns throughtout job. ¿rc 10 bbl1 .6 ppg slurry to surface. Bumped plug. Floats held. Washed out Tee in rig's cemenVstandpipe manifold. Hé..d to run jum er hose. Shut down for +- 10 min. , ' Remarks' Printed: 6/9/2003 10:41:11 AM ) ) .P:hilllps Ala$~a, 'I',ne:. DaUyDrillingReport Page 1.of 2 SUPERVISOR Guy Whitlock CURRENT STATUS 2P-422 I JOB NUMBER I EVE~DC~DE 124 HRS PROG I RIG NAME & NO. I FIELD NAME I OCS NO. naborscm@ppco Nabors 19E Meltwater ACCIDENTS LAST 24 HRS.? N/U BOPE TMD I TVD I DFS 2,878.0 2,402.0 11.00 AUTH MD I DAILY TANG 7,291.0 0 DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 2/15/2002 159,370 ILEAKOFF AFE AK0226 I NEXT CASING 7.625 (in) @ 2,878.0 (ft) 0 I CÙMCOST I 0 Pf/Mt CI Ca H2S LIME ES / I REPT NO. I DATE 20 2/15/2002 ICUM. TANGO CUM INT ANG WI MUD 0 CUM COST WI MUD 1,655,148 WELL NAME 24 HR FORECAST Fin N/U BOPE, Test BOPE. M/U BHA and RIH, test casing LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 2/13/2002 2,802.15 53.710 145.090 16.000 (in) @ 120.0 (ft) DENSITY(Ppg) I 9.95 I PP ,I I,Ecol MUDDATA! DAILVCOST I FV PVNP GELS WLJHTHP Fcrr.SOL, OILlWAT' %SandlMBT Ph/pM 65 18/32 10/20 5.0/ 2/ / fl.O 8.6/ AUTH. 2,497,612 LAST BOP PRES TEST OPERATIÇ>NSSUMMARY FROM TO HOURS .CODE TROUBLE SUB PHASE DESCRIPTION 00:00 00:30 0.50 CASE Np EQIP RURD SURFAC Change out casing elevators 00:30 03:00 2.50 CASE P RUNC SURFAC P/U shoe jt. BL jt., and collar jt. Check floats, RIH w/ 7-5/8" surface casing to 1192' 03:00 03:30 0.50 CASE P CIRC SURFAC Circ casing volume 03:30 05:30 2.00 CASE P RUNC SURFAC RIH w/ 7-5/8" casing, M/U TAM port collar,RIH to 2086' TITE 05:30 06:00 0.50 CASE Np CIRC SURFAC Circ and work thru tite spot 2086' to 2346' 06:00 07:00 1.00 CASE P RUNC SURFAC Continue running 7-5/8" surface casing 07:00 07:30 0.50 CASE P RUNC SURFAC M/U casing hanger and landing jt 07:30 11:00 3.50 CASE P CIRC SURFAC Circ and condition mud @ 6 bpm while reciprocating casing 11:00 11 :30 0.50 CEMENT P SFTY SURFAC Safety meeting w/ crews, cementers and truck drivers 11:30 14:30 3.00 CEMENT P PUMP SURFAC M&P 5 bbl CW1 OO-PT lines to 3500 psi-OK. M& P 75 bbl CW1 00. Drop bottom plug, M&P 50 bbl Mudpush XL @10.2, 316 bbl Lead @ 10.7,81 bbl Tail @ 12 ppg. Drop top lug and pump 10 bbl water to clear lines. Displace wI 117 bbl mud w/ rig pump. Bump plug and check floats. CIP @ 14:06 14:30 16:00 1.50 CEMENT P PULD SURFAC RID cement head and UD landing jt. Wash out stack 16:00 22:00 6.00 CASE P NUND SURFAC N/D diverter equipment 22:00 00:00 2.00 CASE P NUND SURFACClean starting head and install casing/tubing head COMPANY Phillips Nabors 'SERVICE PERSO~NEL DATA, NO. HOURS COMPANY 1 ACI 36 Service TYPE 2P-417 3R-11 NO. REMARKS SUPPORT CRAFT TYPE DS4 G&I SERVICE NO. HOURS 6 10 UNITS U$AGE : ON H~ND bbls 135 gals 1,510 NO. REMARKS 2P-422 'ITEM. Water, Drilling Fuel, Rig UNITS bbls gals USAGE 495 2,475 MArE'RIALS ICONSUMPTION ON HAND. .. : ,ITEM. 390 Water, Potable 11,700 Fuel, Camp 2P-422 2P-422 " RESÊRVOIFff.JÁMê 2P-417 3R-11 , 'RESERVOIR:~Nt).INfef{Y~LiÐÂ"A ZONE TÒþ BASE' 0 0 COMM~NTS 2P-422 2P-422 Printed: 6/9/2003 10:58:59 AM ... WELL NAME , " 2P-422 ,. 'RESERVOIR NAME DS4 G&I 2P-422 ) .. .P~iIIi)~~I~~~~,,~c. . .' :,:D,Uy,'QrUliri,g:Report I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 2,878.0 RESERVOIR ,AND INTERVAL. DATA ZONE ' TOP BASE . ' 0 ) '. . . . . , . . . . P8ge:2'of2 I TVD I DFS I REPT NO. I DATE 2,402.0 11.00 20 2/15/2002 COMMENTS Printed: 6/9/2003 10:58:59 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: 2/20/2002 Supervisor: G.R. Whitlock 2P-422 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: 7-S/8" 29.7# L-80 STC-mod Casing Setting Depth: 2,8571 TMD Hole Depth: 2,895' TMD 2,390' TVD 2,413' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 381 EMW= Leak-off Press. + Mud Weight = 1 ,100 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,413' EMW for open hole section = 18.4 ppg Pump output = 0.1050 bps Fluid Pumped = 0.8 bbl 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 1.900 psi W 1.800 psi a: 1.700 psi ::J 1.600 psi ~ 1.500 psi - W 1,400 psi a: 1.300 psi a. 1.200 psi 1,100psi 1.000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi - 300 psi 200 psi 100 psi 0 psi ~ I , I I I I I I J.. I I I ... I I I '{TlME.....'UNE......,<."..,., ..~! I . I ~ I I J¡-.1 ONE,MiNÚTÉ TIcKs 11-' I~~~ ""'-LEAK-OFF TEST ""'CASING TEST --+-LOT SHUT IN TIME ~CASING TEST SHUT IN TIME -+- TIME LINE I I J I Ã. r. f .~~ ..o",.c+-4\ ~~q ~ = ø N <71 !:1 ~ ~ .. m STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE I----------------'-------------T-------~----' L______---______L_Q._~!~~_-L__!!_e.~!'_--j L______-------_l.._~~~s ~_! O~'p~~-_.l ! i 4 stks L. 400 psi! ¡---------------¡---6-štks-~9ÕÕ pSi-Oj :---------------.:---------------@-;--------..: i ¡ 8 stks : 1,100 psi i :---------------¡--------------Y----------------1 i-------------+----------i--- i ¡----------------t-----------t-. .._---------1 I--------------t--------------f----------i 1--------------r------------t---------------1 ¡=~~=~~~~~~~~~~t~~~~==~=~~~=~~==~ 1------------+-----------t-------1 !-------------.!--------------!-----------4 : : : : :---------------t--------------t-----------i !--------------+-------------t---------------1 !----------------+-----------i----------------i : : t : :----------------+------------t-------------1 1--------______1___________1______-______1 I I I I : : I : :-------------:---------------'----------------1 J I I I !=~~~~~~~~~~~~~l~~~~~=~~~~~~~j~=-~~==~~~~j I I I I I I I I :----------------+------------..J--------------4 I I I I :------------+--------------.1 ¡ I I I I i i ! ! I SHUT IN TIME I SHUT IN PRESSURE 1-..------------...1----------------- --- - --- I 0.0 min ! ¡ 1,100 psi! r---rõ-riiiñ---r--------------1 1,osõ-p-ŠT"1 r--2~õ-riiiñ--f----------l--:C02s pšTl r-- 3.õñiiñ--I-----------1-:i,000 pšT"l r--4~õ-miñ--T-----------T-1;ÕÕÕ--psrl !-------------+------------..J-------. _. - I I 5.0 min : I 8S0 psi: I-------------+-------------f-- - ---~ : 6.0 min ' I 800 psi: I-----------,;,-----i-----------t--------;---i ¡--_?.:2._'!!!~___l______-______L_~!!Q.'p"~!_j L_~:2._~!..n.__l..------------j - ?!~J?..~~_J L-~:9__~!~--1__-_-_-------_L--~~~!---1 L_!Q:9__~~~__L______------j---~~'p~~_.J CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE ,'----------------,---------,----------, L______---______L_t! stks .l_~.e~~_J ! i 4 stks ! 200 psi ¡ r-------------I--- 8 stks -11",1 OÕ pšfl r------------r-12" stkš-l--'1 ,8ÕOpsi I r------------T-:¡¡fstkŠ-1--2,soõ psil r--.--------r------------,---------, I I I , ~-----------~---------~----- I 1 , t------------t-----------1-------i-~ ~ ~---------------~ - .. --------i I I r : 1-----------------t-----------1--------1 I It: t-----------------t--------------1----------i I I I I L---------L------------~----------: I I I I , I I t ~------~-----------I--------': I I I I I I I I :--------------~-------------I---------~ I I I I I I I I r----------------r-----i-----------., t----------------t---------i------------i ~-------------~-----------i---------~ , I I I I I I I r---------------~------------1---------i I I : I '*--------"--------"-------~ I I I I : I I I ~---------~--------------1-------------~ I I I I I I I , i SHUT IN TIME i SHUT IN PRESSURE r---õ~õïñ1iï--r---- - - ¡ 2~500psTl ..----------------~-------,-----------.. I 1.0 min I : 2,500 psi: :--------:.----~-------------~-_. - .-~ I 2.0 mln I : 2,SOO pSI' I------------;--+-----------i---------:" L_~.:.2..mln __L______----.l- ~,SOO ps~ I 4.0 min ! i 2,SOO psi i r---š~õÏniñ---r------! 2,SOO -psfl r--[Õ-min --T---r 2,SOO-¡;š-n r--7~õ-miñ---r- _---_mT2~50(f psrl r--ä:õ-mTñ---r--------------'-- 2,SOO psi 1 ..-----....-------------~-- - --, i 9.0 min I : 2,500 psi: j"------ - .---~-----------~---- - - - -of : 10.0 mln : : 2,SOO psi: I-----------~----I--------i----r"-f I 15.0 mln : : 2,SOO pSI: t--2"õ-:-õriilñ--t------------1-2;šoo psi! i25:õmïñ-¡----------1-2,480 psi-1 r~~~~Q~~~~~r~=~~~:~~--~J=~ð.~~_e~-n NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY TMD ITVD IDFS 3,255.0 2,615.0 16.00 AUTH MD I DAILY TANG 7,291.0 0 DAILY INT WIO MUD 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Test csg. Drillout. Do LOT. Drill ahead 2/11/2002 108,585 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 18.38 AK0226 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 2/13/2002 2,802.15 53.710 145.090 7.625 (in) @ 2,857.0 (ft) 5.500 (in) @ 8,780.0 (ft) DE~SITY(ppg)'1 9.60 I,pp I l~c~'11O.70IMUb::[)AtAlpAILYCO,~TI 0 CUMÇOST 0 FV: ,pvlYP GELS. 'WUHTHP ,FCfT.SOL' OIUWÀT,'" %Sa~dlMBT, . Ph/pM' P'/M' 'CI.: ta H2S LIME ES 52 12/20 5/9 5.31 2/ 1 /7.5 8.81 1 ) .. . .. ',''';.! '''':'1:'' ':;, ','.! . , . . .' . , ;.,' . .;.. ~: ... .'. . , . ,': . . , . .I~:::~,f¡i~~t':c~ ...... I JOB NUMBER I EVENT CODE 124 HRS PROG 2P-422 ODR 377.0 I RIG NAME & NO. I FIELD NAME I OCS NO. naborscm@ppco Nabors 19E Meltwater ACCIDENTS LAST 24 HRS.? , . . , . , WELL NAME SUPERVISOR Guy Whitlock CURRENT STATUS Drillilng @ LITHOLOGY , ' : "I, . . . . . 'Þa~~Jqt<1 : 1'-,' . . ~ .~: .: , . "'" ":: ! . I REPT NO. I DATE 25 2/20/2002 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 2,241,345 AUTH. 2,497,612 LAST BOP PRES TEST I \ ; . ;OPERATIONS SUMMARY FRQ",. . .TO :, HOURS ,CODe TROUBLE 'SUB'. ". FiHASE . DESCRIPOON 00:00 01 :30 1.50 DRILL P PULD PROD Upload MWD 01 :30 02:30 1.00 DRILL P PULD PROD Safety meeting. Load sources in MWD 02:30 04:00 1.50 DRILL P PULD PROD Finish P/U BHA and test MWD 04:00 05:30 1.50 DRILL P TRIP PROD RIH and rotate past port collar @ 982' 05:30 07:00 1.50 DRILL P TRIP PROD RIH to 2725' 07:00 08:00 1.00 DRILL P REAM PROD Wash and ream. Tag at 2765' 08:00 09:00 1.00 DRILL P CIRC PROD Circ and condition mud 09:00 10:30 1.50 DRILL P DEaT PROD RlU and test casing to 2500 psi for 30 min-OK. RID test equipment 10:30 15:30 5.00 DRILL P OTHR PROD Drill float collar, shoe track, float shoe. Clean out to 2878' and drill to 2895' 15:30 16:30 1.00 DRILL P CIRC PROD Circ and condition mud. Displace contaminated mud 16:30 17:30 1.00 DRILL P FIT PROD Perform FIT to 18.0 ppg EMW 17:30 18:00 0.50 DRILL P DEaT PROD Perform PWD baseline test and check SPP/SPR's 18:00 00:00 6.00 DRILL P DRLG PROD Drill from 2895' to 3255'. ART =3.4, AST =.5 TVD=2615 24 HR SUMMARY: P/U MWD. RIH. Test casing to 2500 psi for 30 min-OK. Drill float equipment and 20' of new hole to 2895'. Perform FIT to 18.0 ppg EMW. Drill from 2895' to 3255' .. y/~'J:.::PE~;û~~.N~~\'~~J~ANY . 1 ACI 32 Service I." """ ..!. ' .'., " ..' ,.'.C.Q~PANY.' .'.'. ConocoPhillips Company Nabors ',':,. $ERVicE :' : ,I' . :":itcNi Water, Drilling Fuel, Rig : NiA1"ERIALSJ C,ONSUMPTiON' : OS"G~ ,':'.; '", ;O:N HÁ~D>':~'" :;~: ,', '.... .' \'ITEM' ' 85 1,208 Water, Potable 900 3,530 Fuel, Camp , ,. UNItS " bbls gals . ~::," . ~ , , ,:,¡:'~:SUÞ,PORtCRAFT:<': " > ".RE~A~KS :"":,>': .. . " TYPE" 2P-422 ' DS4 G&I 580 2P-422 , ,. , ,TYPE:' 2P-417 3R-11 . . ~ .':NO." RESERVOIR NAME 2P-417 3R-11 DS4 G&I ':RESERVOIR AND'iNTERVAl'DÀTA: lONE TOP' ,BASE 0 580 0 2P-422 2P-422 2P-422 ,., ..' ~Ò~", ,I:iO~f¡s.,: " 6 9 ::. ¡ '." " ":'U$~qE':,,//:,~ : ",'~~:ÔNHAN,þ 135 1,510 .\' ~.:~ J ... >":y ,:- ':\ "..' -..' " ' .1 "-. ',' \ ~ø.': ,'" 2P-422 ,: :., R,~~ARt<$'" COMMENTS Printed: 10/1/2003 11:29:15 AM -, -. -... - - .." -" . ConoeoPhinip~;Afaska.. - , . . .Casing'Report' . Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - SIDETRACK String Type: Production Casing Hole TVD: 5,984.0 (ft) Ground Level: 225.00 (ft) Circ Hours: (hr) Pennanent Datum: KB-Datum: CF Elevation: Mud Lost: Average Pad Gmd Lvi 225.00 (ft) (ft) (bbl) (in) (ft) (ft) 25.65 (ft) Report #: Start: 1 4/11/2002 . . -. General:lnforrnation' Manufacturer: FMC Hanger Model: FMC Actual TMD Set: 7,279.92 (ft) Model: Gen V Packoff Model: FMC 1 149 1 2.89 6,362.28 10.05 1.18 19.49 0.59 10.13 310.88 6.02 435.43 31.31 0.63 62.79 0.60 Hole Size: Water TMD: Liner Overlap: KB to Cutoff: . , . C~ing Ra'~gølwellhead Item Size (in.) , . - , , IntegralCasirtg. Det~iI' , Wê!9ht .'Grade..;"Drift. Tñiêadš JTS Length' Top '~MU Torq.ITHD, Manufacturer <' Model. (Ibift) .. (in) . (ft) (ft) ~ (ft-Ibf)" . Hanger Casing Casing - Pup Jt Cross Over Baker CSR Assy Cross Over 15.50 L-80 5.500 4.825 BTC Pup Casing Marker Jt 3.500 1 3.500 9.30 L-80 2.867 BTC 10 EUE-8RD 1 3.500 9.30 L-80 2.867 BTC 14 1 2.867 EUE-8RD 1 3,500 9.30 L-80 2.867 BTC 2 3,500 2.867 EUE-8RD 1 Casing Casing w/plug catcher Float Collar Casing Float Shoe 25.65 28.54 6,390.82 6,400.87 6,402.05 6,421.54 6,422.13 6,432.26 6,743.14 6,749.16 7,184.59 7,215.90 7,216.53 7,279.32 7,279.92 ,-.",., ,.~ ": .,'" . ,..p,a.g~r,q('?:,' Spud Date: 1/25/2002 Report Date: 4/21/2002 End: 4/22/2002 Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 7,310.0 (ft) 115,000 (Ibs) 21.00 (°) 10.00 (days) '- Top Hub/Flange: (in) / (psi) BTM Hub/Flange: (in) / (psi) Cbnèt' MaX OD' Mir)ID Cómp~ Name. - (in) (in) 4.950 5 1/2" 15.5# L-8 5 1/2" 15.5# L-8 5-1/2" BTC x 4.7 4.75 Acme x 3-11 -" 3 1/2" 9.3# L-80 2.992 31/2" 9.3# L-80 3 1/2" 9.3# L-80 2.992 31/2" 9.3# L-80 3 1/2" 9.3# L-80 2.992 31/2" 9.3# L-80 Printed: 6/9/. ;0:40:36 AM , '. - , - ,-- '.- . I , . - . ~ - ." ' C,ÒóocoPhil'ipš:~Alàska " .,Casing:Røport, ';: - . " '~.", ,'" '. , , Page2'ò(2, Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - SIDETRACK Report #: Start: 1 4/11/2002 Spud Date: 1/25/2002 Report Date: 4/21/2002 End: 4/22/2002 , " Non~lntegrat pasing. 'Accessories' Accessory Manufacturer , Nurribet 'SpaCil1g (ft) . . Intérval ' , HowFiXéd Top {ftr ' Bottom {ft} . Bowspring Centralizer Bowspring Centralizer Centering Guides WEATHERFORD WEATHERFORD WEATHERFORD 26 16 23 3.5" X 6.5 5.5" X 6.7 5.5" X 6.5 -.........~ ' Rerrfátks Batch mixed cement. Pumped 60 bbls CW 100,40 bbls Mud push, and 69 bbls "G" with gas blok at 15.8. Displaced cement with 9.6 brine at 4 bpm. Pressure i!}.CI~d from 150 psi-1100 psi as the cement started coming up annulus. When the plug entered the 3-1/2" casing the psi increased from 1100 psi to 2200 psi. Slowed pumps down to $, bpm and pontinued pumping. Did not bump plug(calculated volume} but psi increased from 1450 pis to 1750 psi. Floats held CIP @ 1530. Checked vac trucks to confirm the co ét volum~ had been pumped and it had. From the pressure increase as the cement was coming up the back side. it appears the cement should be as calculated with the top at +/-59~,. No returns entir~jo6. { /~ ~-_/P'~ -- Printed: 819/, .0:40:36 AM ) " .. .' .QonocophUlips AI~ska . . . , . . . 'q~m~ntiÍ1gRep,ørt Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - SIDETRACK Hole Size: TMD Set: Date Set: Csg Type: Csg Size: P.rimary 6.750 (in) 7,280 (ft) 4/21/2002 Production Casing 5.500 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: : Time End: : Type: Cement Casing Volume Excess %: Meas. From: Time Circ Prior To Cementing: Mud Circ Rate: (gpm) Mud Circ Press: (psi) ) Page 1.013 Report #: Start: Spud Date: 1/25/2002 1 Report Date: 4/21/2002 4/11/2002 End: 4/22/2002 Cement.Job Type: .Prin:télry ,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: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe'Movement Pipe Movement: No movement Cementer: Kevin Anderson RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 30.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) ,Stage No: 1 of 1 Start Mix Cmt: 13:00 Start Slurry Displ: 13:45 Start Displ: 14:15 End Pumping: 15:30 End Pump Date: 4/21/2002 Top Plug: N Bottom Plug: Y Type: Non-Dìsp. LS Density: 9.5 (ppg) Vise: 36 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Brine Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 4.00 (bbl/min) 4.00 (bbl/min) N 1,750 (psi) (psi) (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: 0 Total Mud Lost: 160.00 (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch Density Meas By: PVIYP: 9 (cp)/9 (lb/100ft2) Gels 10 see: 3 (lb/100ft2) Gels 10 min: 5 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 160.00 (bbl) Mud Data . , Stage NO:,1',Slurry No: 1 of 3' To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/9/2003 10:41 :00 AM ') ) . . ' , .... . . COnocoPhiUipS A(åS~~.:'. . . . . CélTl~i1ting: Repørt . Pagé2 of 3 Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - SIDETRACK Report #: Start: Spud Date: 1/25/2002 1 Report Date: 4/21/2002 4/11/2002 End: 4/22/2002 Stáge No:.1 SlurryNö: 2.'of 3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 12.00 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: 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) 'Stage No: 1 Slurry.No: 3 of 3 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 7,280.00 (ftJTo: 5,920.00 (ft) Cmt Vol: 69.0 (bbl) Water Source: Slurry VoIB25 (sk) Class: G Density: 15.80 (ppg) Yield: 1.20 (ft3/sk) Water Vol: 41.0 (bbl) Other Vol: 0 Purpose: Mix Water: 5.30 (gal) Foam Job: N Test Data Thickening Time: 3.47 Free Water: (%) Fluid Loss: 14.0 (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) St~ge No: 1 Slurry No:'3 of 3 ~Additives Trade. Name Type DISPERSANT GYPSUM RETARDR MID-T . Concentration 0.30 3.00 0.02 Units Liquid Conc. Units D-6S D-53 D-800 Printed: 6/9/2003 10:41 :00 AM ) ) , . , . . . .. .' , ,'.QónocoPhUlipsAlaskä', ,:', . . . . Cèli1enti ng. . Report ., . :':P~ge 3" of 3 Legal Well Name: 2P-422 Common Well Name: 2P-422 Event Name: ROT - SIDETRACK Report #: Sta rt: Spud Date: 1/25/2002 1 Report Date: 4/21/2002 4/11/2002 End: 4/22/2002 Casing Test' Shoe Test : Liner T~p 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 10:41 :00 AM ) ) ," '.1 \ ".. .". .PhnHp~AI~s~:a~ ~n'c'. Dålly DriHhig Report . PagEl1.of2' I JOB NUMBER I EVENT CODE 124 HRS PROG 2P-422 RST SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. D. Wester/ J. Pyron NORDIC 3 n1433@ppco.com 3 Meltwater CURRENT STATUS ACCIDENTS LAST 24 HRS.? Rig up to test tubing and annulus. TMD I TVD I DFS 7,310.0 5,984.0 10.00 AUTH MD I DAILY TANG 7,291.0 0 DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 4/20/2002 139,881 I LEAKOFF AFE AUTH. AK0226 1,621,729 I NEXT CASING LAST BOP PRES TEST 3.500 (in) @ 6,402.0 (ft) 4/19/2002 0 I CUM,.COST.I 0 PflMf CI ' 'Ca' H2S LIME ES 1 1 REPT NO. I DATE 11 4/21/2002 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1,446,931 WELL NAME 24 HR FORECAST Ld & space out.ND/NU tree.Test tbg & annulus.Shear. Frz prt. LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 4/19/2002 7,228.03 29.000 170.110 5.500 (in) @ 7,280.0 (ft) DE"'SITY(ppg) I 9.50 I PP I I ECD I MUD DATAl. D.ÅILY COST I FV PVNP GELS WUHTHP Fcrr.SOL' OIUWAT %Sand/MBT Ph/pM. 36 9/9 3/31 5.8/ 1 / /4.5 9.6/ OPER~TIONS'SUMMARY FROM 'TO HQURS CODE TROUBLE SUB, PHASE 'DES(:RIPTION 00:00 03:00 3.00 CASE Np DH OTHR PROD Continue pulling out of hole. Laid down a total of 40 its. Well swabbing 03:00 03:30 0.50 CASE Np DH OTHR PROD Monitor well 03:30 04:00 0.50 CASE Np DH OTHR PROD Make up top drive to 5-1/2" btc casing. Rotate at 15 rpms,5200 ft Ibs torque, 1.5 bpm with 480 psi. No returns. 04:00 06:00 2.00 CASE Np DH OTHR PROD Rig down tbp drive and rig up to run casing. 06:00 07:00 1.00 CASE Np DH OTHR PROD Clean LCM from pumps. 07:00 11:30 4.50 CASE Np DH RUNC PROD Run casing back to bottom. Ran 149 its 5-1-2" casing and 27 its 3-1/2' casing. Up wt-115K, down wt-65K 11:30 12:30 1.00 CASE P CIRC PROD Lay down fill up tool and make up cement head. Attempt to break circulation No success. Pumped@ 2bpm-650psi, 3bpm-700 psi, 4 bpm-770 psi with no returns. Pumped 50 bbls into formation. 12:30 15:30 3.00 CEMENT P DISP PROD Batch mix cement. Test lines 3500 psi. Mix and pump 60 bbls CW 100,40 bbls, 69 bbls (325 sxs) "G" with gas blok@15.8. Displace 9.6 brine with rig pumps at 4 bpm. As cement started coming up backside pressure increased from 150-1100 psi. When the wiper plug went inside the 3-1/2" casing, the psi increased to 2200 psi, slowed down pumps to 3 bpm , psi drop to 1450 and increased to 1750 before stopped pumping. The plug did not bump, but we went off calculated strokes after we saw the plug enter the 3-1/2 casing and did not over displace. Float held. Checked vac truck to confirm the correct volume had been pumped. 15:30 16:30 1.00 WELLSR P PLGM PROD Rig down casing tools. Install and test packoff 5000 psi for 10 minutes. Good test. 16:30 00:00 7.50 CMPLTN P RUNT CMPL TN Rig up and run tubing per well plan 24 HR SUMMARY: Ud 40 its. Attempt to cir w/top drive. Run csg to btm. Attempt to cir. No returns. Batch and pump cmt. Plug did not bump. Floats held. Install packott. Run tbg COMPANY Nordic Catering Phillips Baker Intec SERVICE P.ERSONNEL'DATA NO. HOURS COMPANY 2 Bariod 2 APC 1 GBR 3 SERVICE HOURS NO. 3 1 2 Printed: 6/9/2003 11 :00:50 AM WELL NAME ITEM Rig Fuel Rig Water TYPE. 2P-415 . RESERVÖIR NAME . , 2P-415 2P-415 2P-422 UNiTs gals BSI NO. 900 2P-422A 2P-422A Heavenly ') . . . .. . ,~hilliPs. :~I~~~~t I~Ç'." . .D.any:DrUHn~.R.e.p().rt, . I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD RST 7,310.0 . MATERIALSIC()NSUMPTION . ON HAND . ITEM . 4,340 Camp Fuel 192 Camp Water USAGE 1,135 434 REMAÀKS SUPPORT CRAFT', . '''TYPE' 2P-415 . RESERVOIR AND INT:ERVALDATA Zo"NE TOP BASE.. 900 0 ) NO. I , ," .. , . '" . . . Page 2 bf2/ TVD DFS REPTNO. I DATE 5,984.0 10.00 11 4/21/2002 U~IT$ gals bbls USAGE! ON HAND. 2,375 51 38 , REMARKS Heavenly COMMENTS . Printed: 6/9/2003 11 :00:50 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-422ST Date: 4/22/2002 Supervisor: Pyron 0 Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 5.5" X 7.625" Casing Setting Depth: 2,8781 TMD Hole Depth: 2,8781 TMD 2,3541 TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 01 EMW= Leak-off PrBssllnj Press. + Mud Weight = 700 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,354' EMW for open hole section = 15.3 ppg Pump output = 0.0583 bps Fluid Pumped = 3.2 bbl 1.200 psi 1.100 psi 1.000 psi 900 psi 800 psi W 700 psi r a:: :J CJ) 600 psi CJ) W a:: 500 psi a. . 400 psi 300 psi 200 psi 100 psi OpSI~ ITIME- u~. ....~... I ONEMiNuTE;nCKS . . J.: ~ :::: ..., 0 -+- LEAK-OFF TEST -tll-CASING TEST -- LOT SHUT IN TIME -:k- CASING TEST SHUT IN TIME - . I I ~ ~ ~ 8 ~ goo ~ ro .. '" ~ ~ ... 0 fñ <n 0 '" '" ~ g: ë; ¡;; STROKES NOTE #1: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT- STROKES PRESSURE r---------------'----Õstks---T-opsi---l :----------------+---------------f-------------~ : : 1 stks : 290 psi: '----------------+---------------t---------, ¡ : 2 stks : 470 psi: ¡---------------r--3--štks!-Š9Õ-ps¡---1 r------____-_mr--4stks---î-jso-ps¡---1 r-------------r--Š-stks---r--jsõ-pš¡---l r--------------r--Ef-štks---r-jsõ-pSi--l r---------------r--=;stks--l--jsõ.psf--l :--------------+--------------..-----------------~ I : 8 stks : 750 psi: I---------------+---------f-----------------~ : : 10 stks : 750 psi: ----------------+--------------t-----------i L____________l__~_~_~!~--_.?~~~!_--j ! i 14 stks i 750 psi i ¡--____m_____-I--:¡-è-stks-I---74õ-pš¡---1 ¡--------------r-rã-štk-Š-¡-74ops¡---1 ¡-----______m-r-2Õstkš-l-j3"õ-psi --1 ¡-__m_____---:--25 štï<š-!- 72Õ-ps¡---1 :---------------+------------..--------~ : : 30 stks : 720 psi I :---------------+-------------t-------------~ : I 35 stks : 720 psi I :--------------+---------------t--------------i : I 40 stks : 720 psi: ¡--------------¡---45siks--r-12õ-psr-1 -------------r--SÕ-stks--¡-j2õ-psr--1 r-------------I--SS-stkS-1---72õpsr--l I----------------T-----------¡----------------' i----------------~ f i I I I J ¡ SHUT IN TIME i SHUT IN PRESSURE I---------~--+-------------r-----------:---"T I 0.0 mln : I 630 pSI: :---------~-+--------------t-----------,;--i L_!:9._I]]~_1____--____1___?6~_I?.~!.._1 L_~:9.._m i~-_.l_--______1_~~0 'psi --.1 L- 3.9..-I]]!~--L--________L-~6~ ps! - j L-~:9.._I]]~---Lm_--------L-~?O psi J ! 5.0 min ! ! 550 psi! 1-------------...-------------.,.--------., 6.0 min : : 540 psi: :------------+--------------+--------~ I 7.0 min I : 540 psi: 1---------,;,----+-------------+ - ----:---~ : 8.0 mln : I 540 pSI: :----------;o---+------------t-----------;---i : 10.0 mln I : 540 pSI: !=_!~~~~rñ[~~I~~=~=~=~[=~~Ë:;i --J CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r------------r--o stkST- 0 psi ---1 ~--------------~--------------~--------I 1 I I I ~-------------i---------------i------------i I I I I . I I I ~--------------r------------1-------------1 I I I I L____________L______------_J_---- -- ------J 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 "----------r--------------~-----------., I , I I I I I I ~--------------~--------------~----------_.! I I I ~------------t-----------I--------------1..~ ~-------------t---____-n -1 - -----i I , , t . I I I I.---------______L______-.I ---.I I I I I I I I I I I I I ~---------------a.-----------..I---------" I I I I I I I I I I , , "-----------Þ-------------I------------I . . . . : I I I "'---------------~-------1----------1 , I . , I I I . I I I I ....--------------r----------------,------------, I I I I I I I I ~-------------4------------~---------I I I I I ~------~-----------i------------i I I I I ~--------~-------------i--------------i I I I I I I I , "'----______L______---_.I_-------~ , I I I I I I I i ¡ ! ! : SHUT IN TIME I SHUT IN PRESSURE "-------------Þ---------~ -- -- ------"'t. L- o.q_~l!!_--L--------j--__g_psi ...J i 1.0 min ! i ! r 2.0- miñ--T--------------r--------l :--------.-----~----------~-------------~ ¡ 3.0 mln : : : r---.iõ-rñlñ---t------------¡-----------i I---------_.~--~--------------t---------- : 5.0 mln : : .,,' :-------.-----:-------------1--------"I~ I 6.0 mln : : I ---------------"---------~-----------_..a ¡ 7.0min ! ! ! ~----~-----------~--- - ..... i 8.0min ! ! ¡ "'---------"------------1-----------"'" i 9.0min i i ! r---------r-------------,------...., ¡ 10.0min I : : r------~--~---------~----------'" ! 15.0 mln : : : r--2Õ.0 min -¡---------1- --- -¡ r- 25:Õ-ñiTñ--t - -- ---- 1 - --~---¡ r-- 30 :-Õ mlñ--¡-----¡-----------¡ ~--------..------------..---------~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY . .':Z::~t~~r~~1jk...'. . . I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS ., 2P-422 RST 7,310.0 5,984.0 11.00 I RIG NAME & NO, I FIELD NAME I OCS NO. AUTH MD I DAILY TANG NORDIC 3 n1433@ppco.com 3 Meltwater 7,291.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 4/22/2002 238,227 I LEAKOFF AFE AUTH. AK0226 1,621,729 I NEXT CASING LAST BOP PRES TEST 3.500 (in) @ 6,402.0 (ft) 4/19/2002 0 ,CUM COST 0 PflMf CI.. Ca. H2S LIME 'ES / ) . " , . ~', .';' . , ~ ---: , . WELL NAME SUPERVISOR J. Pyron CURRENT STATUS Released rig at 1200 hr. 24 HR FORECAST ) . , " .. L . . '." ¡ ~:~;\ .::~~., ..;. - ~ . : . .. . ~. .~ ?,!:.'. ., . ~ , . ',' '- - :.,.. ,~. I REPT NO. [DATE 12 4/22/2002 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1,685,158 Move rig to 2P-427 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 4/19/2002 7,228.03 29.000 170.110 5.500 (in) @ 7,280.0 (ft) ,DE~SriY{p'pg) I 9.50 I, pp I I~CDI IMOD,DATAI:DÀ'LXçO~TI F~ PVIYP GELS WUHTHP Fcrr.SOL ' OIUWAT' "%SandJMBT' ,Ph/pM. 36 9/9 3/31 5.8/ / / /4.5 9.6/ FROM TO HOURS CODE. TROUBLE SUB' 00:00 01 :30 1.50 CMPL TN P RUNT 01 :30 02:00 0.50 WELLSR P PLGM 02:00 04:00 2.00 WELLSR P NUND 04:00 05:00 1.00 WELLSR P NUND 05:00 05:30 0.50 WELLSR P . PLGM 05:30 06:30 1.00 WELLSR P DEOT 06:30 08:30 2.00 WELLSR F FRZP 08:30 09:30 1.00 DRILL P LOT 09:30 12:00 2.50 WELLSR P FRZP OPERATIONS :SUMMARY PftASE ' ' , . DESCRIP1l0N , ' . CMPL TN Finish running 200 jts L-80 EUE Mod tubing. Locate seals, space out and lane hanger. CMPL TN Lay down landing jt and install two way check. CMPL TN ND bop's CMPL TN NU FMC 3-1/8 5M GEN V tree. Test hanger and tree to 250/5000 psi. good test. CMPL TN Pull two way check and rig up to freeze protect CMPL TN Pressure test tubing to 500 psi for 15 minutes. Test 3-1/2" x 5-1/2" annulus to 3000 psi for 30 minutes. Recorded on chart recorder. Sheared out of shear valve with 3100 psi. (set for 3000 psi) CMPL TN Freeze protect 3-1/2" tubing and the 3-1/2" x 5-1/2" annulus to 2000'(45 bbls) CMPL TN Perform Lot on the 5-1/2" x 7-5/8" annulus (injection)with 9.6 brine. Formation broke down with 700 psi. EMW= 15.3 ppg. Injected 3 bbls into formation. CMPL TN Freeze protect 5-1/2" x 7-5/8" with 40 bbls diesel. 2000'. Set BPV. Secure well and release rig. 24 HR SUMMARY: Land& space out. Lnd hgr. ND bops. NU and test tree. Freeze protect annuli. Set bpv. Release rig. . I ";MATERIALSI CONSUMPTION " . 'USAGE ' ''ON' HAND" " "', ':, ': I'1'EM .,., " 532 8,808 Camp Fuel 49. 143 Camp Water , SUPP'ORT CFI'ÃFT' TYPE 2P-415 , COMPANY Nordic Catering ConocoPhillips Company Baker Hughes Inteq SERVICE . , .' rretJ....", " Rig Fuel Rig Water UNITS gals BBI TYPE 2P-415 REMARKS NO. 280 2P-422A '';PERSONNELÒÁTA,', , 'NO." 'HOURS' ,,' ",",COMPANY . ", ,"' ¡ 2 Bariod 2 APC 1 GBR 3 , , , ,"., . SERVICE' ','.,NO.' 3 1 2 ttOtJl;iS ' . ' ,UNITS gals bbls ,U$ÄGE , "q¡¡ÚiAND 2,375 45 6 NO. 290 Heavenly REMARKS RESERVOIR NAME 2P-415 2P-415 RESERVOIR AND INTERVAL DATA ZONE, TOP BASE 280 290 COMMENTS 2P-422A Heavenly Printed: 9/19/2003 1 :25:08 PM ') M____""""----,,,,,,-------,-- ) -~-~..~_~_£~f~~_!_~-~ P_~,---~_!_~~_k a , I_~_~Oo'~- Well: 422A Location: North Slope, Alaska Created by hnaUuk Oat. plotted: 30-Jun-:200J Plat R«3forance I. t.4WD <2878 - 7310'>. Coordlnatu 0,.. In feet ~.r'M' -lot '..22. Tru. VarUCQI Doptha an raf.nlneo RKB(Nordlc 3). -tI: 0000000000"''''00'0000''''''00..'.!:\'.~~9.............................................. Structure: Drill Site 2P Field: Meltwater Scole 1 Inch ~ 100 It gOO eoo 700 600 !OO 400 JCD 200 100 0 East (feet) -> 100 200 300 "00 SOD 800 700 800 900 1000 1100 1200 1300 ,..00 1500 1ðOO 1700 1800 UtOO 2000 2100 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 I I I I I I I 700 S it \\ \~~- \ \ \ ''':::'::'--'''",--"" \ \ '\ '~~=~~,--------------- . ~ \ \\ \ ',~"--.'--.,'....., -.----- -----!!lV. \ '~''------.,'' . ~ ~ I "Oo',,~ 00 S. 715/8 csc -1000 ~ \ ~ \0 ~ .,-, I \ I \ I \\ ! \ I I \ I \ ~ ~ I I I I I I I I I I I t I I I I I I @_._-:;;:;~~:::?,..- ~/:/ ~.. i/ ¡ / II / I f / f 7.~= J 1/ /J. I I / ! I / I; / \ \ \ \ ~ ~ 00 000 II -4<)0 8 ;:I> I -1100 Y -10100 \ \ ) ) ConocoPhillips Alaska, Inc. Drill site 2P 422A slot #422 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 <2878 - 7310'> Our ref: svy6744 License: Date printed: 30-Jun-2003 Date created: 16-Apr-2002 Last revised: 21-Apr-2002 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.663,w150 26 51.900 Slot Grid coordinates are N 5868975.305, E 444049.453 Slot local coordinates are 900.33 S 2092.34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet ') ) ConocoPhillips Alaska, Inc. Drill site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 1 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 Reference wellpath Object wellpath : MWD <3660 - 1l075'>,,415,Drill Site 2P M.D. T.V.D, Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 28~'¡8.0 2388.2 1007.6S 690.9E 3554.5 2388.2 911. 2S 2080.4E 86.0 .1392.8 843.3 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ) ) conocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 Reference wellpath Object wellpath : MWD <5552 - 9038'>,,415A,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2858.0 2388.2 1007.68 690.9E 3554.5 2388.2 911.28 2080.4E 86.0 1392,8 843.3 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ) ') ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-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 28!58.0 2388.2 1007.6S 690.9E 2388.4 2388.2 6,4N 33.5E 327.0 1208.5 1208.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ) ) ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 4 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-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 2858.0 2388.2 1007.68 690.9E 2478.1 2388.2 282.58 1122.5W 291.8 1953.0 1884.2 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level) . ) ') ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater, North Slope, Alaska CLEARANCE LISTING Page 5 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-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 Horiz Dist Min'm Dist 28:j8.0 2388.2 1007.6S 690.9E 2608.7 2388.2 807.2S 549.8W 279.2 1256.8 1254.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level) . ) ) ConocoPhillips Alaska, Inc. Drill site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-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 2858.0 2388.2 1007.6S 690.9E 2863.2 2388.2 1225.9S 694.7W 261.0 1402.7 1294.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ) ') ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 7 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 Reference wellpath Object wellpath : MWD <0 - 9685'>, ,431,Drill Site 2P Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2858.0 2388.2 1007.68 690.9E 3002.6 2388.2 1474.48 260.7W 243.9 1059.9 962.7 ~,.,~,,~',"L""""'''~' Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level) . ') ') ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 8 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-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 28~.iH.O 2388.2 1007.6S 690.9E 3047.4 2388.3 1459.08 314.5E 219.8 587.7 512.3 ----- Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ) ) ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 9 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 Reference wel1path Object wellpath : MWD <0 - 6008'>,,417,Dril1 Site 2P M,D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2858.0 2388.2 1007.6S 690.9E 2389.8 2388.2 22.3N 123.0E 331.1 1176,1 1174.0 .---- Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level) . ) ) ConocoPhillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska CLEARANCE LISTING Page 10 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 Reference wellpath Object wellpath : MWD <0-8974'>,,429,Drill site 2P Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2858.0 2388.2 1007.68 690.9E 2885.5 2388.2 1317.88 97.8E 242.4 669.3 654.0 .--- Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot i422 and TVD from RKB(Nordic 3) (254.00 Ft above mean Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ) ) ~ ¡~..:-'r:~ PHilliPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 31,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2P-422A (202-067) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater we1l2P-422A. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sincerely, ~ 'C I " "\.....:.-- R. Thomas Greater Kuparuk Team Leader P AI Drilling RT/skad RECEIVED JUN 0 5 2002 Alaska Oil & Gas Gons. CommiSSIon Anchorage \ (~~ ~ t; \ 1\ L OR Gt\~f'~\ ) STATE OF ALASKA ), ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of \/Veil at surface 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UMr.:'''è6Mr,;...t[!¡-t¿~Tl. At Top Producing Interval ~ ,3~'E ~ 1124' FSL, 1895' FEL, Sec. 17, T8N, R7E, UM'~'S " ,:D. ~ ~--~ At Total Depth ~ V~j J 921' FSL, 1855' FEL, Sec. 17, T8N, R7E, UM t::--..:..;...:-_,.:.,.,:.,' (ASP: 445364, 5865507) 5, Elevation in feet (indicate KB, DF, etc,) 6. Lease Designation and Serial No, RKB 27' feet ADL 373112 12. D)!1~;Jdjed, 3 ' 13. Date T,D. Reached 1~. Date.ç~~: Susp. Or Aband. -,(fobruary 3', 2Ó02 "tlJ April 19, 2002 íW<1 ~priI2~, !002 ..AD 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 7310' MD 15984' TVD 7185' MD 1 5875' TVD YES 0 No 0 0 0 Abandoned 0 Service 0 Suspended Classification of Service Well 7. Permit Number 202-067 8. API Number 50-103-20400-01 'P:. ';;'; :..;~~~~.. .. t~~i'~:~ ~, ' :¡; ,~ r;.: (ASP: 444049, 5868975¡" t / I. 22. Type Electric or Other Logs Run GR/Res/Neu Dens, PWD 23, 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2P-422A 11. Field and Pool Kuparuk River Field Meltwater Pool 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set Cameo Nipple @ 512' MD 16. No. of Completions 1 21. Thickness of Permafrost 1495' (approx) GRADE B L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 120' Surface 2857' Surface 6401' 6401' 7280' CASING SIZE WT, PER FT. 62.5# 29.7# 15.5# 9.3# HOLE SIZE 16" 42" 7.625" 9.875" 6.75" 5.5" 3.5" 6.75" 24, Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 6872' - 6882' MD 5603' - 5612' TVD 6 spf CEMENTING RECORD 45 sx AS 1 316 bbls AS3 Lite & 81 bbls LiteCRETE AMOUNT PULLED 325 sx Class G (included above) 3.5" balanced plug from 2557' to 2996' TUBING RECORD DEPTH SET (MD) 6402' PACKER SET (MD) N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug #1: 2557' - 2996' 26 bbls Class G frac: 6872' - 6882' placed 285M# proppant in formation, 10 ppa on perfs, left 1000# proppant in wellbore 26, 27. Date First Production May 9,2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Production for OIL-BBL GAS-MCF 808 634 OIL-BBL GAS-MCF 2691 2996 CORE DATA 5/13/2002 6 hours Flow Tubing Casing Pressure press, 266 psi 937 28. Test Period> Calculated 24-Hour Rate> WATER-BBL 0 W A TER-BBL 0 CHOKE SIZE 99 OIL GRAVITY - API (corr) not available GAS-OIL RATIO 1113 Brief description of lithology. porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chiPs'R E C E , V E D None Form 10-407 Rev, 7-1-80 .JUN 0 5 2002 Alaska Oil & Gas Cons. LO/lllim:is'or Anchorage CONTINUED ON REVERSE SIDE r,. I;". ,Ó¡ ~ R B D M 5 B F l \T\~ ~ ~ ~t........... JlJN Submit in duplicate '" Î-- t <-:. 6 2002 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. T-3.1 T-3 T-2 6650' 6776' 7004' Annulus left open - freeze protected with diesel. RECEIVED 'JUN 0 5 2002 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. lJaslà1 Oil & .Gas Cons. vUII U III,':>,':'" , Mchora 98 Questions? Pat Reilly 265-6048 Signed ~~. - Title Randy Thomas Kuparuk Drilling Team Leader Date =>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. Item 28: If no cores taken, indicate "none". Form 10-407 \ ~ , ,. r, i' f i u i c."~ ) ~ ~ ) PHILLIPS ALASKA INC. Operations Suml11aryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - SIDETRACK NORDIC 3 n1433@ppco.com Nordic 3 Date From.. To Hours Code Sub Phase Code 4/11/2002 10:00 - 12:00 2.00 MOVE MOVE MOVE 12:00 - 14:30 2.50 MOVE MOVE MOVE 14:30 - 15:30 1.00 DRILL CIRC SURFAC 15:30 - 16:30 1.00 WELCTL NUND PROD 16:30 - 21 :00 4.50 WELCTL NUND PROD 21 :00 - 00:00 3.00 DRILL PULD PROD 4/12/2002 00:00 - 00:30 0.50 WELLSR PULD REENTR 00:30 - 05:00 4.50 WELCTL BOPE REENTR 05:00 - 06:00 1.00 RIGMNT RSRV REENTR 06:00 - 07:00 1.00 DRILL OTHR REENTR 07:00 - 12:00 5.00 DRILL PULD REENTR 12:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 21 :00 1.00 DRILL TRIP REENTR 0.50 DRILL CIRC REENTR 1.00 CASE DEOT REENTR 6.50 CEMENT COUT REENTR 21 :00 - 22:00 1.00 DRILL CIRC REENTR 22:00 - 00:00 2.00 CEMENT COUT REENTR 4/13/2002 00:00 - 02:00 2.00 CEMENT COUT REENTR 02:00 - 02:30 0.50 DRILL DRLG PROD 02:30 - 03:30 1.00 DRILL CIRC PROD 03:30 - 06:00 2.50 DRILL LOT PROD Page.t of 5 Start: Rig Release: Rig Number: 3 Spud Date: 1/25/2002 End: 4/22/2002 Group: 4/11/2002 Description of Operations. Move rig f/ 2P-431 To 2P-422A sidetrack. Sp ot rig over well & level. Accept rig @ 1200 h rs 4/11/2002 Spot equipment & tanks, R/U Hand-V-Berm, Let down traps, C/O save sud on top drive ( 4" HT38). Pull BPV "0" psi TBG & Annulus. R/U Circulating Manifold to tree & annulus. Pump down 3-1/2" kill string set @ 1681' w/ hot water 100? displace freeze protection di esel f/ 7-5/8" x 3-1/2" annulus. total of 100 bbl's till fluid coming back clear and 65? R /D lines and set 2 way check. N/D 3-1/8" 5M production tree N/U tripple gate w/ Hidrill 11" 5M BOPE. Ch ange pipe rams to 4" top & bottom. Shell tes t. M/U landing jt. Pull hanger to rig floor. Up wt 33k .5 bbl to fill hole. Pull & lay down 3- 1/2" kill string 1681' total of 54 jts. Unload Pipe shed 54 jts of 3-1/2" 9.3# L-80 EUe 8rd mod tbg pulled f/ well. Install test plug. PT BOPE 250/3000 psi Service top drive, C/O grabber set torque & service rig Set wear ring 9-1/16" ID. Clear rig floor. PJSM. P/U M/U 6-3/4" BHA as per programed in well plan. Up load MWD tools. RIH shall ow test MWD @ 300' RIH rotate thru Tam po rt collar @ 982' RIH on 4" HT38 DP tag cement @ 2696' CBU w/ sea water at 5.2 bpm 890 psi PT Casing to 2500 psi for 30 min O.K. C/O cement from 2696' to 2872' 15' below 7 -5/8" csg shoe. 2500/2800 ft/lb torque. 40 r pm. Off btm 1250 psi, On btm 1500 psi 106 spm up wt 65k dn wt 60 k Circ btms up pumped sweep, Switch to 10.0 ppg LSND mud displace @ 6 bpm 1400 psi. 3 500 ft/lb @ 80 rpm. Shut dn clean #1 mud ta n k. Continue to C/O cement f/ 2872' to 2907' MD 2435' TVD Continue to C/O cement in oprn hole f/ 2909 , to 2952' KOP for side track. Still getting 1 00% cement cuttings. Kick off to lowside of hole f/ 2952' to 2997' Started getting formation cuttings. Stop for LOT. CBU and condition mud for LOT. 7.2 bpm @ 1950 psi. Mud wt 10 ppg Run LOT @ 2997' MD 2467' TVD Mud weight 10.0 ppg. Leak off @ 12.2 ppg EMW. Break down @ 13.6 ppg EMW. Printed: 5/10/2002 10:03:06 AM ) (~~ ~ 1~ ~ ') Page 2015 PHILLIPS ALASKA INC. Operations SUrnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - SIDETRACK NORDIC 3 n1433@ppco.com Nordic 3 Date Sub From - To Hours Code Code Phase 4/13/2002 0.50 DRILL TRIP PROD 06:00 - 06:30 06:30 - 07:00 07:00 - 09:30 0.50 RIGMNT RSRV PROD 2.50 CEMENT TRIP PROD 09:30 - 11 :30 2.00 CEMENT TRIP PROD 11 :30 - 13:00 13:00 - 14:00 14:00 - 14:30 1.50 CEMENTCIRC PROD 1.00 CEMENT SFTY PROD 0.50 CEMENT PUMP PROD 14:30 - 15:30 1.00 CEMENTTRIP PROD 15:30 - 22:00 6.50 CEMENT SQEZ PROD 22:00 - 23:00 1.00 CEMENTTRIP PROD 23:00 - 00:00 1.00 CEMENT PULD PROD 4/14/2002 00:00 - 00:30 0.50 CEMENTTRIP REENTR 00:30 - 03:30 3.00 CEMENTTRIP REENTR 03:30 - 04:30 1.00 CEMENTTRIP REENTR 04:30 - 05:00 0.50 CEMENT COUT REENTR 05:00 - 08:30 3.50 CEMENT COUT REENTR 08:30 - 10:00 1.50 CEMENTCIRC REENTR 10:00 - 12:00 2.00 CEMENT COUT REENTR 12:00 - 14:30 2.50 DRILL DRLG REENTR 14:30 - 15:30 1.00 DRILL CIRC PROD 15:30 - 17:00 1.50 DRILL LOT PROD 17:00 - 20:00 3.00 CEMENTTRIP PROD 20:00 - 23:00 3.00 CEMENT PULD PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 4/11/2002 Spud Date: 1/25/2002 End: 4/22/2002 Group: Start: Rig Release: Rig Number: 3 Description 01 Operations Blow down top drive. Pull into 7-5/8" casing shoe @ 2857' MD. Service rig POOH to squeeze 7-5/8" csg shoe @ 2857' M D 2390' TVD. POOH I?A down BHA #1 Down I oad MWD. PJSM Remove sourses fl LWD. L/ D Motor Clear floor load pipe shed wi 16 jt's 3-1/2" 9.3# L-80 tbg/ M/U 3-1/2" mule shoe jt, P/U 16 jt's 3.5" tbg stinger 522' RIH on 4" HT38 Bp to 2995' Circulate and wait on Dowell cemnt crew. PJSM R/U Dowell cement crew. Pump 8.5 bbl's water ahead PT lines to 3500 psi. Mix and pump 25 bbl's Class 'G' cemen t @ 15.8 ppg, Followed by 3 bb's water. Swi tch to rig pump and displace cement w/ 20 b bl's of 10.0 ppg mud. CIP @ 1421 hrs 4/13/2 002 POOH slowly to 2400' 75' above estmatied t op of cement. Circulate long way surface to surface @ 7.5 bpm Squeeze away 5.6 bbl's over 5 hrs. Continue to hold 700 psi till 2200 hrs. POOH stand back 4" HT38 DP LID 16 jts of 3-1/2" 9.3# L-80 Eue 8 rd tbg t bg stinger. Clear rig floor to P/U BHA# 1 M/U BHA #1 PJSM upload LWD-MWD shallow test @ 330' RIH wi HWDP & Jars RIH on 4" HT38 DP to 2430' Circulate and wash down to 2608' Taged ce ment. Shur down pumps set 5k down on cem ent O.K. C/O cement f/ 2608' to 2750' 1600 psi @ 10 1 spm, 1600 ft/lb torque @ 30 rpm. CBU PT 7-5/8" csg to 2500 psi Lost 100 psi in 30 min. Continue to C/O cement to 2878' K.O.P. Sidetrack f/ 2878' appears to be off @2900'. Drilled 30' new hole. CBU pump sweep around for LOT LOT @ 2930' MD 2430', TVD w/ 10.0 PPG mu d. LOT 12.1 ppg EMW, Break down 12.7 ppg EMW POOH to recement 7-5/8" shoe. PJSM Dn loa d LWD-MWD tool L/D same. P/U 522' of 3-1/2" 9.3# L-80 Eue tbg stinger . RIH on 4" HT38 DP. Geologist confirm we are in the C80 sand 2410' TVD top. POOH LI D stinger. Cancel cement JOB. Will continue drilling ahead w/ 6-3/4" hole. P/U BHA # 1 PJSM Upload LWD-MWD RIH sh Printed: 5/10/2002 10:03:06 AM ) ¡;~,. ~ ) Page 3 of5 PHILLIPS ALASKA INC~ Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - SIDETRACK NORDIC 3 n1433@ppco.com Nordic 3 . Date From -To Hours Code Sub . Phase Code. 4/14/2002 23:00 - 00:00 1.00 DRILL TRIP PROD 4/15/2002 00:00 - 03:00 3.00 DRILL TRIP REENTR 03:00 - 00:00 21.00 DRILL DRLG REENTR 4/16/2002 19.00 DRILL DRLG PROD 00:00 - 19:00 19:00 - 20:30 1.50 DRILL CIRC PROD 20:30 - 21 :30 1.00 DRILL WIPR PROD 21 :30 - 22:30 1.00 DRILL WIPR PROD 22:30 - 00:00 1.50 DRILL WIPR PROD 4/17/2002 00:00 - 00:00 24.00 DRILL DRLG PROD 4/18/2002 15.50 DRILL DRLG PROD 00:00 - 15:30 15:30 - 16:30 16:30 - 00:00 1.00 RIGMNT RGRP PROD 7.50 DRILL DRLG PROD 4/19/2002 00:00 - 02:00 2.00 DRILL DRLG PROD 02:00 - 03:30 1.50 DRILL CIRC PROD 03:30 - 04:30 1.00 DRILL WIPR PROD 04:30 - 05:30 1.00 WELCTL OTHR PROD 4/11/2002 Spud Date: 1/25/2002 End: 4/22/2002 Group: Start: Rig Release: Rig Number: 3 Description of Oþerations allow test MWD-LWD RIH Continue P/U BHA #1 PJSM Upload sholl ow t est @ 330' RIH to 2806'. Wash to bottom @ 2930'. upwt 65k, Dnwt 60k, rot wt 60k. ECD 10.8 ppg @ 120 spm Directional drill 6.75" hole f/ 2930' to 3828' MD 3043' TVD. Dropping angle and turn rig ht as Perl program. up wt 72K, dn wt 65k, rt wt 70k, Torque 31-4100 ft/lb on btm, 32-35 00 ft/lb off btm at 80 rpm. ECD 11.0 to 11.2 ppg @ 120 spm Continue DD 6.75" hole F/ 3838' to 4511' M D 3595' TVD topped C-37 sand @ 4340' M D 3448' TVD. No Gas, Up wt 75k dnwt 73k, R.otwt 75k. Torque 43-5100 ft/lb on btm, 40- 4800 ft/lb off btm @ 80 rpm ECD 10.9 to 11. 3 Pumped sweeps as needed. Circulate sweep pump 3 CBU. Blow down top drive. Monitor well for flow O.K. Short trip to 7-5/8" @ 2857' Upwt 100-11 OK. Hole in good condition. Service top drive, Change out grabber. Moni tor well No flow. RIH tag btm, Fill every 10 std's @ 4511' Dn wt 55-60K Continue drlg 6.75" hole f/ 4511' to 5798' M D 4688' TVD. Pumped high vis sweeps as ne eded for hole clearing. upwt 11 Ok, dnwt 90K , Rtwt 90k, Torquue 5500 ft/lb on btm, 45-50 00 ft/lb off btm @ 80 RPM, Pump 120 spm @ 2500 psi. MUD 9.6 ppg and ECD 10.5 to 10. 7 ECD. Hole in good condition. Continue drlg 6.75" hole. Wash piipe leak. Upwt 105k, dnwt 100k, Rtwt 105k, Troque on btm 5000-6300 ft/lb, Off btm 4100-6000 ft/I b @ 80 RPM w 2600 pis pump 120 spm, 294 gpm. Mud wt 9.7 ppg. ECD 10.5 to 10.8 ppg EMW Repair wash pipe. Service top drive. Continue drlg 6.75" hole. Upwt 115k, dnwt 1 10k @ 80 rpm Trq on bt 6000-7500 ft/lb, off btm 5000-6000 ft/lb. Formation top Bermud a 6770' Base @ 7005'. Note! Added 165 bbls 9.6ppg new mud, Started @ 7000'. lost 101 bbl's by midnight. losses slowing. Continue drlg 6.75" Hole F/ 7162' to 7310' M D TD 5984' TVD Pump sweep Circulate bottoms up. @ 7 bpm 2400 psi. Upwt 115k, dnwt 110k, Rtwt 115, Pull 10 std's to 6315'. 150K. Hole not taking flu ¡d. RIH to 7310' Due to improper hole fill on sh ort trip. Printed: 5/10/2002 10:03:06 AM ) ~~ ~ ) Page40f 5 PHILLIPSALASKA>INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - SIDETRACK NORDIC 3 n1433@ppco.com Nordic 3 Date Sub. From - To Hours. Code. Code Phase 4/19/2002 05:30 - 09:30 4.00 WELCTL CIRC PROD 09:30 - 14:00 4.50 DRILL TRIP PROD 14:00 - 14:30 0.50 DRILL OBSV PROD 14:30 - 17:00 2.50 DRILL TRIP PROD 17:00 - 20:00 3.00 DRILL SURV PROD 20:00 - 21 :30 1.50 WELCTL BOPE PROD 21 :30 - 00:00 2.50 WELCTL BOPE PROD 4/20/2002 00:00 - 01 :00 1.00 WELCTL BOPE PROD 01 :00 - 01 :30 0.50 CASE RURD PROD 01 :30 - 03:30 2.00 CASE RUNC PROD 03:30 - 06:00 2.50 CASE RUNC PROD 06:00 - 06:30 0.50 CASE SFTY PROD 06:30 - 14:00 7.50 CASE RUNC PROD 14:00 - 20:30 6.50 CASE CIRC PROD 20:30 - 22:00 1.50 CASE OTHR PROD 22:00 - 00:00 2.00 CASE OTHR PROD 4/21/2002 00:00 - 03:00 3.00 CASE OTHR PROD 03:00 - 03:30 0.50 CASE OTHR PROD 03:30 - 04:00 0.50 CASE OTHR PROD 04:00 - 06:00 2.00 CASE OTHR PROD 06:00 - 07:00 1.00 CASE OTHR PROD 07:00 - 11 :30 4.50 CASE RUNC PROD 4/11/2002 Spud Date: 1/25/2002 End: 4/22/2002 Group: Start: Rig Release: Rig Number: 3 Description of Operations CBU gas cut mud 300 strokes before and 30 0 strokes after bottoms up. Mud weight cut t 0 9.2 ppg. Raised mud weight FI 9.6 to 9.9 P P g. POOH slowly to 7-518" csg shoe at 2i857'. Monitor well for flow. O.K. Continue to POOH to LWD-MWD PJSM Remove sourse. Dn load LWD-MWD, LI D same, Motor and bit. Drain stack, Pull wear ring, install test plug . Change top rams to 5-1/2" Bottom rams to 3-1/2". Weekly BOPE test 300-3500 psi, Annular 30 0-3000 psi Continue weekly BOPE test 300/3000 psi PJSM R/U to run 5.5" X 3.5" Tapper complet ion srting. Run 27 jt's of 3-1/2" 9.3# L-80 Eue 8rd Mod Csg wi SHoe & float 879'. RID 3-1/2" runnin g equipment. PJSM RIU to run 5-1/2" csg. RIH wi 5.5" csg Fill every jt. Circ @ 1500' & 2857' 7-5/8". Service rig and PJSM wi casing crew. Continue running 5-1/2" 15.5# L-80 BTCM to tal of 149 jts. Fill every jt, Circ @ 4700 & 6 000' RIH to 7280' M/U hanger and landing Jt . Up wwt 125k dnwt 75k R/U circulating hoses on cement head. Brea k circulation @ 1 bpm 550 psi no returns. W ork pipe Reciprocate pipe 55' trying to circ. lost 50 bbl's Make up 40 bbl LCM pill 33 pp b LCM. Displace 40 bbl's LCM pill. Followed pill wi 10 ppb LCM. Displaced pill to 7-5/8" csg shoe @ 2857' while reciprocating pipe 55' and pumping on up stroke. only lite retu rns never got any better. RIU to pull back to 5200' wi 5.5" csg. Pump 50 bbl's water down casing. Bleed off press ure check floats O.K. up wt 125k, dnwt 75k Pull and lay down 25 jts plus landing joint. @ 6200' check for flow. Upwt 105k Continue pulling out of hole. Laid down a t otal of 40 jts. Well swabbing Monitor well Make up top drive to 5-1/2" btc casing. Rota te at 15 rpms,5200 ft Ibs torque, 1.5 bpm wi th 480 psi. No returns. Rig down top drive and rig up to run casing. Clean LCM from pumps. Run casing back to bottom. Ran 149 jts 5-1- 2" casing and 27 jts 3-1/2' casing. Up wt-1 15K, down wt-65K Printed: 5/10/2002 10:03:06 AM ) ~~ ~ ') PHILLIPSALASKA.INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - SIDETRACK NORDIC 3 n1433@ppco.com Nordic 3 Date From ~To Hours Code cf6Je Phase 4/21/2002 11 :30 - 12:30 1.00 CASE CIRC PROD 12:30 - 15:30 3.00 CEMENT DISP PROD 15:30 - 16:30 1.00 WELLSR PLGM PROD 16:30 - 00:00 7.50 CMPL TN RUNT CMPL TN 4/22/2002 00:00 - 01 :30 1.50 CMPL TN RUNT CMPL TN 01 :30 - 02:00 0.50 WELLSR PLGM CMPL TN 02:00 - 04:00 2.00 WELLSR NUND CMPL TN 04:00 - 05:00 1.00 WELLSR NUND CMPL TN 05:00 - 05:30 0.50 WELLSR PLGM CMPL TN 05:30 - 06:30 1.00 WELLSR DEQT CMPL TN 06:30 - 08:30 2.00 WELLSR FRZP CMPL TN 08:30 - 09:30 1.00 DRILL LOT CMPL TN 09:30 - 12:00 2.50 WELLSR FRZP CMPL TN Page 50f 5 Start: Rig Release: Rig Number: 3 Spud Date: 1/25/2002 End: 4/22/2002 Group: 4/11/2002 Description of Operations Lay down fill up tool and make up cement he ad. Attempt to break circulation. No succ ess. Pumped@ 2bpm-650psi, 3bpm-700 psi, 4 bpm-770 psi with no returns. Pumped 50 bbls into formation. Batch mix cement. Test lines 3500 psi. Mix and pump 60 bbls CW 100,40 bbls, 69 bbls (325 sxs) "G" with gas blok@15.8. Displace 9.6 brine with rig pumps at 4 bpm. As ceme nt started coming up backside pressure incr eased from 150-1100 psi. When the wiper pi ug went inside the 3-1/2" casing, the psi inc reased to 2200 psi, slowed down pumps to 3 bpm , psi drop to 1450 and increased to 17 50 before stopped pumping. The plug did not bump, but we went off calculated strokes a fter we saw the plug enter the 3-1/2 casing and did not over displace. Float held. Che eked vac truck to confirm the correct volume had been pumped. Rig down casing tools. Install and test pac koff 5000 psi for 10 minutes. Good test. Rig up and run tubing per well plan Finish running 200 jts L-80 EUE Mod tubing. Locate seals, space out and land hanger. Lay down landing jt and install two way chec k. ND bop's NU FMC 3-1/8 5M GEN V tree. Test hanger and tree to 250/5000 psi. good test. Pull two way check and rig up to freeze prot e c t Pressure test tubing to 500 psi for 15 minut es. Test 3-1/2" x 5-1/2" annulus to 3000 psi for 30 minutes. Recorded on chart recorde r. Sheared out of shear valve with 3100 psi . (set for 3000 psi) Freeze protect 3-1/2" tubing and the 3-1/2" x 5-1/2" annulus to 2000'(45 bbls) Perform Lot on the 5-1/2" x 7-5/8" annulus ( injection)with 9.6 brine. Formation broke do wn with 700 psi. EMW= 15.3 ppg. Injected 3 bbls into formation. Freeze protect 5-1/2" x 7-5/8" with 40 bbls diesel. 2000'. Set BPV. Secure well and rei ease rig. Printed: 5/10/2002 10:03:06 AM Date 05/02/02 05/03/02 05/04/02 05/04/02 05/05/02 05/06/02 05/06/02 ) 2P-422A Event History ) Comment PULLED BPV. IN PROGRESS. TAGGED @ 7180' RKB. DRIFTED TBG W/ 13' X 2.63" TO 7180' RKB. REPLACED DCK WITH GAUGE @ 6295' RKB. TBG TEST FAILED, PKG ON GAUGE BLOWN. IN PROGRESS. [PT TBG-CSG] SET BTM LATCH EXTENDED PACKING DV @ 6295' RKB. TESTED IA TO 3550 PSI, PASSED. PULLED 2.78" CATCHER @ 6361' RKB. [FRAC-REFRAC] PERFORATE W/2.5" HSD 6 SPF, HJ / PERFORATIONS - E-LlNE (260). RIH W/2.5" HSD 6 SPF, HYPERJET GUN, TAGGED TO @ 7177', SHOT 6872' - 6882' (10'), POOH, RIH W/PSP, LOGGED JEWELRY, LOGGED - STATIC @ 6877' (MID-PERFS) BHP=2981 'P"SI, BHT=141.5, PULL UP TO STATION #5, PRES=2730.5 PSI, TEMP=127.9 DEG. F / POOH, RDMO, NOTIFIED DSO, LEFT WELL SI. [PERF] PUMPED INITIAL FRAC. PUMPED 1470 BBL BRACKETFRAC, FOLLOWED BY FRAC JOB. EXTENDED 10 PPA STAGE BY 85 BBLS TO 385 BBLS, FLUSHED JOB TO COMPLETION. PLACED 285M# PROPPANT IN FORMATION, 113% OF DESIGN. 10 PPA ON PERFS. LEFT 1000# PROPPANT IN WELLBORE, 30 BBLS OF DIESEL INTO WELL FOR FREEZE PROTECTION. CLEANED OUT TO 7178' CTM W/SEAWATER J313 AND 1-1/2# BIOZAN (EST. 275' OF RATHOLE) USING A 2" JET-SWIRL NOZZLE. WELL LEFT SHUT IN & FREEZE PROTECTED W/DIESEL TO 2500'+. TAGGED @ 7081' RKB, EST. 199' RATHOLE. PULLED DV & SET 5/16" OV. [GLV, TAG] Page 1 of 1 5/14/2002 ) ) Phillips Alaska, Inc. Drill Site 2P 422A slot #422 Meltwater North Slope, Alaska S 0 R V E Y LIS TIN G by Baker Hughes INTEQ Your ref: MWD <2878 - 7310'> Our ref: svy6744 License: Date printed: 29-Apr-2002 Date created: 16-Apr-2002 Last revised: 21-Apr-2002 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 9.663,w150 26 51.900 Slot Grid coordinates are N 5868975.305, E 444049.453 Slot local coordinates are 900.33 S 2092.34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ') Phillips Alaska, Inc. Drill 8ite 2P,422A Meltwater,North 8lope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 115.00 192.80 225.04 255.74 327.20 379.99 410.72 503.66 594.27 686.91 778.77 870.91 965.87 1056.94 1149.49 1244.80 1338.91 1436.71 1529.38 1624.46 1719.86 1815.70 1911.40 2006.39 2101. 49 2195.83 2291.17 2390.91 2479.31 2574.87 2606.20 2701.77 2797.15 2878.00 2979.00 3008.86 3103.55 3198.48 3293.44 3387.10 3481. 80 3576.93 3671.59 3765.92 3861. 26 3955.11 4050.42 4144.97 4239.97 7.23 9.23 10.82 12.59 15.92 19.90 20.40 20.58 23.38 26.56 29.08 31.72 35.51 39.13 43.42 47.34 51.13 55.07 56.55 56.52 56.22 56.37 54.98 53.71 54.40 50.36 50.45 48.69 48.08 48.43 48.08 46.58 44.56 44.03 42.80 41. 04 39.29 37.18 36.74 36.56 0.00 0.00 0.18 0.22 0.21 0.00 0.00 242.59 204.84 274.46 0.00 115.00 192.80 225.04 255.74 327.20 379.94 410.60 503.23 593.39 685.38 776.29 867.02 960.00 1048.25 1136.30 1225.78 1313.93 1404.61 1488.61 1572.70 1654.97 1734.77 1810.87 1882.25 1949.03 2010.62 2067.86 2123.91 2172.65 2225.58 2242.96 2296.85 2352.45 2399.91 2461.54 2480.58 2541.98 2605.04 2668.27 2730.63 2794.82 2861.41 2929.16 2997.68 3068.62 3140.35 3215.21 3290.76 3366.98 ) 8URVEY LI8TING Page 1 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 R E C TAN G U L A R Dogleg Vert COO R DIN ATE 8 Deg/100ft 8ect O.OON O.OON 0.068 0.148 0.188 0.748 2.608 4.498 11. 298 19.208 28.618 39.678 52.948 68.888 87.568 111. 438 139.248 167.068 197.518 229.478 265.268 304.198 346.628 393.525 445.138 500.845 559'.845 623.345 691.525 751.775 816.615 837.945 903.178 967.075 1021.065 1087.615 1106.655 1166.295 1226.555 1288.695 1351.085 1413.635 1475.355 1535.935 1595.255 1653.395 1709.265 1764.705 1818.725 1872.925 O.OOE O.OOE O.l1W 0.18W 0.26W 0.22W 0.63E 1.60E 4.88E 9.10E 14.81E 21.91E 30.92E 41. 74E 54.14E 69.63E 87.09E 104.71E 125.02E 147.56E 173.80E 202.32E 234.16E 268.28E 303.79E 342.22E 382.49E 424.67E 471.10E 513.62E 559.75E 574.73E 619.15E 663.01E 700.00E 744.37E 757.28E 797.75E 835.21E 869.22E 900.69E 931.28E 959.64E 986.10E 1012.24E 1038.27E 1061. 50E 1081.60E 1099.31E 1115.98E 0.00 0.00 0.23 0.42 0.80 1. 45 4.94 2.78 0.69 1. 80 0.60 2.65 4.76 12.30 21.20 G RID COO R D 5 Easting Northing 0.00 0.00 0.01 0.06 0.08 444049.45 444049.45 444049.34 444049.27 444049.19 5868975.31 5868975.31 5868975.25 5868975.17 5868975.12 5868974.57 5868972.70 5868970.80 5868963.98 5868956.04 5868946.58 5868935.47 5868922.14 5868906.11 5868887.34 5868863.36 5868835.42 5868807.46 5868776.87 5868744.74 5868708.76 5868669.61 5868626.94 5868579.79 5868527.92 5868471.92 5868412.62 5868348.81 5868280.28 5868219.71 5868154.54 5868133.10 5868067.53 5868003.31 5867949.04 5867882.16 5867863.02 5867803.08 5867742.54 5867680.15 5867617.53 5867554.76 5867492.83 5867432.06 5867372.54 5867314.22 5867258.17 5867202.58 5867148.44 5867094.12 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean sea level). Bottom hole distance is 3709.03 on azimuth 158.81 degrees from wellhead. Vertical section is from wellhead on azimuth 158.23 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.94 3.53 4.38 4.95 6.42 163.09 153.48 152.29 155.98 148.79 148.74 146.16 145.52 146.13 146.66 147.29 148.46 146.85 145.81 143.92 143.59 143.94 142.37 145.43 145.51 145.30 146.05 146.74 144.77 144.80 144.34 145.51 145.98 145.09 146.07 146.56 145.15 146.56 149.72 152.88 153.59 154.29 156.40 156.40 156.05 155.70 159.21 160.97 162.73 163.08 0.87 2.21 1. 73 1. 87 3.66 32.06 44.97 60.63 79.45 101. 40 4.31 0.67 0.63 2.89 3.54 129.31 161.61 193.99 229.79 267.84 2.66 2.77 4.06 4.25 4.52 310.80 357.54 408.75 464.96 526.06 4.12 4.06 4.17 2.21 0.04 592.05 661. 78 736.39 816.93 888.66 0.51 3.14 1. 51 1. 53 1. 30 965.98 991.34 1068.40 1144.00 1207.87 4.02 3.65 2.18 2.57 2.51 1286.13 1308.60 1379.00 1448.85 1519.17 0.68 1. 67 2.65 0.56 1. 33 1588.79 1658.22 1726.05 1792.13 1856.92 1. 86 3.05 2.49 1. 21 0.29 1920.56 1981.06 2040.01 2096.74 2153.26 444049.23 444050.06 444051.02 444054.25 444058.40 444064.04 444071.06 444079.97 444090.66 444102.91 444118.23 444135.47 444152.88 444172.95 444195.24 444221.20 444249.43 444280.94 444314.70 444349.81 444387.81 444427.63 444469.32 444515.22 444557.28 444602.91 444617.72 444661.65 444705.01 444741.59 444785.44 444798.21 444838.21 444875.21 444908.74 444939.73 444969.85 444997.73 445023.73 445049.41 445074.99 445097.79 445117.47 445134.77 445151.02 ) ) Phillips Alaska, Inc. 8URVEY LI8TING Page 2 Drill 8ite 2P,422A Your ref : MWD <2878 - 7310'> Meltwater,North 81ope, Alaska Last revised : 21-Apr-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D 8 Depth Degrees Degrees Depth COO R DIN ATE 8 Deg/lOOft 8ect Easting Northing 4334.20 35.68 164.13 3443.10 1926.208 1131.66E 1.14 2208.56 445166.30 5867040.72 4430.83 33.31 166.95 3522.74 1979.178 1145. 36E 2.96 2262.82 445179.59 5866987.66 4524.03 32.26 172 . 22 3601.11 2028.758 1154.51E 3.26 2312.27 445188.36 5866938.01 4619.05 32.52 174.68 3681. 35 2079.318 1160.31E 1. 41 2361.37 445193.78 5866887.41 4713.07 33.05 173.98 3760.39 2129.978 1165.35E 0.69 2410.28 445198.42 5866836.72 4807.89 31.90 173.63 3840.38 2180.598 1170.84E 1. 23 2459.32 445203.53 5866786.07 4902.93 31.90 173.27 3921. 07 2230.488 1176.57E 0.20 2507.78 445208.88 5866736.14 4997.53 32.96 173.98 4000.91 2280.908 1182.19E 1.19 2556.69 445214.12 5866685.68 5092.44 33.40 173.27 4080.35 2332.528 1187.96E 0.62 2606.77 445219.49 5866634.03 5186.85 30.94 172 . 92 4160.26 2382.428 1194.00E 2.61 2655.35 445225.15 5866584.09 5281.19 29.00 173.98 4241.98 2429.238 1199.39E 2.13 2700.82 445230.18 5866537.24 5376.24 29.09 17 4.68 4325.08 2475.158 1203.95E 0.37 2745.16 445234.39 5866491.29 5470.40 29.44 173.63 4407.22 2520.948 1208.64E 0.66 2789.42 445238.73 5866445.47 5565.90 30.15 173.27 4490.10 2568.088 1214.05E 0.77 2835.21 445243.78 5866398.29 5660.35 30.94 174.68 4571.44 2615.828 1219.08E 1.13 2881.40 445248.45 5866350.53 5754.58 31.38 172.92 4652.08 2664.288 1224.35E 1. 07 2928.36 445253.35 5866302.03 5850.23 32.17 173.63 4733.39 2714.308 1230.25E 0.91 2977.00 445258.86 5866251.97 5944.46 32.87 172.57 4812.85 2764.598 1236.34E 0.96 3025.96 445264.57 5866201.64 6038.94 33.66 173.63 4891. 84 2816.048 1242.56E 1. 04 3076.05 445270.40 5866150.15 6133.29 32.87 171.16 4970.74 2867.338 1249.39E 1. 66 3126.21 445276.84 5866098.82 6228.42 32.78 170.81 5050.68 2918.268 1257.47E 0.22 3176.51 445284.53 5866047.83 6323.14 31.73 171.52 5130.78 2968.218 1265.24E 1.18 3225.77 445291.92 5865997.83 6417.53 31.20 172.22 5211.29 3016.988 1272.21E 0.68 3273.65 445298.52 5865949.01 6512.40 30.50 171.52 5292.74 3065.148 1279.09E 0.83 3320.93 445305.03 5865900.80 6607.48 29.88 171. 52 5374.92 3112.438 1286.14E 0.65 3367.46 445311.72 5865853.47 6702.07 30.23 171. 52 5456.79 3159.288 1293.13E 0.37 3413.56 445318.34 5865806.56 6796.75 30.32 172 . 22 5538.56 3206.548 1299.88E 0.38 3459.95 445324.73 5865759.27 6891.37 31. 03 171.16 5619.94 3254.308 1306.86E 0.94 3506.89 445331. 35 5865711.46 6986.17 30.15 171.16 5701. 55 3301.978 1314.27E 0.93 3553.91 445338.40 5865663.74 7080.71 29.44 170.11 5783.59 3348.328 1321. 91E 0.93 3599.79 445345.68 5865617.33 7175.98 29.00 170.46 5866.74 3394.168 1329.76E 0.50 3645.27 445353.18 5865571.44 7228.03 29.00 170.11 5912.26 3419.038 1334. 02E 0.33 3669.95 445357.25 5865546.54 7310.00 29.00 170.11 5983.95 3458.188 1340.84E 0.00 3708.84 445363.78 5865507.34 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #422 and TVD from RKB(Nordic 3) (254.00 Ft above mean sea level). Bottom hole distance is 3709.03 on azimuth 158.81 degrees from wellhead. Vertical section is from wellhead on azimuth 158.23 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) Phillips Alaska, Inc. Drill Site 2P,422A Meltwater,North Slope, Alaska SURVEY LISTING Page 3 Your ref: MWD <2878 - 7310'> Last revised: 21-Apr-2002 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 7292.00 5968.21 3449.58S 1339.34E 3 1/2" CSG Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(Z) Mid pt TGT RVS 445321.000,5865720.000,999.00 5594.00 3245.83S 1296.44E 22-Feb-2001 ~~~~¡ ) :F !Æ~!Æ~~~!Æ 1¡ ) ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. "J"i AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. . PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 2P-422A Phillips Alaska, Inc. Permit No: 202-067 Sur Loc: 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 913' FSL, 1879' FEL, Sec. 17, T8N, R7E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confmned by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 2P must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 baITels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, . II (;~'Î~O!-t/~J' ~~~/ C~y !)chsiî'Tàylor ð Chair '- BY ORDER Of/THE COl\1MlSSION DATED thisJ!tb.day of March, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ .') PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com March 11, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, sidetrack 2P-422A Dear Commissioner Taylor: ) Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer sidetrack, KRU 2P-422A, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, çu~~(f Drilling Engineering Supervisor RECEt'VED MAR 1 3 ZOOZ :~Iaska Oil & Gas Coos. Commission Anch'Jí3ge 9. Approximate spud date Amount March 25, 2002 $200,000 14. Number of acres in property 15, Proposed depth (MD and TVD) 2560 7291 ' MD / 5953 ' TVO 17, Anticipated pressu,?'(SeB 20 AAC 25,035 (B)(2)) Maximum surface 1994 psig At total depth (TVO) 2621 psig Setting Depth ') STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL /Sj!1/f ~ D 20 AAC 25.005 1 a. Type of work: Drill [j Redrill Re-entry DDeepen 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM At top of productive interval 1133'FSL,1905'FEL,Sec. 17,T8N,R7E, UM At total depth 913' FSL, 1879' FEL, Sec. 17, T8N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 1879' @ TO feet 2P-421 ,218.5' @ 2952' 16. To be completed for deviated wells Kickoff depth: 2952 MO 18. Casing program size 1b. Type of well. Exploratory D Stratigraphic Test D Service D Development Gas D Single Zone 0 5. Datum elevation (OF or KB) RKB 254 AMSL feet 6. Property Designation AOL 373112 7. Unit or property Name Kuparuk River Unit 8. Well number 2P-422A Maximum hole angle 55° Top Bottom TVD Hole Casing Specifications Grade Coupling MD MD Weight Length TVD 6.75" 6.75" 5.5" 3.5" Surf. 6419' 5211' 5953' Surf. 5211' 6419' 7291' 15.5# 9.3# L-80 3TC, ABmoc 6389' L-80 =UE 8rd Moc 872' 19, To be completed for Redrill, Re-entry, and Deepen Operations, Present well condition summary IIJGA- 3)Iy!o L Development Oil 0 Multiple Zone D 10. Field and Pool Kuparuk River Field Meltwater Pool 11. Type Bond (see 20 AAC 25,0251) Statewide Number #59-52-180 Quantity of Cement (include stage data) 300 sx Class G included above Total Depth: 8853 feet 5969 feet Plug #1: 8253'- 8853' Plug #2: 7653' - 8253' Plug #3: 2657' - 3257' Plugs (measured) measured true vertical Effective Depth: 2657 feet 2273 feet measured true vertical Casing Conductor Surface Production Length 90' 2827' Size Cemented 16" 9 cu yds High Early 7.625" 316 bbls AS III Lite, 81 bbls LiteCrete Measured depth 120' RECEiVED Liner MAR 1 3 ¿002 Perforation depth: None measured True Vertical depth 120' 2389' true vertical None Alaska Oil & Gas Cons. Commission Ancooíage 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0 Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements D 21, I hereby ce~. i at 2i~~g is true n. ft¡7'eCI to the,.b:~f my kno. wi edge Questions? Scott Lowry 265-6869, Signed (!,./ "- Ilícæ¿J4'/' Title: DrillingEngineeringSupervisor Date P MM :1-f)i) 2- Chuck Mallary /' Pn:marp.rI hv Shamn Aflslln-nrakA Commission Use Only Permit Number I API nu er I Approval date ~/I L/~/} Isee cover lett. er Z~.2. '-' ð 6 7 50- 'jt:J3 - 2. ð S"O 0 -0/ / flU j, for other requirements Conditions of approval Samples required DYes (8'f No Mud log required U Yes lSI No Hydrogen sulfide measures D Yes ~ No Directional survey required ~ Yes D No Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D Other: 300()~\ N\,\"'\ 'N..~,^^- \ßf:.::;)~ ~~ ~ Original Signed By Commy Occhs-li Approved by by order of the commission Commissioner Date ~~/j(/~:J, Form 10-401 Rev. 1211/85- i . II oil " ~.. . ~ i¡J' i j,. \I . .. - Submit in triplicate ') App" 10n for Permit to Drill, Well 2P-422A Saved: 7-Mar-02 Permit It - Meltwater 2P- 422A Application for Permit to Drill Document Ml)ximizE Well "101'-11; Table of Contents 1. Well Name.......................................... ....... ............................... ....... ..................... ..... 3 Requirements of 20 AAC 25.005 (f)........................................................................................................3 2. Location Sum mary .................... ...... ....................................... .................................. 3 Requirements of 20 AAC 25. 005( c)(2) ................................................................................................... 3 Requirements of 20 AAC 25. 050(b)......... ................. ................... .... ................... ... ......... .................. ......3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 4 4. Dri II i ng Hazards Information............ ...................................... ................................. 4 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................4 5. Procedure for Conducting Formation Integrity Tests ...........................................4 Requirements of 20 AAC 25.005 (c)(5) ........................................................ ..........................................4 6. Casi ng and Cementing Program ................................................. ............................4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information............ ................ ...................... ........................ ......... 5 Requirements of 20 AAC 25. 005( c)(7) .................................................................."............................... 5 8. Dri II i ng FI uid 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. Seismic Analysis........................................ ............................ ......... ............ ............. 6 Requirements of 20 AAC 25.005 (c)(10) ................................................,...............................................6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ............... ............................................................................ ...., 6 12. Evidence of Bondi ng ........... .................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 2P-422A PERMIT IT 3-6-02. doc Page 1 of 7 0 ~ i G ¡ N A :'rinted: 7-Mar-02 ) App" .1on for Permit to Drill, Well 2P-422A . Saved: 7-Mar-02 13. Proposed Dri II i ng Prog ram............................................ ..... .............................. ...... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ............................ ............................................................ ........ 7 15. Attachments ......................................................................... ...... ...... ........................ 7 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................7 Attachment 2 Directional Plan............................................................................................................... 7 Attachment 3 Drilling Hazards Summary........ ... .................................. .................. .... ...... ... ................... 7 Attachment 4 Well Schematic.................................................................... ............................................ 7 Attachment 5 Cement Details................................................................................................................ 7 2P-422A PERMIT IT 3-6-02. doc Page 2 of 7 Printed: 7-Mar-02 LJ f., '-'~" ~¡...~L ) App" )on for Permit to Drill, Well 2P-422A Saved: 7-Mar-02 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identifled by a unique name des1gnated by the opera/vI' and a unique APl number assigned by the c:vmrm:I.:>:<;ion uncleI' 20 AAC 25,040(b), For a well with multiple well brancf¡es~ each branch must similarly be ident/fied by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2P-422A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Drill must be accompanied by each of the following items, excf:;"pt r..~r an Item already on file with the commission amj identified in the applk'ation: (2) a plat identifying ttle property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surti:,¡ce, at the top of eaä7 objective formation/ and at total deptt'& referenced to govemmental section lines. (8) the cvord!Í7iites of the propOS'ed loc,1t1on of the well at the sulf'ace, refÓrenæd to the state plane coordinate 5"ystem for this 5"tate as maintained by the National Geodetic Survey in the National Oceanic and Atmosp/1edc Administration; (C) the proposed depth olthe wdl at the top of each oL?J'ective f'ormation and at total depth/' Location at Surface NGS Coordinates Northings: 5868975.31 Eastings: 444049.45 901' FNL, 2089' FWL, Sec 17, T8N, R7E, UM RKB Elevation: 254.0 ft AMSL Pad Elevation: 224.0 ft AMSL Location at Mid Point of Productive Interval (Bermuda Formation) NGS Coordinates Northings: 5865720.0 Eastings: 445321.0 1133' FSL, 1905' FEL, Sec 17, T8N, R7E, UM Measured Depth (RKB feet): True Vertical Depth (55 feet): True Vertical Depth (RKB feet): 6869' 5340' 5594' Location at Total Depth NGS Coordinates Northings: 5865499.8 Eastings: 445346.9 913' FSL, 1879' FEL, Sec 17, T8N, R7E, UM Measured Depth (RKB feet): 7291' True Vertical Depth (55 feet): 5699' True Vertical Depth (RKB feet): 5953' and (0) other /Ì7formation required by 20 AAC 25.050(/)); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, tile application for a PermIt to Drill (Form 10..401) must (1) include a pla~ drawn to a suitable scale, showing the path of the proposed wellbore/ including all adjacent wellbores within 200 feet of any pOltion of the proposed well,' Please see Attachment 2: Directional Plan and (2) for all wells wIthin 200 feet of the proposed wel/bore (A) list the names of tlJe operators of tlJOse ¡!'ie/ls, to the extent that tlJose names are known or discoverable /Ì7 pub/lc records, and show that each named operator has been furnished a copy of tl7e application by certified mail,' or (8) state tl7at the applicant is the only affected owner. The Applicant is the only affected owner. 2P-422A PERMIT IT 3-6-02. doc Page 3 of 7 Printed: 7-Mar-02 l,. M * ~ ... , j 'i4 r i '- ) APpl'1on for Permit to Drill, Well 2P-422A Saved: 7-Mar-02 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pennie to Drill must be accompanied by each of'the fol/owing items, except for an Item already on file with the commission and identified in the application: (3) a diagram and desoiptio!7 of the blowout prevention eqwiJment (BOPE) as required by 20 AAC 25:035~ 20 AAC 25.036, or 20 AAC 25:037, as applkt:Jble; Please refer to Nordic 3 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pe!7171t to Drill must be acevmpanied by each of'the following Item5~ except lor an Item already on flle with the commission and identified in the applicatìon: (4) information on drilling haza¡d~ including (A) the maximum downhole pressure that may be encountere(~ crìte(/~1 used to determine it and maxl/num potent/~71 surface pres.5ure based 0/7 a methane gradient/ 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: MPSP =(5698 ft)(0.46 - 0.11 psi/ft) =1994 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 (2395' TVD) can be expected to occur at 1988 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated above. (B) data on potentkil gas zones; The Cairn interval is a potential gas zone. and (C) data concerning potential causes or hole problems such as abnormally geo-pres:.ç,vred !:jtrata/ lost ckculation zone5~ and zones tflat have a propensity for differential sliding; Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commis:,'ion and identified in the application: (5) a descnption or the procedure for conducting formation If7tíqrdY tests, as required under 20 AAC 25.030(f),' A formation integrity test was performed to 18.0 ppg EMW at the 7 5/8" casing shoe on 2/20/2002. A copy of the Phillips Alaska LOT / FIT procedure is currently on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Pelmle to Onll must be accompanied by each of the followlÍ7g Items, except for an Item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 030, and a description of any slotted l¡f7er, pre- perforated liner, or screen to be 1Ì7stalled; 2P-422A PERMIT IT 3-6-02. doc Page 4 of 7 0 1 'G. At ~rinted: 7-Mar-02 ) APp")On for Permit to Drill, Well 2P-422A Saved: 7-Mar-02 Casing and Cementing Program Hole Size (in) 42 CsglTbg 00 (in) 30 X 16 Insulated 7-5/8 Weight (Iblft) 62.5 Grade H-40 Connection Welded Length (ft) 80 Top MDITVD (ft) 30 / 30 Btm MDITVD (ft) 110/ 110 Cement Program 9 cy High Early Cemented to ,/" surface as per original drilling permit. 9-7/8 29.7 L-80 BTC,AB Modified 2827 30 / 30 2857 / 2395 3-1/2 6-3/4 9.3 L-80 872 6419/5211 7291/5953 300 sx 15.8 /' ppg Class 'G' Planned Top of Cement: 5919' MD ./' 5 1/2 6-3/4 15.5 L-80 BTC,AB Modified EUE, 8rd Mod 6389 30 / 30 6419/5211 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already 017 tïle wIth the commis.';;'/on and ¡(jent/tied in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25',O35~ unJes:'i thl<; requirement is waived by the commis..c,ion under 20 AAC25~035(h}(2)/ N/A 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application fÒr a Permit to Dli// must be accompanied by each of the to/lowing items~ except for an item already on tïle wIth the commi:.:-:;iOI7 and Identified 1Ì7 the application: (8) a drilling flUId program/, inc!udl/1g a diagram and descr/~ìtíon or the dn/I/ng flllld sy.'item/, as required by 20 MC 2.5.033; Water based drilling fluid systems will be utilized to drill this sidetrack. These systems will be built and maintained to the following specifications: Drill Out to Top Bermuda Top Bermuda To Well TD Initial Value Final Value Initial Value Final Value Density (ppg) 9.6 9.6 9.6 9.6 ./ Funnel Viscosity 50 65 50 65 (seconds) Yield Point 10 25 20 30 (cP) Plastic Viscostiy 6 14 6 14 (lbl1 00 sf) 10 second Gel 2 6 4 7 Strength (lb1100 sf) 10 minute Gel 4 8 4 8 Strength (lb1100 sf) pH 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5 API Filtrate(cc) <6 <6 8-10 8-10 Please refer to Nordic 3 Fluid System Components currently on file with the Commission. 2P-422A PERMIT IT 3-6-02. doc A . Page 5 of 7 ) ~ I G ¡ 1\ t - Printed: 7-Mar-02 ) App" 'tn for Permit to Drill, Well 2P-422A Saved: 7-Mar-02 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application fòr a Penmt to Drill must be accompanied by each ot'the following Item.'i¡ except for an Item already on file with the commission and identifìed in the application: (9) for an exploratory or stratiqrapl7ic test wel¿ a tabufc':.Jtion setting out the depths o(prediäed abnormally gea-pressured strata as required by 20 MC 2.5: 033(n- Not applicable: Application is not for an exploratory of stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicatíon for a Permit to Drill mLlst be accompanied by each ot'the fiJllowing item5~ except for an item already on file with the commission and identifìed in the application: (10) f'or an exploratory or stratigr'r.'1phic test well a seismic fi:'?f'raction or reflection analysl'i as required by 20 MC 25.061(£1)/' 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 application for a Permit to Drill must be accompanied by each of the tollowiny item5~ except f'or an item already on file with the wmmif,:.<;ion and identitìed in the application: (11) for a well drilled finm an offshore plattorrn mobile bottom~founded structure/ }/Jck-up rig/ or floating drilling veS"se¿ an analysis of seabed condItions as" requíred 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 Drill must be accompanied by each of the followinq item-,,~ except fÒr an item already on file with the commif,:.<;ion and identified in the application: (1.7) evidence showiny that the requirements of 2{} AAC 25. 025 {Bondlng}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for cÎ Permit to Drill must be accompanied by each of'the following item~ except tor an item already on tYe with the commis.,iol7 and Identified 1i7 the application: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Move in / rig up Nordic 3. /' 2. Nipple up BOPE and test to 3000 psi. Record results. 3. P/U directional BHA, trip in hole, and drill out cement plug. Planned kick-off point is 2952' MD (+1- 100' below the 7 5/8" surface casing shoe). 4. Directionally drill production hole to total depth according to directional plan. Run MWD I LWD logging tools in drill string for directional monitoring and formation data gathering (GR/Res/Density- Neutron). Circulate and condition hole. POOH. 5. Run open hole e-line or drill pipe conveyed logs as needed (none planned). 6. Run and cement tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +1- 100' above the planned top perforation. / 7. Run and land production tubing. Displace well to sea water. 2P-422A PERMIT IT 3-6-02. doc 0 . Page 6 of 7 h j U I J V A L Printed: 7-Mar-02 ) App" 'rn for Permit to Drill, We1l2P-422A Saved: 7-Mar-02 8. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Install test plug. Pressure test production tree. Pull test plug. Secure well. 9. Freeze protect well. Set BPV. Release rig and turn well over to production. 10. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Pull BPV. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applicEJtio/7 for a Permit to Drill mustc be accompanied by eacl7 of the following items, eXCéyJt for an item already on file with t/7e commission and identified in ttie application: (14) a general desaiption of flow the operator plans to dispose of dnlling mud and cuttings and a statement of whether the operator IÌltends to request authorization under 20 MC 25.080 for an annular di:pO$al operation in tile well,; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P pad or hauled to a Class II disposal well. All cuttings will be either processed on-site and disposed of down the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing and disposal down an approved disposal well. At the end of drilling operations, a request will be submitted for this well to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details 2P-422A PERMIT IT 3-6-02. doc 0.; G . :.. \.A "'" Prlnt:;aKe:.~~; 300- n 0 - 300 - I 600 - 900 - 1200 - 1500 - 1800 - ----- -+- Q) 2100- Q) - "--" ..s::: 2400 - -+- 0.. Q) 0 2700 - 0 U -+- 3000 - I- Q) > Q) 3300 - :J I- -- I 3600 - V 3900 - 4200 - 4500 - 4800 - 5100 - 5400 - 5700 - 6000 - ,) Philli ) } Ince s Alaska, \ " 1000 \, \ \. 1300 \ \ \. 1600 \ \ \11\ 1900 ~... 2200 '"'-., , ",.,~:OO "~ 2800 ); '.. KOP - Sidetrack pt CSO 3100 54,22 . "- 50.U.0 .., 3400 47.39', 45.73,,11<. 3700 44.09, 42.47 " C50 4~~~ '~OOO 37,80 "0. C40 36,31,* 4300 34,S7 " 33.47 ".4600 C37 32.14 )1<, EOC " ''At,~:00 ',)¡,:~OO "*,~~OO , '<~~OO ',.... 6100 " ".,~400 , '. Structure: Drill Site 2P Field: Meltwater Ri~,r t'olor'dic III F¿KB Uevotíon: 254' DLS: 2,00 deg per 100 It TANGENT ANGLE: 31.68 DEG. 300 900 1800 1200 1500 600 ~HI~lIPS'> Well: 422A Location: North Slope, Alaska \..\'-:"':""~:i ~. .." ;; ~è;:..:.,.."".':J [~rp;ott~(~I. 6-~;~I;lo2 Plot Reference is 2P-422A Version#1. Coordinates ore In feet reference ~Iot *422A. Verticol Demiii reference RK8(Nordic DML Created by bmichocl $ fi!¡:¡; 2p4220Y 158.23 AZIMUTH 3495' (TO TARGET) *** Plane of Proposal*** T7 5 1/2 x 3 1/2 XO T4.1 (Top Cairn) T3.1 13 (Top Bermuda) Bermuda Midpoint Target T2 (Base Bermuda) MW(Z) Mid Pt TGT RVSD 4 MAR 02 C35 TO - Csg Pt .1/ ~\. 2100 2700 3900 4200 3000 3300 3600 2400 Vertical Section (feet) -> Azimuth 158.23 with reference 0.00 N, 0.00 E from slot #422A c = '; N Ii ~ ') ) Philli s Alaska~ Incø ~~~ Structure: Drill Site 2P Field: Meltwater Well: 422A Location: North Slope, Alaska ~. ,:,~::.i>:;,;;;.<~d For: Pat Reil!y Dot. plott.d: 6-Mor-2002 Plot Reference i. 2P-422A Vecolon#1. Coordinotc:s ore in feet reference :slot H422A. Verlicol Depths ore reference RKB(Nordic i'&íiïii ~Ls Creoted by bmichoel East (feet) -> 200 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 200 Bermuda Midpoint Target - 0 - 200 - 400 - 600 - 800 - 1000 - 1200 - 1400 (J) 0 c - - 1600 :J ---. ...... CD - 1800 CD - '--'" I - 2000 V - 2200 - 2400 - 2600 - 2800 - 3000 - 3200 - 3400 - 3600 \, \\, , \ , , \ , \ \ \ \ \\, '\ \ \ , , \ , , ~~ KOP - Sidetrack pt \: cao ESTIMATED SURFACE LOCATION: 901' FNL 2089' FWL SECTION 17, T8N-R7E STK. LD. LOCATION 913' FSL 1879' FEL SECTION 17, T8N-R7E 5 1/2 x 3 1/2 XO T4,1 (Top Cairn) 13,1 13 (Top Bermuda) MW(Z) Mid Pt TGT RVSD 4 MAR 02 T2 (Bose Bermuda) C35 TO - Csg Pt J l C50 158.23 AZIMUTH 3495' (TO TARGET) *** Plane of Proposal*** C40 C37 ~, ~ f).d TRUE T7 y.. N STK. TARGET LOCATION 1133' FSL 1905' FEL SECTION 17, T8N-R7E 0 f'~G I~ ~\I ; . f ~-:.r~.l' "'f. p.~ ~ ! I ,I Ii Ii 'i ~ Ii rJ h .i- Phillips Alaska, Ince ~'.; Für: Pot f<ei¡ly Structure: Drill Site 2P Well: 422A - Dote plotted: 6-'-4or-2b02 Plot Reference is 2P-422A VersionKl, Field: Meltwater Location: North Coordinates are in feet reference slot N422A. Vertical Depths arc reference RKB(Nordic 1M.. BJU(D Created by bmichael HUGl8:S file: 2.p422ccorn INTEQ ---~- - = = = = PROF~ LE COMMENT DATA == = = -' ----- Point ----- MO Inc Oir TVO North East V. Sect Oeg/100 KOP - Sidetrack pt 2952.00 55.06 145.26 2442.64 -1071.09 733.86 1266.89 0.00 C80 3001.00 54.20 145.86 2471.00 -1104.04 756.46 1305.87 2.00 C50 3862,74 39.90 159.13 3058.00 -1655.69 1053.33 1928.28 2.00 C40 4160,81 35.43 165.59 3294.00 -1828.84 1108.94 2109.71 2.00 C37 4401.37 32,12 171.89 3494.00 -1959.75 1135.34 2241.07 2.00 EOC 4435.36 31.68 172.87 3522.85 -1977.55 1137.72 2258.49 2.00 T7 5721.09 31.68 172.87 4617.00 -2647,56 1221.57 2911.80 0.00 5 1/2 x 3 1/2 XO 6418.98 31.68 172.87 5210.90 -3011.24 1267.08 3266.42 0.00 - " T 4.1 (Top Cairn) 6518.98 31.68 172.87 5296.00 -3063.35 1273.61 3317,23 0.00 T3. 1 6612.99 31.68 172.87 5376.00 -3112.34 1279.74 3365.00 0.00 a ::X:--'1 T3 (Top Bermuda) 6772.80 31.68 172.87 5512.00 -3195.62 1290.16 3446.21 0.00 ....-...~. ~:j Bermuda Midpoint Tar 6869.16 31.68 172.87 5594.00 -3245,83 1296.44 3495.17 0.00 --...,... T2 (Base Bermuda) ~ - 6991.37 31.68 172.87 5698.00 -3309.52 1304.41 3557.27 0.00 ~:~:~ ,.~ C35 7126.50 31.68 172.87 5813.00 -3379.94 1313.23 3625.93 0.00 r-- ~ TO - Csq pt 7291.37 31.68 172.87 5953.30 -3465.85 1323,98 3709.70 0.00 - -- -------- ) ) Inc. Phillips Alaska, 320 );\7 '/;;J}I l:3~ @ '" 3300 .~. 2100 .~ 3600 .. 3900 . >I< 4200 .. 4500 t",2t&Bo '" 5100 >I< 5400 * 5700 2700 8 >I< 3000 @J Structure: Drill Site 2P ~~~~ \ ... 2100 , , \ \ ' '" 1 800 , \\2400, '..,.2400 , \2442,64 1800"', \ \ ' ~ ~\ \ '\ , \ \, '. 27qO*l\,270ö2400 " \ \ , \ '\ \ \ '. \ \ . \ \ ',I \ 3000~\ \ \. ',3000 \, \ \. \ 3300.~ ' '" 2;Ò,0 \ ' \, I \ \ ,\ ' .~ 3600' \3300 I \ I \ I ' ~ 3900 '\ \ \ \ I \ \ \ 3600 I * ¡. 4200 \ I \ \ \ I \ I \ ¡. 4500 . 240Ò\ \ ~', I , II '\ 3900 ' . 4800 \ I \ I \ \ \ \ \ .~ 5100 \ \ \ . I '~ 4200 0\,54°. 0 \'o" .~ 5700 , ~- . 2700 - 3360 I \ ~ R:a. IlAlŒR NIIGHi¡ ~ 160 320 0 160 ~'~ * 3000 .~ 1800 ;. 2400 Field: Meltwater 480 640 ;. 2700 .. 3000 3900 4200 \ID Well: 422A Location: North Slope, East (feet) -> 800 960 1120 1280 1440 1600 1760 1920 2080 2240 I I I I I ~.~~ .. . Ii< 18ÒO, .. 640 ~ ~" """""'" '. ~'" -" """",,. 2400 """" ~ - 960 '~ - 800 . '" 3000 .", 2.400 '" 2700 '>1<,3300 >It 2100 - 1120 >It 3600 .. 21 00.. . .. 2700 .. 300b ..... ~ - 1280 ..." 3900 '", 2700 .. - 1440 .....,.~- '" 3300~ "<¿] - 1600 >\1,2100 . 2100 .. 3000 .~..2~ - .... - 1760 ~- '", 2700 - 1920 >\(.2400 - 2080 IJ) 0 C - - 2240 :r- ~ -+. CD - 2400 ~ '--" ~- I - 2560 V >It 2400 \". 3300 '".3000 ~ ":5 - 2720 2700 '" - 2880 . 3300 ~- - 3040 - 3200 '" 3000 .. 3600 ~ \d - 3520 - 3680 B ~ - 3840 t 4000 0 ""G fi~'. ~., L ).~ ...:.. ,., ,) . 1 , i i 'IrJ i~'a ) Phillips AlasJka, Inc. Plot Reference is 2P-422A Version#1. Structure: Drill Site 2P Well: 422A Vertical Depths are reference RK8(Nordic Field: Meltwater Location: North Slape, iiö:¡¡¡iiI BAKER lIuœtI!IS ~ TRUE NORTH <=:r c::::J 350 0 1 0 340 20 330 210 30 320 40 310 50 300 60 290 70 280 80 30 270 38°6 -'-~- .-2?0 90 30 "'" .~,? -.' " 260 100 250 1 1 0 240 ;¡. 120 3000 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 v ~ ,. J """ ~ J .~ r~ J- ) Phillips Alaska, Inc. Drill Site 2P 422A slot #422A Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 2P-422A version#1 Our ref: prop5167 License: Date printed: 7-Mar-2002 Date created: 5-Mar-2002 Last revised: 6-Mar-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 9.663,w150 26 51.900 Slot Grid coordinates are N 5868975.305, E 444049.453 Slot local coordinates are 900.33 S 2092.34 E projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) 0'iÎ~j,~¡-.L ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,422A Your ref: 2P-422A Version#l Meltwater, North Slope, Alaska Last revised: 6-Mar-2002 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth COO R DIN ATE S Sect Maj or Minor Vert. Azi. 2952.00 55.06 145.26 2442.64 1071. 09 S 733.86 E 1266.89 64.09 l2.23 10.75 325.39 3000.00 54.22 145.84 2470.42 1103.38 S 756.00 E 1305.08 66.14 12.49 11. 09 325.41 3001.00 54.20 145.86 2471.00 1104.04 S 756.46 E 1305.87 66.18 12.49 11.10 325.41 3lOO .00 52.49 147.10 2530.10 1170.25 S 800.33 E 13 83 .63 70.21 13.02 11. 78 325.51 3200.00 50.78 148.41 2592.16 1236.55 S 842.17 E 1460.72 74.06 13.56 12.44 325.66 3300.00 49.08 149.79 2656.54 1302.20 S 881.48 E 1536.27 77.69 14.11 13.07 325.85 3400.00 47.39 151.23 2723.15 1367.12 S 918.20 E 1610.17 81.11 14 .66 13.68 326.08 3500.00 45.73 152.76 2791. 90 1431.22 S 952.30 E 1682.35 84.33 15.22 14.25 326.34 3600.00 44.09 154.38 2862.72 1494.43 S 983.73 E 1752.71 87.33 15.77 14.80 326.62 3700.00 42.47 156.10 2935.52 1556.67 S 1012.46 E 1821.16 90.13 16.32 15.32 326.91 3800.00 40.88 157.92 3010.22 1617.86 S 1038.44 E 1887.63 92.72 16.87 15.81 327.22 3862.74 39.90 159.13 3058.00 1655.69 S 1053.33 E 1928.28 94.23 17.22 16.11 327.43 3900.00 39.32 159.86 3086.71 1677.94 S 1061.65 E 1952.03 95.13 17.42 16.28 327.55 4000.00 37.80 161.94 3164.91 1736.82 S 1082.06 E 2014.29 97.35 17.96 16.72 327.88 4100.00 36.31 164.16 3244.72 1794.44 S 1099.64 E 2074.32 99.38 18.50 17.14 328.22 4160.81 35.43 165.59 3294.00 1828.84 S 1108.94 E 2109.71 100.51 18.82 17.38 328.43 4200.00 34.87 166.54 3326.04 1850.73 S 1114.37 E 2132.05 101.24 19.03 17.53 328.57 4300.00 33.47 169.10 3408.78 1905.61 S 1126.24 E 2187.43 102.94 19.56 17.91 328.92 4400.00 32.14 171.85 3492.84 1959.03 S 1135.23 E 2240.36 104.48 20.08 18.26 329.27 4401.37 32.12 171.89 3494.00 1959.75 S 1135.34 E 2241.07 104.50 20.09 18.26 329.28 4435.36 31. 68 172 . 87 3522.85 1977.55 S 1137.72 E 2258.49 105.00 20.27 18.38 329.40 4500.00 31.68 172 . 87 3577.86 2011.24 S 1141.93 E 2291. 33 105.97 20.61 18.60 329.62 5000.00 31.68 172.87 4003.36 2271.79 S 1174.54 E 2545.40 113.58 23.31 20.32 331.28 5500.00 31.68 172 .87 4428.86 2532.35 S 1207.15 E 2799.46 121.42 26.05 22.04 332.77 5721.09 31.68 172 . 87 4617.00 2647.56 S 1221. 57 E 2911.80 124.98 27.27 22.80 333.37 6000.00 31. 68 172.87 4854.35 2792.90 S 1239.76 E 3053.52 129.46 28.80 23.76 334 .12 6418.98 31.68 172.87 5210.90 3011.24 S 1267.08 E 3266.42 136.34 31.10 25.20 335.14 6500.00 31.68 172.87 5279.85 3053.46S 1272.37 E 3307.59 137 . 67 31. 55 25.48 335.34 6518.98 31.68 172.87 5296.00 3063.35 S 1273.61 E 3317.23 137.99 31.65 25.54 335.38 6612.99 31.68 172 . 87 5376.00 3112.34 S 1279.74 E 3365.00 139.55 32.16 25.86 335.59 6772.80 31.68 172 . 87 5512.00 3195.62 S 1290.16 E 3446.21 142.22 33.04 26.41 335.94 6869.16 31. 68 172.87 5594.00 3245.83 S 1296.44 E 3495.17 143.82 33.56 26.74 336.16 6991.37 31. 68 172.87 5698.00 3309.52 S 1304.41 E 3557.27 145.87 34.23 27.17 336.41 7000.00 31.68 172.87 5705.35 3314.02 S 1304.98 E 3561.65 146.02 34.27 27.19 336.43 7126.50 31.68 172 .87 5813.00 3379.94 S 1313.23 E 3625.93 148.16 34.96 27.63 336.69 7291.37 31.68 172 .87 5953.30 3465.85 S 1323.98 E 3709.70 150.94 35.86 28.20 337 .02 All data is in feet unless otherwise stated. Coordinates from slot #422A and TVD from RKB(Nordic 3) (254.00 Ft above mean sea Bottom hole distance is 3710.13 on azimuth 159.09 degrees from wellhead. Vertical section is from wellhead on azimuth 158.23 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . 0 . , .... . . . ì ! tílU,ívM... ') ) Phillips Alaska, Inc. Drill Site 2P,422A Mel twater, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-422A Version#l Last revised: 6-Mar-2002 POSITION UNCERTAINTY SUMMARY - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - --- - - - - - - - ---- Depth From Posi tion Uncertainty Major Minor Vert. To Survey Tool Error Model - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 0 2952 ARCO (H.A) Mag) ARCO (H.A) Mag) User specified User specified 12,23 35.86 64,09 150,94 2952 7291 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 Rectangular Coords. Comment TVD - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - - - - -- 2952.00 2442.64 1071. 09 S 733.86 E KOP - Sidetrack pt 3001.00 2471.00 1104,04 S 756,46 E C80 3862.74 3058.00 1655,69 S 1053.33 E C50 4160.81 3294.00 1828.84 S 1108.94 E C40 4401.37 3494,00 1959,75 S 1135.34 E C37 4435.36 3522,85 1977.55 S 1137.72 E EOC 5721,09 4617.00 2647.56 S 1221. 57 E T7 6418,98 5210,90 3011.24 S 1267,08 E 5 1/2 x 3 1/2 XO 6518.98 5296.00 3063.35 S 1273.61 E T4.1 (Top Cairn) 6612,99 5376.00 3112,34 S 1279.74 E T3.1 6772.80 5512.00 3195,62 S 1290.16 E T3 (Top Bermuda) 6869.16 5594,00 3245.83 S 1296.44 E MW(Z) Mid pt TGT RVSD 4 MAR 02 6991,37 5698,00 3309.52 S 1304.41 E T2 (Base Bermuda) 7126,50 5813,00 3379.94 S 1313 ,23 E C35 7291,37 5953.30 3465,85 S 1323,98 E TD - Csg pt Casing positions in string 'A' - -- ---- ------- - -- - - ----- -- --- - ------- - - - ---- - -- - - --- -- -- ---- TOP MD Top TVD Rectangular Coords, Bot MD Bot TVD Rectangular Coords, Casing ----------------------------------------------------------------------------------------------------------- n/a 2442,64 733,86E 7291.37 5953.30 1323,98E 3 1/2" CSG 3465.85S 1071,09S Targets associated with this wellpath - - ------- --- - - - ---- ---- -- - - - ----- - --- - ------------ - -- -- - --- - -- -- - --- --- --- Target name Geographic Location Rectangular Coordinates Revised T.V,D. ----------------------------------------------------------------------------------------------------------- MW (Z) Mid pt TGT RVS 445321. 000,5865720.000,999.00 5594,00 3245.83S 1296.44E 22-Feb-2001 10.75 28.20 OJ 1 ;AA~ ) Phillips Alaska, Inc. Drill Site 2P 422A slot #422A Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2P-422A Version#l Our ref: prop5l67 License: Date printed: 6-Mar-2002 Date created: 5-Mar-2002 Last revised: 6-Mar-2002 Field is centred on 441964.235,5869891.466,999,QOOOO,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9,663,w150 26 51,900 Slot Grid coordinates are N 5868975,305, E 444049.453 Slot local coordinates are 900.33 S 2092,34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) U .'j , U i J Y 1-1 L ') ) Phillips Alaska, Inc, PROP08AL LI8TING Page 1 Drill 8i te 2P, 422A Your ref: 2P-422A Version#l Meltwater,North 81ope, Alaska Last revised: 6-Mar-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D 8 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 8 Easting Northing COO R DIN ATE 8 2952,00 55.06 145.26 2442,64 1071. 098 733.86E 444775.06 5867898.75 n70 2 59.13 w150 26 30,77 3000.00 54,22 145,84 2470.42 1103.388 756,OOE 444796.95 5867866.31 n70 2 58.81 w150 26 30.13 3001.00 54,20 145,86 2471.00 1104.048 756,46E 444797,40 5867865,64 n70 2 58.80 w150 26 30.12 3100,00 52.49 147.10 2530,10 1170.258 800.33E 444840.76 5867799.10 n70 2 58,15 w150 26 28.86 3200.00 50.78 148.41 2592.16 1236.558 842,17E 444882.09 5867732.49 n70 2 57.50 w150 26 27.65 3300.00 49,08 149,79 2656.54 1302.208 881. 48E 444920,90 5867666.55 n70 2 56,85 w150 26 26.52 3400.00 47.39 151. 23 2723,15 1367,128 918,20E 444957.12 5867601.36 n70 2 56,21 w150 26 25,47 3500.00 45.73 152.76 2791. 90 1431. 228 952, 30E 444990.73 5867537.01 n70 2 55.58 w150 26 24.48 3600.00 44,09 154,38 2862.72 1494.438 983. 73E 445021,67 5867473,57 n70 2 54,96 w150 26 23.58 3700,00 42.47 156,10 2935.52 1556,678 1012.46E 445049,92 5867411.12 n70 2 54,35 w150 26 22,75 3800.00 40.88 157.92 3010.22 1617.868 1038,44E 445075,43 5867349,73 n70 2 53.75 w150 26 22.01 3862.74 39,90 159,13 3058.00 1655,698 1053.33E 445090,03 5867311. 80 n70 2 53,38 w150 26 21,58 3900.00 39,32 159,86 3086,71 1677.948 1061,65E 445098.18 5867289.49 n70 2 53.16 w150 26 21,34 4000.00 37.80 161. 94 3164.91 1736.828 1082. 06E 445118,14 5867230.45 n70 2 52.58 w150 26 20.75 4100.00 36,31 164,16 3244.72 1794.448 1099. 64E 445135,28 5867172.71 n70 2 52,01 w150 26 20,24 4160.81 35.43 165.59 3294.00 1828.848 1108, 94E 445144,32 5867138,25 n70 2 51.67 w150 26 19.98 4200.00 34.87 166.54 3326.04 1850.738 1114.37E 445149.59 5867116.31 n70 2 51. 46 w150 26 19,82 4300,00 33,47 169.10 3408,78 1905,618 1126, 24E 445161.03 5867061.35 n70 2 50.92 w150 26 19.48 4400.00 32.14 171,85 3492,84 1959.038 1135.23E 445169,61 5867007.87 n70 2 50.39 w150 26 19.22 4401.37 32.12 171.89 3494.00 1959.758 1135.34E 445169.71 5867007.15 n70 2 50,38 w150 26 19.22 4435.36 31.68 172,87 3522,85 1977 . 558 1137, 72E 445171,96 5866989,33 n70 2 50,21 w150 26 19.15 4500.00 31.68 172 . 87 3577.86 2011.248 1141.93E 445175.92 5866955.62 n70 2 49,88 w150 26 19,03 5000,00 31.68 172 ,87 4003.36 2271,798 1174,54E 445206.54 5866694,85 n70 2 47.32 w150 26 18,09 5500.00 31.68 172,87 4428,86 2532,358 1207.15E 445237,16 5866434,08 n70 2 44.75 w150 26 17.16 5721.09 31.68 172.87 4617,00 2647.568 1221.57E 445250.69 5866318.77 n70 2 43,62 w150 26 16,74 6000,00 31.68 172,87 4854,35 2792.908 1239.76E 445267,77 5866173.30 n70 2 42,19 w150 26 16,22 6418,98 31.68 172.87 5210.90 3011.248 1267,08E 445293.43 5865954.79 n70 2 40,04 w150 26 15.44 6500.00 31. 68 172 . 87 5279.85 3053,468 1272, 37E 445298.39 5865912.53 n70 2 39.63 w150 26 15.29 6518,98 31,68 172 ,87 5296,00 3063,358 1273.61E 445299.56 5865902.63 n70 2 39,53 w150 26 15,25 6612,99 31.68 172.87 5376.00 3112.348 1279.74E 445305.31 5865853.60 n70 2 39,05 w150 26 15,07 6772,80 31. 68 172 ,87 5512,00 3195,628 1290.16E 445315.10 5865770.26 n70 2 38,23 w150 26 14,78 6869,16 31.68 172,87 5594,00 3245.838 1296, 44E 445321.00 5865720.00 n70 2 37,73 w150 26 14,60 6991.37 31. 68 172 . 87 5698.00 3309,528 1304,41E 445328,48 5865656,26 n70 2 37.11 w150 26 14.37 7000,00 31.68 172 ,87 5705,35 3314.028 1304. 98E 445329.01 5865651.76 n70 2 37,06 w150 26 14,35 7126,50 31. 68 172 ,87 5813 ,00 3379,948 1313,23E 445336.76 5865585,78 n70 2 36,42 w150 26 14.11 7291,37 31. 68 172 ,87 5953,30 3465.858 1323.98E 445346.86 5865499.80 n70 2 35,57 w150 26 13,81 All data in feet unless otherwise stated, Calculation uses minimum curvature method, Coordinates from slot Jl422A and TVD from RKB(Nordic 3) (254,00 Ft above mean sea level). Bottom hole distance is 3710,13 on azimuth 159,09 degrees from wellhead, Total Dogleg for wellpath is 29,67 degrees, Vertical section is from wellhead on azimuth 158,23 degrees. Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0 r'-.~' .\ ~ rI fA ril~JiV ~ ') ') Phillips Alaska, Inc. Drill 8ite 2P,422A Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-422A Version#l Last revised: 6-Mar-2002 Comments in wellpath ----- -- - ----- - -- - --- ------ - --- -- ----- --- MD TlJD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 2952.00 2442.64 1071,09S 733.86E KOP - Sidetrack pt 3001. 00 2471.00 1104, 04S 756.46E C80 3862,74 3058.00 1655.698 1053, 33E C50 4160.81 3294,00 1828.848 1108.94E C40 4401.37 3494,00 1959, 75S 1135.34E C37 4435,36 3522,85 1977.558 1137, 72E EOC 5721,09 4617.00 2647,568 1221,57E T7 6418.98 5210,90 3011.248 1267.08E 5 1/2 x 3 1/2 XO 6518.98 5296,00 3063.358 1273.61E T4.1 (Top Cairn) 6612.99 5376.00 3112,348 1279,74E T3.1 6772.80 5512.00 3195.628 1290.16E T3 (Top Bermuda) 6869.16 5594,00 3245.838 1296.44E MW (Z) Mid pt TGT RV8D 4 MAR 02 6991.37 5698.00 3309. 52S 1304.41E T2 (Base Bermuda) 7126.50 5813.00 3379,948 1313.23E C35 7291.37 5953.30 3465.858 1323. 98E TD - Csg pt Casing positions in string 'A' - -- ------------ --- - ------ ----- - -- --------- --- ------ - -------- Top MD Top TlJD Rectangular Coords. Bot MD Bot TlJD Rectangular Coords, Casing ----------------------------------------------------------------------------------------------------------- nla 2442,64 733.86E 7291.37 5953.30 1323.98E 3 1/2" C8G 1071.09S 3465,858 Targets associated with this wellpath - ------- ---- -- ---- --- - ------ --------- - ------- ------ --- - ---- ---------- ----- Target name Geographic Location Rectangular Coordinates Revised T.V,D, - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- MW(Z) Mid pt TGT RV8 445321,000,5865720,000,999.00 5594.00 3245,83S 1296,44E 22-Feb-2001 O"liuÎ,ù~L ) Phillips Alaska, Inc. Drill Site 2P 422A slot #422A Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2P-422A Version#l Our ref: prop5l67 License: Date printed: 6-Mar-2002 Date created: 5-Mar-2002 Last revised: 6-Mar-2002 Field is centred on 44l964.235,586989l.466,999.00000,N Structure is centred on 44l964.235,586989l.466,999.00000,N Slot location is n70 3 9.663,w150 26 51,900 Slot Grid coordinates are N 5868975,305, E 444049.453 Slot local coordinates are 900.33 S 2092.34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) 0 "p h¡unJ¡~~ ) ') Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,422A Your ref: 2P-422A Version#l Mel twater, North Slope, Alaska Last revised: 6-Mar-2002 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 2952,00 55,06 145 ,26 2442.64 1071. 09 S 733.86 E 0,00 1266,89 KOP - Sidetrack pt 3000,00 54.22 145,84 2470.42 1103,38 S 756.00 E 2,00 1305,08 3001.00 54.20 145,86 2471.00 1104.04 S 756,46 E 2,00 1305,87 C80 3100,00 52.49 147,10 2530.10 1170.25 S 800.33 E 2,00 1383,63 3200,00 50.78 148,41 2592,16 1236.55 S 842,17 E 2,00 1460,72 3300,00 49,08 149,79 2656.54 1302.20 S 881. 48 E 2,00 1536.27 3400,00 47.39 151,23 2723 ,15 1367.12 S 918,20 E 2,00 1610.17 3500,00 45.73 152,76 2791,90 1431.22 S 952.30 E 2,00 1682.35 3600,00 44,09 154,38 2862,72 1494.43 S 983,73 E 2,00 1752.71 3700,00 42.47 156.10 2935,52 1556.67 S 1012,46 E 2.00 1821.16 3800,00 40.88 157,92 3010,22 1617.86 S 1038.44 E 2.00 1887.63 3862,74 39,90 159.13 3058.00 1655,69 S 1053.33 E 2,00 1928.28 C50 3900,00 39,32 159.86 3086,71 1677,94 S 1061.65 E 2,00 1952.03 4000,00 37.80 161.94 3164.91 1736,82 S 1082.06 E 2,00 2014,29 4100,00 36,31 164.16 3244.72 1794,44 S 1099,64 E 2,00 2074,32 4160,81 35,43 165,59 3294.00 1828,84 S 1108,94 E 2,00 2109.71 C40 4200,00 34,87 166,54 3326.04 1850.73 S 1114.37 E 2.00 2132,05 4300,00 33,47 169,10 3408.78 1905.61 S 1126.24 E 2.00 2187.43 4400,00 32,14 171,85 3492,84 1959.03 S 1135,23 E 2.00 2240.36 4401. 37 32.12 171,89 3494,00 1959.75 S 1135.34 E 2.00 2241. 07 C37 4435,36 31.68 172,87 3522,85 1977,55 S 1137.72 E 2,00 2258,49 EOC 4500,00 31.68 172 ,87 3577,86 2011,24 S 1141,93 E 0,00 2291,33 5000,00 31.68 172 .87 4003.36 2271,79 S 1174,54 E 0,00 2545,40 5500,00 31,68 172 .87 4428.86 2532.35 S 1207,15 E 0,00 2799,46 5721,09 31.68 172 . 87 4617.00 2647.56 S 1221. 57 E 0.00 2911. 80 T7 6000,00 31.68 172.87 4854.35 2792.90 S 1239.76 E 0.00 3053.52 6418,98 31.68 172 ,87 5210.90 3011.24 S 1267.08 E 0,00 3266.42 5 1/2 x 3 1/2 XO 6500,00 31.68 172 ,87 5279,85 3053.46 S 1272 .37 E 0,00 3307,59 6518,98 31.68 172 ,87 5296,00 3063,35 S 1273.61 E 0,00 3317,23 T4.1 (Top Cairn) 6612,99 31. 68 172,87 5376,00 3112,34 S 1279,74 E 0,00 3365,00 T3.1 6772,80 31. 68 172 .87 5512.00 3195,62 S 1290,16 E 0.00 3446,21 T3 (Top Bermuda) 6869,16 31.68 172 .87 5594.00 3245.83 S 1296.44 E 0.00 3495.17 MW(Z) Mid pt TGT RVSD 4 MAR 02 6991. 37 31,68 172 .87 5698.00 3309.52 S 1304.41 E 0,00 3557.27 T2 (Base Bermuda) 7000,00 31,68 172 . 87 5705,35 3314.02 S 1304.98 E 0,00 3561. 65 7126,50 31,68 172.87 5813 ,00 3379.94 S 1313,23 E 0,00 3625,93 C35 7291. 37 31. 68 172 ,87 5953,30 3465,85 S 1323,98 E 0,00 3709,70 TD - csg pt All data is in feet unless otherwise stated, Coordinates from slot #422A and TVD from RKB(Nordic 3) (254,00 Ft above mean sea Bottom hole distance is 3710,13 on azimuth 159.09 degrees from wellhead. Total Dogleg for wellpath is 29,67 degrees, Vertical section is from wellhead on azimuth 158.23 degrees, Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ level) . O'II~lIvAL ) Phi 11 ips Alaska, Inc, Drill 8i te 2P, 422A Mel twa ter, North 81ope, Alaska PROP08AL LI8TING Page 2 Your ref: 2P-422A Version#l Last revised: 6-Mar-2002 Comments in wellpath ------- - - -- - - ---- --- -------- - ---- ---- --- MD TVD Rectangular Coords. Comment - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 2952.00 2442,64 1071,09 8 733,86 E KOP - 8idetrack pt 3001.00 2471.00 1104,04 8 756.46 E C80 3862.74 3058,00 1655,698 1053.33 E C50 4160.81 3294,00 1828,84 S 1108,94 E C40 4401.37 3494,00 1959.75 8 1135,34 E C37 4435,36 3522.85 1977.55 8 1137,72 E EOC 5721,09 4617.00 2647.56 8 1221,57 E T7 6418,98 5210.90 3011.24 8 1267,08 E 5 1/2 x 3 1/2 XO 6518.98 5296.00 3063,35 8 1273,61 E T4.1 (Top Cairn) 6612,99 5376.00 3112,34 8 1279,74 E T3.1 6772,80 5512.00 3195,62 8 1290.16 E T3 (Top Bermuda) 6869,16 5594.00 3245.838 1296.44 E MW(Z) Mid pt TGT RV8D 4 MAR 02 6991.37 5698.00 3309,52 8 1304,41 E T2 (Base Bermuda) 7126.50 5813 ,00 3379,94 8 1313.23 E C35 7291,37 5953,30 3465,85 8 1323.98 E TD - Csg pt Casing positions in string 'A' ------------- ----- ----- --- - --- ------------ ----- ----- - - --- --- TOP MD TOp TVD Rectangular Coords, Bot MD Bot TVD Rectangular Coords, Casing ----------------------------------------------------------------------------------------------------------- n/a 2442.64 1071.098 733,86E 7291.37 5953,30 3465,858 1323.98E 3 1/2" C8G Targets associated with this we11path -- - -------- -- ---- --- - --- ------ ------- -- - -- ------- - ---- --- ---------- ------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(Z) Mid pt TGT RV8 445321.000,5865720,000,999,00 5594.00 3245,838 1296.44E 22-Feb-2001 \¡ ~ iIi u v. ~ ~ .,,' J J.. ") 2P-422A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) ) (See Well Plan for further discussion of these risks) Interval Risks Event Lost Circulation in Bermuda interval High ECD and swabbing if higher MW is required Hole stability during e- line runs if necessary I Risk Level High Low I Mitigation Strategy Good drilling practices. LCM as needed. Stay within ECD Hardline of 11.1 ppg. Pumping and rotating out on trips as needed to reduce swab and barite sag potential. Emphasis on maintaining mud properties. Clean out runs as needed. Good drilling practices Moderate 2P-422A Drilling Hazards Summary.doc prepared by Pat Reilly C 1 ¡ G ¡ Nt l:a~S¡~?~ Meltwater 2P-4~~A Proposed Completion Schematic Slim hole Base Case - 3-1/2" Completion String 16" 62,6# @ +1- 120' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Port Collar 1000' MD Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 2857' MD 12395' TVD Casing cemented to surface 2/15/02. 12' Pup (Critical) Intermediate csg. 5-112" 15,5# L-80 BTCM run CSR to surface +1- 6419' MD 15211' TVD Future Perforations Production csg 3-1/2" 9,3# L-80 EUE8RD TD to CSR +1- 7291' MD I 5953' TVD r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~..... ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -- ..-- ~ +- l ~,..,w....-n"'í ~ ~~~ ~ØW'Q...tc ,. , : , : : : ; : : +-- , . , . : ~ : : , , . . . , , . , . , , . , , . , i ¡ . . , , , . , . , , . . . , , : : , . , . , . . . , . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~') PHI¿UPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Cameo 'DS' nipple wI 2,875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Cameo 'KBG-2-9' Mandrels wI DV's and RK latch's (Max, aD 4,725", ID 2,90"), IBT box x box, 3-1/2" X 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 1ST pin x EUE8RD pin handling pup installed below, Spaced out wI 3-1/2" 9,3# L-80 EUE8RD tubing as follows: .G..!..M..1t TVD- RKB +/- MD-RKB GLM placement TBD. 3-1/2" x 1" Cameo 'KBG-2-9' mandrel wI DCK-3 shear valve and bottom latch (Max. aD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9,3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve w/ 2.813" Cameo No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top - Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" aD x 4" ID 17' Seal Bore Extension CSR set at +1- 100' MD above the top of the Bermuda (OR 100' MD ABOVE THE TOP OF THE CAIRN IF THE CAIRN IS PRESENT) 3-1/2" x6' 9,3# L-80 EUE8RD marker joint set just above the top of the Bermuda interval 0 f¡. .. ".;";./1 4 n, \.:1' ¡VA SLL, 16/02 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 3/6/2002 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 233-8808 email: ceavant@slb.com ri' '.! ~ I; ; t¡¡ i~l¡t i ¡L Previous Csg. .L[ < 75/8",29.7#, L-80 grade STC, A B Modif ied at 2,857 ft. MO Schlumbepger . Cb,.nCADEprélimihé\r)rJôb ..qesign 5t/2". x:3112'~Production Preliminary Job Design based on limitBd input data, For estimate purposes only, Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurrv (minimum thickening time 132 min.) GasBLOK wi Class G + D53, D600, D135, 0800, D047, D065, per lab testing @ 15.8 ppg, 1.2 fe/sk 0.0835 fe/ft x 500' x 1.75 (750/0 excess) = 0.1817 fe/ft x (7291' - 6419') x 1.75 (75% excess) = 0.0488 ft3/ft x 80' (Shoe Joint) = 73.1 fe + 277.3 fe + 3.9 ft3 = 354.3 fe I 1 .2 ft3/sk = Round up to 300 sks 73.1 ft3 277.3 fe 3.9 ft3 354.3 fe 295.3 sks BHST = 149°F, Estimated BHCT = 127°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative < 51/2",15.5#, L-80grade Stage (bpm) Volume (min) Time BTC, A B Modif ied (bbl) (min) in 6 3/4" OH CW 100 6 60 10.0 10.0 Drop Bottom Plug 3.9 13.0 MudPUSH XL 6 40 6.7 19.7 Tail Slurry 6 64 10.7 30.4 Drop Top Plug '3.0 33.4 Displacement 6 151 25.2 58.6 < Top of Tail at Bump Plug 3 9 3.0 61.6 5,919 ft. MO < X-over at 6,419 ft. MO < Top of Cairn Fm. at 6,519 ft. MO < 31/2",9.3#, L-80 grade EUE, 8rd Modified in 6 3/4" OH ìD at 7,291 ft. fv1D (5,953 ft. NO) . Mark of Schlumberger MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv:= 19-22, T y := 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. C 'J"G~J~Jði ,11 i\fd- ) ) Phillips Alaska, Inc. Drill Site 2P 422A slot #422A Meltwater North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 2P-422A Version#l Our ref: prop5167 License: Date printed: 12-Mar-2002 Date created: 5-Mar-2002 Last revised: 6-Mar-2002 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 9,663,w150 26 51.900 Slot Grid coordinates are N 5868975,305, E 444049.453 Slot local coordinates are 900.33 S 2092.34 E Proj ection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath MW L Version #1.C, ,421/L,Drill Site 2P 2P-419 AV version #1. C, ,419, Drill Site 2P 2P-418 AF version #l,C,,418,Dril1 Site 2P 2P-416 AZ version #l,C,,416,Drill Site 2P 2P-413 AC Version #l,C" 413, Drill Site 2P 2P-412 AW Version #1. C, ,412, Drill Si te 2P 2P-410 AX Version #1. C, ,410, Drill si te 2P 2P-424 AT Version #l.C, ,424,Drill Site 2P 2P-445 Version #2.a, ,445,Drill Site 2P 2P-408 AU Version #1.C,,408,Drill Site 2P MW AO Version #1.c, ,444/AO,Drill Site 2P MW E Version#1.e, ,442/E,Drill Site 2P MW AD Version#l.b, ,437/AD,Drill Site 2P 2P-434 Version #3,,434,Drill Site 2P 2P-443 Version #1.D,,443,Drill Site 2P 2P-449 (AR) VER#3.B,,449,Drill Site 2P 2P-446 C Version#O,a,,446,Drill Site 2P MW R Version#1.b" 432/R, Drill Site 2P 2P-414 S Version #1.C,,414/S,Drill Site 2P 2P-404 P Version #l,C,,404,Drill Site 2P 2P-402 U Version #1.C,,402,Drill Site 2P 2P-403 T Version #1.A,,403,Drill Site 2P 2P-406 (V) Version #1.C,,406,Drill Site 2P MW Q Version#1.b, ,433/Q,Drill Site 2P MW AK Version#l,b, ,435/AK,Drill Site 2P MW M VERSION #l,C,,426,Drill Site 2P 2P-425 K Version #l,A,,425,Drill Site 2P MW Y Version#1.b, ,428/Y,Drill Site 2P MW AP version#l.b, ,440/AP,Drill Site 2P MW AL Version#l.b, ,439/AL,Drill Site 2P 2P-427 Version#2,,427,Drill Site 2P Sperry Sun MWD 4052-7593 'MD(1/13/2)" 448A,Dril Sperry Sun MWD 0-755'MD(12/23/01),,448,Drill S MWD <0-2040'>,,448,Drill Site 2P Sperry Sun MWD 848-8663'MD(1!7/2) ,,448,Drill S MWD <0-9224'>,,438,Drill Site 2P MWD <0 - 6008'>,,417,Drill Site 2P MWD <0-6860'>,,420,Drill Site 2P MWD <0-8974' >, ,429, Drill Site 2P MWD <0-8853'>,,422,Drill Site 2P 2P-451 Version #2,,451,Drill Site 2P MWD <0-5950' >, ,451, Drill Site 2P 2P-447(AY OPTU) V1I4.B,,447,Drill Site 2P MWD <3660 - 11075'>,,415,Drill Site 2P MWD <5552 - 9038'>, ,415A,Drill Site 2P 2P-431 Version 1I3,,431,Dril1 Site 2P 2P-441 Version #l,D" 441, Drill Site 2P MWD <0-???'>,,441,Drill Site 2P MWD <0 - 8848' >Depth Shi fted, ,422A, Drill Site PMSS <0-6122' >, ,MWN#l, Meltwater North #1 PMSS <2212-7349'>, ,MWN#2A, Heltwater North #2 PMSS <0-6300'>, ,MWN#2,Meltwater North #2 PMSS <0-8935'>"MWSouthl,Meltwater South #1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D, Diverging from M.D, ll-Feb-2002 218.5 2952,0 2952,0 Il-Feb-2002 614.0 2952,0 2952,0 Il-Feb-2002 246,1 2952.0 2952,0 Il-Feb-2002 743,0 2952.0 2952,0 Il-Feb-2002 499,5 2952.0 2952,0 ll-Feb-2002 590.5 2952,0 2952,0 ll-Feb-2002 596.4 2952,0 2952,0 Il-Feb-2002 612.0 2952,0 2952,0 Il-Feb-2002 1787,1 2952.0 7291.4 Il-Feb-2002 979,0 2952.0 2952,0 Il-Feb-2002 1698.0 2952,0 2952,0 ll-Feb-2002 1548.8 2952,0 2952,0 Il-Feb-2002 1275.5 2952,0 2952,0 2-Jan-2002 1088.1 2952,0 2952.0 4-Jan-2002 1939.6 2952.0 2952.0 24-Sep-2001 2086,0 2952.0 2952,0 12-Sep-2001 1781.8 2952.0 2952,0 23-May-2001 1709.2 2952,0 2952,0 13-Dec-2001 1497.6 2952,0 2952.0 27-Nov-2001 1589,6 2952,0 2952.0 27-Nov-2001 1279,1 2952.0 2952.0 27-Nov-2001 1241,6 2952.0 2952,0 27-Nov-2001 1078.5 2952,0 2952.0 23-May-2001 1939.3 2952.0 2952,0 23-May-2001 1989,1 2952.0 2952,0 4-Jan-2002 1738,2 2952.0 2952.0 Il-Feb-2002 593,4 2952.0 2952.0 Il-Feb-2002 1005,3 2952.0 2952,0 ll-Feb-2002 1458.0 2952,0 2952,0 23-May-2001 2003.9 2952,0 2952.0 20-Feb-2002 543.1 2952,0 2952.0 20-Feb-2002 1911,2 2952.0 2952.0 20-Feb-2002 2312.0 2952.0 2952,0 28-Dec-2001 1932.9 2952,0 2952,0 20-Feb-2002 1911.2 2952,0 2952,0 4-Jun-2001 1357,5 2952.0 2952.0 25-May-2001 1246,8 2952.0 2952.0 14-Jan-2002 1285.5 2952.0 2952,0 27-Feb-2002 682.7 2952,0 2952,0 Il-Mar-2002 0,0 2952,0 2952.0 I1-Jan-2002 1958,6 2952.0 2952.0 Il-Mar-2002 1962,6 2952,0 2952,0 22-Jan-2002 1845.9 2952,0 2952,0 2-Dec-2001 890.3 2952,0 2952.0 17-Dec-2001 890,3 2952.0 2952.0 8-Mar-2002 999.3 2952.0 2952.0 I-Mar-2002 1305.2 2952,0 2952,0 12-Mar-2002 1311.7 2952,0 2952,0 5-Mar-2002 0.0 2952,0 2952.0 26-Feb-2001 3604,8 7291,4 7291.4 26-Feb-2001 2153.5 4250,0 4250,0 26-Feb-2001 2190,2 4520.0 4520,0 6-Mar-2001 43512.4 7291,4 7291,4 J 1 'GJ ~, j~ " ~ i~ .~, \~ ~ j ,. j V ;:-1 1.. PHilliPS ALASKA, INC. PAl PAYABLES P,O. Box 102776 Anchorage, AK 99510-2776 73-426/839 CHECK NUMBER 205112337 0997579 PAY TO THE ORDER OF: STATE OF ALASKA AOGCC 333 W. 7TH AVENUE, SUITE 100 FEBRUARY 28, 2002 *** VOID AFTER 90 DAYS *H "-" ,.., ~ BANK = ONE. - BANK ONE, NA . 0710 Chicago, IL Payable through Repub lie Bank & Trust Company EXACTLY **********100 DOLLARS AND 00 CENTS $********100.00 c Qf¿/~ /' é TRACE NUMBER: 205112337 $tð~A III 20 5 . . 2 j j 7111 I: 0 8 j gO '-t 2 b 21: 0 g g 7 5 7 gill "-"' REC ïVED MAR 1 3 200Z Alaska Oil & Gas CQ¡1S, Commissíon Anchorage ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ;fR4 .z,P- tjZ;¿/! CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL V EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) Pll.,OT HOLE (PH) , ANNU~SAL $.~NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a new wellbore segment of existing weD -----' Permit No, ,API No. . " Production should continue to be reported as a function of the original API number stated above. ' In accordance with 20 AAC 2S.005(f), all records, data and logs acquired for' the pilot hole mu'st be clearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (n~me on permit). Annular disposal has ~ot been requested... Annular Disposal, of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS ~ , 6£J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY //ffi)¡;.Ç WELLNAME#¿¡ u-~:¿2-A FIELD & POOL 7'<?ð /~o INITCLASS ¡J(2A/ /-ð;/ ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated. is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . \j;y N 11. Permit can be issued without conservation order. . . . . . . . Y N AJjfR - 9~ T7 12. Permit ca~ be issued without administrativ~ approval.. . . . . Y N ¡r¡!(./ 1//1/ð.2.. 13. Can permit be approved before 15-day walt.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . v--tt ~ 15. Surface casing protects all known USDWs. . . . . . . . . . . ¥---N- AlIA 16. CMT vol adequate to circulate on conductor & surf csg. . . . .¥---N-' 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . . Y N.,...... + 18. CMT will cover all known productive horizons. . . . . . . . . . (ý) N Ack1JvJJJ' 8¡~r-Rç ~ C-l.V(-," 19. Casing designs adequate fo.r C. T, B & permafrost. . . . . . . ~. N j,. '7 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . <y N No ¡ lÞ-a... ::> 21. If a re-drill. has a 10-403 for abandonment been approved. . . -¥-N 22. Adequate well bore separation proposed.. . . . . . . . . . . . & N 23. If diverter required. does it meet regulations. . . . . . . . . . -¥--N-' N/A 24. Drilling fluid program schematic & equip list adequate. . . . . &. N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . &2 N. .' \ 26. BOPE press rating appropriate; test to jOOO psig. ~ N tV{ Sp= l'1q.¡ f k , 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (JSD 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ~PR . - 9f.Tft 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . fir . ,JiI..v ð'?, 34. Contact name/phone for weekly progress reports [exploratory on ANNULAR DISPOSAL 35. With proper cementing records. this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N \ r ~ +. ¡ APPR DATE ,(B) ~iII not contaminate freshwater; or cause drilling waste. .. Y N tJv CkOI. ~ S p. 0U.' ,vve-tA./. f'-f,¡, ¡APÇ. t-ld ¡ to surface; ~, .\ - I Ì\ \. \ à ~ - - ~ (C) will not impair mechanical integrity of the well used for disposal; Y N f' O-'t- ~ ~~<:t. ~'l ~ ~'\ ..... ~ Q.."....: ~ 0" ~ .. (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: COMMISSION: RP&- TErh~'?1~'1 SFD- WGA lJJCtA-J PROGRAM: Exp - Dev X Redrl~ Serv - Wellbore seg - Ann. disposal para req - GEOL AREA ?7C) UNIT# /// .6 ð ON/OFF SHORE O~ APPR DATE w ÇA "S j N( (}'"J..- 1f:?f{) ~lt"\wù~ GEOLOGY < Commentsllnstructions: COT /1 ¡; DTS O~5/;71 ¿; L JMH G:\geology\templates\checklistdoc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simpltfy finding infonnation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically, . organize this category of infonnation. ) &œ-OW~ ) . .RECEIVED **** REEL HEADER **** LDWG 03/10/29 AWS 01 NOV 12 2003 Ata8ka on" Gu Coni.ComrniMCJn "'ïd\CI~gc.) I 2 :¿>-~-- **** TAPE HEADER **** LDWG 03/10/30 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER MELTWATER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA LDWG File Version 1.000 Extract File: LISTAPE.HED 2P-422A 501032040001 Phillips Alaska, Inc. BAKER HUGHES INTEQ 30-0CT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 F. WENDLER D. WESTER MWD RUN 2 2 C. WONG D. WESTER MWD RUN 3 3 S. TUFTON D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 17 8N 7E 254.00 224.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 7.625 2857.0 7310.0 6.750 # REMARKS: PER PHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 3' 9.6638" LONG: W150 DEG 26' 51.900" LOG MEASURED FROM D.F. AT 254.0 FT. ABOVE PERM. DATUM \2~~~"Ç}.J ) (Iv!. "L.). COMMENTS: (1) Baker Hughes INTEQ runs 1, 2, & 3 utilized the slimhole Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (OR D), Caliper Corrected Neutron (CCN), along with AP (Annular Pressure) and MPR (Mutiple Propagation Resistivity) services from 2878 - 7310 feet MD (2400 - 5984 TVD). ) REMARKS: (1) Depth of 7 5/8" Casing Shoe - Logger: 2856 feet MD (2387 TVD) Depth of 7 5/8" Casing Shoe - Driller: 2857 feet MD (2388 TVD) (2) The interval from 7259 to 7310 feet MD (5939 - 5984 TVD) was not logged due to senso-bit offset at TD. $ Tape Subfile: 1 67 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 clipped curves; all bit runs merged. .5000 START DEPTH 2857.0 STOP DEPTH 7310.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP lR 2857.0 2R 2879.0 MERGE BASE 2879.0 7310.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN 422a 5.xtf LCC CN WN FN COUN STAT 150 Phillips Alaska, Inc. 2P-422A Meltwater North Slope Alaska ) ) *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPS 0.0 RPX RPX RPCSHM 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 19 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 469 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 2857.000000 7310.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 517 records... Minimum record length: 8 bytes Maximum record length: ) 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE011.HED 2 ) log header data for each bit run in separate files. 1R .2500 START DEPTH 2800.0 STOP DEPTH 2879.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 14-APR-02 MSB 18704 4.75 SDN MEMORY 2930.0 2800.0 2879.0 0 54.0 54.0 TOOL NUMBER DAS 1363 10044706 10044706 MPR 1088 SRIG 2116 6.750 2857.0 LSND 10.00 .0 .0 50 .0 .000 .000 .000 .000 92.0 .0 .0 .0 Sandstone 0.00 .000 .0 # EWR FREQUENCr ,lz): REMARKS: # BIT RUN lR (MWD Run 2) . GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER PHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 422a.xtf 150 Phillips Alaska, Inc. 2P-422A Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 14 1 ) FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK COMP 68 1 PU-S 4 4 14 ROPS COMP 68 1 FPHR 4 4 15 RPTH COMP 68 1 MINS 4 4 16 TCDM COMP 68 1 DEGF 4 4 ------- 64 Total Data Records: 23 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 2800.000000 2879.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 133 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE012.HED 3 log header data for each bit run in separate files. 2R .2500 START DEPTH 2879.0 STOP DEPTH 7310.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 19-APR-02 SURFACE SO~.)ARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RES IS. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # MSL )704 4.75 SDN MEMORY 7310.0 2879.0 7310.0 0 29.0 50.0 TOOL NUMBER DAS 1363 10044706 10044706 MPR 1088 SRIG 2116 6.750 2857.0 LSND 9.80 .0 .0 600 .0 .000 .000 .000 .000 123.0 .0 .0 .0 Sandstone 0.00 .000 .0 0 BIT RUN 2R (MWD Run 3) . GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER PHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS 1 , MNEM VALU ) ) ------------------------------ WDFN LCC CN WN FN COUN STAT 422a.xtf 150 Phillips Alaska, Inc. 2P-422A Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 14 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK COMP 68 1 PU-S 4 4 14 ROPS COMP 68 1 FPHR 4 4 15 RPTH COMP 68 1 MINS 4 4 16 TCDM COMP 68 1 DEGF 4 4 ------- 64 Total Data Records: 1267 . .. ~ ~ .\ ) Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 03/10/30 01 **** REEL TRAILER **** LDWG 03/10/29 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: ) 2879.000000 7310.000000 0.250000 1377 records... 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes