The URL can be used to link to this page

Home My WebLink About204-0221. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Extend Suspension Date 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7350' 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 12/31/2025 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple Perforation Depth MD (ft): L-80 2622' 1617'-1638', 2650-2800', 6922- 6942' (below cement plugs) 7316' 1569-1588', 2369-2479', 5593- 5608' (below cement plugs) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2650' 5916'7344' 16" 9-5/8" 82' 6336' MD 110' 2369' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6319' MD and 5139' TVD 512' MD and 512' TVD Leslie Manning 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 (907) 263-3731 Senior CTD/RWO Engineer KRU 2P-406 5921' 28' 28' 28', 1650', 2250', 2750', 2820', 5025', 6862', 6899' N/A 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 Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: e: Leslie Manning 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:Leslie.Manning@conocophillips.com (907)263-3731 Senior CTD/RW O Engineer Date for 15.W ell Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG esentative:GINJ Op Shutdown Abandoned 12/31/2025 nts: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service SSSV Type:Packers and SSSV MD (ft) and TVD (ft):Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple 6319' MD and 5139' TVD 512' MD and 512' TVD 3-1/2" pth MD (ft): L-80 650-2800', 6922- cement plugs) 1569-1588', 2369-2479', 5593- 5608' (below cement plugs) Perforation Depth TVD (ft): 6336' Tubing Grade: Tubing MD (ft):Tubing Size: on 7316'5-1/2" x 3-1/2"5916'7344' ate e 2622'2650'9-5/8"2369' or 110'16"82'110' quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Extend Suspension Date er Casing ame:4.Current Well Class:5.Permit to Drill Number: Exploratory Development Stratigraphic Service 6.API Number: g:8.W ell 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 MD s Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst ADL0373112 204-022 360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended quire a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): KRU 2P-406 5921'28'28'28', 1650', 2250', 2750', 2820', 5025', 6862', 6899' 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 326-011 By Grace Christianson at 8:37 am, Jan 09, 2026 SFD 1/22/2026 July 1, 2026 DSR-1/22/26 VTL 1/26/2026 none July 1, 2026 Reassessment of well status by March 1, 2026. 10-403 required to continue work. JLC 1/26/2026 01/26/26 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. 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-4 (PTD# 20 ). This 10-403 is being submitted to request an extension of the Suspension Expiration Date from December 31, 2025 to July 1, 2026. The purpose of this extension is to allow for systematic monitoring of OA pressure and to enable a data-driven decision on the appropriate next steps. We will monitor OA pressure and, by March 1, 2026, determine the path forward based on pressure data analysis. Depending on the results, we anticipate one of the following actions: 1) If OA re-pressurization ceases, we will proceed to post-rig P&A surface excavation work. 2) If OA re-pressurization is trending down, we will continue monitoring and bleeding, and reassess options to complete the abandonment. 3) If OA re-pressurization increases, we will plan to perform RWO to complete the abandonment. A new 10-403 will be submitted prior to any further intervention. If you have any questions, please contact me at (907) 263-3731. Sincerely, Leslie Manning Senior CTD/RWO Engineer Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.0 2P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated TOC after slickline tag 2P-406 8/21/2025 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007 WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 62.50 WELDED SURFACE 9 5/8 8.83 28.1 2,649.8 2,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 -36.0 2,540.0 2,287.2 15.50 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 2,590.0 7,344.1 5,916.0 15.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 2,945.0 Set Depth 6,336.0 Set Depth 5,151.3 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.9 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.6 5,052.6 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.3 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.5 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 1,650.0 1,598.0 30.58 CIBP Baker CIBP 11/14/2025 0.000 2,500.0 2,257.4 41.95 CEMENT RETAINER K1 Cement Retainer 11/12/2025 0.000 2,820.0 2,493.8 43.31 CIBP YJ CIBP, OAL 2.2' 11/25/2024 0.000 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTS CIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 1,616.5 1,638.0 1,569.0 1,587.7 11/14/2025 APERF 4 3/8" Gator Mechanical Perforating Tool. from 1638' T/ 1616.5 2 cuts at 180deg phasing at 1.5' Spacing. 2,650.0 2,800.0 2,369.0 2,479.2 11/25/2024 APERF 4 3/8" Gator Mechanical Perforating Tool. from 2,800' to 2,650'. 4 cuts at 90deg phasing at 1.5' Spacing. Rotated 45deg each cut. 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.0 6,942.0 1 FRAC 5/10/2004 0.0 0.00 0.00 2P-406, 1/7/2026 3:42:21 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 2,590.0-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.6 GAS LIFT; 5,721.9 Cement Casing; 3,845.0 ftKB Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 CIBP; 2,820.0 Production String 1 Cement; 2,750.0 ftKB APERF; 2,650.0-2,800.0 SURFACE; 28.1-2,649.8 PRODUCTION 5.5"x3.5" @ 6333'; -36.0-2,540.0 CEMENT RETAINER; 2,500.0 Squeeze Behind Casing Squeeze; 2,250.0 ftKB CIBP; 1,650.0 APERF; 1,616.5-1,638.0 Cement Casing; 34.0 ftKB CONDUCTOR; 28.0-110.0 Plug & Abandonment; 28.1 ftKB KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE2P-406 Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 34.0 2,650.0 34.0 2,369.0 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 102Drag up (lbs): 110Time started reciprocating: 16:30Time stopped reciprocating: 20:35Annular flow after cement job (Y/N): NCirculating BHT (F): 74Static BHT (F): 58Pressure before cementing (psi): 450Hours circulated between stages: 2.25Bbls cmt to surf: 121.9Method used to measure density: DensometerMethod used for mixing cement in this stage: TUBReturns (pct): FULLTime cementing mixing started: 19:42 2/28/2004 3,845.0 7,344.0 3,260.6 5,915.9 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 75000Drag up (lbs): 140000Time started reciprocating: 00:30Time stopped reciprocating: 12:35Annular flow after cement job (Y/N): NCirculating BHT (F): 113Static BHT (F): 143Pressure before cementing (psi): 300Hours circulated between stages: 11Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchReturns (pct): FULLTime cementing mixing started: 09:45 4/26/2004 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 5,025.0 6,253.0 4,157.5 5,088.8 Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2,750.0 2,820.0 2,442.7 2,493.8 Production String 1 Cement Layed in 420' 15.8 PPG Class G Cement Plug (TOC=2400') DRILLED OUT CEMENT T/ 2750 11/8/25 W/ 7ES. 7/11/2025 2,250.0 2,750.0 2,071.8 2,442.7 Squeeze Behind Casing Squeeze Hesitation squeeze 38 Bbls of 15.8 PPG PTA cement below cement retainer @ 2500'. Un Sting balance 7 Bbls of 15.8 PPG PTA cement on top of retainer. 11/11/2025 28.1 1,650.0 28.1 1,598.0 Plug & Abandonment Pump 175 Bbls 15.8 PPG PTA cement @ 3.5 BPM, 1060 PSI. 25 Bbls cement Returned T/ surface. 11/15/2025 2P-406, 1/7/2026 3:42:23 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 2,590.0-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.6 GAS LIFT; 5,721.9 Cement Casing; 3,845.0 ftKB Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 CIBP; 2,820.0 Production String 1 Cement; 2,750.0 ftKB APERF; 2,650.0-2,800.0 SURFACE; 28.1-2,649.8 PRODUCTION 5.5"x3.5" @ 6333'; -36.0-2,540.0 CEMENT RETAINER; 2,500.0 Squeeze Behind Casing Squeeze; 2,250.0 ftKB CIBP; 1,650.0 APERF; 1,616.5-1,638.0 Cement Casing; 34.0 ftKB CONDUCTOR; 28.0-110.0 Plug & Abandonment; 28.1 ftKB KUP PROD 2P-406 ... WELLNAME WELLBORE 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 Originated: Delivered to:20-Nov-25Alaska Oil & Gas Conservation Commiss20Nov25-NRATTN: Meredith Guhl333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539Anchorage, AK 99518(907) 273-1700 main (907)273-4760 faxWELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTIONDATA TYPE DATE LOGGED2P-A 50-103-20475-01-00 204-009 Kuparuk River WL SCMT FINAL FIELD 6-Nov-252P-406 50-103-20484-00-00 204-022 Kuparuk River WL IBC-CBL FINAL FIELD 9-Nov-25CD4-209 50-103-20532-00-00 206-065 Colville River WL Patch Setting FINAL FIELD 11-Nov-251Y-22 50-029-22369-00-00 193-070 Kuparuk River WL LDL FINAL FIELD 14-Nov-251G-12 50-029-21009-00-00 183-132 Kuparuk River WL LDL FINAL FIELD 15-Nov-25Transmittal Receipt________________________________X__________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.Nraasch@slb.comSLB Auditor - TRANSMITTAL DATETRANSMITTAL #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-PrivateT41163T41164T41165T41166T411672P-406 50-103-20484-00-00204-022Kuparuk RiverWLIBC-CBLFINAL FIELD9-Nov-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.21 09:11:58 -09'00' 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:Umait Drilling Rig:X Rig Elevation:Total Depth:7350 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 110 Feet Csg Cut@ na Feet Surface:9 5/8"O.D. Shoe@ 2,650 Feet Csg Cut@ na Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:5 1/2"-3 1/2"O.D. Shoe@ 7,344 Feet Csg Cut@ na Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2 O.D. Tail@ 6,336 Feet Tbg Cut@ 2,945 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Retainer 2750 ft 2250 ft Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 0 0 0 IA 1700 1620 1600 OA 1700 1620 1600 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to KRU 2P-406 to witness a cement plug tag and CMIT-IAxOA. Nabors Rig 7ES was over the well and set a cement retainer @ 2500 ft MDS after section milling Surface casing from 2540 ft t- 2590 ft MD (remedial work per Sundry 325-589). They tagged to of cement at @ 2,250 ft MD with a solid 10k lb tag, followed by a 30 minute test to 1500 psi. AOGCC Engineer Victoria L. approved the tag and 1500psi test on 11-13-2025 which is different from the sundry approval. November 14, 2025 Adam Earl Well Bore Plug & Abandonment KRU 2P-406 CPAI PTD 2040220; Sundry 325-589 none Test Data: P Casing Removal: K.Barr Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1114_Plug_Verification_KRU_2P-406_ae                  Refer to AOGCC Inspection Report 8/20/2025 (J. Hunt) for background info. -- J. Regg; 12/3/2025 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U MELT 2P-406 JBR 12/30/2025 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:3 2 7/8" test joint used for testing. The LPR were not tested as they are not to be used. The PVT's and flow indicator audible were not functional due to a software/server issue. I did not witness the retesting of them once they were working properly. Videos of them working were sent to me and I gave them the go-ahead to go to work. Test Results TEST DATA Rig Rep:C. Kelly/J. HintonOperator:ConocoPhillips Alaska, Inc.Operator Rep:K. Barr/Chase Erdman Rig Owner/Rig No.:Nabors 7ES PTD#:2040220 DATE:11/7/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC251107132319 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 0 Sundry No: 325-589 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5" VB P #2 Rams 1 Blind P #3 Rams 1 3 1/2"x5 1/2" 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 0 NA System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P12 Full Pressure Attained P117 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@ 2100 ACC Misc NA0 P PTrip Tank F FPit Level Indicators P FFlow Indicator P PMeth Gas Detector P PH2S Gas Detector P PMS Misc Inside Reel Valves 0 NA Annular Preventer P23 #1 Rams P6 #2 Rams P6 #3 Rams NT0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1            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:14. Permit to Drill Number / Sundry: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI:x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth:x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 9-5/8"L-80 2369' 5-1/2"L-80 5149' 3-1/2"L-80 5916' 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 6333' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 7344' 28' 5149' 62.5# 40# 110' 28' WT. PER FT.GRADE 448028 448361 CEMENTING RECORD 5868628 1375' MD/ 1351' TVD SETTING DEPTH TVD 5868605 TOP HOLE SIZE AMOUNT PULLED Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl:Water-Bbl: Layered in 420' 15.8 ppg Class G Cement 5025' (SW TOC)-6253'31 bbls 15.8 ppg Cement Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: Flow Tubing 2363'-2820' SUSPENDED 2650-2800' MD and 2369-2479' TVD (below cement plug) 6922-6942' MD and 5593-5608' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 6319' MD/5139' TVD (seal assembly) PACKER SET (MD/TVD) 42" 12.25" 104 sx AS I 28'342 sx AS Lite, 229 sx LiteCrete 9.3# 28' 6333' 2650'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20484-00-00 KRU 2P-406 ADL0373112 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM 1240' FNL, 1123' FWL, Sec. 16, T8N, R7E, UM ALK 32092 2/27/2004 7350' MD/ 5921' TVD 2363' MD/ 2156' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444361 5869047 1219' FNL, 789' FWL, Sec. 16, T8N, R7E, UM 4/24/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 6. Date Comp., Susp., or Aband.:08/20/2025 204-022/ 324-620 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 623 sx Class G8.5" 6336'3-1/2" CASING G s d 1 0 p dB Pf L (a Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Suspended 8/20/2025 JSB RBDMS JSB 110325 xG Received 10/29/2025 DSR-11/26/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1375' 1351' Top of Productive Interval N/A 31. List of Attachments:Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email:Jill.Simek@conocophillips.com Contact Phone: (907) 263-4131 Staff Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: N/A - Suspended Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS N/A- Suspended N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jill Simek DN: CN=Jill Simek, E=jill.simek@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2025.10.29 15:18:44-08'00'Foxit PDF Editor Version: 13.1.6Jill Simek Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.02P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated TOC after slickline tag2P-406 8/21/2025 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 2,945.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.9 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.6 5,052.6 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.3 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.5 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 2,820.02,493.8 43.31 CIBP YJ CIBP, OAL 2.2'11/25/2024 0.000 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 2,650.0 2,800.02,369.02,479.211/25/2024 APERF 4 3/8" Gator Mechanical Perforating Tool. from 2,800' to 2,650'. 4 cuts at 90deg phasing at 1.5' Spacing. Rotated 45deg each cut. 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 34.0 2,650.0 34.0 2,369.0 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 102Drag up (lbs): 110Time started reciprocating: 16:30Time stopped reciprocating: 20:35Annular flow after cement job (Y/N): NCirculating BHT (F): 74Static BHT (F): 58Pressure before cementing (psi): 450Hours circulated between stages: 2.25Bbls cmt to surf: 121.9Method used to measure density: DensometerMethod used for mixing cement in this stage: TUBReturns (pct): FULLTime cementing mixing started: 19:42 2/28/2004 2P-406, 10/3/2025 10:47:53 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.6 GAS LIFT; 5,721.9 Cement Casing; 3,845.0 ftKB Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 CIBP; 2,820.0 APERF; 2,650.0-2,800.0 SURFACE; 28.1-2,649.8 Production String 1 Cement; 2,363.0 ftKB Cement Casing; 34.0 ftKB CONDUCTOR; 28.0-110.0 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 3,845.0 7,344.0 3,260.6 5,915.9 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 75000Drag up (lbs): 140000Time started reciprocating: 00:30Time stopped reciprocating: 12:35Annular flow after cement job (Y/N): NCirculating BHT (F): 113Static BHT (F): 143Pressure before cementing (psi): 300Hours circulated between stages: 11Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchReturns (pct): FULLTime cementing mixing started: 09:45 4/26/2004 6,862.06,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 5,025.06,253.0 4,157.5 5,088.8Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2,363.0 2,820.0 2,156.0 2,493.8 Production String 1 Cement Layed in 420' 15.8 PPG Class G Cement Plug (TOC=2400') 7/11/2025 2P-406, 10/3/2025 10:47:55 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.6 GAS LIFT; 5,721.9 Cement Casing; 3,845.0 ftKB Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 CIBP; 2,820.0 APERF; 2,650.0-2,800.0 SURFACE; 28.1-2,649.8 Production String 1 Cement; 2,363.0 ftKB Cement Casing; 34.0 ftKB CONDUCTOR; 28.0-110.0 KUP PROD 2P-406 ... WELLNAME WELLBORE SUNDRY NOTICE 10-407 ConocoPhillips Well 2P-406 Plug and Abandonment October 1, 2025 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2P-406, per Sundry #325-356. After PWC steps were performed, the P&A program was aborted due to failing drawdown tests on the OA. This 10-407 will close out P&A activities to this point. A rig will be used to finish the abandonment activities, under a separate sundry application. DTTMSTART JOBTYP SUMMARYOPS 6/23/2025 SUPPORT OTHER OPERATIONS TRAVEL FROM 2P-447. SPOT UP RIG UP CTU #4. PULLED PLUG @ 2445', FREEZE PROTECT WELL WITH 60 BBLS DIESEL. READY FOR PWC. 7/9/2025 SUPPORT OTHER OPERATIONS MOVE UPRIGHTS & OPEN TOP'S OVER FROM 2P-415 TO 2P-406. MIRU CTU 6 W/ 11,500' OF 2" CT (29.3 BBLS FUV) & SUPPORT EQUIPMENT. IN PROGRESS. 7/10/2025 SUPPORT OTHER OPERATIONS TAG @ 2820' RKB. PERF WASH 2820' - 2600'.UP/DOWN/UP/DOWN PER PROCEDURE PUMPING SLICK FRESH WATER AT 3.50 BPM. DROP 5/8" BALL & SHIFT CEMENT NOZZLE PISTON. HALLIBURTON CEMENTERS CURRENTLY RIGGING UP IN PROGRESS. 7/11/2025 SUPPORT OTHER OPERATIONS WASH/LAY IN 15.8 PPG CLASS G CEMENT FROM 2818' RKB UP 800' RKB, CLEAN OUT DOWN TO 2400', FREEZE PROTECT W/ DIESEL FROM 2300' TO SURFACE. READY FOR STATE WITNESS TAG & TEST IN 48 HOURS. 7/14/2025 SUPPORT OTHER OPERATIONS PERFORMED A MIT-T TO 1500 PSI *PASS* READY FOR SLICKLINE SW TAG & TEST 7/16/2025 SUPPORT OTHER OPERATIONS (P&A) BLEED OA (IN PROGRESS) 7/20/2025 SUPPORT OTHER OPERATIONS (P&A) BLEED OA (COMPLETED) 7/24/2025 SUPPORT OTHER OPERATIONS (P&A) OA DDT TO 0 PSI. (PASSED) 7/29/2025 SUPPORT OTHER OPERATIONS (P&A) OA DDT TO 0 PSI (PASSED) 7/31/2025 SUPPORT OTHER OPERATIONS (P&A) OA DDT TO 0 PSI (PASS) 8/2/2025 SUPPORT OTHER OPERATIONS (P&A) OA DDT TO 0 PSI (PASS). 8/4/2025 SUPPORT OTHER OPERATIONS (P&A) OA DDT TO 0 PSI (PASS). 8/20/2025 SUPPORT OTHER OPERATIONS AOGCC WITNESS: JOSH HUNT TAG TOC @ 2342' SLM / 2363' RKB, OBTAIN PASSING MIT-T 1500 PSI. 2P-406 Suspend/Plug and Abandon Summary of Operations 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:Loepp, Victoria T (OGC) To:Ohlinger, James J Cc:McLellan, Bryan J (OGC) Subject:KRU 2P-447(PTD 203-154, Sundry 325-587) and KRU 2P-406(PTD 204-022, Sundry 325-589) APPROVAL Date:Tuesday, October 28, 2025 12:33:28 PM Attachments:2P-447_406 Sundry Letter.docx James, The outlined modifications to the approved sundries are approved. Please include this approval with each of your copies of the approved sundries. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Tuesday, October 28, 2025 8:45 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: 2P-447 and 2P-406 Sundry Please find the attached updates to the Sundries listed. James J. Ohlinger CPAI CTD Staff Engineer Office: 907-265-1102 Cell: 907-229-3338 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 27, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: We are expecting to move the rig to 2P-406 after 2T-208 which is to begin operations shortly, so we estimate to begin Nov. 1st-7th. Recently ConocoPhillips submitted and received sundries for 2P-406 (325-589) and 2P-447 (325-587). The basic operations are summarized as: Plan • Drill out cement • IBC/DSLT (CBL) logging tool • Section Mill casing • Set cement retainer • Pump cement • Pressure test OA • Punch casing • Cement casing and OA to surface We are writing the operational procedural and have had several meetings to discuss lessons learned and best practices. Upon review, we’d like to discuss a few variables that may or may not affect the original sundry. Section Milling – We are relying on the IBC/DSLT log to depict where we section mill. The preference is to complete the 50' of section milling entirely above the Surface Casing shoe to repair inadequate cement within the surface casing. My sundry application has it described to mill from 10-14’ inside the surface casing down, for a 50’ total. Cementing – The base plan is to set a cement retainer above the section milled area; however a balanced plug may be required. We have developed a list of pros/cons for either option and will let wellbore conditions and injection rate determine if a cement retainer or balanced plug is used. Cement retainer • if we see high flow rate into the OA with low pressure • Ability to apply and keep pressure, perform hesitation squeezes • Only limited to amount of cement available at surface Cement Plug • low rate with high injection pressure • Just as good if we have circulation • Faster and less rig up equipment • Can easily mill out if needed Cementing – This concept applies to 2P-406. Currently the OA DDT test will pass after the OA pressure is bleed off and monitored for an hour. It takes several days to build any pressure; i.e. between 7/29 and 7/31 it built 13 psi. If we are able to verify injectivity through the existing cement down squeeze in the Surface Casing, we request the ability to utilize an option to cut and pull the production casing above the TOC within the Surface casing. This would be followed by utilizing a kill string to pump cement from the casing cut to surface and squeezing cement down through the inadequate cement. Please let us know if you have questions, comments, or suggestions. James Ohlinger CTD/RWO Staff Engineer CPAI Drilling and Wells 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: RIG PA 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): 7350' 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 10/27/2025 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple Perforation Depth MD (ft): L-80 2622' 2650-2800', 6922-6942' (below cement plug) 7316' 2369-2479', 5593-5608' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2650' 5916'7344' 16" 9-5/8" 82' 6336' MD 110' 2369' 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 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6319' MD and 5139' TVD 512' MD and 512' TVD James Ohlingher 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: James.J.Ohlinger@conocophillips.com (907) 265-1102 Staff CTD/RWO Engineer KRU 2P-406 5921' 2363' 2156' 2363', 2820', 5025', 6862', 6899' N/A m n P s 66 tc N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:55 am, Oct 01, 2025 Digitally signed by James J. Ohlinger DN: CN=James J. Ohlinger, E=James.J.Ohlinger @cop.com Reason: I am the author of this document Location: Date: 2025.09.30 16:28:53-08'00' Foxit PDF Editor Version: 13.1.6 James J. Ohlinger 325-589 Record daily wellhead pressure readings for 30 days after placing cement plugs. Report any signs of sustained casing pressure to AOGCC. DSR-10/15/25A.Dewhurst 14OCT25 OA DDT spans at least 24 hrs after cement is circulated in place. Provide 24 hrs for AOGCC to witness last 1 hr of DDT. Submit results of DDT and obtain approval from AOGCC before perforating for surface cement job. X BJM 10/21/25 X BOP test to 2500 psi Surface cement plug must be minimum of 150' in length, extending to ground surface. Provide 24 hrs notice for AOGCC opportunity to witness 15 klb tag of top of cement at ~2550' MD and pressure test CMIT IAxOA to 2000 psi. 10-407 10/22/25 General Well info Estimated Start Date: 10/27/25 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is Suspended as of 11/26/24 Well Type: Producer History: 2P-406 was a jet pump producer that was shut in, Sept 2021. This well has been suspended with a reservoir cement plug and an intermediate cement plug (covered in a separate 10-403). Different than others in the P&A Campaign, the OA had an arctic pack cement job performed in 2012. The steps outlined in Sundry 324-619 included pulling the tubing, setting a plug in and above the C80 formation, and casing punches below the surface casing shoe on Nordic 3. Sundry 325-356 scope was to perform PWC, then cement to surface and excavate/remove wellhead. PWC was attempted 7/11/25 (37 bbls Class G cement). A passing MIT was obtained (1500psi), however the OA has repressurized. 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. The objective of this procedure is to stop the OA pressurization, and continue to fully P&A. BOP configuration: Annular/Variable Bore Rams/Blind Rams/Pipe Rams Following subject to change/be updated with pre-rig work: Meltwater Formation: Reservoir pressure 5/14/13 = 2474 psi @ 5600 TVD MASP = 0 psi (Cemented) C-80 Formation: OA Pressure = 168 psi (8/29/24) (TOC in OA estimated @ 1787 RKB, assume diesel gradient) MASP = 758 psi using 0.1 psi/ft gas gradient Intermediate plug TOC = 2363 (SL Tagged) Tubing cut depth = 2950 RKB Most recent tests: MIT-T 8/20/25 to 1500psi Initial I/O = 65 / 55 DDT-OA Passed; Initial SI Vac/13 60 Min = 0 / 0 Cemented with 50 bbls 12 ppg DeepCrete followed by 83 bbls Isotherm insulating packer fluid 1/15/2012. -bjm OA DDT spans at least 24 hrs after cement is circulated in place. Provide 24 hrs for AOGCC to witness last 1 hr of DDT. Submit results of DDT and obtain approval from AOGCC before perforating for surface cement job. -bjm Confirm TOC by setting 15klbs down and CMIT IAxOA to 2000 psi. Provide 24 hrs notice for AOGCC opportunity to witness. -bjm 2P-406 Existing Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.06 62.5 Welded Surface 2650 2369 9.625 8.83 40 L-80 BTC Production 7344 5916 5.5 4.95 15.5 L-80 BTC Liner 7344 5916 3.5 2.992 9.3 L-80 EUE Tubing 6336 5151 3.5 2.992 9.3 L-80 EUE Arctic Cement Diesel Pack BBLS BBLS Surface Casing Production 3-1/2" Conductor 2P-406 Proposed RWO P&A Completion 9-5/8" Surface Casing 2650' MD Production 3-1/2" Conductor Production Casing 5.5" - 15.5# Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,932.0 2P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated TOC after slickline tag 2P-406 8/21/2025 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007 WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 62.50 WELDED SURFACE 9 5/8 8.83 28.1 2,649.8 2,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.0 15.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 2,945.0 Set Depth 6,336.0 Set Depth 5,151.3 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.9 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.6 5,052.6 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.3 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.5 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 2,820.0 2,493.8 43.31 CIBP YJ CIBP, OAL 2.2' 11/25/2024 0.000 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTS CIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 2,650.0 2,800.0 2,369.0 2,479.2 11/25/2024 APERF 4 3/8" Gator Mechanical Perforating Tool. from 2,800' to 2,650'. 4 cuts at 90deg phasing at 1.5' Spacing. Rotated 45deg each cut. 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.0 6,942.0 1 FRAC 5/10/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 5,025.0 6,253.0 4,157.5 5,088.8 Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2,363.0 2,820.0 2,156.0 2,493.8 Production String 1 Cement Layed in 420' 15.8 PPG Class G Cement Plug (TOC=2400') 7/11/2025 2P-406, 8/21/2025 4:37:52 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.6 GAS LIFT; 5,721.9 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 CIBP; 2,820.0 APERF; 2,650.0-2,800.0 SURFACE; 28.1-2,649.8 Production String 1 Cement; 2,363.0 ftKB CONDUCTOR; 28.0-110.0 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE2P-406 Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 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:Loepp, Victoria T (OGC) To:Jill Simek Cc:Greg S Hobbs; Lau, Jack J (OGC) Subject:Re: 2P-406 P&A Next Steps (PTD#204-022/Sundry#324-620)APPROVAL Date:Thursday, August 21, 2025 3:05:45 PM Jill, Approval is granted for the milling steps. Please include this approval with your copy of the approved sundry. Based on your evaluation, a change of approved program will be required for further work. Victoria Sent from my iPhone On Aug 21, 2025, at 2:50 PM, Simek, Jill <jill.simek@conocophillips.com> wrote: Victoria, On July 10-11,2025, Perforate/Wash/Cement operations were performed on 2P-406, per Approved Sundry #324-620. Unfortunately, the PWC plug has failed, as evidenced by a failed extended drawdown test on the OA. ConocoPhillips requests permission to mill out cement in the production casing, for further evaluation of the failed PWC plug. Next steps will be determined after this evaluation, and a 10-403 Change of Approved Sundry will be submitted accordingly. Please let me know if milling steps are approved. Thank you, Jill Simek Well Interventions Engineer | ConocoPhillips Alaska ATO-1400 M: 907-980-7503 / O: 907-263-4131 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:7350 ft MD Lease No.:ADL 0373112 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 2650 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:5-1/2" x 3-1/2"O.D. Shoe@ 7344 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 6336 Feet Tbg Cut@ 2945 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Annulus Bridge plug 2820 ft 2342 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1540 1390 1360 IA 1540 1390 1360 OA 50 50 50 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: see attached August 20, 2025 Josh Hunt Well Bore Plug & Abandonment KRU 2P-406 ConocoPhillips Alaska Inc. PTD 2040220; Sundry 324-620 Remarks, Photo Test Data: P Casing Removal: Ryan Moore Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0820_Plug_Verification_KRU 2P-406_jh           See below, * * MIT on 2P-406 does not meet Pass criteria – based on initial pressure 1540 psi, max allowed pressure loss was 154 psi during the test; actual loss was 180 psi (MIT acceptance criteria are pressure loss trend toward 0 psi, AND not more than 10% total pressure loss during a 30-min test). CPAI observed slow OA pressurization several days at a later date (prior to continuing with surface abandonment) and developed a plan for remediating. Refer to Sundry 325-589, approved 10/22/2025, and Inspector A. Earl report dated 11/14/2025 following CPAI's remedial work. -- J. Regg, 12/3/2025 2025-0820_Plug_Verification_KRU_2P-406_remarks_jh Page 1 of 1 Plug Verification – KRU 2P-406 (PTD 2040220) AOGCC Inspector J. Hunt 8/20/2025 I traveled to location and met with Ryan Moore representing ConocoPhillips Alaska. We looked over the Sundry and plan forward for the well. This is the third cement plug in a series of four. The crew was already rigged up with the standard BHA consisting of spangs, jars, a stabilizer, and a 2.25-inch drive down bailer. This BHA assembly is around 200 lbs and 33 feet long. They had a solid tag at 2342 ft MD (2363 ft RKB). I had them tag it several times to confirm. Next, they performed a 30-minute MIT to confirm the pressure integrity of the cement plug. Photo - The bailer had a small, soft, mushy cement sample. T R A N S M I T T A LL FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7 th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska RE:: 2P-406 DATE: 07/02/2025 Transmitted: 2P-406 Via SFTP Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM CC: 3T-612 - e-transmittal well folder Receipt: Date: 204-022 T40630 7/2/2025Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.02 15:33:35 -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: 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): 7350'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 6/30/2025 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple Perforation Depth MD (ft): L-80 2622' 6922-6942' (below cement plug) 7316' 5593-5608' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2650' 5916'7344' 16" 9-5/8" 82' 6336' MD 110' 2369' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6319' MD and 5139' TVD 512' MD and 512' TVD Jaime Bronga 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: Jaime.Bronga@conocophillips.com (907) 265-1053 Senior Well Integrity Engineer KRU 2P-406 5921' 2450' 2220' 2450', 2820', 5025', 6862', 6899' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jaime Bronga DN: OU=Conoco Phillips Alaska, CN=Jaime Bronga, E=jaime.bronga@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.10 16:01:59-08'00' Foxit PDF Editor Version: 13.1.6 Jaime Bronga 325-356 By Grace Christianson at 9:04 am, Jun 11, 2025 VTL 6/11/2025 none A.Dewhurst 20JUN25 December 31, 2025 Well abandonment must be complete by 12/31/2025. DSR-6/18/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.24 06:13:29 -08'00'06/24/25 RBDMS JSB 062425 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 10, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find the attached 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2P-406 (PTD 204-022). We are requesting to Extend the Suspension date to December 31, 2025, to complete the Plug and Abandon procedure. If you need additional information, please contact us at 265-1053. Sincerely, Jaime Bronga Well Integrity Engineer ConocoPhillips Alaska, Inc. 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 9-5/8" L-80 2369' 5-1/2" L-80 5149' 3-1/2" L-80 5916' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 623 sx Class G8.5" 6336'3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 11/26/2024 204-022/ 324-619 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20484-00-00 KRU 2P-406 ADL0373112 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM 1240' FNL, 1123' FWL, Sec. 16, T8N, R7E, UM ALK 32092 2/27/2004 7350' MD/ 5921' TVD 2450' MD/ 2220' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444361 5869047 1219' FNL, 789' FWL, Sec. 16, T8N, R7E, UM 4/24/2004 6319' MD/5139' TVD (seal assembly) PACKER SET (MD/TVD) 42" 12.25" 104 sx AS I 28'342 sx AS Lite, 229 sx LiteCrete 9.3# 28' 6333' 2650'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 5025' (SW TOC)-6253' 31 bbls 15.8 ppg Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 6922-6942' MD and 5593-5608' 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: 6333' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 7344' 28' 5149' 62.5# 40# 110' 28' WT. PER FT.GRADE 448028 448361 CEMENTING RECORD 5868628 1375' MD/ 1351' TVD SETTING DEPTH TVD 5868605 TOP HOLE SIZE AMOUNT PULLED Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 11:58 am, Dec 23, 2024 Suspended 11/26/2024 JSB RBDMS JSB 010225 xGA.Dewhurst 04MAR25 DSR-4/7/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1375' 1351' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Elliott Tuttle Digital Signature with Date:Contact Email: elliott.tuttle@conocophillips.com Contact Phone:(907) 263-4742 Staff 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 Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - Suspended Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 'HF Page 1/3 2P-406 Report Printed: 12/18/2024 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) 11/23/2024 14:00 11/23/2024 22:00 8.00 MIRU, MOVE MOB P Pull support equipment away from rig. Lay T-mats and cellar pit liner at 2P-406. Lay rig mats behind rig to pull off 2P- 447. T/S Boogey wheel controls. Back rig off 2P-447 @ 18:00. Lay rig mats in front of 2P-406. Move rig down pad and pull over well. 0.0 0.0 11/23/2024 22:00 11/24/2024 00:00 2.00 MIRU, MOVE RURD P Spot in support equipment. Spot tanks. RU hardline. Work through rig acceptance checklist. Accept rig @ 00:00. Load 9.8# Brine into pits. RU circ equipment in cellar for well kill. Pump open SSV. Initial Pressures T/IA/OA= 0/0/0 0.0 0.0 11/24/2024 00:00 11/24/2024 03:00 3.00 MIRU, MOVE RURD P Complete rig up check list, take on 9.8# brine, hook up tiger tank line and squeeze skid, hook up lines to well head for kill operations 0.0 0.0 11/24/2024 03:00 11/24/2024 04:00 1.00 MIRU, WELCTL DISP P Flood lines, pressure test line to tiger tank 3000 psi // Check lines no leaks // Circulate 4bpm @ 563 psi // Displace well T/ 9.8# NaCl 0.0 0.0 11/24/2024 04:00 11/24/2024 04:30 0.50 MIRU, WELCTL OWFF P OWFF for 30 min. 0.0 0.0 11/24/2024 04:30 11/24/2024 05:00 0.50 MIRU, WHDBOP MPSP P Set BPV w/ test dart 0.0 0.0 11/24/2024 05:00 11/24/2024 08:00 3.00 MIRU, WHDBOP NUND P ND Tree. Inspect Tubing hanger neck threads. Good condition. Functioned ULDSs. Measure RKBs. NU BOP. 0.0 0.0 11/24/2024 08:00 11/24/2024 09:00 1.00 MIRU, WHDBOP RURD P Install flow riser. RU trip tank hose. Install mousehole. RU testing equipment on rig floor. Test Gator ball drain sub on test rack. Confirmed o-ring are good after redress to 1" ball seat profile. 0.0 0.0 11/24/2024 09:00 11/24/2024 17:00 8.00 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" & 3 ½” donut 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. Test 2 7/8" and 3 1/2" FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1750 PSI, 200 PSI attained = 17 sec, full recovery attained = 97 sec. UVBR's = 4 sec Annular = 21 sec. Simulated blinds = 4 sec. HCR choke & kill = 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. Witnessed waived by AOGCC Inspector Austin McLeod. At 13:30 CMV #13 failed to test. Rebuilt valve while finishing other tests. Passed after redress. F/P on CMV #13. 0.0 0.0 11/24/2024 17:00 11/24/2024 18:30 1.50 MIRU, WHDBOP RURD P RD testing equipmnet. Prep rig floor to pull 3 1/2" Tubing. MU 3 1/2" EUE landing joint to Tubing Hanger. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2024 Page 2/3 2P-406 Report Printed: 12/18/2024 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) 11/24/2024 18:30 11/24/2024 19:30 1.00 COMPZN, RPCOMP THGR P Screw in TD. Set 10K down. BOLDS. Pull tubing hanger to rig floor @ 55K. L/D hanger w/ pup. Inspect and save for contingency. Pull 3 1/2" Tubing from pre-rig cut @ 2,945'. 0.0 2,945.0 11/24/2024 19:30 11/24/2024 23:00 3.50 COMPZN, RPCOMP PULL P Pull 3 1/2" Tubing from pre-rig cut @ 2,945'. Install thread protectors on good joints and save for contingency cement string. 2,945.0 0.0 11/24/2024 23:00 11/25/2024 00:00 1.00 COMPZN, RPCOMP CLEN P Prep floor for running 2-7/8" HT-Pac Pipe 0.0 0.0 11/25/2024 00:00 11/25/2024 00:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 1 // 5.5" CIBP 0.0 10.0 11/25/2024 00:30 11/25/2024 02:45 2.25 COMPZN, RPCOMP TRIP P TIH on stands 2-7/8" HT-Pac pipe to 2,830' 10.0 2,830.0 11/25/2024 02:45 11/25/2024 03:15 0.50 COMPZN, RPCOMP MPSP P Space out plug 2820' TOP // Up Wt 57K Dn Wt 55K // Pump ball on seat 3.5bbls // Tool stroke 1600psi stage 3 min, gain 7K wob // Stage pump 2000psi 2 min pick up neutral pump 2300psi shear off plug 2,830.0 2,820.0 11/25/2024 03:15 11/25/2024 05:00 1.75 COMPZN, RPCOMP TRIP P TOOH racking back 2 7/8" stands. 2,820.0 10.0 11/25/2024 05:00 11/25/2024 05:15 0.25 COMPZN, RPCOMP BHAH P L/D CIBP setting tools. 10.0 0.0 11/25/2024 05:15 11/25/2024 06:00 0.75 COMPZN, RPCOMP RURD P RU testing equipment. Flood lines. Close blinds. Line up through kill line. Install sensator on test spool. 0.0 0.0 11/25/2024 06:00 11/25/2024 06:15 0.25 COMPZN, RPCOMP PRTS P PT CIBP to 2,500 psi for 10-min. Charted. Bleed off. Open Blinds. Blowdown lines. 0.0 0.0 11/25/2024 06:15 11/25/2024 07:00 0.75 COMPZN, RPCOMP BHAH P MU 4 3/8" OD Gator Tool w/ ball drain sub. 0.0 17.0 11/25/2024 07:00 11/25/2024 08:45 1.75 COMPZN, RPCOMP TRIP P TIH w/ Gator tool to 2,820'. Set down 10K on CIBP. PUH. Obtain parameters. PUW = 57K. SOW = 55K. 17.0 2,800.0 11/25/2024 08:45 11/25/2024 09:45 1.00 COMPZN, RPCOMP PERF P Obtain parameters. 1.5 BPM @ 970 psi. 2 BPM @ 1,720 psi. 2.5 BPM @ 2,216 psi. 2.75 BPM @ 2,691 psi. 3 BPM @ 3,222 psi. Made 1st perforate @ 2,800'. SD pumps. Bleed off. PU out of first perf. PUH 1.5' and rotate DP 1/4 turn (90 deg). Park Gator Tool knives @ 2,798.5'. Peform 2nd perf. Cont. to perforate 5 1/2" Casing F/ 2,800' T/ 2,762.5''. See gas bubbles at surface. Trip LEL gas alarms in pits. See 1-3K overpull on avg to pull up into next perf depth. 2,800.0 2,762.5 11/25/2024 09:45 11/25/2024 11:00 1.25 COMPZN, RPCOMP CIRC P Circ BU until returns cleaned up. 2,762.5 2,762.5 11/25/2024 11:00 11/25/2024 11:15 0.25 COMPZN, RPCOMP OWFF P OWFF. 2,762.5 2,762.5 11/25/2024 11:15 11/25/2024 14:15 3.00 COMPZN, RPCOMP PERF P Cont. perforating from 2,762.5' to 2,650'. After final perf 2,650', PU to next connection. Set in slips. Drop 1" ball to open ball drain sub. Shear open circ sub. 2,762.5 2,650.0 11/25/2024 14:15 11/25/2024 14:30 0.25 COMPZN, RPCOMP CIRC P Circ STS to load well with 9.8# Brine. 4 BPM @ 1,093 psi. OA = 400 psi. 2,650.0 2,650.0 11/25/2024 14:30 11/25/2024 15:00 0.50 COMPZN, RPCOMP OWFF P OWFF 2,650.0 2,650.0 11/25/2024 15:00 11/25/2024 16:30 1.50 COMPZN, RPCOMP TRIP P TOOH w/ 4 3/8" OD Gator Tool. 2,650.0 17.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2024 Page 3/3 2P-406 Report Printed: 12/18/2024 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) 11/25/2024 16:30 11/25/2024 16:45 0.25 COMPZN, RPCOMP BHAH P L/D Gator tool. Document condition of tool w/ pictures. In good shape. 17.0 0.0 11/25/2024 16:45 11/25/2024 17:30 0.75 COMPZN, RPCOMP BHAH P MU 5 1/2" Casing WRBP. Crew C/O. 0.0 14.0 11/25/2024 17:30 11/25/2024 19:30 2.00 COMPZN, RPCOMP TRIP P TIH w/ WRBP and park Top of WRBP @ 2,450'. (COE @ 2,453'). PUW = 55K. SOW = 53K. 14.0 2,450.0 11/25/2024 19:30 11/25/2024 21:00 1.50 COMPZN, RPCOMP MPSP P Drop ball. Screw in TD. Set WRBP @ 2,450' (Top of plug). Pressure up 1700 psi to shear and set. Hold 1,700 psi for 5-min. Pressure up to 2,000 psi. Bump up to 2,850psi. No shear to release. PU 5K to shear off. L/D 1 joint. Set in slips. Blowdown TD. 2,450.0 2,426.0 11/25/2024 21:00 11/25/2024 21:45 0.75 COMPZN, RPCOMP PRTS P Screw in TD. Set 10K down. Close UPR. Install sensator on test spool. Line up to PT WRBP through kill line. PT WRBP to 2,500 psi for 30-min. Took 11 strokes to pressure up. Chart. 2,426.0 2,363.0 11/25/2024 21:45 11/25/2024 23:30 1.75 COMPZN, RPCOMP TRIP P Bleed off. Drain Trip Tank and Stack. TOOH (dry) w/ WRBP setting tools to create +/- 9 bbl void for diesel freeze protect. 2,363.0 11.0 11/25/2024 23:30 11/26/2024 00:00 0.50 COMPZN, RPCOMP BHAH P L/D WRBP setting tools. 11.0 0.0 11/26/2024 00:00 11/26/2024 02:00 2.00 COMPZN, WHDBOP FRZP P RU hose from rig LEPD tank to IA. With stack open, top fill well with xxx gallons (9.5 bbls) to FP to approx. 375' 0.0 0.0 11/26/2024 02:00 11/26/2024 02:30 0.50 COMPZN, WHDBOP OWFF P OWFF 0.0 0.0 11/26/2024 02:30 11/26/2024 05:30 3.00 COMPZN, WHDBOP NUND P ND BOP. NU Dry Hole Tree. Fill w/ diesel. PT tree to 1,500 psi for 10-min. Bleed off. 0.0 0.0 11/26/2024 05:30 11/26/2024 06:00 0.50 DEMOB, MOVE RURD P RD LRS . Clean and clear cellar. Release Rig @ 06:00 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2024 DTTMSTART JOBTYP SUMMARYOPS 11/23/2024 RECOMPLETION Pull support equipment away from rig. Lay T-mats and cellar pit liner at 2P-406. Lay rig mats behind rig to pull off 2P-447. T/S boogey wheel controls. Back rig off 2P-447 @ 00:00 on 11/24/24. Lay rig mats in front of 2P-406. Move rig down pad and pull over well. Spot in support equipment. Spot tanks. RU hardline. Work through rig acceptance checklist. 11/24/2024 RECOMPLETION Work through rig acceptance checklist. Accept rig @ 00:00. Load 9.8# Brine into pits. RU circ equipment in cellar for well kill. Pump open SSV. Kill well with 9.8# brine. OWFF. Set BPV + test dart. ND tree. NU BOP. RU testing equipment. Perform initial BOP test to 250/2500 psi. Witness waived by AOGCC (Austin McLeod). RD testing equipment. Pull BPV + test dart. MU landing joint. Prep floor to pull 3 1/2" tubing. Screw in TD. Set 10K down. BOLDS. Pulll hanger to rig floor @ 55K. Pull and lay down tubing from cut @ 2,945', clean and clear floor for running CIBP 11/25/2024 RECOMPLETION Pick up BHA#1, CIBP, TIH T/ 2,830'. Drop ball. Set CIBP @ 2,820'. TOOH racking back 2 7/8" DP. L/D setting tool. RU test equipment. PT CIBP to 2,500 psi. MU 4 3/8" Gator Perforating Tool. TIH and tag CIBP @ 2,820'. PUH to position Gator knives at 2,800'. Perforate 5 1/2" Casing F/ 2,800' T/ 2,762.5''. See gas bubbles at surface. Circ BU until returns cleaned up. OWFF. Cont. perforating from 2,762.5' to 2,650'. PU. Set slips. Drop 1" ball. Shear open drain sub. Circ STS. OWFF. TOOH w/ 4 3/8" Gator Tool. L/D same. Inspect. MU 5 1/2" WRBP. TIH and set WRBP @ 2,450'. Pickup off plug. Close UPR. Screw in TD. PT WRBP to 2,500 psi for 30-min. Chart. TOOH dry to create void for Diesel FP. 11/26/2024 RECOMPLETION L/D WRBP setting tools. Top fill well with diesel freeze protect. ND BOP's. NU dry hole tree. PT dry hole tree. Clean and clear cellar, Rig Released 06:00 2P-406 Plug and Abandon - Rig Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.02P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated schematic post RWO2P-406 12/4/2024rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 2,945.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.9 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.6 5,052.6 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.3 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.5 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 2,450.02,220.3 42.37PLUG Yellow Jacket 5 1/2" WRBP Evolution Oil Tools WRBP 11/25/2024 0.000 2,820.02,493.8 43.31 CIBP YJ CIBP, OAL 2.2'11/25/2024 0.000 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 2,650.0 2,800.0 2,369.0 2,479.2 11/25/2024 APERF 4 3/8" Gator Mechanical Perforating Tool. from 2,800' to 2,650'. 4 cuts at 90deg phasing at 1.5' Spacing. Rotated 45deg each cut. 6,922.06,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 5,025.0 6,253.0 4,157.5 5,088.8 Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2P-406, 12/19/2024 11:36:37 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.6 GAS LIFT; 5,721.9 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 CIBP; 2,820.0 APERF; 2,650.0-2,800.0 SURFACE; 28.1-2,649.8 PLUG; 2,450.0 CONDUCTOR; 28.0-110.0 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 7350'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-406 5921' 5025' 4157' 2490 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 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): 6319' MD and 5139' TVD 512' MD and 512' TVD Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst 6336' MD 110' 2369' 110' 2650' 5916'7344' 16" 9-5/8" 82' 2622' 6922-6942' (below cement plug) 7316' 5593-5608' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 11/25/2024 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple 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 Plugs (MD): 5025',6862', 6899' 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: 2024.10.24 14:50:45-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor By Grace Christianson at 9:08 am, Oct 31, 2024 324-620 SFD 10/31/2024 DSR-11/6/24 See attached "Condition of Approval" 10-404 JJL 12/6/24 X SFD June 30, 2025 Abandoned X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.06 13:19:54 -09'00'12/06/24 RBDMS JSB 121324 KRU 2P-406 Abandonment ŽŶĚŝƟŽŶƐŽĨƉƉƌŽǀĂů͗ 1. ǀĂƌŝĂŶĐĞŝƐŐƌĂŶƚĞĚĨƌŽŵϮϬϮϱ͘ϭϭϮ;ĂͿ;ϭͿ;ͿǁŚŝĐŚƌĞƋƵŝƌĞƐĂĐĞŵĞŶƚƉůƵŐĨƌŽŵϭϬϬΖ ďĞůŽǁƚŚĞďĂƐĞŽĨƚŚĞŚǇĚƌŽĐĂƌďŽŶ-ďĞĂƌŝŶŐƐƚƌĂƚĂ͘ 2. ǀĂƌŝĂŶĐĞ ŝƐŐƌĂŶƚĞĚƵŶĚĞƌ ϮϬϮϱ͘ϭϭϮ;ŝ) to allow the ĂůƚĞƌŶĂƚĞƉůƵŐƉůĂĐĞŵĞŶƚĚĞƐĐƌŝďĞĚĂƐ perf/wash/cement job 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 Recompletion Report 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. Procedure Rig operations are planned to cut and pull tubing from ~3080’ KB, set a plug, and mechanically perforate 150’ of production casing from approx. 2800’ KB to 2650’ KB Coil 1. MIRU. 2. RIH with wash/cement tool. Gently tag the CIBP. 3. PU and wash perfs per wash/cement tool’s vendor procedure. 4. After wash procedure, cement through perforations per wash/cement tool’s vendor procedure. POOH. Job is planned for ±65bbls cement, including excess. 5. Leave Top of Cement in production casing ±150ft above top perforation at ±2500ft KB (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 6. RDMO. Wait on cement. Slickline 7. RIH and tag TOC (AOGCC witness) 8. Pressure test plug to 1500 psi (AOGCC witness) Top Bottom Size ID bbls/ft ft volume ft/bbl notes 5-1/2" casing 0 1000 5.5" 15.5# 4.95" 0.0238 1000 23.8 42.0 from punc 5-1/2" x 9-5/8" annulus 0 1000 5.5" 16.5# x 9.625" 40#8.83" x 5.5" 0.0464 1000 46.4 21.6 from punc 2P-406 Intermediate Plug Suspension Katherine O’Connor (214-684-7400) Background & Objecve 2P-406 was a jet pump producer. The OA shoe was cemented in late 2012 to facilitate a surface casing repair. The OA passed a pressure test in 2022, but the OA sees some repressurization. This well was suspended in 2024 with a reservoir plug and 1500’ intermediate balanced plug. The rig will cut and pull tubing before this procedure takes place. The objective of this procedure is to get a lateral barrier above the C80 for abandonment and fully abandon the well. Well Data Reservoir pressure 5/14/2013 =2490psi @ 5400 = 8.86 ppg KWF MITOA passed to 1800 psi 2/24/2022 OA FL at surface Estimated cement top in the OA @ 1636’ MD Min ID 2.75” @ 6270’ RKB Reservoir suspended 8/9/24 with passing MITT, intermediate balanced plug was placed 9/28//24 and witnessed tag (5025’) and PT 10/5/24. Rig operations are planned to cut and pull tubing from ~3080’ KB and mechanically perforate 150’ of production casing Calculations Eline 9. RIH and punch casing at 1000’ MD Fullbore/Pumping 10. Circulate ±95 bbls of cement into casing and annulus for final surface job Surface Excavation 11. DHD to perform drawdown test on tubing, IA and OA 12. Remove well house. 13. Bleed off T/I/O to ensure all pressure is bled off the system. 14. Remove production tree in preparation for excavation and casing cut. 15. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 16. Cut off wellhead and all casing strings at 4 feet below original ground level. 17. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 18. Send the casing head with stub to materials shop. Photo document. 19. 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-406 c. PTD #: 204-022 d. API #: 50-103-20484-00-00 20. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 21. Obtain site clearance approval from AOGCC. RDMO. 22. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed cementing unit and associated equipment. 2P-406 Well Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 130 bbls of 15.8# Gas Block Cement Calculated TOC @ 4,591' KB 4 6 5Production Casing: 5.5" x 3.5" @ 6,333' KB, 15.5# x 9.3#, L-80 BTC Set @ 7,344.1’ KB T-3 Peforations: @ 6,922' – 6,942' KB (20') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,649.8' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,335.96' KB Item Depth - tops (KB) 1 FMC Tubing Hanger 26' 2 Camco DS Nipple 511.6' 4 Baker CMU Sliding Sleeve (Opened 2/21/2020)6,254.2' 5 Camco D Nipple 6,270.3' 6 Baker GBH-22 PBR 6318.6' 7 Baker 15' Stroke Seal Assembly 6319.4' 7 C80 @ 2800' KB C80 @ 2800' KB Plug #1 – Reservoir TOC ±6862' RKB (SL tagged) Plug #2 – Intermediate From 6254' KB to 5025' RKB (SL tagged) Plug #4 – Surface TOC @ surface BOC @ 1000' RKB Plug #3 – Surface Shoe, PWC TOC @ 2800' RKB BOC @ 2500' RKB Tubing cut at 2945' KB w/ jet cutter Perforations 2650 - 2800' KB Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.0 2P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-406 10/19/2024bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.026.00.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.6511.5 4.58 NIPPLE 4.550 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 2,556.2 2,299.2 41.77 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.8 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.5 5,052.5 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.2 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.4 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 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) 2,556.2 2,299.2 41.77 1 GAS LIFT Open 1 10/1/2024 4,065.5 3,427.5 40.61 2 GAS LIFT DMY INT 1 0.0 12/30/2017 0.000 5,017.2 4,151.5 40.03 3 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 5,721.8 4,692.0 41.20 4 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 6,204.5 5,052.5 41.78 5 GAS LIFT DMY INT 1 0.08/22/20200.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 2P-406, 10/24/2024 10:05:11 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 FRAC; 6,922.0 IPERF; 6,922.0-6,942.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,025.0 6,253.0 4,157.5 5,088.8 Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2P-406, 10/24/2024 10:05:13 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 FRAC; 6,922.0 IPERF; 6,922.0-6,942.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD 2P-406 ... WELLNAME WELLBORE Repair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Pull TubingOther StimulatePerforateSuspend Alter CasingPerforate New Pool Re-enter Susp WellPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None7350' CollapseCasing Structural Conductor Surface Intermediate Production Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLOIL WINJCommencing Operations:Suspended SPLUGGSTORWAGGASDate:16. Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearancePlug Integrity BOP Test Mechanical Integrity Test Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:THE AOGCCCOMMISSIONERApproved by: Sr Res EngSr Pet GeoSr Pet EngComm.Comm. 11/20/2024 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple Perforation Depth MD (ft): L-80 2622' 6922-6942' (below cement plug) 7316' 5593-5608' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2650' 5916'7344' 16" 9-5/8" 82' 6336' MD 110' 2369' ConocoPhillips Alaska, Inc. SizeLength Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended BurstTVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing MD (ft):Tubing Grade: 6319' MD and 5139' TVD 512' MD and 512' TVD Elliott Tuttle Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 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: elliott.tuttle@conocophillips.com (907) 263-4742 Senior CTD/RWO Engineer KRU 2P-406 24904157'5025'5921' 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 Operations shutdown Change Approved Program Other: PA-Rig portion Plugs (MD): 5025',6862',6899' Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.10.24 11:05:21-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle By Grace Christianson at 9:03 am, Oct 31, 2024 Suspended X 10-407 June 30, 2025 SFD 10/31/2024 PA-Rig portion X DSR-11/6/24 BOP Test to 2500 psi, Annular test to 2500 psi. See attached "Conditions of Approval" VTL 11/21/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.22 13:31:47 -08'00'11/22/24 RBDMS JSB 112624 KRU 2P-447 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 perf/wash/cement job below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. The plug must pass a State Witnessed pressure test and tag according to 20 AAC 25.112(g). 3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. 4. A failed pressure test of the surface casing shoe plug requires the submission of a new sundry (10-403) to cover the rigless abandonment scope if planned. Completion of workover operations under the original sundry will be complete and a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days following the completion of workover operations. 5. If surface abandonment operations are not initiated within 30 days after the successful placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days after the completion of workover operations to date. 6. Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. 7. AOGCC witness is required after the wellhead cutoff and prior to a top job. Variances granted provide for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or freshwater. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 24th, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby resubmits an Application for Approval to Plug & Abandon 2P-406 (PTD 204- 022). This sundry covers the portion to be performed on-rig by Nordic 3 starting in early-November 2024. 2P-406was ajet pump producerthatwasshut in,Sept2021. This wellhasbeensuspendedwitha reservoir cement plug and an intermediate cement plug (covered in separate 10-403). Different than others in the P&A Campaign, the OA had an arctic pack cement job performed in 2012. The steps outlined in this sundry request will include pulling the tubing, setting a plug across the C80 formation, and Perforating below the surface casing shoe on Nordic 3. Cementing off the shoe by way of perf wash and cement (PWC), plug abandonment cement plug to surface and ultimately execute final abandonment will be outlined in an additional sundry request. If you have any questions or require any further information, please contact me at 907-252-3347. Elliott Tuttle Senior Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer , O=Conoco Phillips, CN=Elliott Tuttle , E=elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.10.24 11:05:41-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle final abandonment will be outlined in an additional sundry request. 2P-406 P&A Summary (RWO Portion) Meltwater Producer PTD# 204-022 Page 1 of 4 2P-406 Plug and Abandonment (RWO Portion) Background & Objective 2P-406 was a jet pump producer that was shut in, Sept 2021. This well has been suspended with a reservoir cement plug and an intermediate cement plug (covered in separate 10-403). Di.erent than others in the P&A Campaign, the OA had an arctic pack cement job performed in 2012. The steps outlined in this sundry request will include pulling the tubing, setting a plug across the C80 formation, and Perforating below the surface casing shoe on Nordic 3. 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. The objective of this procedure is to prepare for an off rig PWC job above the C80 and final P&A. Well Data Meltwater Formation: Reservoir pressure 5/14/13 = 2474 psi @ 5600’ TVD MASP = 0 psi (Cemented) C-80 Formation: OAP = 168 psi (8/29/24) (TOC in OA estimated @ 1787’ RKB, assume diesel gradient) MASP = 758 psi using 0.1 psi/ft gas gradient Intermediate plug TOC = 5025’ RKB (SL Tagged) Tubing cut depth = 2950’ RKB (Planned) MIT-OA 2/24/2022 to 1800psi (failed) CMIT TxIA to 1500psi (passed) 10/5/24 2P-406 P&A Summary (RWO Portion) Meltwater Producer PTD# 204-022 Page 2 of 4 2P-406 P&A Summary (RWO Portion) Meltwater Producer PTD# 204-022 Page 3 of 4 RWO P&A Setup Date: 10/10/2024 Prepared by: Elliott Tuttle Estimated Start Date: 11/20/2024 MIRU 1. MIRU on 2P-406. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed o. 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 ConEguration: 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 at 2950’ RKB to surface and LD. Prepare for and Perforate Below Casing Shoe 1. Set bridge plug in production casing at ~2850’ RKB. 2. MU Gator perforator (438 version, 4 blade) 3. Make 2 perforations every 3 ft, starting at 2800’ RKB (or more if CFD suggests), making last perforation at 2650’ RKB noting overpull on each actuation. Observe well for How 4. MU WRPB, set at 1100’ RKB (permafrost measured at 1050’ TVD), PT plug to 2500psi for 30 minutes, POOH keeping hole full with KWF 5. ND BOPE. NU dry hole tree. Freeze protect WH/ tree with diesel. 6. RDMO. without filling hole. Fill hole with diesel. 2P-406 P&A Summary (RWO Portion) Meltwater Producer PTD# 204-022 Page 4 of 4 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.0 2P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-406 10/19/2024bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.026.00.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.6511.5 4.58 NIPPLE 4.550 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 2,556.2 2,299.2 41.77 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.8 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.5 5,052.5 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.2 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.4 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 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) 2,556.2 2,299.2 41.77 1 GAS LIFT Open 1 10/1/2024 4,065.5 3,427.5 40.61 2 GAS LIFT DMY INT 1 0.0 12/30/2017 0.000 5,017.2 4,151.5 40.03 3 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 5,721.8 4,692.0 41.20 4 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 6,204.5 5,052.5 41.78 5 GAS LIFT DMY INT 1 0.08/22/20200.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 2P-406, 10/24/2024 10:05:11 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 FRAC; 6,922.0 IPERF; 6,922.0-6,942.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,025.0 6,253.0 4,157.5 5,088.8 Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2P-406, 10/24/2024 10:05:13 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 FRAC; 6,922.0 IPERF; 6,922.0-6,942.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD 2P-406 ... WELLNAME WELLBORE 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 9-5/8" L-80 2369' 5-1/2" L-80 5149' 3-1/2" L-80 5916' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 623 sx Class G8.5" 6336'3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/19/2024 204-022/ 324-485 50-103-20484-00-00 KRU 2P-406 ADL0373112 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM 1240' FNL, 1123' FWL, Sec. 16, T8N, R7E, UM ALK 32092 2/27/2004 7350' MD/ 5921' TVD 5025' MD/ 4157' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444361 5869047 1219' FNL, 789' FWL, Sec. 16, T8N, R7E, UM 4/24/2004 CEMENTING RECORD 5868628 1375' MD/ 1351' TVD SETTING DEPTH TVD 5868605 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 6319' MD/5139' TVD (seal assembly) PACKER SET (MD/TVD) 42" 12.25" 104 sx AS I 28'342 sx AS Lite, 229 sx LiteCrete 9.3# 28' 6333' 2650'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 5025' (SW TOC)-6253' 31 bbls 15.8 ppg Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 6922-6942' MD and 5593-5608' 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: 6333' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 7344' 28' 5149' 62.5# 40# 110' 28' WT. PER FT.GRADE 448028 448361 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:54 pm, Oct 29, 2024 Suspended 10/19/2024 JSB RBDMS JSB 103024 xGDSR-11/22/24A.Dewhurst 04MAR25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1375' 1351' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - Suspended Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this documentLocation: Date: 2024.10.29 09:58:54-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 8/18/2024 CHANGE WELL TYPE DRIFT w/ 2.79'' GAUGE TAG 2.75'' D-NIPPLE @ 6270' RKB, OPEN SLEEVE 6254' RKB, LRS CONFIRM COMMUNICATION BETWEEN TUBING & IA, (JOB IN PROGRESS) 8/22/2024 CHANGE WELL TYPE (P&A) CDDT T X IA (PASSED) 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), 9/20/2024 SUPPORT OTHER OPERATIONS PUNCH TUBING 6250' - 6253' W/ 2" PUNCHER (4 SPF) JOB COMPLETE, READY FOR SL 9/21/2024 SUPPORT OTHER OPERATIONS SET 3-1/2" SLIP-STOP CATCHER @ 2731' RKB, PULLED 1" DMY VLV FROM STA # 1 @ 2556' RKB, MADE ONE ATTEMPT TO SET SOV IN STA # 1, BROUGHT VLV BACK, LDFN, JOB IN PROGRESS. 9/22/2024 SUPPORT OTHER OPERATIONS SET 1" 2000 PSI CSG SOV IN STA# 1 @ 2556' RKB, PULLED 3-1/2" SLIP-STOP CATCHER FROM 2731' RKB. READY FOR PUMPING CEMENT. 9/28/2024 SUPPORT OTHER OPERATIONS INTERMEDIATE CEMENT BALANCE PLUG. LOAD TBG & IA WITH 9.8 PPG NaCl KWF. PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. PLACING TOC IN TBG & IA @ ~4730' MD. WAIT ~48 HRS TO FREEZE PROTECT. IN PROGRESS 10/1/2024 SUPPORT OTHER OPERATIONS PUMP DOWN IA TO SHEAR SOV, PUMP DOWN TBG TAKING RETURNS OUT IA TO OPEN TOP, PERFORM CMIT TO 1500 PSI, CMIT PASSED AT 1480/1490/140 10/1/2024 SUPPORT OTHER OPERATIONS PUMP TRUCK SHEARED THE SOV BUT HAD SIGNS OF PLUGGING OFF. PULLED THE SHEARED SOV @ 2556' RKB. PUMPED 55 BBLS OF DIESEL DOWN THE TBG TAKING RETURNS FROM THE IA TO THE OPEN TOP TANK. ACHIEVED A CMIT PASSING TO 1500 PSI. JOB IN PROGRESS. 10/2/2024 SUPPORT OTHER OPERATIONS DRIFT TBG W/ SAMPLE BAILER & TAG TOP OF CEMENT @ 5017' RKB.READY FOR SW TOC & CMIT. 10/5/2024 SUPPORT OTHER OPERATIONS STATE WITNESS (SEAN SULLIVAN) TAG TOC @ 5025' RKB. PERFORM PASSING CMIT T x IA TO 1500 PSI. READY FOR E-LINE. 10/19/2024 SUPPORT OTHER OPERATIONS CUT TUBING AT 2945' RKB W/ 2.5" JET CUTTER. JOB COMPLETE, READY FOR RIG 2P-406 Intermediate Suspend Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.02P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-406 10/19/2024bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.8 2,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.026.00.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.6511.5 4.58 NIPPLE 4.550 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 2,556.2 2,299.2 41.77 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.8 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.5 5,052.5 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.2 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (Open 08/18/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.4 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 2,945.0 2,584.8 42.98 CUT JET CUT @ 2945' RKB 10/19/2024 2.992 6,250.0 5,086.5 41.45 TUBING PUNCH TBG PUNCH FROM 6250' TO 6253' RKB 4 SPF 9/20/2024 2.992 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 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) 2,556.2 2,299.2 41.77 1 GAS LIFT Open 1 10/1/2024 4,065.5 3,427.5 40.61 2 GAS LIFT DMY INT 1 0.0 12/30/2017 0.000 5,017.2 4,151.5 40.03 3 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 5,721.8 4,692.0 41.20 4 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 6,204.5 5,052.5 41.78 5 GAS LIFT DMY INT 1 0.08/22/20200.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 2P-406, 10/24/2024 10:05:11 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 FRAC; 6,922.0 IPERF; 6,922.0-6,942.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 5,025.0 6,253.0 4,157.5 5,088.8 Cement Plug Cement Bal. Plug - PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 41 BBLS OF 9.8 PPG NaCl KWF. 9/28/2024 2P-406, 10/24/2024 10:05:13 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 FRAC; 6,922.0 IPERF; 6,922.0-6,942.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 TUBING PUNCH; 6,250.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 Cement Plug; 5,025.0 ftKB GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 CUT; 2,945.0 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD 2P-406 ... WELLNAME WELLBORE ORIGINATED TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5131 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5131 2P-406 50103204840000 Tubing Cut Record 19-Oct-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-022 T39707 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 15:23:06 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: 7350 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2650 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5-1/2"x 3-1/2" O.D. Shoe@ 7344 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 6336 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 6230 ft 5025 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1875 1760 1735 IA 1740 1680 1675 OA 154 155 156 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Traveled to KRU 2P pad for plug tag and MIT-TxIA combo test of the intermediate balanced plug on 2P-406. Wire line tool was 28 ft long with 150lbs of weight bar and a flap bailer on the end. Initial tag at 5017 ft MD and beat down to 5025 ft MD for final tag. The bailer returned a good cement sample. 1bbl in and 1 bbl out during the MIT. October 5, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-406 ConocoPhillips Alaska Inc. PTD 2040220; Sundry 324-485 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1005_Plug_Verification_KRU_2P-406_ss 9 9 9 99 9 99 9 9 9 9 9 9999 9 9 99 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.18 15:55:33 -09'00' ORIGINAL TRANSMITTAL DATE: 9/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5072 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 5072 2P-406 50103204840000 Tubing Puncher Record 20-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 204-022 T39583 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.24 10:02:29 -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 Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Change Approved ProgramPull TubingOther StimulatePerforateSuspend Alter Casing Other: Suspend - Intermediate PlugPerforate New Pool Re-enter Susp WellPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Effective Depth TVD:Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: None7350' CollapseCasing Structural Conductor Surface Intermediate Production Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLOIL WINJCommencing Operations:Suspended GSTOR SPLUGWAGGASDate:16. Verbal Approval: AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearancePlug Integrity BOP Test Mechanical Integrity Test Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:THE AOGCCCOMMISSIONERApproved by: Sr Res EngSr Pet GeoSr Pet EngComm.Comm. (907) 263-3718 Senior Well Interventions Engineer KRU 2P-406 6862', 6899'5547'5921' 6862' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com AOGCC USE ONLY Tubing MD (ft):Tubing Grade: 6319' MD and 5139' TVD 512' MD and 512' TVD Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. SizeLength Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended BurstTVD 6336' MD 110' 2369' 110' 2650' 5916'7344' 16" 9-5/8" 82' 2622' 6922-6942' (below cement plug) 7316' 5593-5608' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 9/10/2024 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): By Grace Christianson at 8:06 am, Aug 22, 2024 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.08.21 15:31:25-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-485 VTL 9/3/2024 DSR-8/26/24 X X SFD 8/28/2024 10-407 June 30, 2025 0 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.03 16:34:07 -08'00'09/03/24 RBDMS JSB 090524 2P-406 Intermediate Plug Suspension Katherine O’Connor (214-684-7400) Background & Objecve 2P-406 was a jet pump producer. The OA shoe was cemented in late 2012. The OA passed a pressure test in 2022. This well has been shut in since Sept 2021. This well is 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. KRU 2P-406 had an OA cement shoe pumped in 2012 to facilitate a surface casing repair. The OA now passes an MIT-OA and has fluid level at surface. Well Data Reservoir pressure 5/14/2013 = 2490psi @ 5400 = 8.86 ppg KWF MITOA passed to 1800 psi 2/24/2022 OA FL at surface Min ID 2.75” @ 6270’ RKB Suspended 8-9-24, passing MITT Calculations Procedure Wireline & Pumping 1. Punch tubing at ±6230’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±135 bbls KWF c. ±31 bbls cement d. ±41 bbls KWF 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 4730’ MD 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 5. Cut tubing at ±2950’ RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 6230 3.5" 9.3# 2.99" 0.0087 6230 54.1 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 6230 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 6230 74.2 84.0 from punch depth Tubing Cement 4730 6230 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 4730 6230 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 2P-406 Well Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 130 bbls of 15.8# Gas Block Cement Calculated TOC @ 4,591' KB 1 2 4 6 5Production Casing: 5.5" x 3.5" @ 6,333' KB, 15.5# x 9.3#, L-80 BTC Set @ 7,344.1’ KB T-3 Peforations: @ 6,922' – 6,942' KB (20') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,649.8' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,335.96' KB Item Depth - tops (KB) 1 FMC Tubing Hanger 26' 2 Camco DS Nipple 511.6' 4 Baker CMU Sliding Sleeve (Opened 2/21/2020)6,254.2' 5 Camco D Nipple 6,270.3' 6 Baker GBH-22 PBR 6318.6' 7 Baker 15' Stroke Seal Assembly 6319.4' 7 C80 @ 2800' KB C80 @ 2800' KB Plug #1 – Reservoir TOC ±6862' RKB Plug #2 – Intermediate TOC ±4760 BOC ±6230 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:O"Connor, Katherine To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]RE: DS-2P Intermediate plug sundries Date:Tuesday, September 3, 2024 2:08:14 PM Yes - MASPS should all be zero. My perspective for having MASP there was just thinking about KWF and force of habit for calculating surface pressure. Here is a table of data requested. All witnessed tests passed. Prod/Inj Well Tubing Size PC Size Fluid Weight Well Suspended Tag Depth Pressure Test MASP Prod 2P-406 3.5 5.5 8.6 6862 1500 0 Prod 2P- 424A 3.5 5.5 8.6 10599 1500 0 inj 2P-427 3.5 5.5 10.7 9569 1500 0 inj 2P-432 3.5 7 10.2 5683 1500 0 Prod 2P-441 3.5 5.5 8.6 6848 1500 0 inj 2P-447 4.5 7 10.9 7509 1500 0 Prod 2P- 448A 3.5 5.5 8.6 7118 1500 0 Thanks, Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, September 3, 2024 11:30 AM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: [EXTERNAL]RE: DS-2P Intermediate plug sundries 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. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.0 2P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: DB cement on CIBP 2P-406 7/15/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007 WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.0 26.00.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.6 511.5 4.58 NIPPLE 4.550CAMCO DS LANDING NIPPLE CAMCO DS 2.875 2,556.2 2,299.2 41.77 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.8 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.5 5,052.5 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.2 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (closed 07/12/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.4 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 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) 2,556.2 2,299.2 41.77 1 GAS LIFT DMY INT 1 0.0 10/5/2014 0.000 4,065.5 3,427.5 40.61 2 GAS LIFT DMY INT 1 0.0 12/30/2017 0.000 5,017.2 4,151.5 40.03 3 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 5,721.8 4,692.0 41.20 4 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 6,204.5 5,052.5 41.78 5 GAS LIFT DV INT 1 0.08/22/20200.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,922.06,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 2P-406, 8/13/2024 5:06:11 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 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: NA Rig Elevation: NA Total Depth: 7350 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: X P&A: NA Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ NA Feet Surface: 9-5/8" O.D. Shoe@ 2650 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@ 7344 Feet Csg Cut@ NA Feet Liner: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing: 3-1/2" O.D. Tail@ 6336 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 6899 ft MD 6863 ft MD 10.7/6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1750 1640 1610 IA 135 130 130 OA 169 170 171 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to location to witness the tag and mechanical integrity test (MIT) of the bottom perforation isolating plug inside the wells production casing. The cement plug on top of the cast iron bridge plug (6899 ft MD ft MD) was dumped bailed on 7/15/24. Using your generic 2-1/4 inch slickline string they tagged the plug at 6863 ft MD (inclination 41°) with multiple hard set downs. A passing MIT was then done to a target of 1500psi. Top perforation at 6922 ft MD. August 9, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-406 ConocoPhillips Alaska, Inc. PTD 2040220; Sundry 323-444 none Test Data:MITT P Casing Removal: rev. 3-24-2022 2024-0809_Plug_Verification_KRU_2P-406_am 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.24 14:57:01 -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 110' 9-5/8" L-80 2369' 5-1/2" L-80 5149' 3-1/2" L-80 5916' 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 6333' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 7344' 28' 5149' 62.5# 40# 110' 28' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 6862-6899' MD Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 6922-6942' MD and 5593-5608' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 6319' MD/5139' TVD (seal assembly) PACKER SET (MD/TVD) 42" 12.25" 104 sx AS I 28'342 sx AS Lite, 229 sx LiteCrete 9.3# 28' 6333' 2650'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 4/24/2004 CEMENTING RECORD 5868628 1375' MD/ 1351' TVD SETTING DEPTH TVD 5868605 TOP HOLE SIZE AMOUNT PULLED 448028 448361 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20484-00-00 KRU 2P-406 ADL0373112 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM 1240' FNL, 1123' FWL, Sec. 16, T8N, R7E, UM ALK 32092 2/27/2004 7350' MD/ 5921' TVD 6858' MD/ 5544' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444361 5869047 1219' FNL, 789' FWL, Sec. 16, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 204-022/ 323-444 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 623 sx Class G8.5" 6336'3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 08/09/2024 Dump bailed 0.26 bbl Class G cement By James Brooks at 2:57 pm, Aug 14, 2024 Suspended 8/9/2024 JSB RBDMS JSB 081624 xGDSR-8/27/24A.Dewhurst 04MAR25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1375' 1351' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: N/A - Suspended Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location:Date: 2024.08.14 14:16:46-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.02P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: DB cement on CIBP 2P-406 7/15/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 6,336.0 Set Depth … 5,151.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.0 26.00.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.6511.5 4.58 NIPPLE 4.550 CAMCO DS LANDING NIPPLE CAMCO DS 2.875 2,556.2 2,299.2 41.77 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.8 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.5 5,052.5 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.2 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (closed 07/12/24) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.4 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 6,899.3 5,575.5 41.02 CIBP 2.630" CIBP, OAL = 1.37', MOE = 6900' TTSCIBP CPAI 2105- 263- AC- 001S R 7/14/2024 0.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 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) 2,556.2 2,299.2 41.77 1 GAS LIFT DMY INT 1 0.0 10/5/2014 0.000 4,065.5 3,427.5 40.61 2 GAS LIFT DMY INT 1 0.0 12/30/2017 0.000 5,017.2 4,151.5 40.03 3 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 5,721.8 4,692.0 41.20 4 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 6,204.5 5,052.5 41.78 5 GAS LIFT DV INT 1 0.08/22/20200.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,922.06,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.06,942.0 1 FRAC 5/10/2004 0.00.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,862.0 6,899.3 5,547.3 5,575.5 Cement Plug Dump Bail cement on CIBP 7/15/2024 2P-406, 8/13/2024 5:06:11 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 FLOAT SHOE; 7,343.5-7,344.1 FLOAT COLLAR; 7,249.1- 7,249.8 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 CIBP; 6,899.3 Cement Plug; 6,862.0 ftKB SEAL; 6,319.4 SBE; 6,313.9-6,333.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 SLEEVE-C; 6,254.2 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 SURFACE; 28.1-2,649.8 FLOAT SHOE; 2,648.1-2,649.8 FLOAT COLLAR; 2,571.1- 2,572.5 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 28.2-30.7 HANGER; 28.1-29.3 HANGER; 25.9 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 7/7/2024 CHANGE WELL TYPE DRIFT W/ 2.79" DWN TO JET PUMP @ 6254' RKB. PULL JET PUMP W/ GAUGE @ 6254' RKB. BRUSH D-NIPPLE @ 6270' RKB. SET 2.75" CA-2 PLUG IN D- NIPPLE @ 6270' RKB, READY FOR CIRC-OUT 7/11/2024 CHANGE WELL TYPE CIRC-OUT PUMPED 132 BBLS OF CISW DOWN TBG TAKING RETURNS OFF THE IA TO TANKS. PUMPED 38 BBLS DIESEL DOWN TBG, U-TUBED FOR A FREEZE PROTECT. CMIT TO 2500 PSI, PASSED. READY FOR SLICKLINE. 7/12/2024 CHANGE WELL TYPE CLOSE CMU SLIDING SLEEVE @ 6254' RKB MIT-T TO 2500 PSI. (pass) IN PROGRESS 7/13/2024 CHANGE WELL TYPE PULLED CA-2 PLUG FROM 6270' RKB. DRIFT AND TAG w/ 2.69" DMY CIBP DRIFT TO 6250' RKB.. READY FOR E-LINE & CIBP. 7/14/2024 CHANGE WELL TYPE PUMPED 72 BBLS 10.7 PPG BRINE & 17 BBLS DIESEL FP SET 2.630" CIBP, LOG CORRELATED TO SLB PERF RECORD DATED 9-MAY- 2004 CCL OFFSET=9.7', ME SET DEPTH=6900', CCL STOP DEPTH=6890.3' MIT-T TO 1800 PSI *PASS*, WELL LEFT S/I, JOB IS READY FOR SL. 7/15/2024 CHANGE WELL TYPE DUMP BAILED ~ 44' OF CEMENT ON TOP OF CIBP @ 6899 RKB. LEAVING TOC ~ @ 6858' RKB. READY FOR STATE WITNESS TOC/MIT IN 72 HOURS. 8/9/2024 CHANGE WELL TYPE STATE WITNESS (AUSTIN McLEOD) TAG TOC @ 6862' RKB (GOOD SAMPLE) PERFORM MIT-T TO 1500 PSI, PASS. READY FOR NEXT P&A STEPS. 2P-406 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: ___________________ 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): 7350'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 13. Well Class after proposed work: Detailed Operations Program Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: 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 3-1/2" Packer: Baker 15' Stroke Seal Assy. SSSV: Camco DS Nipple Perforation Depth MD (ft): L-80 2622' 6922-6942' 7316' 5593-5608' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2650' 5916'7344' 16" 9-5/8" 82' 6336' MD 110' 2369' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A-Abandon TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 204-022 P.O. Box 100360, Anchorage, AK 99510 50-103-20484-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6319' MD and 5139' TVD 512' MD and 512' TVD Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Interventions Engineer KRU 2P-406 5921' 6932' 5600' 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 Wellbore schematic BOP Sketch 9/15/2023 Date: 323-444 By Grace Christianson at 8:49 am, Aug 04, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.08.03 15:31:54-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 10-407 x VTL 10/3/2023 NO x 12/31/2024 VTL 10/3/23 DSR-8/7/23 Reservoir plug #1 approved with this sundry. Plug #2 and plug #3 NOT approved with this sundry. x MDG 8/23/2023 *&:JLC 10/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.03 12:14:32 -08'00' RBDMS JSB 100523 Slickline & Pumping 1. MIRU SL and associated equipment. 2. Pull jet pump from sleeve at 6524’ RKB 3. Set tubing plug in nipple @ 6270’ RKB 4. Fluid pack tubing and IA 5. Perform CMIT-TxIA to 2500 psi, record results 6. Close sliding sleeve 7. Perform MIT-T to 2500 psi, record results 8. Pull plug 9. Drift with dummy CIBP plug to TD (need to be able to set plug within 50’ of perfs for abandonment) 10. Displace tubing to 9.8 brine, pump ±75 bbls down tubing Schedule EL quickly after slickline to avoid losing brine to formation Eline – Reservoir Abandonment String Top Bottom Size Length ID bbls/ft volume ft/bbl notes 3.5" tubing 0 6336 3.5" 9.3# 6336 2.992" 0.0087 55.1 115.0 3.5" x 5.5" annulus (IA) 0 6319 3.5" 9.3# x 5-1/2" 15.5# 6319 4.825" x 3.5" 0.0107 67.7 93.3 to seal 3.5" liner 6333 7344 3.5" liner 1011 2.867" 0.0080 8.1 125.2 2P-406 P&A Date:03 August 2023 Katherine O’Connor (214-684-7400) Background & Objecve 2P-406 was a jet pump producer. The OA shoe was cemented in late 2012. The OA passed a pressure test in 2022. This well has been shut in since Sept 2021. This well is 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. KRU 2P-406 had an OA cement shoe pumped in 2012 to facilitate a surface casing repair. The OA now passes an MIT-OA and has fluid level at surface. ConocoPhillips intends to use the proven barrier of the OA cement shoe as permanent isolation to the C-80 sands. An additional plug will be placed within the tubing and IA adjacent to the C-80 sands. A final cement plug will be pumped into the tubing, IA, and OA as the surface cement plug. Well Data Reservoir pressure 5/14/2013 = 2491 psi MITOA passed to 1800 psi 2/24/2022 OA FL at surface Min ID 2.75” @ 6270’ RKB Calculations 1. Set CIBP @ ±6900’ RKB 2. Dump bail at least 30’ of cement on top of perforations Slickline – Tag Cement & Pressure test 1. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 2. MIRU SL and associated equipment 3. RIH and tag TOC, approx. 6870’ RKB (MUST BE AOGCC WITNESSED) 4. RU LRS as necessary. Perform MIT-T to 1500 psi (MUST BE AOGCC WITNESSED) 5. Perform DDT and record results 6. RIH and open sliding sleeve for next step, pumping the intermediate cement plug 7. RDMO Pumpers – pump intermediate cement plug from sliding sleeve to 2500’ RKB 3. Rig up HAL cementing unit. 4. Pump the following pump schedule: ±148 bbls 9.8 brine 5 bbls FW spacer 73 bbls 15.8# Class G cement Drop 5” foam wiper ball ±21 bbls 9.8 ppg brine displacement 5. RDMO. Volumes: 1. TBG and IA from sliding sleeve to 2500’: 0.0107 * 3754’ = 40 bbls 2. TBG from sliding sleeve to 2500’: 0.0087 * 3754’ = 33 bbls Slickline – Tag Cement 8. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 9. MIRU SL and associated equipment 10. RIH and tag TOC, approx. 2500’ RKB (MUST BE AOGCC WITNESSED) 11. RU LRS as necessary. Perform MIT-T to 1500 psi (MUST BE AOGCC WITNESSED) 12. Perform DDT and record results 13. RDMO Eline – Perforate tubing and production casing for surface cement job 1. Rig El and any associated equipment 2. RIH with 5’ of perf guns. 60 deg phasing, 6 spf to shoot through tubing and production casing 3. Perforate @ ±2300’ RKB and confirm circulation through IA and OA Pumping/Cementers – Fullbore TxIA plug 1. Rig up HAL cementing unit to pump down the tubing and take returns from IA (5.5” x 3.5” annulus) and OA (9.625” x 5.5” annulus) independently 2ND AND 3RD NOT APPROVED ON THIS SUNDRY As a contingency, also rig up to take returns from tubing when pumping down IA or OA in case tubing locks up 2. Ensure adequate circulation from tubing to IA (5.5” x 3.5” annulus) and then from tubing to OA (9.625” x 5.5” annulus). 3. After adequate circulation has been confirmed, pump the following schedule. Begin taking returns from the OA ±25 bbls surfactant wash ±150 bbls freshwater Shut in OA and begin taking returns from the IA ±25 bbls surfactant wash ±60 bbls freshwater Line up to begin pumping cement, start taking returns down the OA ±190 bbls 15.8# class g cement (152 volume with 20% excess) Once good cement returns are seen from OA, swap to take returns from IA Mix on the fly and pump excess cement as needed to get good cement returns across tubing, IA and OA 4. Shut in master valve and circulate surface lines clean 5. RDMO Volumes: 1. TBG from 2300’ to surface: 0.0087 * 2300 = 20 bbls 2. IA from 2300’ to surface: 0.0107 * 2300 =25 bbls 3. OA from 2300’ to surface: 0.0464 * 2300 = 107 bbls SURFACE WORK – Excavate wellhead, cut off below grade, well plate, backfill 1. DHD to perform drawdown test on tubing and IA. 2. Remove well house. 3. Bleed off T/I/O to ensure all pressure is bled off the system. 4. Remove production tree in preparation for excavation and casing cut. 5. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 6. Cut off wellhead and all casing strings at 4 feet below original ground level. 7. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 8. Send the casing head with stub to materials shop. Photo document. 9. 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. ConocoPhillips KRU 2P-406 PTD #: 202-022 API #: 50-103-20484-00-00 10. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 11. Obtain site clearance approval from AOGCC. RDMO. 12. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed cementing unit and associated equipment. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 6,932.0 2P-406 12/28/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Jet Pump Swap 2P-406 9/12/2020 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - CHARGING OA 11/27/2007WV5.3 Conversio n NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 1/2/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 28.0110.0110.062.50 WELDED SURFACE 9 5/88.83 28.12,649.82,368.9 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 6333' 5 1/2 4.95 28.2 7,344.1 5,916.015.50 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.0 Set Depth … 6,336.0 Set Depth… 5,151.3 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.0 26.00.00 HANGER 8.000 FMC TUBING HANGER 3.500 511.6 511.5 4.58 NIPPLE 4.550CAMCO DS LANDING NIPPLE CAMCO DS 2.875 2,556.2 2,299.2 41.77 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,065.5 3,427.5 40.61 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,017.2 4,151.5 40.03 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,721.8 4,692.0 41.20 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,204.5 5,052.5 41.78 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,254.2 5,089.7 41.42 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE (OPENED 2/21/2020) BAKER CMU 2.810 6,270.3 5,101.8 41.30 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750 6,318.6 5,138.2 40.92 LOCATOR 4.500 BAKER GBH-22 PBR BAKER GBH-22 3.000 6,319.4 5,138.8 40.91 SEAL 4.000 BAKER 15' stroke SEAL ASSY BAKER 15' stroke 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) 6,254.0 5,089.5 41.42 Jet Pump 2.81" C-Lock (2.835" No Go) & 3" RC Jet Pump (8B Ration) w/ Single Sparek Gauge (96" OAL) PH- 1053 9/12/20200.000 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 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) 2,556.2 2,299.2 41.77 1 GAS LIFT DMY INT 1 0.0 10/5/2014 0.000 4,065.5 3,427.5 40.61 2 GAS LIFT DMY INT 1 0.012/30/2017 0.000 5,017.2 4,151.5 40.03 3 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 5,721.8 4,692.0 41.20 4 GAS LIFT DMY INT 1 0.0 4/27/2004 0.000 6,204.5 5,052.5 41.78 5 GAS LIFT DV INT 1 0.08/22/2020 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,922.0 6,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX 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) 6,922.0 6,942.0 1 FRAC5/10/2004 0.00.00 0.00 2P-406, 7/6/2023 4:28:36 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 Jet Pump; 6,254.0 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 SURFACE; 28.1-2,649.8 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 KUP PROD KB-Grd (ft) 36.81 RR Date 2/29/2004 Other Elev… 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: GL to Jet Pump Conv Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7350'feet N/A feet true vertical 5921'feet N/A feet Effective Depth measured 7350'feet N/A feet true vertical 5921'feet N/A feet Perforation depth Measured depth 6922'-6942'feet True Vertical depth 5593'-5608'feet Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 6336' MD 5151' TVD Packers and SSSV (type, measured and true vertical depth)SSSV Camco DS Nipple 512' MD 512' TVD Seal Assembly Seal assembly 6319' MD 5139' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Contact Phone: (907) 265-1109 N/A P.O. Box 100360 Anchorage, AK 99510 Authorized Name: Sayeed Abbas Authorized Title: Staff Drillsite Petroleum Engineer Sayeed Abbas Sayeed.Abbas@conocophillips.com 234 ConocoPhillips Alaska, Inc. WINJ WAG 0 Water-Bbl MD 110' 2650' ADL 0373112 15 Oil-Bbl measured true vertical Packer 360 2270 0 Representative Daily Average Production or Injection Data 3000 Casing Pressure Tubing Pressure KRU 2P-406 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-022 50-103-20484-0000 5. Permit to Drill Number:2. Operator Name N 3. Address: 4. Well Class Before Work: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 48 Gas-Mcf measuredPlugs Junk measured N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-575 299 Size Authorized Signature with date: Liner Kuparuk River Field/ Meltwater Oil Pool Conductor Surface Intermediate Production Length 82' 2622' 7316' Casing Structural 16" 9-5/8" 5-1/2"7344' TVD 110' 2369' 5916' Burst Senior Engineer:Senior Res. Engineer: Collapse t Fra O 204 6. A G L P s G 25.070, 2 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:56 am, Sep 28, 2020 Sayeed Abbas Digitally signed by Sayeed Abbas Date: 2020.09.24 19:17:49 -08'00' RBDMS HEW 10/26/2020 VTL 11/03/20 SFD 9/29/2020 DSR-9/28/2020 ! " #$%&' ($ ! " )')*! " & & '%#*! %% & %%( *# &+!&+ &, +# +% &, -#+./ - % &,-#./" ($ %%'& ! & * #$%& ! " # " $% %! &## ! .%!/" #$&&&%#*! " & &&*#! & # #$ **! ' %)-&" %' *$&&&%#*! " & $%). *&/ &#*! " $%%!.& -#$/ -$% ./'! &&#*! " %%& % ( $%%!+'&&#*! $%%!'&&#*! .0#-/ + &)%) %&% % *122345678943:;6< Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 6,932.0 12/28/2016 2P-406 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Jet Pump Swap 9/12/2020 2P-406 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 110.0 Set Depth (TVD)… 110.0 Wt/Len (l… 62.50 Grade Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 28.1 Set Depth (ftKB) 2,649.8 Set Depth (TVD)… 2,368.9 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION 5.5"x3.5" @ 6333' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 28.2 Set Depth (ftKB) 7,344.1 Set Depth (TVD)… 5,916.0 Wt/Len (l… 15.50 Grade L-80 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.0 Set Depth (ft… 6,336.0 Set Depth (TVD) (… 5,151.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 26.0 26.00.00 HANGER FMC TUBING HANGER 3.500 511.6511.5 4.58 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,254.2 5,089.7 41.42 SLEEVE-C BAKER CMU SLIDING SLEEVE (OPENED 2/21/2020) 2.810 6,270.3 5,101.8 41.30 NIPPLE CAMCO D NIPPLE 2.750 6,318.6 5,138.2 40.92 LOCATOR BAKER GBH-22 PBR 3.000 6,319.4 5,138.8 40.91 SEAL BAKER 15' stroke SEAL ASSY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 6,254.0 5,089.5 41.42 Jet Pump 2.81" C-Lock (2.835" No Go) & 3" RC Jet Pump (8B Ration) w/ Single Sparek Gauge (96" OAL) 9/12/2020 0.000 PH-1053 Surface Casing Patch Surface Casing Sleeve is 8.5 long. Welded sleeve from bottom of 9 5/8 pup collar (2') to 10.5 on 9 5/8 surface casing. Sleeve made with 10" .500 wall X--65 pipe. 4/5/2013 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,922.06,942.0 5,592.6 5,607.7 T-3, 2P-406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX Frac Summary Start Date 5/10/2004 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 5/10/2004 Top Depth (ftKB) 6,922.0 Btm (ftKB) 6,942.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 2,556.2 2,299.2 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 10/5/2014 2 4,065.5 3,427.5 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/30/2017 3 5,017.2 4,151.5 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 4/27/2004 4 5,721.8 4,692.0 CAMCO KBG-2- 9 1GAS LIFT DMY INT 0.000 0.0 4/27/2004 5 6,204.5 5,052.5 CAMCO KBG-2- 9 1GAS LIFT DV INT 0.000 0.0 8/22/2020 Notes: General & Safety End Date Annotation 11/27/2007NOTE: WAIVERED WELL - CHARGING OA 1/2/2005 NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 2P-406, 9/13/2020 7:49:49 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6333'; 28.2-7,344.1 IPERF; 6,922.0-6,942.0 FRAC; 6,922.0 SEAL; 6,319.4 LOCATOR; 6,318.6 NIPPLE; 6,270.3 Jet Pump; 6,254.0 SLEEVE-C; 6,254.2 GAS LIFT; 6,204.5 GAS LIFT; 5,721.8 GAS LIFT; 5,017.2 GAS LIFT; 4,065.5 SURFACE; 28.1-2,649.8 GAS LIFT; 2,556.2 NIPPLE; 511.6 CONDUCTOR; 28.0-110.0 HANGER; 25.9 KUP PROD KB-Grd (ft) 36.81 Rig Release Date 2/29/2004 2P-406 ... TD Act Btm (ftKB) 7,350.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048400 Wellbore Status PROD Max Angle & MD Incl (°) 43.48 MD (ftKB) 2,851.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 50 Date 11/23/2016 Comment SSSV: NIPPLE THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Sayeed Abbas Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, KRU 2P-406 Permit to Drill Number: 204-022 Sundry Number: 319-575 Dear Mr. Abbas: Alaska Oil and Cas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, . Price Commissioner DATED this 2 day of January, 2020. gBDMSX-t-/j'AN 0 3 2020 L- A-il 6 STATE OF ALASKA DEC 18 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION /z[ 3 c l /7 v* s APPLICATION FOR SUNDRY APPROVALS A®CCC; On nor a non 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[-] Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change App��tl Grogram❑ Plug for Redrill El Perforate New Pool ElRe-enterSusp Well El Alter Casing 11 Other: [[1 Ch'�np'AL 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development • Stratigraphic ❑ Service ❑ 204-022 3. Address: 6. API Number: PO Box 100360, Anchorage, AK, 99510 50-103-20484-0000 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2P-406 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO373112 • Kuparuk / Meltwater Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7350' 5921' 6942' 5608' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 16" 110 110 Surface 2622' 9.625" 2650 22369 Intermediate Production 7316' 5.5" 7344' 5916' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6922-6942' 5593-5608' 3.5 L-80 6336' Packers and SSSV Type: No SSSV. Camco D nipple Packers and SSSV MD (ft) and TVD (ft): Cameo Nipple: 512' MD, 512' TVD Seal Assy Seal Assy: 6319' MD, 5139' TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� � Service ❑ 14. Estimated Date for 2/1/2020 15. Well Status after proposed work: Commencing Operations: OIL E] ' WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: N/A Date: Commission Representative: GINJ ❑ Op Shutdown E] Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sayeed Abbas Sayeed Abbas Contact Name: Authorized Title: Staff DrillSite Petroleum Engineer Contact Email: sa eed.abbaS conoc0 hllli S.Com p Contact Phone: 907-365-1109 � -20 Authorized Signature: Date: I � � 11 COMMISSION U E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,,) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS4"AN 0 3 2020 Post Initial Injection MIT Req'd? Yes ❑ No ,f� Spacing Exception Required? Yes ❑ -! No Subsequent Form Required: 6/i —4.7 APPROVED BY 14150 )5,O Approved by: 1 COMMISSIONER THE COMMISSION Date: �v` Ian G J� Submit Form and Form 10-403 Revised 4/2017 Approved app I n's I f r from the date of approval. Attachments in Duplicate ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 December 16th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska Inc well KRU 2P-406 (PTD 204-022). The request is for approval to convert this producer from a gas lifted well to jet pump. We currently do not have lift gas available in Meltwater 2P drillsite and the producers do not have enough reservoir pressure to naturally flow. Converting the producers to jet pump would enable to keep producing. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Email: sayeed.abbas(@conocophillips.com Ph: 907-265-1109 Attachments: Sundry Application Proposed Steps Well Schematic KRU 2P-406 DESCRIPTION SUMMARY OF PROPOSAL Jet Pump conversion for KRU 2P-406 CPAI proposes the following plan: 1. Remove 2" GI spool piece connecting the GI header to individual well, install 2" WI spool piece connecting the WI header to individual well. 2. Pull OV from 6205' and replace with a dummy 3. Slide sliding sleeve open 4. Set jet pump across sliding sleeve at 6254' 5. Submit 10-404 post -conversion KUP PROD 2P-406 Conoc himps hVeg AttributesMax An" MID ITD p.I- ( Wellbore APIIUWI 'I'llName Wpllbo,e 3klu[ Lei VIMO(Xlag 1wt him MKBI 501p32pd66pp MELTWATER PROD 43.46 2,651]] 7,35Op Commea[ I H23 (pp.) Oab SSSV: NIPPLE 50 11123/2016 AnnotellOn Entl GNe Last WO: KBGrtl (XI qip gelm[e Gele 38.81 212912006 $wo3 Trzrzmsq 64W PM isece- m AnnINallan Dep[M1 (flKBt Entl OMa FnnMMlon Lesl Matl By Entl Oak Lasi Tag: SLM 8,9320 12/28/2016 Re Meager GLVCIC(K2,p5) pproven 1/212018 asmg mgs GainHArvceq: CONDUCTOR On oo (In) to(int TOp (XNBt SH apIM1 (XKet Sel OeplM1 (TVOL.. LouWYp... i6 15.062 26.0 1100 1108 6250 Gratla Casln00es[rlption OG (in( 10 [nt Top (ItNB) 3e[OepIM1 flKBI set Depm (IVOt... WtlLen p... Grad. FL Sel OepmTVOt...—Lou (L.. 5916.0 15 W Gntla L8p ® 6333' Tubing 3trin s Tubing Description Sb1na Ma... ID (In) Top (XKb) ser Depth (11- sat Depth (rvo) I, wl pn/Xt Grade TOP eonnecnon TUBING 31/2 2.992 280 6,J36.0 5,151.3 9.30 L80 EUE6rtl corv0umoq'zeanGo Cumpletlon Details TOp HAS) Taprv0lOme) rap lnd l°I Item ommal ID em Des cOnl xIPPLE', 511,6-26G 280 0.00 HANGER FMC LASING HANGER 3EGG 5116 511,5 6.58 NIPPLE CASCO DS I-NNDING MPPLEw/2.7 "PROFILE 2875 6,254.2 5,089.7 41.42 SLEEVE -C BAKER CMU SLIDING SLEEVE(CLOSED 121132012) 2.810 GAS LIFT: 2556.2 6,270.3 5,101.8 41.30 NIPPLE CAMCODNIPPLE 2.750 6,318.6 5,138.2 40.82 LOCATOR BAKER GBH -22 PER J.000 6,319.4 5.138.8 61191 SEAL BAKERIS'a.ke GE4LASSY 3.000 tither in Mole pllireline retrievable plugs, valves, pumps, fish, at Top(WD) TOpma TOp(XKet MKS) 1•) Des cum Ran Oare mXnt Surtace surtace Casing slgave, 66510ng. Weldetl sleeve 4/52013 3URFACE,glI Casing PetCb 119m bpflbm Of95/e pup collar(2)(o 10.50.195/8 6YRacecasing. sleeve made with l0"S00wall X- 65 pipe. Perforations & Slots snot Dan ¢ASLIFT:4.M5.5 top (111m) Bum (flKDI Top(rv0) (XBB) BM 71" MKB) IDne Date Izgolsll y type com 6,922.0 6.842.0 55926 560].] ID, 2P-406 5/9/2004 66 IPERF 2.5"HSD, 60 deg phase, - .1250P CM1argefi, ROX Stimulations 8 Treatments Pueppam Desaned Ii b) Proppam In Formation IS, Dae GPS LIFT; 5,012$ 511 0/2006 Sdmuladons 8 Treatmems SI9p lop (ftKB) Bim (RKB) pale SIIMTrm[Fluitl Vol Cleen Pump Ibel) Vol Slmry(bbR 1 6,922.0 6,942.0 5/10/2004 Mandrel Inserts ¢As LIEF; s.m.6 sl at r Tcp ITVDt N TOp(flKB) (flKet MCMe V,Ive Matlel OD Ent Sery Type Lakn PO(in) TRORun Type (In) (pzp Run Oele Cam 1 2,5582 2299.2 CASCO KBG-2- 1 GAS LIFT DMV 9 IW 0.000 0.0 10/512014 2 4,11855 3,42].5 CASCO MEG -2 - 1 GAS LIFT DMV INT 0.000 0.0 121J0201] ¢A6 LIFT; 6.ID<3 9 3 5,01 2 6,1515 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 OD 4/2]12004 B 4 5,]21.8 4,692.0 CASCO KBG-2- 1 GASLIFT DMy IM 0000 0.0 42712004 9 5 6,204.5 5,052.5 CASCO KBG-2- 1 GAS LIFT OV INT 0.156 00 12130201] SIGEVEC: 63543 9 Notes: General8 Safety End Dae Annotmbn NIPPLE; 6,n93 1/212005 I NOTE: ENCOUNTERED TIGHT SPOTS @552',5104',5636 7—M 11/2]/200] NOTE'. WAIVERED WELL -CHARGING OA LOCATOa 6,3108 BEPL;8,3194 FRAC; 6,9Y10 P.,"6,9221F. Qg PRODUCTIOx55Y3.5"M 6= 2B.L].3441� • • Keck zp-Anc, prb zo4o zzo Regg, James B (DOA) From: Dethlefs, Jerry C [Jerry.C.Dethlefs @conocophillips.com] Sent: Thursday, September 26, 2013 1:33 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Nenahlo, Thomas L; Dethlefs, Jerry C; Fleming, Gavin Subject: Casing pressure rating Jim and Chris: To follow up on our meeting today, I am answering a couple of questions that were brought up. Casing MASP calculation: Barlow's formula was used to generate the MASP pressures. Here is a Wikipedia link to the formula: http://en.wikipedia.org/wiki/Barlow's formula I do not know at this point if this is used as a company standard, but it is used in Alaska for our Surface Casing excavation project by the Mechanical Engineers. For the wells on the slides, the deepest pits were used in the calculation. The UT inspection showed the wall loss for each well at: 2P-406: 48.5% wall loss (now sleeve patched) 2P-420: 3% 2P-429: 25.7% 2P-443: 3.2% 2P-447: 2.3% SCANNED L . 7 Details for the 2P-406 surface casing patch: Length of sleeve patch = 8'-6" Patch material: 0.500 wall X-65 casing, 10" OD Photos attached showing the patch halves in place, and welded. The patch is then covered with Denso anti-corrosion tape before reburial. Let me know if you have any other questions. Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska Office:907-265-1464 Cell:907-268-9188 1 • • i I ,,',,,,-4 ,,•''',-:...„. ,.4...„ . ,� , s� --k* iP e p} ate" O ' , , , , ;riy,,,,,,—..-.7., ,...,. .,,,,,,. .._ . ir .., oA o . “I'llt. .11.-- s':. ' ...,::' ' "i'F' . v, cz r-, ■o cct ' o 0 ' ...,'".. . _',. ;N 3+ N bA esi eq U _ a • • a. .3:.v Ades J e ... °+x ' r b , 1 -vb. t . 4f °xi J ; x r .E 1 '" Q a " O N 1- W .� ,e t" _ 1 N N to • o P' I //7 ct THE STATE Alaska Oil and Gas ALASKA Conservation Commission * , GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 9 A LAS Main: 907.279.1433 SCANNED JAN 2 � 2.013 Fax: 907.276.7542 Martin Walters Well Integrity Supervisor ConocoPhillips Alaska, Inc. !1 0 t -� P.O. Box 100360 "G Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P -406 Sundry Number: 312 -461 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, )04617,74,L, Cathy . Foerster Chair DATED this day of December, 2012. Encl. • ' RECEIVED . • STATE OF ALASKA S DEC 0 4 2012 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ��C 20 AAC 25.280 ` Y"' `t/ 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r .''Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate ,' Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:SC sleeved repair p 2. Operator Name: 4. Current Well Class:10 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r-I t►' Exploratory r 204 - 022 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20484 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 2P - 406 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0373112 • Kuparuk River Field / Meltwater Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7350 • 5921 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 82' 16" 110' 110' 1640 630 SURFACE 2622' 9 -5/8" 2650' 2369' 5750 3090 PRODUCTION 7316' 5 -1/2" 7344' 5916' 7000 4990 I Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 L - 80 6319 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 15' STROKE SEAL ASSY • MD= 6319 TVD= 5139 SSSV - CAMCO DS LANDING NIPPLE • MD= 512 TVD= 511 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development (7 • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/1/2013 Oil p . Gas r WDSPL r Suspended r 16. Verbal Approval: Date: W1N J r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Email: n1878 Printed Name Martin Walters Title: Well Integrity Supervisor Signature ;?74#154;7760110 Phone: 659 - 7224 Date: 12/03/12 Commission Use Only Sundry Number: 2 ---4(p( Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: k ,,,..-, SS A-- S IllI -o4 �5 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: U — /d _ l `f / ` 1L o 7 ZD �, APPROVED BY 0 AJ r ! p ^proveddbby: / COMMISSIONER THE COMMISSION Date: /2 -7- lZ Approved application is valid for 12 months from the date of approval. -7 � L k , \4 i 12) �c Z � 6 L Submit Form and Attach in Duplicate • • ConocoPhillips Alaska, Inc. Kuparuk Well 2P -406 (PTD 204 -022) SUNDRY NOTICE 10 -403 APPROVAL REQUEST December 3, 2012 This application for Sundry approval for Kuparuk (Meltwater) well 2P -406 is for the inspection and repair of the surface casing near surface. This well was drilled and completed as a development well in 2004. On 09/26/11 a surface casing leak was diagnosed and estimated to be less than 20'. ConocoPhillips would like to permanently repair the well with a welded patch. ✓ With approval, repair of the surface casing will require the following general steps: 1. Secure the well as necessary. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove any previous sealant treatment from the conductor. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casin g and remove cement from the outside of the surface casing for inspection. 6. Excavate wellhead location as needed to remove cellar and repair leak. 7. Remove conductor insulation and conductor to find damage to surface casing. Notify AOGCC Inspector for opportunity to inspect. 8. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 9. If a patch is required, QA/QC will verify the repair for a final integrity check. 10. Perform pressure test of the patched area. 11. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 12. Replace the conductor and insulation, fill the void with cement, and top off with sealant. Y. 13. Backfill as needed with gravel around the wellhead. i\ ,�, 1 C9 ti 14. Remove plugs and return the well to service. qtr' 1 w v v 15. File 10 -404 with the AOGCC post repair. D P f `y I ', s ) S)/v Well Integrity Project Supervisor 12/3/2012 4. • KUP 2P-406 ConocoPhillips f Well Attributes - Max Angle & MD TD NAaK4 h; Wellbore APVUWI Field Name Well Status Intl (°) MD (ftKB) Act Btm(ftKB) ConocoINCa,Ps 501032048400 MELTWATER PROD 43.48 2,851.77 7,350.0 ' • Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date •.. weneonlo. •2P- m61anr1o72lO09:4OAM SSSV: NIPPLE 90 6/18/2009 Last WO: 36.81 2/29/2004 Schematic • AWN! Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM , 6,944.0 11/12/2009 Rev Reason: WELL REVIEW osborl 10/1/2012 - - -- - - - -- Caste Sttin4ls Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 WELDED HANGER, 28 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd - SURFACE 95/8 8.835 28.1 2,649.8 2,368.7 40.00 L-80 BTC ; - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 28.2 7,344.1 5,916.0 15.50 L-80 BTC j 5 5 " @ 6333 Kam.. z rr ..-. . n .rovc Tubing Strings it Tubin Descrip String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 26.0 6,336.0 5,151.3 9.30 L -80 EUE - 8rd CompletlPn Details CONDUCTOR, II Top Depth 28 -110 (TVD) Top Intl Nomi... Top (ftKB) (B) ( °) Item Description Comment ID (in) 26.0 26.0 0.00 HANGER FMC TUBING HANGER 3.500 NIPPLE,512 a 511.6 511.4 5.82 NIPPLE CAMCO DS LANDING NIPPLE w/ 2.75" PROFILE 2.875 6,2542 5,089.7 41.42 SLEEVE -C BAKER CMU SLIDING SLEEVE - CLOSED 10/11/11 2.810 IIIF 6,270.3 5,101.8 41.30 NIPPLE CAMCO D NIPPLE 2.750 GAS LIFT, 6,318.6 5,138.2 40.92 LOCATOR BAKER GBH -22 PBR 3.000 2,558 IL 6,319.4 5,138.8 40.91 SEAL BAKER 15'stroke SEALASSY 3.000 I II Other fro reline retrievable plugs, valves, pumps, fish, etc.) I. Top Depth I (TVD) Top Incl I h Top (ftKB) (B) ( °) Description Comment Run Date ID (in) 6,270.3 5,101.8 41.30 PLUG 2.75" CA -2 PLUG 10/10/2011 0.000 SURFACE. J IL Perforations & Slots 28 -2,650 Shot Top(TVD) Bttn(TVD) Dens Top(ftKB) Btm(RKB) (ftKB) (ftKB) Zone Date (sh ... Typo Comment 6,922.0 6,942.0 5,593.2 5,608.0 T -3, 2P -406 5/9/2004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX GAS LIFT, 4,065 r Stirttulations & Treatments • Bottom M in Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) ';.j (RKB) (ftKB) (ftKB) (ftKB) T Date Comment 6,922.0 6,942.0 5,593.2 5,608.0 FRAC 5/10/2004 PUMP 200,216# 16/20 PROPPANT GAS LIFT Notes: General & Safety 5, 017 : End Date Annotation 1/2/2005 NOTE: ENCOUNTERED TIGHT SPOTS @ 552, 5104', 5636' SLM IR 11/27/2007 NOTE: WAIVERED WELL - CHARGING OA GAS LIFT, ' 5,722 :: I li Ili GAS LIFT, 8,205 IF L SLEEVE -C, 8,254 NIPPLE. 6,270 .,,. PLUG.6,270 /.. r/ It 11 ..., 1 LOCATOR, 6,319 ION SEAL,6,319 III Mandrel Details Top Depth Top Port (ND) Ind OD Valve Latch Size TRO Run Stn Top (ftKB) (MO) (1 Make Model (in) Sery Type TIT. (i ^) (psi) Run Date Com... 1 2,556.2 2,299.2 41.55 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 4/27/2004 2 4,065.5 3,427.5 40.61 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 427/2004 3 5,017.2 4,151.5 40.03 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 4/27/2004 IPERF, 4 5,721.8 4,692.0 41.20 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 4/27/2004 6,922.6,942 FRAC, 6,922 ' 5 6,204.5 5,052.7 41.81 CAMCO KBG -2 -9 1 GAS LIFT DMY ' BTM 0.000 0.0 10/10/2011 PRODUCTION 5.5'83.5" 6330, 28 -7,344 \ ° • ' TD, 7,350 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other r Pump OA Shoe Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension T Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r -' 204 - 022 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 - 50 - 103 20484 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0373112 " _ 2P - 406 9. Field /Pool(s): . Kuparuk River Field / Meltwater Oil Pool 10. Present Well Condition Summary: Total Depth measured 7350 feet Plugs (measured) None true vertical 5921 feet Junk (measured) None Effective Depth measured 7218 feet Packer (measured) 6319 true vertical 5818 feet (true vertucal) 5139 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 2622 12 2650 2370 PRODUCTION 7316 10.6 7344 5916 RECE1 - E� MAR 1 61 p Perforation depth: Measured depth: 6922 - 6942 A 0 9 L True Vertical Depth: 5593 - 5606 Alaska Oil & Gas Cons. 00mmissicr i Anchorage 1 Tubing (size, grade, MD, and TVD) 3.5, L -80, 6319 MD, 5138 TVD -.__ .- - - - - -- - - - -- "" Packers & SSSV (type, MD, and TVD) SEAL - BAKER 15' STROKE SEAL ASSY @ 6319 MD and 5139 TVD NIPPLE - No SSSV @ 0 MD and 0 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r - Service r Stratigraphic r 15. Well Status after work: . Oil F7 Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -391 Contact MJ Loveland /Martin Walters Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature Phone: Date 03/05/12 SDMS MAR 0 9 2012 31, / /- Form 1 -404 Revised 10/2010 0 iMi,tibmit Original Only • 2P-406 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/15/12 Cemented outer annulus casing shoe to create barrier to allow excavation and surface casing repair. Pumped 50 -bbl of 12.0 -ppg DeepCrete cement (40 -bbl with 1 -ppb CemNet), for a designed cement column of 1000' MD. Preceded cement with 20 -bbl diesel, 20 -bbl CW100 chemical wash, and 20 -bbl 11.0 -ppg MudPush. Displaced cement with 83 -bbl of 100 -deg -F Isotherm insulating packer fluid, and trapped 530 -psi on OA. Did not over - displace; did not bleed down the OA. 02/17/12 OA -DDT ( FAILED ), MIT -OA / DIESEL ( FAILED) LLR .092 GPM @ 1000 PSI, .07 @ 1500 PSI, .07 @ 1800 PSI. 02/18/12 SCLD, (IN PROGRESS) T /I /0= SI/1235/290. OA -FL @ SF (diesel). 02/20/12 SCLD, LEAK @ unknown depth T /I /0= SI/1210/325. OA -FL @ NS, IA -FL @ 1805'. Stung into OC packoff with 0+ psi POT (passed). Summary Pumped OA cement shoe designed for 1000' column of cement. Follow up MITOA failed due v to known SC leak. I I 6 t ' • • (in E F ! IL SEAN PARNELL, GOVERNOR L LW if L ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 ao - Q 9%') Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P -406 Sundry Number: 311 -391 Dear Ms. Loveland: ' ¢' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, or Daniel T. Seamount, Jr. Chair DATED this 2 7 day of December, 2011. Encl. • • I • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 December 16, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2P -406, PTD 204 -022 surface casing cement shoe. V Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures 111 RECEIVED • S TATE OF ALASKA 'tip �� • . ALASitIL AND GAS CONSERVATION COMMISS N C 2 0 2011 APPLICATION FOR SUNDRY APPROVALS 01 20 AAC 25.280 auks Oil 4 Gas Crag CIPIllikke ACIIRIIL 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Appr rrogram r Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r 'd Other: OA Shoe r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 -022 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20484 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r • 2P-406 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0373112 • Kuparuk River Field / Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7350 5921 ` 7218' 5818' None None Casing Length Size MD ND Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 2622 9.625 2650' 2370' PRODUCTION 7316 5.5 7344' 5916' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6922 -6942 5593 -5606 3.5 L -80 6319 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) SEAL - BAKER 15' STROKE SEAL ASSY MD= 6319 ND= 5139 NIPPLE - MD= 512 ND= 512 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r` Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/26/2011 Oil r , Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the be of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature r /�° j / Phone: Date ir.V/ te j e d Commission Use Only � /y Sundry Number: 1 1 - 4'6 �1 1 Conditions of approval: Notify Commission so that a representative may witness ,,/ •/ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: fO — Yo `f APPROVED BY Approved by 1 OMMISSIONER THE COMMISSION Date. / Z� I DD Form 10 -403 Revise OM DEC 2 8 2011' ' s , 2 S ubmi in D p 'Cate i , , � , R 1NA . v re f1 VI' • • • ConocoPhillips Alaska, Inc. Kuparuk Well 2P -406 (PTD 204 -022) SUNDRY NOTICE 10 -403 REQUEST 12/16/11 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kuparuk Meltwater well 2P -406. A surface casing cement shoe was not pumped at the time of original completion in 2004. The cement shoe is required in order to pressure test the surface casing to verify integrity after a report of a / suspected surface casing leak. The well's primary barrier is the 3.5" tubing. The well's secondary barrier is the 5.5" production casing and packer. If the cement shoe remediation is successful (resulting in a passing MIT -OA), there will be confirmation of the integrity of the surface casing. If the cement shoe remediation is unsuccessful (resulting in a failing MIT -OA), ✓ further diagnostics will be undertaken to identify the location and severity of the leak. With approval, the OA cement shoe will require the following general steps: � � a 0 1 /0 1. Bleed IA to < 100 psi. 2. Pump 50 bbls of cement into the OA. ( /Do ° ' c^ p 3. Displace cement with 83 bbls of Isotherm (insulating fluid) for a calculated cement top at 1636' MD.,/ 4. Wait 48 hrs on cement 5. MITOA to 1800 psi and / or establish LLR. 6. Submit 10 -404 to AOGCC. NSK Problem Well Supervisor 12/16/2011 ~2ECEIVEC~ BAR ~ ~ Zara STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Pertormed: Ab Repair w ell SPJP to Gaslift IB~ ^ Rug Perforations ^ Stimulate ^ Other ~ ~~~ P ll T i " u ub Casing ^ ng ^ FZ'rforate New Pbol ^ Waiver ^ Time 6ctension ^ r Chan a roved Pro ram Operat. Shutdown ^ Perforate IZe-enter S spended Wei 9 Pp 9 ^ ^ ^ 2.Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ 6rploratory ^ 204-022 3. Address: Stratigraphic ^ Service ^ .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20484-00 7. Pro~rty Designation: 8. Well Name and Number. ADL 373112 ~+ 2P-406 9. Field/Pool(s): Kuparuk River Field / Meltwater Oil Pool 10. Present Well Condition Summary: Total Depth ~' measured 7350 feet Plugs (measured) None true vertical 5921 feet Junk (measured) None Effective Depth measured 7218 feet Packer (measured) 6319 true vertical 5818 feet (true vertucal) 5138 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 16 110 110 0 0 SURFACE 2651 9.625 2651 2370 0 0 PRODUCTION 7344 5.5 7344 5816 . - - ~- 0 0 Perforation depth: Measured depth: 6922 - 6942 E (~~ ' ~, ~ ~ True Vertical Depth: 5593 - 5608 ~:.. ~' 1,°~h~rfi~=¢.: ~:~~ ~? ~ ~ Le e„w-s r~.tl`1~.:r Tubing (size, grade, MD, and TVD) 3.5, L-80, 6327 MD, 5145 TVD Packers &SSSV (type, MD, and TVD) SEAL -BAKER G-22 LOCATOR SEAL ASSEMBLY @ 6319 MD and 5138 TVD SSSV -NIPPLE @ 512 MD and 512 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-AAcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 766 253 Subsequent to operation 245 31 40 504 358 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory ^ Development Q Service ^ . Well Status after work: Oil ~ Gas ^ WDSPL ^ Daily Report of Well Operations X GSTOR ^ WAG ^ GASINJ ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: N/A Contact Bob Christensen/Darrell Humphrey Printed Name b D. Chri ensen Title Production Engineering Specialist Signature ~--Phone: 659-7535 Date R6DMS MAR 2 4 201 Form 10-404 Revised 7/2009 ~~~,~ ~`~y~/~' ~'~' `~~~/_e Submit Original Only • 2P-406 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/12/09 11/13/09 PULLED 2.81" JET PUMP @ 6254' RKB, NO EROSION. TAGGED @ 6944' SLM, EST. 15' RATHOLE. SET 2.75" CAT SV @ 6270' RKB. IN PROGRESS. i PUMPED 130 BBL DSL DOWN IA UP TBG TO PRODUCTION. CLOSED CMU @ 6254' I! RKB. MITIA 3640 PSI, PASSED. PULLED 2.75" CAT SV @ 6270' RKB. COMPLETE. 12/10/09 MEASURED BHP @ 6932' RKB: 1639 PSI. COMPLETE. 03/20/10 MEASURE BHP @ 6932' RKB, PULL DMY VLV @ 6205' RKB. SET OV @ 6205' RKB. COMPLETE. ~ KUP ~ 2P-406 .~,.p~ ~OIIOCaJr1)I~~IpS ell Attributes ax An le S MD TD Ala~d.ln' Wellbora APIlUWI Field Nama Well Statue Inc! (°) MD ((tKB) 501032048400 MELTWATER PROD 43.48 2,851.77 Act Rtm (ftKB) 7,350.0 C "' Well Con -2P-IDB if(F(1IX7970'.2532 AM amalic-ACNeI A omment M23 (ppm) SSSV: NIPPLE 60 nnotation Depth (ftKB) End Date Data An notation Entl Data 10/2112007 Last WO: Annotation KB-Gr0 (ft) 36.81 Laat Mod By Rig Release Date 2292004 End Data Last Tag: SLM 6,944.0 11/12/2009 Rev Reason: Pull Pump, Tag, Close CMU Imosbor 11/25/2009 Casin Strin s Casing Deacrlptlon String OD (In) String ID (In) Top (ftKB) Set Depth (RNB) Set Depth (TVD) (RNB) String Wt (IbsRt) String Grade Siring Top Thrtl CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 WELDED coNOUCroR, tto SURFACE 95/8 8.697 0.0 2,651.0 2,369.6 40.00 L-80 BTCM PRODUCTION 51/2 4.950 0.0 6,333.0 5,149.1 15.50 L-80 BTCM PRODUCTION 31/2 2.992 6,333.0 7,344.0 5,915.9 9.30 L-80 EUE8rd mod NIPPLE 512 Tubin Strin $ , Tubing Deacrlptlon String 00 Iin) String lD (in) Top (ftKB) Set Depth (RKB) Sat Depth (TVD) (RKB) String Wl (Ibattt) String Gratle String TOp Thrd TUBING 31/2 2.992 0.0 6,327.0 5,144.6 9.30 L-80 EUESrdmod 3 Other In Hole All Jewel :Tubin Run 8 Retrievable Fish etc. GAS LIFT, 2,533 Top (RKB) Top Depth (TVD) (RKB) Top loci (°) Deacrlptlon Commenl Run Date ID (In) 512 511.8 5.84 NIPPLE CAMCO DS LANDING NIPPLE W2.875" PROFILE 4/28!2004 2.875 2,556 2,299.0 41.55 GAS LIFT CAMCO/KBG2-9/1/DMY/INT/// Comment STA 1 4/272004 2.900 4,065 3,427.2 40.61 GAS LIFT CAMCOMBG2-9/1/DMYIINT//I Comment: STA 2 427/2004 2.900 5,017 4,151.4 40.03 GAS LIFT CAMCO/KBG2-9/1IDMY/INT///Comment: STA3 41272004 2.900 5,722 4,692.1 41.20 GAS LIFT CAMCO/KBG2-9/1lDMY/INTI// Comment: STA 4 41272004 2.900 SURFACE, 2,651 6,Z0$ 5,053.0 41.81 GAS LIFT CAMCO/KBG2-9/1/DMY/INT/.313//Comment: STA5 5232005 2.900 6,254 5,089.5 41.43 SLEEVE-C BAKER CMU SLIDING SLEEVE CLOSED 11/132009 428/2004 2.810 6,270 5,101.6 41.30 NIPPLE CAMCO NO GO'D'NIPPLE 4/2&2004 2.750 6,319 5,138.5 40.92 SEAL BAKER G22 LOCATOR SEAL ASSEMBLY 4282004 3.000 6,336 5,151.3 40.78 SHOE 428/2004 2.992 GAS uFT Perforations $ Slots , I Ofi5 Top (ftl(B) Btm (RKB) Top (TVD) (RNB) Btm (TVD) (RKB) Zane Date Shot Dens (°h... Type Comment 6,922 6,942 5,593.2 5,608.0 5!92004 6.0 IPERF 2.5" HSD, 60 deg phase, HP 2506 charges, RDX GAS uFr. StlmulaUona & Treatments s.ot7 Mln Top Depth (RKB) Max Btm Oepm (RKB) Top Depth (TVD) (RKB) Bonom Depth (TVD) (RKB) ypa ata omment 6,922.0 6,942.0 5,593.2 5,608.0 F RAC 5/10/2004 PUMP 200,216# 16/20 PROPPANT GAS LIFT Notes: General & Safe , s 7zz End Data annotation , 122005 NOTE: ENCOUNTERED TIGHT SPOTS @ 552', 5104', 5636' SLM 11272007 NOTE:WAIVEREDWELL-CHARGING OA GAS LIFT. 8,205 SLEEVE-C, 6,254 NIPPLE,6270 SEAL, 6 319 PRODUCTION, 8,333 SHOE, 6,336 IPERF, 8,922-6,942 FRAC, 6,922 PRODUCTION, 7,314 ro, ~ 3W I • L6~ ~i.J r---=~_=-~=- _,-- ~ TR,4/1/I~~/TT,4L ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West international Airport Road suite c ~~~NNEE~ JUL ~ ~ 20Q8 Anchorage, AK 99518 Fax: (907) 245,8952 1) Caliper Report 06-JuF~08 28406 1 Report / EDE 50-103-2048400 2) Caliper Report 04~1u1.08 2N-319 1 Report/ EDE ~~~(--Gad d~,~'~~ U~"'~t~'Co°~~Sl ~/t~5~`~ ~~ Slgne~ : _i.~ Print Name: 1„~ ~~ t ~ ,~ ~? U~a ~~~~~ 50-103-20271-00 Date PROACTNE Dwt3NOSTIG SERVICES, INC., 13D W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (947)245-88952 E-WAIL - ___ ___ _ WEBSRE , .,~,. C:\Documenls and Settin~s\Owner\Desktop\Transmit_C~oco.doc II • • Memory MultirFinger Caliper Log Results Summary _...;:, Company: ConocoPhil9ips Alaska, Inc. Well: 2P-406 Log Date: July 6, 2008 Field: Kuparuk Log No.: 8131 State: Alaska Run No.: 1 API No.: 50-103-20484-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 Top Log Intvl: Surtace Pipet Use: Tubing & Liner Bot. Loc~lntvl: 6,943 Ft. (MD) ~ Inspection Type : Corrosive 8 Mechanical Damage lnspection COMMENTS : 7"his caliper data is tied into the Sea/ Assembly ~ B,399' (Dril/er's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical ~' damage. The caliper recordings indicate the 3.5" tubing and liner logged are in good condition with respect to corrosive damage, with no significant wall penetrations, areas of cross-sectional waN loss or 1. D. restrictions recorded. i MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 17%) are recorded throughout the tubing and liner logged. ~ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 7°~j are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: R:,4. Richey Analyst: M. Lawrence Witness: J. Hansen ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS±dsmemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 1 ~!- ova ~ /~~~ • Correlation of Recorded Daman Pipe 1 3.5 in (10.5' - 6942.6') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2 P-406 Kuparuk ConocoPhillips Alaska, Inc. USA July 6, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 14 25 784 50 1569 75 2354 GLM 1 100 3153 ~ ~ a~ E ~ ~ ._ z 125 3930 s GLM 2 ~ Q. 'o a, D 1SO 4728 GLM 3 175 . 5527 GLM 4 GLM 5 200 6408 217 6943 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 217 • • PDS Report Overview ~ S, Body Region Analysis Well: 2P-006 Survey Date: )uly 6, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, lnc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body metal loss body 2 50 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 234 pene. 0 206 28 0 0 0 loss 155 79 0 0 0 0 Damage Configuration (body ) 10 Q isolated general line ring hole~poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 10 8 2 0 0 0 Damage Profile (% wall) ~ penetration body ;rte metal loss body 0 50 100 0 48 GLM 1 96 GLM 2 144 GLM 3 GLM 4 190 GLM 5 Bottom of Survey = 217 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3,5 in 9.3 ppf L-80 Well: 2P-406 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 6, 2008 Joint No. Jt. Depth (Ft.) I'~~n. I ll~~~•i (IrnJ Pen. Body (Ins.) Pc~n. % ~Ic•i,il I c~ti~ ,<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 11 ~~ 0.01 4 I 2.93 P P 1 14 a 0.01 G .93 1.1 45 t~ 0.02 £3 ~' 2.93 PU 1.2 51 ~~ 0.02 tf I 2.93 PUP 2 57 i ~ 0.0 t3 I .95 3 9 ~) .02 i 4 4 121 i~ 0. 2 t3 1 2.9 5 153 U .02 7 I 2.95 6 184 U 0.02 £i 1 2.94 7 215 U .02 8 2 96 247 ~ ~ 0.02 .96 9 278 U 0.02 £s I 2.96 10 309 a 0.02 1 .96 11 341 (~ 0.02 f3 1 .96 1 37 U 0.02 £3 1 2.95 13 403 ~~ 0. 2 t3 2.9 14 435 ~~ .02 tt I 2.96 15 466 a 0.0 ti I 2.9 15.1 498 ~ ~ 0 ~ ~ ~ ~ 2.88 DS Lan in Ni le 16 500 l ~ 0.02 £j 2.9 17 531 t) 0.0 t3 I 2.96 18 563 O 0.02 9 5 2.83 Sli Mash. 19 594 c) 0.02 7 .95 20 626 ~ ~ 0.02 2.95 58 U 1 v 2.95 22 689 ~) 0.02 t3 1 2.94 23 721 a 0.02 ~ I 2.94 24 752 a 0.02 ft 2.95 25 784 U .02 7 2.95 26 815 O 0.02 £~ 1 .95 7 847 t) 0.0 7 t ~ 2.92 28 878 a 0.02 7 2.95 29 909 U 0.02 t3 2.95 30 941 O 0.02 t i _' 2.94 31 97 ~) 0.02 I .9 32 1004 ~ ~ 0.02 ti 1 2.95 33 1035 U 0.02 7 1 2.93 34 1067 t) 0.02 ti I 2.96 35 1 98 U 0.0 ti I 2.95 36 1128 a 0.02 ti _' 2.95 37 159 U .02 8 ' .95 38 1191 U 0.02 8 I 2.94 39 12 2 U 0.02 ~ U 2.96 40 1254 i ~ 0.02 ti 1 2.96 41 1 86 ~ ~ 0.0 t3 I .95 42 1317 a 0.02 7 ~) 2.95 43 1349 i ~ 0.0 8 I 2.94 44 1380 ~ ~ 0.02 7 l ~ 2.96 45 1411 ~) 0.0 t3 1 .96 46 1443 ~ ~ 0.02 I 2.97 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2P-406 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 6, 2008 Joint No. )t. Depth (Ft) Pc~n. t llx<~t (In~,l Pen. Body (Ins.) Pen. % Metal I oss °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1474 ~ ~ 0.0 £i I 2.97 48 15 U 0.02 1 2.96 49 1537 i) 0.0 7 I 2.96 5 1569 a 0.02 £3 _' 2.94 51 1600 U 0.02 - 2. 6 5 163 U 0.02 - I .9 53 1663 U 0.0 £3 I .95 54 1694 U 0.0 £i I 2.96 55 1726 l) 0.02 £i I 2.96 5 1757 t) 0.02 ~ I 5 7 1789 t) 0. £3 I 6 58 1820 U 0.01 b 2 94 5 1 52 t) 0.02 t3 I 2.96 60 1883 t) 0.02 7 2.96 61 1914 t) 0.02 7 2.9 62 1946 ~) 0.0 ~ I 2.95 3 1978 t) 2 ~) I .9 64 2009 U .0 ti I 2.96 65 2041 U 0.0 8 1 2.94 6 072 t) 0.02 7 I 2.94 67 10 t~ 0.02 £3 I 2. 6 68 13 t) 0.02 7 I 2.96 69 2166 t) 0.0 - I 2. 7 70 2197 ~l 0.02 £3 I 2.96 71 u ' .9 72 2260 U 0.02 £~ I 2.96 73 2292 u 0 0 2.95 74 2323 t) 0.02 £~ i 2.96 75 354 t) 0.0 7 U 2.94 76 2386 U 0.02 8 1 2.95 77 2417 t) 0.02 £3 2 2.96 7 2449 U 0.02 7 I 2.96 7 2480 a 0.02 ti I 2.96 80 2512 l) 0.02 8 I 2.95 80.1 2543 t) 0.03 I1 2.94 P P 80.2 2549 ~) 0 U ~) N A GLM 1 Deviation 80.3 2555 a 0.01 v ' 2.95 PUP 81 2561 ~ ~ 0.02 f3 1 2.93 8 2 5 2 c) 0.02 8 I 2.96 83 2624 ~ ~ 0.02 7 1 2.96 2 55 U .02 8 ' 2.96 85 2687 U 0.02 7 i) 2.95 86 718 t) 0.02 ti 2.96 87 2750 ~> 0.02 8 I 2.96 88 2781 ~1 0.02 B 1 2.94 89 2 813 ~ ~ 0.02 £3 1 2.96 0 843 ~~ 0.02 8 l) .9 91 2874 i) 0.02 8 t) 2.93 92 903 t) 0.0 £3 2.95 93 2934 t) 0.03 1t7 2.94 Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 2 P-406 Kuparuk ConocoPhillips Alaska, Inc. USA July 6, 2008 Joint No. Jt. Depth (Ft.) Pc~n. UF~sr~t 11ns.1 Pen. Body (Ins.) I'en. `io Mewl loss `%~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 94 2 66 ~) 0. 2 7 ~l 2.93 95 29 7 U 0.02 U .93 96 3029 ~) 0.02 7 [) 2.92 97 3060 l ~ 0.02 ~~ ~) .9 98 309 U 0.0 ~) 2.92 9 3123 U 0.02 I .95 10 3153 c~ .02 ti ~ ~ 2.94 101 3185 ~ ~ 0.02 ~ i 2.94 102 3 16 (~ 0.02 7 1 2.94 103 324 ~ ~ 0.02 7 u 2.94 104 3279 (I 0.02 0 i! .94 105 3310 ~ I 0.02 c~ I ~ 2.93 106 3342 U 0 02 t3 I 2.94 10 3373 ~~ 0.02 7 u .94 1 8 340 U 0. 2 i U 2. 4 109 343 U .02 7 i ~ 2.94 110 3466 U 0.02 i U 2.93 111 3496 c ~ 0.02 7 i 1 .93 112 3528 a 0.0 7 I 2.94 113 3559 ~ I 0. 2 i ~ ~ 2.94 114 3591 U 0. 2 8 ~ ~ 2.93 115 3620 t1 0. 7 ~ ~ 2.94 116 3650 l) 0.02 6 11 .95 117 3681 U 0.02 8 1 2.94 118 7 u 0. t3 1 119 3744 ~~ 0.02 ti 1 2.93 1 0 3775 t ~ 0.02 t; I 2.9 121 3806 ~~ 0.02 t3 I 2.93 12 3838 a 0.02 t3 I 2.94 123 3869 c~ 0.02 7 ~~ 2.93 124 3901 U 0.02 7 I .95 125 3930 ~~ 0.02 7 I 2.94 126 3962 ~1 0.02 ~ I .9 127 3993 a 0.02 is I 2.97 12 4025 ~~ 0.02 8 I 2.96 128.1 4056 a 0.02 FS U 2.94 PUP 128.2 4062 u 0 U t) N A GLM 2 atch ~ 4:00 128.3 4068 ~~ 0.02 1 2.98 PUP 129 4074 t~ 0.02 i _' 2.95 130 4106 U 0.02 ~ ~) 2.93 131 4137 (~ 0. 2 ~ U 2.93 132 4169 ~ ~ 0.02 ~ I 2.94 133 4 99 ~ ~ 0.0 7 U 2.93 134 4230 U 0.02 7 (1 2.93 1 5 4262 a 0.02 8 ,' 2.93 136 4293 (1 0.02 7 _' 2.96 137 4324 a 0.0 ~ 2.94 138 4355 U 0.02 7 1 2.93 139 4386 ~ ~ 0.02 ~) .9 140 4417 ~ 0.02 - ~ % 2.94 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • i LATI O N SHEET 2 P-406 Kuparuk ConocoPhillips Alaska, Inc. USA July 6, 2008 joint No. jt. Depth (Ft.) I'c~n. t lt~yc~t (In,.) Pen. Body (Ins.) Pen. %> Mc~t,~l I cuss `i'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 141 4449 U 0.0 7 t> 2.93 142 4480 t ~ 0.0 7 U .94 143 4 11 tl 0.0 8 tt .93 144 4542 t~ .03 1 1 ~? 2 93 145 574 l) 0.02 i I 2.95 14 4606 (~ 0.02 t ~ 2.94 147 4637 u 0 03 1 U I 2.94 148 466 t~ 0. 2 ti .95 149 47 0 t~ 0.02 t3 I 2.95 150 4728 l) 0.0 8 tl 2. 5 151 4760 0 7 I 2.94 15 4791 l) 0.02 ~ I 2. 4 153 48 3 l) 0.02 7 U 2.95 154 4854 t) 0.02 7 t) 2.93 155 4885 t I 0.02 1 .9 156 4917 tt 0.02 ~ I 2.94 157 4948 ! ? .02 ' > .9 15 4980 U 0 0 7 I 2.95 158.1 5009 t1 0.02 ~~ ~ 2.93 P P 158.2 5016 tt 0 U U N A GL 3 Latc 4.00 15$.3 5021 t1 0.01 6 ~ 2.98 PUP 159 502 7 U 0.03 I I I .92 160 058 U 0.02 ~~ I 2.95 161 5090 i l 0.02 t3 1 2.96 1 5120 t ~ 0 03 I ~ 4 .85 SI' Mas . 163 5151 a 0.03 13 -1 2.92 Shallow ~ttin . 164 5183 t t .03 1 ? I 2.93 165 5214 U 0.03 1 ~ (~ 2.95 166 5245 U 0.04 1 i ~ h Ilo it'n . 167 5276 U 0.02 ~t ~ 2.94 168 30 t 1 0.03 1 1 ? 2.93 169 5339 t~ 0.03 1 ~ _' 2.93 170 5371 a 0.02 t3 r i 2.96 171 5401 t ~ 0.03 1 1 ~ 2.95 172 5433 U 0.02 ~~ ; .9 173 5464 U 0.02 8 I 2.94 174 5495 U 0.03 1 U I 2.94 175 5527 tl 0.02 ~) b 2.93 17 5559 tl 0.02 ti 2.97 177 5589 U 0.02 ~~ _' 2.94 178 5622 U 0.02 ~) 2. 5 179 5653 t~.t~' 0.02 ~ u .93 1 684 l) 0.02 9 I .9 180.1 5715 a 0.03 11 _' 2.94 PUP 180.2 5721 tl 0 0 u N A M 4 atch ®10:30 180.3 57 6 t) 0.03 11 3 2.94 PUP 181 5733 tl 0.03 1 .93 182 5765 t~ 0.02 t3 I 2.97 183 5794 0.03 I ~ 2.92 Shall w ittin . 184 5825 (7.04 I'% 2.93 Shallow ittin . _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2 P-406 Kuparuk ConocoPhillips Alaska, Inc. USA July 6, 2008 Joint No. Jt. Depth (Ft.) I'r~n. Lll~tir~t (Inti.) Pen. Body (Ins.) Nen. °'° Metal I cxs °~~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 185 5 56 U 0. 2 7 I 2.96 186 58 7 U 0.03 12 ~ 2.93 187 5918 U 0.02 8 U 2.95 188 5948 U 0.03 13 2.92 Shallow ittin . 189 5979 t ~ .03 1 1 ~ 2.95 190 6011 t>.11b 0.02 - 1 2.97 191 6041 a 0.04 1 ~ !~ 2.94 Shallow corrosion 192 6073 r ~ 0.02 ~~ ~' 2.92 193 610 a 0.02 I 2.94 194 613 6 t 1 0.02 £i .93 19 16 l ~ 0.0 7 I 2.96 195.1 6198 +~ 002 ~) -a 2.96 PUP 195.2 6205 U 0 O U N A GLM La ch ~ 11: 0 195.3 6 10 t~ 0.04 14 t, 2.98 PUP Shallow ittin . 196 621 t~ 04 14 a 2.94 Shallo ittin . 196.1 6248 (~ 0.02 8 t~ .94 PUP 196.2 6254 n 0 0 t~ .81 Slidin Sleeve 196.3 6258 a 0. 2 7 ct 2 94 P P 196.4 62 70 t ~ 0 0 t ~ 2.75 D Ni le 96.5 6272 t~ 0.03 13 1 2.89 PUP Sh low Corrosion. 197 6278 r ~ 0.02 7 r ~ 2.95 197.1 6309 U 0.02 £i n .93 PUP 197.2 6319 t~ 0 0 U 3.00 Seal Assembl 197.3 6337 t) 0 0 l~ 4.00 Cr ss-0ver to Liner 197. 6340 a 0.0 9 _' .95 PUP 198 6346 l ~ 0.02 £3 I 2.94 199 6376 U 0.02 I 2.95 200 6408 U 0.02 7 ~ 2.91 201 6439 It 0.03 11 I 2.93 202 6470 (~ 0.02 ti I 2.97 2 3 6502 t~ 0.02 I 2. 6 204 6534 (~ 0.02 £3 2.96 205 6565 t~ 0. 3 1 Z 2.92 206 6597 t) 0.02 8 2.96 207 6628 (~ 0.03 1:3 2.92 Shallow ittin . 208 6660 t ~ 0.02 t3 ~ 2.98 209 6691 tt 0.03 II Z 2.9 210 6720 a 0.03 1 U u 2.92 211 6752 t ~ 0.02 H ,' 2.95 212 6783 U 0.03 11 t ~ 2.93 213 6814 t 1 0.02 i i 2.97 214 6845 tl 0.02 9 ~ 2.94 214.1 6876 t~ 0.02 £3 1 2. 5 P P 215 6883 a 0.01 5 _' 2.95 216 6914 t~ 0 0 U 2.96 Perforations. 217 6943 t ~ 0 0 r ~ 2.97 Perforations. Penetration Body Metal Loss Body Page 5 ConocoPhillips Alaska, Inc. • KRU 2P-406 2P-406 API: 501032048400 Well T e: PROD An le TS: TUBING SSSV T : NIPPLE Ori Com le5on: 2292004 An le TD: 39 d 7350 0327, Annular Fluid: Last W/O: Rev Reason: WAIVERED WELL OD:3.500, Reference L 28' RKB Ref Lo Date: Last U a[s: 12/92007 ID:2.992) Last Ta : 6952' TD: 7350 ftKB SURFACE Last Ta Date: 12/28/2006 Max Hole An le: 43 d 2852 9 6zs; Ca in Strin -ALL STR INGS ~~ ~) Deacri Uon Size To Bottom TVD Wt Grode Thread CONDUCTOR 16.000 0 110 110 62.50 WELDED SURFACE 9.625 0 2651 2369 40.00 L-80 BTCM PRODUCTION 5.500 0 6333 5149 15.50 L-80 BTCM PRODUCTION 3.500 6333 7344 5916 9.30 L-80 EUE8rd mod >ROOUCTION - Tubi Stri -TUBING (D-6~, Size To ottom TVD Wt G rade Thread OD:5.500, ' 3.500 0 6327 5145 9.30 L-80 EUESrdmod Wt .15.60) Perforations Summa Interval TVD Zone Smtu Ft SPF Da te T e Comment 6922 - 6942 5593 - 5608 20 6 5/92 004 IPERF 2.5" HSD, 60 deg phase, HP 2506 char es RDX Stimulations & Treatme nts ~g Lnt rWred/Dlinm _ Inte 1 Dete T Comment y i ~ Valve 2 ~ ~ 6922 - 6942 5/102004 FRAC PUMP 200 216ri 16/ 20 PROPPANT (4os5-4°ss, a Lift M andr elsNelve s OD:4.725) St MD TVD Man Mfr Man Type V Mfr V Type V OD Letoh Port TRO Date Run Vlv Cmnt 1 2556 2299 CAM CO KBG-2-9 DMY 1.0 INT 0.000 0 4/272004 2 4065 3427 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4272004 Gas LiR 3 5017 4151 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4272004 indrevpummy 4 5722 4692 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/272004 VaNe3 - ~ 5 6205 5053 CAMCO KBG-2-9 DMY 1.0 INT 0.313 0 5/232005 (50,7-5o1e, OD:4 725 Other u ui .etc . -COMPLETION . ) De th D T Deacri tio n ID 512 512 NIP CAMCO DS LANDING NIPPLE W/2.875" PROFILE 2.875 6254 5090 SLEEVE-O BAKER CMU SLIDING SLEEVE OPEN 12/30/2006 2.810 Gas Lift - -- 6254 5090 PUMP 3" TRICO JET PUMP (SN #PH-1123) 10-B RATIO: #10 NOZZLE, #11 THROAT, reset 2/112007 0.000 indreuDUrnmy 6270 5102 NIP CAMCO NO GO'D' NIPPLE 2.750 Valve 4 6319 5139 SEAL BAKER G-22 LOCATOR SEAL ASSEMBLY 3.000 (5722-5723, 6333 5149 XO 3.500 OD:4.725) 6336 5151 SHOE 2.992 Gener al te s Date Note 1/22005 NOTE: ENCOUNTERED TIGHT SPOTS 552' 5104' 5636' SLM Gas LM - 11/27/2007 NOTE: WAIVERED WELL -CHARGING OA ~ rwrel/DUmmy r Valve 5 (6205.6206, OD:4.725) SLEEVE-O (6254-6255, OD:4.490) NIP (6270-627i, OD:4.500) SEAL (631&6320, OD:4.000) XO (6333334, OD:5.500) FRAC (6922-6942) Pert (6922-6942) I JII 4 • • --~- .~~~- ~. ~,~~. _ -~~ MICROFILMED 03/01/2008 D4 NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc - ---- ConocdJ'hillips Alaska g~ r=_F:f\/ED j\:1= JU~ () ;) Z006 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 -1 ).., ~ ~2i C.9t4S ~1©:~:\~ ~ ~ <= ~ CG{rtmj5s~Ori !~Dthorage June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ~ANNED ,-JUt 0 7 2006 d-,oL(- ~ 0 d-?- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfill 404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05,2006. Schlumberger Well Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18t\ 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. -~ :::lio Perry Klein ConocoPhillips Problem Well Supervisor ('(..~~,-J d~ o6/~ù/ð6 Attachment n ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Corrosion Well Initial top Vol. of cement Final top of Cement top Royfill404B inhibitor/ Name pro# of cement pumped cement off date RG2041 vol vol. sealant date ft bbls ft Qal gal 5/19/2006 2P406>" ~0+022 4 - 0.0 4 na ~ 5~7 17.1 - 5/19/2006 2P-415a 201-226 5.5 0.0 5.5 na 7.1 30.9 5/19/2006 2P417 201-069 7.5 0.7 2.5 - 51-1/2006 - , ,5.7 - ~9 5/18/2006 2P-419 204-017 1 0.0 1 na 6.7 0 5/18/2006 - 2P.:.4:20- 201-182 3.5 o~o 3.5 na 7.1 17.3 --5/18120Q6 2P-422a 202-067 13.5 2.3 2.5 5/1/2006 7.1 10.7 5/18/2006 2P-424a 204-009 4.5 0.0 4.5 na 5.7 17.6 5/1812006 2P-427 202-018 10 1.6 2.5 5/1/2006 7.1 13.7 5/18/2006 _i2Þ429 -201-102- 2 0.0 2 na ~3.8 5.7 511812006 2P-431 202-053 13 1.9 2.5 5/1/2006 7.1 10.1 5/18/2006 2P432 -202-091 8.5 0.9 2.5 -5/1/2006 5.7 t3.8 511812006 2P-434 203-153 14 2.0 2.5 5/1/2006 5.7 6.2 5/18/2006 2P-438 -201.œ2 5 0.0 5 na 5.7 21.9 5/18/2006 2P-441 202-107 15 2.0 2.5 5/1/2006 7.1 13.1 5/18/2006 2P-443 204-032 3.5 0.0. 3.5 na 8.7 11.4 5/1812006, 2P-447 203-154 2.5 0.0 2.5 na 9.5 0 5/18/2006 2PM8a - 2o.2-OOS' 1.5 0.0 1.5- na 9.5 0 . 5/·18/2006 2P-449 204-026 3 0.0 3 na 5.7 11.5 5/31/2006 2P-451 . 202-008- 10 2.1 2.5 5/1/2006 7.1 6.5 5/18/2006 ') ConocriP'hillips Alaska ",lcEIVE0 JUN 1 2 : ¡Uì Alaska Oil &Gas Cons. Comrniss1on Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~-O~9- June 06,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUN 2 7 20D5 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 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 ::'~¡::2þ¢4OEr . 2P-415 f:::îp4í7, .... .' 2P-419 ;::<~t;~42Ð .'. 2P-422 Ii '~~P~4: 2P-427 ~,,2~4~9:.: \" 2P-431 ...2e_:,: 2P-434 ;;2ì?~38:'.·:·:" .' 2P-441 ·::2~3· 2P-447 .:.2Þ~", 2P-449 . 2pl.45i· I nitial top of cement ft '·4'; 5.5 . .7~5 1 . 3:~5' .' 13.5 '4~5 '. 10 :'2'.: 13 ··.:8~S:·. . 14 ":'5'.'·. 15 '. :'3.5:'. 2.5 .:.. .·1'~5· 3 '10 . Vol. of cement pumped bbls ..o~ó:· 0.0 . .0.7 '".' 0.0 >O~O· 2.3 ". . ·.·O~O' . 1.6 0;0:'.' '. 1.9 ;O~9" 2.0 ·.·,'ôt:C»· . 2.0 ..O~ è)' 0.0 O~O· . ' 0.0 2~1' Final top of cement ft ~, ::4 5.5 :}2~5 1 ." ~" ··:;>3~5,' 2.5 1·.4~5·. 2.5 . " .,: .2,,·;, 2.5 ':::.!Z5',·· 2.5 "I:. .,~::'$' :.C: 2.5 . '. ...;.:t:5~ ' '., 2.5 , ',~:1':5 .' 3 . 1"2.5:' ., . Kuparuk Field June 6,2006 Cement top off date RG2041 vol J 9al , . n·a. ' . - ..5..7 na 7.1 ~·:·.51112006. . ..; ,;.'5,~7·"· 6.7 ·:7A·'" 7.1 .'5;7:'" 7.1 "', ·:.3;~8·, 7.1 -·5~1".:·.: 5.7 , '. ,"5~7:, 7.1 8·T· . 9.5 '9.5:' ' 5.7 7~t na .:n$' 5/1/2006 nå:':.·.:; . 5/1/2006 . ,~...' t" " . , ., .. " .na" .. . . .' : ..' . ~'ö; . . ~:' '. '" .'" . . :" 5/1/2006 > :51112006: 5/1/2006 :;;ná.::·' . 5/1/2006 : ···.:ria:. na ." .nà, na 51.112006. . , Royfill4048 vol. gal " 17:~ t . 30.9 ":"9,':' o 17;3:.:' 10.7 , ':17~6::' 13.7 ., .'5:7, " 10.1 "f3~·a,:: 6.2 . 21:.9'.' 13.1 '·11.4 o . .':.' 0 11.5 '6:.5. Corrosion inhibitor/ sealant date 5/19/2006 . j5';16MOO'a.:· " '.~ fli,', .i:ff ~. ' U.".,· 5/19/2006 ::. ·.~p~8I1~~~.' 5/18/2006 . ~~1~812Q06·>c;: ',' 5/18/2006 '. ":5/j:812QOa,:; .:;. 5/18/2006 ,> '. ::!$Pt8120Q6:::::: 5/18/2006 : .; .,.:::....$l1SØ1Q$:< ':;.: 5/18/2006 ". .5lt8l2006:· "" 5/18/2006 ···$18120œ.·' 5/18/2006 '. ..$1W2006·:·:· ' 5/31/2006 . '~, '. . 5h8J200tr.··... q J'W\L ~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040220 Well NamelNo. KUPARUK RIV U MELT 2P-406 Operator CONOCOPHILLlPS ALASKA INC S'puvi ¡ 7 ¡=;,(, .¿ 6 Q '1 API No. 50-103-20484-00-00 MD 7350 / .-' Completion Date 5/9/2004 /" TVD 5921 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neu, SCMT Well Log Information: Electr Digital Dataset Med/Fnnt Number Log Log Run Scale Media No Blu Blu Blu Blu Name Directional Survey Induction/Resistivity /' Log Induction/Resistivity lÆg Density I I ~ Density C ~05 See Notes 12505 LIS Verification !J.eg Cement Evaluation I I6g Pressure Blu Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent Directional Survey Y. s (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 6/17/2004 2648 7350 Open 6/1/2004 MULTIPLE PROPAGATION RESISTIVITY GR 2648 7350 Open 6/1/2004 MULTIPLE PROPAGATION RESISTIVITY GR 0 0 Open 6/1/2004 ADVANTAGE POROSITY LOGGING SERVICE 2648 7350 Open 6/1/2004 ADVANTAGE POROSITY LOGGING SERVICE 0 0 Open 6/1/2004 RWD-GRlMPRlCCN/ORD 0 0 Open 6/1/2004 6100 7034 Case 5/27/2004 SCMT CEMENT BOND LOG/JEWELRY LOG/SCMT-CB/PBMS-A 6203 7105 Case 5/27/2004 STATIC BOTTOM HOLE PRESSURE SURVEY Sample Set Number Comments . . DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040220 Well NamelNo. KUPARUK RIV U MELT 2P-406 Operator CONOCOPHILLlPS ALASKA INC MD 7350 TVD 5921 Completion Date 5/9/2004 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Well Cored? Y & Chips Received? ~ Daily History Received? Gffi {J/N Formation Tops Analysis Received? ¥"rfr API No. 50-103-20484-00-00 UIC N Comments: ~ Date: Compliance Reviewed By: 8Jw--~~ . . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 5, 2005 Mr. Tom Maunder Alaska Oi 1 & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 . f'~" ,-,. N' r j.. '\L", ~,' " JiY~ (l) l1MJ(JS fJ~r ¿~ ~'.."~.; ¡:~;i,-_ r" Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 2L-311 (PTD # 203-155), 2P-406 (PTD # 204-022), 2P-242A (PTD# 204-009),and 2P-443 (PTD # 204-032) The Sundries report the conversion of each well from gas lift to surface powered jet pump artificial lift operations. Please call Marie McConnell or me at 659-7224 if you have a questions. Problem Well Supervisor Attachments . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION jUN 'J!'nr::; <-.Uvv REPORT OF SUNDRY WELL OPERATIONS Repair Well D Pull Tubing D Operat. ShutdownD Other Abandon D Alter Casing ~ Change Approved Program IZI 2, Operator Name: ConocoPhillips Alaska, Inc. 3. Address: p, O. Box 100360 7. KB Elevation (ft): RKB 254' a. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION Perforation depth: Plug Perforations D Perforate New Pool D Perforate D 4, Current Well Status: Development _ 0 Stratigraphic D Stimulate D Waiver D Time Extension Re-enter Suspended Well 5, Permit to Drill Number: D D Exploratory Service 204-022 6. API Number: 50-103-20484-00 9. Well Name and Number: 2P-406 10. Field/Pool(s): Kuparuk River Field I Meltwater Oil Pool measured 7350' feet true vertical 5921' feet measured feet true vertical 6276' feet Length Size MD 110' 16" 110' 2397' 9-5/8" 2651' 6079' 5-1/2" 6333' 1011' 3-1/2" 7344' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 2369' 5149' 5916' Measured depth: 6922 - 6942 ft true vertical depth: 5593 -560a ft RBDMS BFL JUN 0 7 2005 Tubing (size, grade, and measured depth) 3-1/2" , L-aO, 6327' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 326 611 0 609 263 Subsequent to operation 383 462 54 1505 270 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16, Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Marie McConnell/MJ Loveland @ 659-7224 MJ v land Problem Wells Supervisor 907 -659-7224 Date ~3JtJrV ¿/ _________ Title ~ Phone Submit Original Only r) L. li?\' .Al ! I'J, L · 2p-406 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary· Convert from GL to Suñace Powered Jet Pump 5/22/2005 TAGGED CMU @ 6254' RKB. BRUSHED TBG. WI LRS PUMPED HOT DIESEL (SOFT PARAFFIN IN TBG ). PULLED OGLV FROM STA # 5 @ 6205' RKB. SET 2.75 CSA-2 PLUG @ 6270' RKB. CMIT TBG. X IA ( PASSED ON THIRD TEST) 5/23/2005 SET DGLV @6205' RKB, PT IA ,MITIA to 3000 psi passed, SHIFT CMU OPEN, PULL CA-2 PLUG FROM "D" NIPPLE. ATTEMPT TO SET PUMP (TIGHT SPOT 552' SLM) 5/24/2005 SET JET PUMP (SIN: PH-1123, 10 B RATIO) ON 2.81 CS LOCK IN CMU SLIDING SLEEVE AT 6254' RKB. . . ConocoPhillips Alaska, Inc. KRU 2P-406 2P4406 f22e' ........ " ..................... " 'fi "iff f - API: 501032048400 Well Type: PROD Anç¡le @ TS: deç¡@ TUBING (0-6327. SSSV Tvpe: NIPPLE Oria Completion: 2/29/2004 Anale @ TD: 39 dea @ 7350 OP:3.500. Annular Fluid: Last W/O: Rev Reason: Set DMY, Set 10:2.992) Pump Reference Loa: 28' RKB Ref Loa Date: Last Update: 5/27/2005 Last Taç¡: 6977 TO: 7350 ftKB Last T aa Date: 5/1 0/2005 Max Hole Anale: 43 dea @ 2852 ...Y.....f) .·.Y)".Y··.·.·····.·.. f!Y f¡i> ii DescriDtion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 WELDED SURFACE SURFACE 9.625 0 2651 2369 40.00 L-80 BTCM (O-2651. PRODUCTION 5.500 0 6333 5149 15.50 L-80 BTCM 00:9.625, PRODUCTION 3.500 6333 7344 5916 9.30 L-80 EUE8rd VVI:40.00) mod Y'''> > fY> ....>! !Y> ............................... .·.···..·.·.....·Y··········· Size Top I Bottom TVD I Wt I Grade I Thread 3.500 0 I 6327 5145 I 9.30 I L-80 I EUE8rdmod ROOUCTlON .......!!.."........ > 2 "" .·..)Y.. .................... (0-6333. Interval TVD Zone Status Ft SPF Date Tvpe Comment 00:5.500. wt:15.50) 6922 - 6942 5593 - 5608 20 6 5/9/2004 IPERF 2.5" HSD. 60 deg phase, HP 2506 charaes, RDX f Y> ·..·.··..·.·.·.··..··f.···.·. ff ." ..·..·..··.·.>.2.··>·... Interval I Date Tvpe I Comment 6922 - 6942 I 5/10/2004 I FRAC I PUMP 200216# 16/20 PROPPANT Ga~ ..... 2 .............................. 'ff!y .·..·..·Y>y.·..·.;·. )"f St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2556 2299 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 2 4065 3427 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 3 5017 4151 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 4 5722 4692 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 5 6205 5053 CAMCO KBG-2-9 DMY 1.0 INT 0.313 0 5/23/2005 Othêr(î···luQs··.ê···iui"'· .'.Y'.f.'. fY f. Y' Depth TVD TVDe DescriDtion ID 512 512 NIP CAMCO DS LANDING NIPPLE W/2.875" PROFILE 2.875 6254 5090 SLEEVE BAKER CMU SLIDING SLEEVE 2.810 6254 5090 PUMP TRICO JET PUMP (SN #PH-1123) 10-B RATIO: #10 NOZZLE, #11 THROAT, 0.000 set 5/24/2005 6270 5102 NIP CAMCO NO GO 'D' NIPPLE 2.750 6319 5139 SEAL BAKER G-22 LOCATOR SEAL ASSEMBLY 3.000 6333 5149 XO 3.500 6336 5151 SHOE 2,992 GêíiêrafNôtêš ..... ..·.YYyY>2>Y ,,> " ..·Y.;>. .....;>Y2y .......... SLEEVE Date Note (6254-6255. 4/28/2004 TREE: 3-1/8 WKM (GMC) GENERATION V, 5000 psi 00:4.490) TREE CAP CONNECTION: OTIS 4" 1/2/2005 ENCOUNTERED TIGHT SPOTS @ 552' 5104' 5636' SLM NIP (6270-6271. 00:4.500) ff SEAL t:J (6319-6320. 00:4.000) XO (6333-6334. 00:5,500) FRAC ~ ~ (6922-6942) Perf (6922-6942) Producer MITIA Pre GL to IP Conversion . . Subject: Producer MITlA Pre GL to JP Conversion From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sat, 04 Jun 2005 15:42:07 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jimJegg@admin.state.ak.us>, bob _ fleckenstein@admin.state.ak.us Tom, Attached are MITIA forms for 4 producers prior to surface power jet pump conversion. The 10-404's are in the US mail. Please let me know if you have any questions. MJ Loveland «MITP KRU 2P-443 05-25-05.xls» «MITP KRU 2P-424A 05-21-05.xls» «MITP KRU 2P-406 05-23-05.xls» «MITP KRU 2L-311 05-28-05.xls» Content-Description: MITP KRU 2P-443 05-25-05.xls KRU 2P-443 05-25-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2P-424A 05-21-05.xls KRU 2P-424A 05-21-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2P-406 05-23-05.xls KRU 2P-406 05-23-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2L-311 05-28-05.xls KRU 2L-311 Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 6/6/20057:56 AM e e Transmittal Form ,,__ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 2P-406 Contains the following: 1 LDWG Compact Disc -- # ) À)"'D).- (Includes Graphic Image files) 1 LDWG lister summary ./ 1 blue line - MPR Measured Depth Log .......- 1 blue line - MPR TVD Log L-/ 1 blueline - CCN/ORD Measured Depth Log v 1 blueline - CCN/ORD TVD Log ~ LAC Job#: 640243 Sent By: Gle~ yorel Received By: Î~JOILI Date: May 28, 2004 Date: I J~ ÁM v{ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 )o~{~· ~ Á- 2- · . e e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conoc~hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 May 25, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-406 (APD # 204-022 / 304-065) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-406. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. . Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEIVE MAY 2 7 2004 ORIGINAL Alaska Oil ~~h""I¡ìlsslon AnchuH!ge · . e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged U Abandoned D Suspended D WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJ D WINJ D WDSPL D No. of Completions _ Other - Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., ~~ '11 %01 Ai .'. 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. Þ'l204-022/304-065 or Aband.: A', ~Zß 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 February 27,2004 50-103-20484-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: ... Surface: 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM April 24, 2004 2P-406 At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 1219' FNL, 789' FWL, Sec. 16, T8N, R7E, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Meltwater Oil Pool 1240' FNL, 1123' FWL, Sec. 16, T8N, R7E, UM 7218' MD / 5818' TVD 4b. Location of Well (State Base Plane Coordinates): I 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-444361 ../ y- 5869047 Zone- 4 ... 7350' MD /5921' TVD' ADL 373112 TPI: x- 448028 y- 5868628 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 448361 y- 5868605 Zone- 4 Landing Nipple @ 512' ALK 32092 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1375' MD 21. Logs Run: GRlRes/Dens/Neu, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE CEMENTING RECORD WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# B 28' 108' 28' 108' 42" 104 sx AS I 9,625" 40# L-80 28' 2650' 28' 2367' 12.25" 342 sx AS Lite, 229 sx LiteCrete 5,5" 15.5# L-80 28' 6333' 28' 5149' 8.5" 623 sx Class G 3.5" 9.3# L-80 6333' 7344' 5149' 5916' 8.5" included above 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 6336' none 6922'-6942' MD 5593'-5608' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6922'-6942' 200216# of 16/20 proppant 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) May 16, 2004 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/17/2004 7.5 hours Test Period --> 822 636 33 100% 1119 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 284 psi 909 24-Hour Rate -> 2145 2401 102 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rB~j,i~¡:~i~S;.i···~ RECE\\/E,D ~,,\: i¡ ì 5.:.-_:t?- . \ NONE 2üü4 V3<~) . MA'< 27 ø-¡:"\ .; ~..\. { ~-_.... r í'ns Commission I\\~!t\(a Qi\ &. ro.}'!,) . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE I\I1CnU1O'd" ORIGINAL ~BFL (#',(¡ JUK (() 8 J[ì.t1~ \? \ · 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2P-406 T3 T3,1 T2 6850' 6832' 7126' 5538' 5525' 5747' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed N~.Thomas Title: Signature l ~e KUDaruk Drillinc Team Leader ''-'S- G-e so Date 5f¿S(c:;>¥' Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated, Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 e e KRU 2P-406 ConocoPhillips Alaska, Inc. 2:¡!i,i#QS :: '? :: ...···..·;1;; :? , , ??... ............................".', API: 501032048400 Well Tvpe: PROD Anllle (â) TS: deQ tâJ TUBING SSSV Tvoo: NIPPLE Oriq Completion: 2/29/2004 Anllle (â) TD: 39 deo tâJ 7350 (26-6327, Annular Fluid: Last W/O: Rev Reason: Tao. PERF FRAC OD:3.500, Reference LOQ: 28' RKB Ref LOll Date: Last Update: 5/14/2004 ID:2.992) Last Tall: 7106 TD: 7350 ftKB SURFACE Last Tall Date: 5/12/2004 Max Hole Anole: ~3 deo tâJ 2852 (28-2651, €åsiríõStriríõgBIillSMBIIíI<SS iiii,fff .:.."·"·i·" . f'.""""", fffff..iiffff ff .i:...??iifl OD:9.625, Wt:40.00) DescriPtion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 WELDED SURFACE 9.625 28 2651 2369 40.00 L-80 BTCM PRODUCTION 5.500 29 6333 5149 15.50 L-80 BTCM PRODUCTION 3.500 6333 7344 5916 9.30 L-80 EUE8rd mod 'RODUCTION Mubiriî!îStfil\Ìî!îgmWSIIíIIS FF .....?··.i·:f ·....1;1;; "i"'i" ·.,··'·ii·i·i·ii·i,ii·i.·iFFFFFFfF?FF: :: (29-6333, Size TOD I Bottom I TVD I Wt I Grade Thread OD:5.500, 3.500 26 6327 5145 I 9.30 I L-80 EUE8rdmod Wt:15.50) E!enorationsSúffiffiáfý' F .. ·???FF ·ii··'··....·....,.·i i.. Interval I TVD I Zone Status I Ft I SPF I Date Tv De €omment 6922 - 6942 5593 - 5608 I I 20 I 6 I 5/9/2004 IPERF 2.5" HSD, 60 deg phase, HP Gas Lift ~ Type I Comment I mdrel/Dum my PUMP 200 216# 16/20 I Valve 2 (4065-4066, ......., ,.? f:?f:ffl OD:4,725) St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 1 2556 2299 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 2 4065 3427 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 Gas Lift 3 5017 4151 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 mdrel/Dummy 4 5722 4692 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/27/2004 Valve 3 5 6205 5053 CAMCO KBG-2-9 SPARTEK 1.0 INT 0.000 0 4/27/2004 11 (5017-5018, 1. GAUGES set 5/8/2004 OD:4.725) Otherffì l.ùõsiíiiú¡Ð¡.·'ØfØ¡~- aeWeliA~ .·...:.·.;f i.. i.....;;;; .. ,. ii" ii. ...................i.· ....?F Fii?? "'ii? Depth TVD Type Description ID 512 512 NIP CAMCO DS LANDING NIPPLE W/2.875" PROFILE 2.875 6254 5090 SLEEVE BAKER CMU SLIDING SLEEVE 2.810 Gas Lift 6270 5102 NIP CAMCO NO GO 'D' NIPPLE 2.750 mdrel/Dummy 6319 5139 SEAL BAKER G-22 LOCATOR SEAL ASSEMBLY 3.000 Valve 4 6333 5149 XO 3.500 (5722-5723, 6336 ,151 2.992 OD:4.725) Gênêral '.' '.' ',. i,i','i,ii 'i'iii "??ii?;." ,i..f Date Note 4/28/2004 TREE: 3-1/8 WKM (GMC) GENERATION V, 5000 psi TREE CAP CONNECTION: OTIS 4" Gas Lift MandrelNalve 5 (6205-6206, SLEEVE (6254-6255, OD:4.490) NIP (6270-6271, OD:4.500) SEAL (6319-6320, OD:4.000) XO (6333-6334, OD:5.500) ~ ~ FRAC ~ (6922-6942) r-¿- Perf ti (6922-6942) ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: Move Pipe shed, Sub & support modules off 2P-443. Spot Sub, Pits & Pump modules on 2P-406. Spot Motors, Boilers, Rock washer, Pipe shed, Work on steam, Water & air lines. Work on rig acceptance check list. Note; Accepted rig at 14:30 hrs 2/26/2004. Nipple up Diverter system, Take on mud in pits. Pick up mud motor, Make up bit, Thaw BHA tools. Held Pre- Spud meeting with both drilling crews and rig personnel. Thaw out Diverter and Funtion test same, Test waived by AOGCC John Spaulding. Make up BHA, Orient motor and MWD, Program LWD. Fill Conductor, Check for leaks, Surface test pump lines. Attempt to circ- No good, LWD plugged w/ ice plug, Change out LWD tools, Reorient MWD, Clean out ice plug f/ 85' to 108', Drill f/1 08' to 918' ART = 3,2 hrs AST = 1,5 hrs, Pump Hi-vis weighted sweeps every 4 to 5 stands, WOB 15/25K, 80 RPM, 590 GPM @ 1500 psi, UP 78K, DN 84K, ROT 82K, TO 3/4K on/1 K off, Mud weight to 10,5 ppg w/ vis 250, BGG 30 to 45 units. 12.00 DRILL DRLG SURFAC Drill f/ 918' to 2,409' ART = 5.3 hrs AST = 2.9 hrs, Pump Hi-vis weighted sweeps every 4 to 5 stands, WOB 15/25K, 80 RPM, 654 GPM @ 2250 psi, UP 104K, DN 100K, ROT 103K, TO 517K on! 3K off, Mud weight to 10,5 ppg w/ vis 180, BGG 30 to 45 units, Max gas 95 units. 2.50 DRILL DRLG SURFAC Drill f/ 2,409' to 2,656' ART = 1.5 hrs AST = 0.3 hrs, Pump Hi-vis weighted sweeps every 4 to 5 stands, WOB 15/25K, 80 RPM, 654 GPM @ 2300 psi, UP 106K, DN 104K, ROT 105K, TO 6.5K on/3.5K off, Mud weight to 10.5 ppg w/ vis 180, BGG 30 to 45 units, Max gas 175 units. Pump Hi-vis weighted sweep around, Monitor well. Back Ream out of hole f/ 2,656' to 1,388' at drilling rate, (Extreme amount of cuttings unloaded from hole on btms up), Circ hole clean. POOH on elevators to Ghost reamer, Lay down same, POOH w/ HWDP, Down load and lay down BHA, Clear rig floor of tools, Rig to run 9-5/8" casing. PJSM, Ran Float shoe, 2 jts. 9-5/8", 40#, L-80, BTC casing, Float collar, 66 jts casing, FMC hanger, Ran Bowspring centralizers 1-5' above shoe, 1- on first collar, 1- 10' below floar collar, 1-20' above float collar, 1 on every jt. #3 thru #20 (Total of 22 centralizers), Casing stopped @ 315' and had to wash down to 418' at rate of 3 bpm @ 200 psi, Then ran to 1,847' and displacement decreased, Washed down 2 jts f/1 ,847' to 1,920', Ran casing to btm @ 2,649'. Note; Shoe @ 2,649.83', Float collar @ 2,571.07'. Circ & condition mud for cement while reciprocating pipe 15', UP 110K, DN 102K, Mud wt. 10.4 ppg, vis 46, PV 23, YP 11, Gels 417, PH 8.0, Stage rate up to 6 bpm @ 450 psi. Lay down Frank's fill up tool, Pick up Dowell cement head. Continue to circ & condo mud, PJSM on cement job, Dowell batch mix spacers. Rig Dowell, Mix & pump 10 bbls CW1 00 at 8.3 ppg at rate of 4.3 bpm @ 260 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 7.0 bpm @ 550 psi, Shut down and drop btm plug, Mix & pump 342 sxs (271.6 bbls) Lead ArcticSet III 2/26/2004 04:30 - 08:30 4.00 MOVE MOVE MOVE 08:30 - 12:00 3.50 MOVE MOVE MOVE 12:00 - 14:00 2.00 MOVE MOVE MOVE 14:00 - 16:30 2.50 MOVE RURD MOVE 16:30 - 19:30 3.00 WELCT SURFAC 19:30 - 21 :00 1.50 DRILL SURFAC 21 :00 - 21 :15 0.25 DRILL SURFAC 21:15 - 22:15 1.00 WELCT SURFAC 22:15 - 23:30 1.25 DRILL PULD SURFAC 23:30 - 00:00 0.50 DRILL CIRC SURFAC 00:00 - 04:15 4.25 DRILL PULD SURFAC 04:15 - 12:00 7.75 DRILL DRLG SURFAC 2/27/2004 12:00 - 00:00 2/28/2004 00:00 - 02:30 02:30 - 03:00 0.50 DRILL CIRC SURFAC 03:00 - 06:00 3.00 DRILL TRIP SURFAC 06:00 - 09:15 3.25 DRILL TRIP SURFAC 09:15 - 10:30 1,25 CASE RURD SURFAC 10:30 - 16:30 6.00 CASE RUNC SURFAC 16:30 - 17:30 1.00 CEMEN CIRC SURFAC 17:30 - 18:00 0.50 CEMEN PULD SURFAC 18:00 - 19:15 1.25 CEMEN CIRC SURFAC 19:15 - 21:15 2.00 CEMEN PUMP SURFAC Printed: 5/21/2004 3:04:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: 2/28/2004 19:15 - 21 :15 2,00 CEMEN PUMP SURFAC cmt mixed at 10.7 ppg w/ additives at rate of 6.8 bpm @ 610 psi, Followed by 229 sxs (100.8 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg w/ additives at rate of 6.7 bpm @ 950 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 173.3 bbls 10.4 ppg mud (total of 193.3 bbls to bump plug) at rate of 7.0 bpm @ 500 to 680 psi, Slowed rate to 3.0 bpm @ 380 psi for last 10 bbls of displacement, Bump plug w/1100 psi, Floats held- OK, CI P @ 21: 15 hrs 2/28/04, Had good returns thru out job, Reciprocate csg. 15' until cement 59 bbls from surface then pipe began taking wt., Had 121,9 bbls good cmt returns to surface. 21 :15 - 21 :45 0.50 DRILL DEQT SURFAC Rig & test 9-5/8" casing to 3500 psi f/30 min.- OK. 21 :45 - 00:00 2.25 CEMEN PULD SURFAC Lay down Dowell cement head, Break out & lay down landing joint, Rig down and clear 9-5/8" csg. tools from rig floor. 2/29/2004 00:00 - 04:00 4.00 WELCT NUND SURFAC Nipple down Diverter system, Change out bails. 04:00 - 05:00 1.00 WELCT NUND SURFAC Install & Nipple up FMC Gen 5 wellhead, Test same to 1000 psi-OK. 05:00 - 08:00 3.00 WELCT BOPE SURFAC Install & Nipple up BOPE, Set test plug & test wellhead flange to 250 psi low & 5000 psi high, Rig down test equip, Install wear bushing. 08:00 - 10:15 2.25 DRILL PULD SURFAC RIH w/10 stands HWDP, POOH & Lay down same, Lay down Baker Inteq BHA subs from floor. 10:15 - 12:00 1.75 DRILL PULD SURFAC RIH wI 17 stands 5" drill pipe, POOH & lay down same. 12:00 - 12:30 0,50 DRILL PULD SURFAC Pull wear bushing. 12:30 - 13:00 0.50 DRILL CIRC SURFAC Pump & flush out mud pumps with fresh water. 13:00 - 15:15 2.25 WELCT TRIP SURFAC Rig & run 3-1/2", 9.3#, L-80 Tubing as Kill string to 1,655', Make up & land tbg. hanger, Install 2-way check. 15:15 - 16:45 1.50 WELCT NUND SURFAC Nipple down BOPE. 16:45 - 19:00 2.25 WELCT NUND SURFAC Nipple up Tree & test same to 5000 psi- OK, Pull 2-way check. 19:00 - 22:00 3,00 CMPL TN FRZP SURFAC Rig & Freeze protect well wI 125 bbls diesel thru tbg @ 1,655' at rate of 3 bpm @ 550 psi untill diesel back to surface. 22:00 - 23:00 1.00 CMPL TN OTHR SURFAC Set BPV & Secure well. 23:00 - 00:00 1,00 CMPL TN OTHR SURFAC Finish injecting remaining fluids, Finish cleaning rock washer pits. Note: Released rig @ 24:00 hrs 2/29/2004. 0 4/19/2004 04:00 - 05:15 1.25 MOVE DMOB MOVE Rig released from 2p-443 at 04:00 4/19/04. Prepare rig for move. 05:15 - 06:15 1.00 MOVE MOVE MOVE Move from 2P -443 to 2P-406 06:15 - 07:15 1.00 MOVE POSN MOVE Spot and level rig over well. 07:15 - 12:00 4.75 DRILL RIRD RIGUP Berm rig, drop tarps, spot out buildings and cuttings box. Load mud in pits and RlU to displace freeze protect from well. 12:00 - 12:30 0.50 DRILL CIRC PROD Accept rig at 12:004/19/2004. Pull BPV. Reverse circulate 125 bbl diesel with 10.5 ppg LSND mud. Set BPV. 12:30 - 13:00 0,50 DRILL RIRD PROD RID circulating hoses. 13:00 - 13:15 0,25 DRILL SFTY PROD PJSM for Tree removal and NU BOPE. 13:15 - 14:00 0.75 WELCT NUND PROD NID production tree 14:00 - 19:00 5.00 WELCT RIRD PROD NIU BOPE. Confirmed no BOP test required prior to pulling tubing per C. Scheve, AOGCC. BOP to be tested prior to picking up BHA for drill out. 19:00 - 19:30 0.50 DRILL RIRD PROD Set Mousehole. Fill stack and check riser boot seals. 19:30 - 20:00 0.50 DRILL TRIP PROD Pull BPV. MIU landing joint and tubing running tool. Latch up and BOLDS. 20:00 - 20:30 0.50 DRILL TRIP PROD Unseat, pull and layout tubing hanger. 20:30 - 00:00 3.50 DRILL TRIP PROD Pull and stand back kill string. Rabbit tubing to 2.867". Replace seal rings. Layout 2 jts. 1 bad pin & 1 bad box, 4/20/2004 00:00 - 00:45 0.75 DRILL TRIP PROD Continue POOH with 3.5" kill strin. Drift, ring and stand back in derrick. 00:45 - 04:45 4.00 WELCT BOPE PROD R/U amd test BOPE. Test to annular to 500/3500 psi. Test rams to Printed: 5/21/2004 3:04:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: 500/5000 psi. All tests OK. AOGCC Test witness waived by C. Scheeve, AOGCC. 04:45 - 05:45 1.00 WELCT PROD Pull test plug and run wear bushing. 05:45 - 11 :00 5.25 DRILL PROD PU BHA. Orient and upload directional tools. PJSM for loading Nuclear tool sources. Load Nuclear tools. Change out drilling jars. 11 :00 - 12:00 1.00 DRILL PULD PROD MU TD and Shallow test MWD, Blow down TD. 12:00 - 12:30 0.50 DRILL PULD PROD RIH w/ HWDP fron derrick and MU Ghost reamer. 12:30 - 13:30 1.00 RIGMNT RSRV PROD Service TD, Check bolts 7 hoses. Fix hose guard, 13:30 - 14:00 0.50 DRILL TRIP PROD RIH with 4" DP from pipe shed. 14:00 - 15:00 1,00 DRILL SFTY PROD Stripping drill. 15:00 - 16:00 1.00 DRILL TRIP PROD RIH w/4" DP. Picked up 30 joints. Continue in with stands fron derrick. 16:00 - 18:00 2.00 CEMEN DSHO PROD Wash to float collar and drill out FC, shoe track, FS, rat hole and 20' new formation. CBU for FIT. 18:00 - 19:00 1,00 DRILL FIT PROD Pull back 2 Std. Blow down TD. R/U and conduct FIT. MW = 10.3 ppg. Pressure at leakoff = 950 psi. FIT EMW = 18,0 ppg. 19:00 - 19:15 0.25 DRILL DEQT PROD Deep function test MWD tools. 19:15 - 00:00 4.75 DRILL DRLG PROD Drill from 2678' to 3038' MD, 2651' TVD.PU = 73K, SO = 65K, ROT = 73K. Torque at 80 RPM = 3.8K off & 4K on. Pump 540 gpm @ 2750 psi. ART = 3.0 hr. AST = 0.5 hr. TDT = 3.5 hr. 4/21/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill to 3861'. Pump Hi-Vis sweep at 3620'. PU = 85K, SO = 70K, ROT = 70K. Torque = 4300 off/4800 on, Pump at 530 gpm & 2800 psi off/3100 psi on. MW = 10.7 ppg ECD = 11.7 ppg. ART = 7.9, AST = 0.4, TDT = 8.3 BGG = 40 units CG = 100 units. 12:00 - 14:00 2.00 DRILL DRLG PROD Drill to 4080'. Sweep at 3930'. 14:00 - 15:15 1,25 DRILL CIRC PROD Sweep, circulate and condition for short trip for electrical tie in of new centrifuge. 15:15 - 18:00 2.75 DRILL WIPR PROD Back ream out to 3050'. Clay balling in flowline. CBU and clean out clay, Pump out to 2945'. POOH to 2660'. BDTD. 18:00 -19:00 1.00 DRILL OTHR PROD Flow check. Blow down steam to cellar heater, cuttings tank and BD tank and prepare for power down. 19:00 - 19:45 0.75 DRILL OTHR PROD Shutdown electric power and tie in new centrifuge electrical pannel to rig power distribution. 19:45 - 20:30 0.75 DRILL CIRC PROD CBU. Max.gas 55 units. 20:30 - 22:00 1.50 DRILL WIPR PROD RIH to 3990' No excess drag, 22:00 - 22:30 0.50 DRILL REAM PROD Precautionary ream to bottom and CBU. No fill. CBU. Max gas = 1200 units. BGG = 50 units. 22:30 - 00:00 1.50 DRILL DRLG PROD Drill to 4200' MD, 3530' TVD. PU = 85K, SO = 83K, ROT = 83K. Torque = 4900 off/5800 on. Pump at 530 gpm & 2850 psi off/3150 psi on. MW = 10.7 ppg ECD = 11.7 ppg. ART = 2.4, AST = 0.0, TDT = 2.4, 24 hr. TDT =10.5 hr. BGG = 40 units CG = 100 units. 4/22/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill to 5310' MD, 4330' TVD, PU = 120K, SO = 80K, ROT = 95K. Torque = 5400 off/6500 on. Pump at 515 gpm & 3000 psi off/3450 psi on. MW = 10.7 ppg ECD = 11.7 ppg, ART = 8.1, AST = 0.0, TDT= 8.1,. BGG = 50 units CG = 50 to 400 units. CG from 3795', 12:00 - 22:15 10,25 DRILL DRLG PROD Drill to 6030' w/ 210 spm & 3250 psi. Pump #1 pulsation dampener manifold leaking at 3" nipple washed out. 22:15 - 22:30 0,25 DRILL CIRC PROD Circulate wI Pump #2 and work pipe while evaluating pump #1. 22:30 - 00:00 1,50 DRILL DRLG PROD Control drill to 6092' MD, 4669' TVD with 110 stk. 271 gpm. & 1500 psi. MW = 10.5 in /10.6 out ppg ECD = 11.0 ppg. PU = 105K, SO = 98K, ROT = 102K, Torque =7000 off17800 on ART = 5.3, AST = 2.8, TDT = 8,1. 24 hr ADT = 16,2 hr. BGG = 50 units CG = 50 to 765 units. CG from 3795'. 4/23/2004 00:00 - 01 :00 1.00 DRILL OTHR PROD Work balled bit while welding nipple in #1 pump pulsation dampener Printed: 5/21/2004 3:04:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: 4/23/2004 00:00 - 01 :00 1.00 DRILL OTHR PROD manifold. (NOTE: HCM 605 Bit will not self clean at 260 gpm in this interval. Therefor it is recommened Not even attempting to drill on reduced pump with this bit.) 01 :00 - 03:00 2.00 DRILL DRLG PROD Drill to 6239' MD, MW = 10.6 in /10.7 out ppg ECD = 11.5 ppg. PU = 110K, SO = 11 OK, ROT = 105K. Torque = 7200 off/8000 on. BGG = 50 units CG = 300 to 400 units. CG from 3795', 03:00 - 05:00 2.00 DRILL CIRC PROD Circulate and condition while change out valve, seat and Popoff on # 2 pump. Raise Mud wt to 10.8 ppg. 05:00 - 07:30 2.50 DRILL DRLG PROD Drill to 6417' MD, 5213' TVD. ART = 3.3 hr. AST= 0.0 hr. TDT = 3.3 hr. 07:30 - 09:30 2.00 DRILL CIRC PROD CBU while R & R. CG, = 350 U. Shut down 10 min for simulated connection. PU = 140K & SO = 90K w/o pump. CBU, CG from 3795' = 525 u. Circ Hi-vis sweep and flow check, 09:30 - 12:30 3.00 DRILL WIPR PROD Back ream OOH 14 std. CBU std 13 & 14 w/ BUG = 250 units, POOH on stands to 3600'. 12:30 - 13:00 0.50 DRILL OBSV PROD Flow check and service TD. Well stable. 13:00 - 14:00 1,00 DRILL WIPR PROD RIH w/ stands. No excess drag. 14:00 - 14:30 0.50 DRILL CIRC PROD Fill pipe and break circ. 14:30 - 15:15 0,75 DRILL WIPR PROD RIH w/ stands to 6352'. 15:15-16:15 1.00 DRILL CIRC PROD MUTD and circulate to bottom. BGG> = 30 - 50 units. BUG = 1600 u, 16:15-19:30 3.25 DRILL DRLG PROD Drill to 6545'. Circ @ 510 gpm & 3200 psi. Torque = 8000 ftlb on. WOB =20K. 19:30 - 21 :00 1.50 DRILL CIRC PROD Circulate on # 2 pump while repairing Suction header flex coupling. 21 :00 - 23:00 2.00 DRILL DRLG PROD Drill to 6570' with low ROP. Work possible balled bit. Drilled hard calcarious tuft stringers. 23:00 - 00:00 1.00 DRILL DRLG PROD Drill to 6620' MD, 5364' TVD, PU = 115K, SO = 107K, ROT = 11 OK. Torque = 7500 off/9200 on. Pump at 512 gpm & 3100 psi off/3500 psi on. MW = 10.9 ppg ECD = 11.5 ppg. ART = 2,9, AST = 1.8, TDT = 4.7, 24 hr TDT = 8.0 hr. BGG = 5 - 10 units CG = 100 to 300 units. CG from 3795', 4/24/2004 00:00 - 03: 15 3.25 DRILL DRLG PROD Drill from 6620' to 6862' MD, 5547' TVD at prognosed top of T-3, 03:15 - 03:45 0.50 DRILL CIRC PROD Flow check and CBU for sample. 03:45 - 04:00 0.25 DRILL DRLG PROD Drill to 6875' MD, 5557' TVD. 04:00 - 04:30 0,50 DRILL CIRC PROD Flow check and CBU and confirm formation sample. 04:30 - 11 :00 6.50 DRILL DRLG PROD Drill to 7350' MD, 5921' TVD. PU = 130K, SO = 97K, ROT = 110K. Torque = 8400 off/9200 on, Pump at 508 gpm & 3200 psi off/3650 psi on. MW = 10.9 ppg ECD = 11,5 ppg, ART = 7.0, AST = 0.0, TDT = 7.0, 24 hr TDT =7.0 hr. Max. Formation gas = 1200 u. BGG = 40 units CG = 100 to 226 units, CG from 3795', 11 :00 - 12:00 1.00 DRILL CIRC PROD Flowcheck. Survey and CBU while R & R. CBU second time @ 205 spm & 3300 psi and 11,2 PPG EMW. 12:00 - 12:30 0.50 DRILL OBSV PROD Shut down pumps and observe, No flow. PU= 160K., SO = 95 K W/O pump, 12:30 - 14:00 1.50 DRILL WIPR PROD Backream OOH 12 stds. 20K @ f/ 7013' to 7000'. POOH 3 stands on elevators. No excess drag, Hole fill correct. Note; Overall hole in very good shape. 14:00 - 15:00 1.00 DRILL WIPR PROD RIH on Elevators. No excess drag or tight spots. PU = 170K. SO = 85 K at bottom. 15:00 - 18:15 3.25 DRILL CIRC PROD Break circulation and stage pumps to 205 spm. CBU, Pump Hi - vis Sweep and CBU 2 times. PU = 170K and SO = 90 K w/o pumps. 18:15 -18:45 0.50 DRILL OBSV PROD BDTD and flow check. Well stable. 18:45 - 19:45 1.00 DRILL TRIP PROD Pump out 10 stands with no rotation. No excess drag. Hole fill correct. 19:45 - 22:15 2.50 DRILL TRIP PROD BD TD and POOH on elevators to 3985'. Hole fill correct. No tight spots. Printed: 5/21/2004 3:04:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: 4/24/2004 22:15 - 23:00 0,75 DRILL CIRC PROD Displace hole from 3985' with 11.5 ppg mud. Max gas = 550 u. BGG at end of displacement = 170 u and falling. 23:00 - 23:45 0.75 DRILL OBSV PROD Flow check. Hole static. Fill Trip tank wI 11.5 ppg mud and BDTD> 23:45 - 00:00 0.25 DRILL TRIP PROD POOH. 4/25/2004 00:00 - 03:00 3.00 DRILL TRIP PROD Continue POOH to top of Drill collars. Hole fill correct. 03:00 - 04:15 1.25 DRILL PULD PROD Lay down flex Drill collars, 04:15 - 04:30 0.25 DRILL SFTY PROD PJSM for laying down Nuclear tool source modules. 04:30 - 05:45 1.25 DRILL PULD PROD LD Nuclear sources, download MWD data and LD MWD tools. 05:45 - 07:00 1.25 DRILL PULD PROD LD remaining BHA and Bit. Clear floor and shed of BHA and tools, 07:00 - 09:00 2.00 CASE NUND PROD P/U stack washer and wash out stack and wellhead. LD washer and PU WB tool. Pull WB, Change bottom rams to 5.5". Run Test plug and test BOP shell to 2500 Psi. Pull and LD test plug. C/O elevators and tongs for casing, 09:00 - 09:15 0,25 CASE SFTY PROD PJSM for running casing 09:15 - 10:00 0.75 CASE PUTB PROD P/U 5 1/2" hanger and make dummy run. LD hanger. Clear for running 31/2" 1 0:00 - 12:00 2.00 CASE PUTB PROD PU shoe track and test floats. RIH w/3 1/2" casing and centralizers. Run 32 jts. + pup for 1010.12' with 48 3 1/2" x 8 1/2" centralizers. 12:00 - 13:00 1.00 CASE RURD PROD R/U 5 1/2" tools. PU long bails, elevators, spider and elevators. 13:00 - 14:45 1.75 CASE RUNC PROD PU 3,5 x 5.5 XO/PBR assembly. Continue RIH wI 5.5" csg. to 1800'. Ran 155.5" x 8.5" centralizers 14:45 - 15:15 0.50 CASE CIRC PROD Circulate to clear fill up tool back pressure valve and confirm function of fillup tool and floats, 15:15 - 16:00 0.75 CASE RUNC PROD RIH wI 5,5" csg to 2560'. 16:00 - 16:45 0.75 CASE CIRC PROD CBU at surface casing shoe. 16:45 - 18:15 1.50 CASE RUNC PROD RIH w/5.5" csg to 3994'. Hole conditions good. Full returns 18:15 - 20:00 1,75 CASE CIRC PROD CBU and displace remaining 11.5 ppg mud. Circulate and balance MW at 10,8+ ppg, Max gass at BU = 335 u. BGG at end of circulaion = 17 u. PU = 95K, SO = 65K. Pump 65 spm @ 385 psi. Hole conditions good. Full returns 20:00 - 22:00 2.00 CASE RUNC PROD Run 5.5" casing to 5675' w/ full returns and no excess drag. 22:00 - 22:30 0.50 CASE CIRC PROD Break Circulation at 5675'. Pump 35 spm @ 450 psi. PU = 98K SO = 65K. Full returns. 22:30 - 00:00 1.50 CASE RUNC PROD Run 5.5" casing to 6895'. Full returns. 4/26/2004 00:00 - 00:30 0.50 CASE RUNC PROD RIH to 7313', Full returns. PU out of slips 70 to 75K, Slack off 60 -65 K. 00:30 - 00:45 0.25 CASE CIRC PROD Break circulation. PU = 130K. SO = 70 K. Pump at 10 spm w/280 psi. w/ full returns, MW = 10,8 ppg in and 10,9 ppg out. 00:45-01:15 0,50 CASE CIRC PROD P/U Landing Joint and hanger. Continue circulation stage to 1,2 BPM wI 500 psi and full returns. Wash to 1 ft above landing shoulder. No fill. Stop pump and land out on hanger at 7344. Confirm strap and P/U from hanger. 01:15-02:30 1.25 CASE CIRC PROD Resume pump and attempt to recriprocate, Hanger catching in stack. Circ and R/U tugger and center casing in stack. Pull hanger above floor and recriprocate while circulating. Max Gas from 3795' = 295 u. Continue circulating and stage up to 3.8 bpm at 480 psi. at bottoms up. Full returns and declining pump pressure on each stage up increment through out circulation. 02:30 - 04:15 1.75 CASE CIRC PROD Attempt to stage to 4.6 BPM and lost circulation at 500 psi. Slow pump to 0.5 bpm and P/U . No returns. Stop pump and flow chech. Well taking fluid. Work pipe wI PU = 140 K and SO = 70 K. Fill hole on back side and circ down casing at 1.5 BPM, Work casing. Partial returns on up stroke and no returns on down stroke, Establish continuous but partial circulation at 1.5 bpm and 350 psi. with 0.8 bpm lost. Reduced Printed: 5/21/2004 3:04:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: 4/26/2004 02:30 - 04:15 04:15 - 04:45 04:45 - 09:00 09:00 - 11 :00 11:00 -13:15 1.75 CASE 0.50 CASE CIRC CIRC PROD PROD 4.25 CASE CIRC PROD 2.00 CEMEN CIRC PROD 2.25 CEMEN PUMP PROD 13:15 - 14:30 1.25 CEMEN RURD PROD 14:30-16:15 1.75 CMPL TN NUND PROD 16:15 - 18:00 1,75 CMPL TN OTHR PROD 18:00 - 20:00 2.00 CMPL TN RURD PROD 20:00 - 20:15 0,25 CMPLTN SFTY PROD 20:15 - 22:00 1.75 CMPL TN RUNT PROD 22:00 - 22:45 0,75 CMPL TN OTHR PROD 22:45 - 00:00 1.25 CMPL TN RUNT PROD 4/27/2004 00:00 - 05:45 5.75 CMPL TN RUNT CMPL TN 05:45 - 07:30 1.75 CMPL TN SOHO CMPLTN 07:30 - 08:30 1.00 CMPL TN CIRC CMPL TN 08:30 - 09:30 1.00 CMPL TN SOHO CMPL TN 09:30 - 11 :00 1.50 CMPL TN DEQT CMPL TN 11 :00 - 11 :30 0.50 CMPL TN PULD CMPL TN 11 :30 - 12:00 0.50 CMPL TN OTHR CMPL TN 12:00 - 12:30 0.50 CMPL TN PULD CMPL TN 12:30 - 20:30 8.00 CMPL TN PULD CMPL TN 20:30 - 23:00 2.50 CMPL TN NUND CMPL TN pump to 1.0 bpm at 250 psi and regain full circulation. Pump 30 bbl LCM pill at 20 ppb concentration. MW = 10.8 ppg. Increase to 1.5 bpm w/ full returns. Continue displacing while recriorocating and building LCM in full system. Pump 1.5 bpm at 225 psi. Max gas 50 units. Continue circulating with full returns while mixing LCM and staging up rate. Max gas peak from 3795' = 412 u. at 05:45 due to initial loss and shut down of circulation. Stage to 2.0 BPM & 275 psi. w/ full returns. PU = 135K , SO = 75K. Increase to 3.0 bpm & 350 psi. w/ full returns. Final MW = 10.8 ppg & 11 ppb LCM. BGG 25 U. Run Hanger through stack and wash to bottom w/ no fill. Total mud loss was 120 bbl. Flow check well. BDTD & LD Fillup tool. MU Cement head and lines. PU off hanger. Circulate and recriprocate short strokes below stack. PJSM for cementing. Circulate at 3.0 bpm & 300 psi. Dump mud and batch mix cement while circulating. PU = 135K , SO = 75K, Turn over to Dowell. Pump 10 bbl CW100. Test lines to 3500. Pump 50 bbl CW100. Pump 30 bbl. Mud Push at 12.0 ppg, Pump 130.0 bbl (623 sxs) Gas Block cement with additives at 15,8 ppg. Pumped Spacers and cement at rate of 3 bpm at 500 to 190 psi. Drop wiper dart and displace with 148.6 bbl. sea water at rate of 5 bpm @ 400 to 1100 psi, slowed rate to 2 bpm @ 800 to 1100 psi (Observed Dart pass thru XO), Continue to displace to a total of 156.2 bbls and Bumped plug w/2000 psi (Had 700 psi lift pressure). CIP @ 13:10 hrs 4/26/04, Check floats OK. Had full returns throughout job. Recirocated pipe 5' until cmt just outside shoe, then pipe became tight. RD and off load cementing and casing equipment. LDLJ. Drain and clean stack. MU packoff tool. Run packoff, verify spaceout nad RILDS. Test PO to 5000 psi. 10 min. LD packoff tool. Service rig, crown and Top drive. Load Seal assembly and GLM into shed. Finish RU floor for tubing completion. PJSM with rig crew and Baker completion hand for tubing completion, Run seal assembly, D nipple, 2 GLM and 38 jts tubing, Repair leaking upper riser boot seal. Continue RIH w/3 1/2" tubing. Ran total 80 jts. Continue running 3-1/2" L-80 EUE8rd tubing a d completion jewelry to 6336.38' M/U circulating head and hose on Jt. #198. Circulate down to confirm seals stung into seal bore extension. P/U and confirm 16' seal stroke. UD 1 jt and r/u head pin. Circulate 290 bbl seawater @ 5 bpm-1500 psi. Space out and land hanger. RILDS and RIU to test tubing. Test tubing to 3500 psi on chart for 30 minutes. Bleed tubing pressure to 1500 psi. Test casing to 3500 psi for 30 minutes on chart. Bleed off tubing pressure and shear open DKV. UD landing jt. and install 2-way check, RIU hot oil and perform injectivity test on 9-5/8" x 5-1/2" annulus. Pump 160 bbl water in annulus followed by 85 bbl diesel for freeze protect. Pre floor to UD d.p, UD HWDP in mousehole UD 4" d.p. in mousehole and remove remaining 4" tools. UD mousehole and UD riser. N/D BOPE and secure on stump Printed: 5/21/2004 3:04:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-406 2P-406 ROT - DRILLING Doyon Drilling Inc Doyon 141 Start: 2/26/2004 Rig Release: 2/29/2004 Rig Number: Spud Date: 2/9/2004 End: 2/29/2004 Group: 4/27/2004 23:00 - 00:00 1.00 CMPL TN NUND CMPL TN Clean up hanger and change out lockdown screw 4/28/2004 00:00 - 02:00 2.00 CMPL TN NUND CMPL TN N/U CIW 3-1/2" x 5k Xmas tree 02:00 - 03:00 1.00 CMPL TN OTHR CMPL TN RlU and test tree to 250/5000 psi. Test hanger void to 5000 psi. Pull 2-way check. 03:00 - 04:30 1.50 CMPL TN FRZP CMPL TN RlU circulating line and pump 100 bbl diesel down annulus. 04:30 - 05:30 1.00 CMPL TN FRZP CMPL TN Allow diesel to u-tube into tubing 05:30 - 06:00 0,50 CMPL TN OTHR CMPL TN RID lines and set BPV. Printed: 5/21/2004 3:04:07 PM · . e 2P-406 Well Events Summary e Date Summary 05/08/04 TAG FILL@7115' WLM,PULL DCK SHEAR VALVE@6185WLM (6205'RKB),SET SPARTEK SPMG @ THE SAME DEPTH. PT TBG TO 3500 PSI,GOOD TEST. PT IA TO 3500 PSI GOOD TEST. IN-PROGRESSD [PT Tbg-Csg] 05/09/04 DRIFTED TBG TO 7074' WLM(7099') W/ 23'-7" OF 2.5" DUMMY GUNS. JOB COMPLETE [Perf] 05/09/04 TAG AT 7034' RKB - RUN SCMT LOG - GOOD CEMENT BOND (>80%) :TD TO 6988', 6922'-6664', & 6556'-6416' - FOUND CEMENT ALL THE WAY TO LINER TOP- PERFORATED 6922' TO 6942' USING 2.5" HSD GUN LOADED 6 SPF, 60 DEG .,/ PHASING WITH HYPERJET 2506 CHARGES, RDX - TOTAL PERFORATED 121 HOLES. 05/10/04 PUMP FRACTURE TREATMENT USING 30# X-LINKED GEL AT 30 BPM. PUMPED A TOTAL OF 200,216# OF 16/20 CERAMIC PROPPANT. SCREENED OUT WITH 10 PPA ON PERFS, PLACING 180,640# OF PROP BEHIND PIPE.D [Frac-Refrac] 05/11/04 CTU FCO POST FRAC FROM SURFACE TO TD (7189' CTM) USING 260 BBLS SLICK SEA WATER, 290 BBLS SLICK DIESEL, AND 70 BBLS GEL DIESEL - TAGGED AT 7189 CTM - MADE THREE PASSES FROM TD TO 6200' CTM. GOT BETTER THAN 1:1 RETURNS - POOH AND LEFT WELL SI. 05/12/04 WORKED THRU HYDRATE PLUG FROM 300'-400' PUMPING METHANOL & HOT DSL. TAGGED FILL @ 7106' RKB, EST. 164' RATHOLE.D [Tag, Hydrates-Ice] 05/13/04 SET 2.75" CAT SV @ 6270' RKB. PULLED SIDE POCKET GAUGE @ 6205' RKB. IN PROGRESS.D [Frac-Refrac] 05/14/04 PUMPED 130 BBL DSL DOWN IA TAKING RETURNS TO PRODUCTION @ 4.5 BPM. SET 5/16" OV @ 6205' RKB. PULLED 2.75" CAT SV @ 6270' RKB.D [Frac-Refrac] . . . eonoc6'Phillips ...... . ...... SURVEY LISTING Page 1 Well bore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 - - - r&ií. BAKER HUGHES INTEQ ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska Errors start at Slot Permanent Datum (2,30) Ellipses scaled to 2.58 standard deviations. Only Depth and Magnetic Reference Field error terms are correlated across tie points Wellbøre Name , 1 Created I Last Revised 406 12S-Feb-2004 I 28-ADr-2004 e Well Name 406 1 Government ID ISO-103-20484-00 I Last Revised 12S-Feb-2004 I I I Slot Name slot #406 Latitude Lon ¡tude North East N70 3.1 O.3J~~º-- Y115~~~~42.93~~__lfi~º,º~~____ 2403.61 E ______ 1".tâIIUlti;CJn Name Eastina Northina Coord Svstem Name North Alianment Drill Site 2P 441964,2388 5869891.4660 AK-4 on NORTH AMERICAN DATUM 1927 True datum e All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 9S.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated . .. eonoc6'Phillips .....'.' . ...... SURVEY LISTING Page 2 Well bore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska . . -. r&íí. BAKER HUGHES INTEQ 'P·iiejlfJ , Name Eastina Northina Coord Svstem Name I North AliQnment Meltwater 441964,2388 5869891.4660 AK-4 on NORTH AMERICAN DATUM 1927 I True I datum i '.~' by Tom Jones for Philip Hayden Doyon #141 Accepted: 26-Feb-04 TO surface hole: 28-Feb-04 Nordic III Accepted: 19-Apr-04 TO Well: 24-Apr-04 Spud Date: 27-Feb-04 Doyon #141 Released: 29-Feb-04 . _ Begin Drilling 8.5" hole: 20-Apr-04 Nordic III Released: 28-Apr-04 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated e e - -- eonocJPh¡lIips ------ ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska .. ----- SURVEY LISTING Page 3 Wellbore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 _, - - R: '&1. BAKER HUGHES INTEQ Wellpath (Ellil3se Semi-Axis) Report MD Inc Azi TVD North East Dogleg Vertical Ellipse Major Ellipse Minor Ellipse Ellipse [ft] [deg] [deg] [ft] [ft] [ft] [deg/100ft] Section[ft] Semi-Axis [ft] Semi-Axis [ft] Vertical Minor Azi. Semi-Axis rftl deal 2.30 0.00 0.00 2.30 O.OON O,OOE 0.00 0.00 0.00 0.00 2.96 N/A 110,30 0.00 0.00 110.30 O.OON O.OOE 0.00 0.00 0.31 0.31 2.96 N/A 213.52 0.22 70.43 213.52 0.07N 0.19E 0.21 0,18 0.34 0.34 2.97 __ N/A 303.66 0.46 85.42 303.66 0.15N 0.71E 0.28 0.69 0.52 0,52 2.97 N/A 392,99 1.03 102.59 392.98 0.01N 1.85E 0.68 1,84 0.71 0.70 2.97 N/A 485.91 3.24 116.03 485,83 1.33S 5.03E 2,42 5,14 0.96 0.95 2.97 N/A --~.~.- 574.81 7.88 118.08 574.29 5.30S 12.66E 5.22 13.16 1.31 1.26 2.96 121.26 ---~-- 665.43 10.83 119.38 663.69 12.40S 25.57E 3.26 26.75 1.85 1,55 2.94 120.26 755.37 10.99 119.15 752.01 20,72S 40.42E 0,18 42.41 2.47 1.80 2.95 120.53 846.94 10.69 119.44 841.94 29.15S 55.44E 0,33 58.25 2.59 1,56 2.96 118.94 937,34 11.59 117.23 930.64 37.43S 70.81E 1.10 74.43 3.27 1.82 -~ __119c~ 1028.57 13.21 110.35 1019.74 45.25S 88.74E 2.40 93.10 4.00 2,06 2.96 118.39 1127.62 15.42 106.01 1115.71 52.81S 112.01E 2.48 117.05 4.95 2.35 2.96 116.43 1219.85 17.66 101.57 1204.13 59.00S 137.51E 2,79 143.06 5.94 2,62 2.95 114.20 1313.12 19.51 97.85 1292.53 63.97S 166.80E 2.35 172.72 7.06 2,88 2.95 111.73 1405.97 21.86 97.56 1379.39 68.36S 199.30E 2.53 205.50 8.34 3.18 2.95 109,51 1497.96 25.23 97.72 1463.71 73.25S 235.71E 3.66 242.23 9.79 3.49 2.93 107.72 1591.07 28.47 98.01 1546.77 79.01 S 277.36E 3.48 284,26 11 .49 3.80 2.92 106,24 1683.50 31.78 97.54 1626.70 85.28S 323.32E 3,59 330.63 13.39 4.11 2.92 105,02 1776.27 34.94 97.10 1704.18 91.77S 373.91 E 3.42 381.63 15.51 4.41 2.94 103,95 1869.75 37.64 95.23 1779.52 97.68S 428.92E 3,12 436.94 17.80 4.69 2.98 102.91 1962.06 39.35 94.04 1851.77 102.31S 486.18E 2,02 494.37 20.18 4.95 3.07 101,90 2054.25 39.35 93.84 1923.06 106.33S 544.50E 0.14 552.78 22.24 5.04 3.15 101.07 e e All data is in Feet ùnless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean'sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ... Conocci'Phillips ....-. - ----- SURVEY LISTING Page 4 Wellbore: 406 Wellpath: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 _, _: ~. B.: r&~. BAKlR HUGHES INTEQ ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska Wetlpath (EUiI;>se Semi-Axis) Report MD Inc Azi TVD North East Dogleg Vertical Ellipse Major Ellipse Minor Ellipse Ellipse [ft] [deg] [deg] [ft] [ft] [ft] [deg/100ft] 8ection[ft] 8emi-Axis [ft] 8emi-Axis [ft] Vertical Minor Azi. 8emi-Axis [ft] [deg] 2147.40 40.55 95.88 1994.47 111,418 604.09E 1.91 612.57 24.63 5.24 3.23 100.47 2239.69 41 .49 95.90 2064.10 117.628 664.34E 1,02 673.14 27.26 5.49 3.37 100.04 2332.04 41.94 94.63 2133.04 123.26S 725.53E 1,04 734.59 29.70 5.67 3.51 99.61 2427.39 42.56 94.52 2203.62 128.378 789.43E 0,65 798.67 32.48 5,93 3.69 99.19 2519.67 41.78 94.84 2272.01 133.428 851.18E 0.88 860.60 34.47 5.87 3.72 98.88 2585.16 41.76 94.68 2320.85 137.048 894.65E 0.17 904.21 36.11 6.26 4.40 98.68 2756.68 42.98 96.57 2447.58 148.398 1009.67E 1.03 1019.78 38.79 6.31 4.45 98.47 2851.76 43.48 94.71 2516.86 154.798 1074.47E 1.44 1084.90 40.42 6,34 4.48 98.33 2945.39 42.98 94.08 2585.08 159.718 1138.41 E 0.71 1148,99 42.11 6,36 4.53 98.14 3040.73 41.66 95.83 2655.57 165.248 1202.36E 1,86 1213.16 43.90 6.38 4.61 97.99 3135.37 41.08 95.11 2726.59 171,208 1264.62E 0.79 1275,70 45.74 6.42 4.68 97.86 3230.21 40.61 94.99 2798.34 176.668 1326.41E 0,50 1337.72 47.64 6.47 4.76 97.73 3325.34 40.85 93.93 2870.43 181.498 1388.29E 0.77 1399,76 49.57 6.54 4.84 97.57 3419.83 41.13 93.67 2941.75 185.598 1450.13E 0.35 1461.69 51.54 6.61 4.91 97.40 3514.47 41.61 93.76 3012.78 189,658 1512.55E 0.51 1524.18 53.58 6.68 4.99 97.24 3608.60 41.67 93.90 3083.12 193.828 1574.95E 0,12 1586.67 55.65 6,76 5.08 97.10 3702.63 41 .49 94.08 3153.46 198,178 1637.21E 0.23 1649,03 57.74 6.83 5.18 96.97 3797.66 41.12 93.95 3224.85 202.568 1699.78E 0,40 1711.71 59.90 6.91 5.29 96.85 3892.11 40.75 95.02 3296.20 207.408 1761.47E 0.84 1773,56 62.04 7,00 5.40 96.76 3988.74 40.83 96.17 3369.36 213.558 1824.30E 0,78 1836.68 64.27 7.09 5.52 96.71 4081.94 40.56 95.61 3440.02 219.798 1884.74E 0.49 1897.45 66.42 7.18 5.63 96.67 4177.65 40.37 96.59 3512.84 226.398 1946.50E 0.69 1959.56 68.67 7.29 5.76 96.65 4272.04 40.72 95.05 3584.57 232.608 2007.54E 1.12 2020.92 70.86 7.39 5.88 96.61 -- --~ e e All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical 8ection is from O.OON a.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated 11_- Conoc;;:;hillips ------ -. ____1111 ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LISTING Page 5 Wellbore: 406 Wellpath: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 11& II, _~ '&1. BAKER HUGHES INTEQ Wellpath (Elli )se Semi-Axis) Report MD Inc Azi TVD North East Dogleg Vertical Ellipse Major Ellipse Minor Ellipse Ellipse [ft] [deg] [deg] [ft] [ft] [ft] [deg/100ft] Section[ft] Semi-Axis [ft] Semi-Axis [ft] Vertical Minor Azi. Semi-Axis rftl rdeQl 4366.32 40.29 95.49 3656.25 238.238 2068.52E 0.55 2082.14 73.11 7.50 6.02 96.56 4460.94 40.38 95.23 3728.38 243.958 2129.49E 0.20 2143,38 75.33 7.60 6.14 96.52 4555.59 40.54 95.97 3800.40 249.94S 2190.62E 0.53 2204.80 77.60 7.72 6.27 96.49 4650.04 40.73 96.07 3872.07 256.398 2251.79E 0.21 2266.31 79.86 7.84 6.40 96.47 4744.73 40.54 95.64 3943.93 262.69S 2313.13E 0.36 2327.97 82.15 7.95 6.54 96.45 4839.04 40.41 95.96 4015.67 268.878 2374.04E 0,26 2389.19 84.46 8.09 6.70 96.43 4933.88 40.39 97.06 4087.90 275.848 2435.11E 0,75 2450.65 86.80 8,22 6.85 96.44_ 5028.20 39.98 96.53 4159.95 283.048 2495.54E 0.57 2511.51 89.09 8,35 7.00 96.44 5123.29 39.63 97.58 4233.00 290.528 2555.95E 0.80 2572.37 91.42 8.50 7.17 96.47 5217.57 38.90 97.94 4306.00 298.578 2615.08E 0,81 2632.02 93.71 8,65 7.35 96.50 5313.14 38.53 96.24 4380.57 305.958 2674.39E 1,18 2691,78 95.95 8,78 7.50 96.51 ---~- 5407.08 40.45 95.89 4453.06 312,268 2733.79E 2,06 2751.52 98.18 8.92 7.62 96.50 5502.03 40.22 95.29 4525.44 318.258 2794.95E 0.48 2812.97 100,53 9.07 7.78 96.47 5596.78 40.50 - - 96.00 4597.64 324.288 2856.01 E 0,57 2874.33 102,87 9.22 7.94 96.46 "~._~_._--_._-~-_. 5690.98 41 .40 94.94 4668.79 330.168 2917.47E 1.21 2936,06 105.23 9.36 -_.~-_._- 8.09 96.43 5786.71 40.79 96.55 4740.93 336.468 2980.07E 1,28 2998,98 107.69 9,53 8.28 96.42 5880.89 41.57 96.23 4811.82 343,368 3041.70E 0,86 3060,99 110.07 9,68 8.43 96.42 5975.37 41.64 95.01 4882.47 349.508 3104.13E 0,86 3123.72 112,50 9,83 8.60 96.40 6069.76 42.38 93.79 4952.60 354.348 3167.11E 1,17 3186.85 114,95 10.00 8.77 96.35 6166.40 42.05 94.53 5024.18 359.058 3231.87E 0,62 3251.75 117,51 10.18 8,96 96.31 ' 6258.67 41.39 93.34 5093.05 363,278 3293.13E 1.12 3313,10 119.89 10.341 9.14 96.26 6354.46 40.64 93.79 5165.32 367,188 3355.87E 0.84 3375,90 122.34 10.52 9.34 96,21 ì 6449,62 41.21 95.06 5237.22 371,998 3418.02E 1.06 3438,20 124.76 10.70 --ª.5?_ ______ 96.1fu i All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated e e - -- y ConocoPhillips ------ ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska - .. ... ...~ - ~ -., SURVEY LISTING Page 6 Wellbore: 406 Wellpath: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 ~ Ia1 .. '&i. BAKER HUGHES INTEQ Well path (Ellh:>se Semi-Axis. Report I MD Inc Azi TVD North East Dogleg Vertical Ellipse Major Ellipse Minor Ellipse Ellipse [ft] [deg] [deg] [ft] [ft] [ft] [deg/100ft] Section[ft] Semi-Axis [ft] Semi-Axis [ft] Vertical Minor Azi. Semi-Axis fftl fdeQl 6542.90 41.47 94.39 5307.26 377.06S 3479.42E 0.55 3499,79 127,17 10.87 9,70 96.15 6638.40 41.53 94.19 5378.78 381.80S 3542.53E 0,15 3563,04 129,65 11.04 9.88 96.12 ~"~~- 6732.30 41.13 95.21 5449.30 386.88S 3604.33E 0,83 3625,03 132.10 11.22 10.08 96.10 6826.77 40.79 93.46 5520.64 391.56S 3666.07E 1.27 3686,92 134,52 11.41 10.27 96.06 6921.29 41.09 95.01 5592.04 396.13S 3727.83E 1.12 3748,81 136.95 11.59 10.46 96.04 7015.57 40.90 93.46 5663.20 400,70S 3789.51 E 1,10 3810,62 139.38 11.77 10.66 96.00 7109.08 40.24 93.18 5734.23 404,23S 3850.22E 0,73 3871,36 141.75 11.97 10.86 95.96 7205.17 39.37 93.26 5808.05 407,68S 3911.64E 0.91 3932.79 144.15 12.17 11.07 95.92 7259.62 38.96 92.94 5850.27 409,54S 3945.98E 0.84 3967.13 145.49 12.28 11,19 95.89 "~ 7350.00 38.96 92.94 5920.55 - 412.46S 4002.73E 0.00 4023.87 147.65 12.45 11,37 95.85 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96,19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated e e II II II Conoc6Phillips II II 11- II II III~ II II II II II·' _ II~ III _1In r4.. BAKER HUGHES INTEQ ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LISTING Page 7 Wellbore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 28-Apr-2004 Gomm-ents . MDrft1 TVDrft1 Northrftl Eastrftl Comment 2658.30 2375.19 141.39S 943.42E Proiected - NO SURVEY 7350.00 5920.55 412.46S 4002.73E Proiected Data - NO SURVEY Hole Sections Diameter Start in MD ft 12 1/4 81/2 e Start TVD ft 2.30 2658,30 Start End End MD ft TVD ft O.OOE 2658.30 2375.19 943.42E 7350.00 5920.55 End North ft 141.39S 412.46S Start Well bore East ft 943.42E 406 4002.73E 406 Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDrftl TVDrftl Northrftl Eastrftl MDrftl TVDrftl Northrftl Eastrftl 16" Conductor 2.30 2.30 O.OON O.OOE 110.30 110.30 O.OON O.OOE 406 9 5/8" Casino 2.30 2.30 O.OON O.OOE 2652.13 2370.63 140.99S 939.29E 406 5 1/2" x 3 1/2" 2.30 2.30 O,OON O.OOE 6333.40 5149.36 366.28S 3342.16E 406 XO 3 1/2" Casino 6333.98 5149.80 366.30S 3342.54E 7344.10 5915.96 412,27S 3999.03E 406 e Stuve Reference 652442 I 1 TVD ft 2585.16 Surve Tool 2320,85 ISCWSA MWD Error Model MWD+SAG - ISCWSA - 28 . Jan 03 OJH ____~I All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated Conoc~illips ConocoPhillips Alas~c.slot #406 Drill Site 2P Meltwater,North Slope, Alaska SURVEY LaG Page 1 Well bore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 7-May-2004 ,&¡. BAKER HUGHES INTEQ ¡-I ~ ':;,:'::-t;';;-;;~~ yL<SXt, ""l" <,(e;:.; :-.«>3 ":>;::':'/)'<L';;:;;{,'Ú' "_'~cc"c"""'" I~'~ -"~"T"~"", ·.'.::;I~-;1t:~~~:~t,iIi~t~1~¡Wl;~:~~:_:j -.':~'-\<?';':.-:'<;--:--:"::!-"':'-".";:';..", '-,' ',"; ,:::~:i~~í: "J1r~~~~::~~~ ;"'J'''?'::.;' »:>::"(,y.<''. "~'1 ';' "I", ~V:' <>::><;,/ Ai:0;'-:!JiM I Fiéld :ater I Easti · ~41964 2388 I North' 1:698914660 I~~~ 1---- I ,. ....f" · MERI~.;~~1~7:~DJ. All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated dJJ c..{ - 0;)",7- ConocJ'Pmllips . ConocoPhillips Alaska, Inc.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 2 Wellbore: 406 Wellpath: MWD wlSag <0-7350'> Date Printed: 7-May-2004 '&1. BAKER HUGHES INTEQ Well path lGrid\Report MD[ftJ I nc{ degJ Azi[degJ TVD[ftJ Station Station Dogleg Severit) Vertical Easting Northing Position(Y) Position(X) Sectionfftl 2~0 000 000 ? ~o OOON OOOF 0.00 0.00 444~6125 "'''''anA7 "'" 11n ':\0 000 0.00 110~0 OOON OOOF 000 000 444361.25 "'''''anA7 "'" 213.52 0.22 70.43 213.52 0.07N 0.19E 0.21 0.18 444361.44 5869047.30 ~m66 04R 854? ~o~ RR n15N 0.71E 0.28 0,69 444~6196 ",,,,,anA 7 "''' ,:\Q? QQ 1.m 102.59 ~9298 001N 1R5F 068 1.84 LlLlLl':\R':\ 10 ",,,,,anA 7 "" 485.91 3.24 116.03 485.83 1.33S 5.03E 2.42 5.14 444366.27 5869045.87 574.81 788 118.08 574 ?9 5~0~ 1? RRF 5 ?? 1~16 Ll.4Ll':\7':\ A7 ",,,,,anA 1 "A RR<;.4':\ 10 A':\ 119.38 663.69 1240S 25.57E 3.26 26.75 444386.72 "'A"an"'ilM 755.37 10.99 119.15 752.01 20.72S 40.42E 0.18 42.41 444401.51 5869026.21 ALlRQLl 10.69 119.44 841.94 29,15S 5544E O.~~ 58.25 44441647 "o"nn.7 "A 9~7 .::14 11 <;Q 117 ?':\ 930.64 37.43S 70.81 E 1.10 74.43 444431.78 ~n~^^^"I ?Q 1028.57 13.21 110.35 1019.74 45,25S 88.74E 2.40 93.10 444449.65 5869001.34 11 ?7.R? 1<; Ll? 106.01 1115.71 52,81S 112.01E 2.48 117.05 444472.86 ~n^n^^'\RO 1?1985 17.RR 10V,7 1204.13 59.00S 137.51E 2.79 143.06 444498.31 '.2~ 1313.12 19.51 97.85 1292.53 63.97S 166.80E 2.35 172.72 444527.56 5868982.05 1405 Q7 ?1 AR Q7 <;R 1379.39 68.36S 199.30E 2.53 205.50 Ll.4Ll<;RO O? '4? 149796 ?5?~ 977? 14R':\ 71 7':\?<;~ 235.71E 3.66 242.23 iliIiI¡:;QR Lln '?7 1591.07 28.47 98.01 1546.77 79.01S 277,36E 3.48 284.26 444638.00 5868966.20 1 R8~ 50 ~1 7A 97 5Ll 1R?R 70 85.28S 323.32E 3.59 330.63 444R8~ 91 IRn 177627 ::1494 9710 1704 18 Q1 77~ 373.91 E 3.42 381,63 LlLlLl7<tð. Ll¡:; '7'" 1869.75 37.64 95,23 1779.52 97.68S 428.92E 3.12 436.94 444789.40 5868946.43 19R? OR ~9 ':\<; 9404 18<;1 77 102.31S 486.18E 2.02 494.37 444ALlR R? "IA ?05Ll ?¡:; ~9~5 9~84 19?':\ OR 10R~~~ 5Ll4 <;OF 014 55278 Ll.4LlQM Qn : aA 2147.40 40.55 95.88 1994.47 111.41S 604.09E 1.91 612.57 444964.45 5868931.43 ??':\9R9 4149 9<;.90 ?ORLl10 117.62S 664.34E 1.02 673.14 445024,65 5868924.77 2332.04 41.94 946~ ?1':\':\ 04 1?':\?R~ 725.53E 1.04 734.59 445085..Z9 5868918.69 2427.39 42.56 94.52 2203.62 128.37S 789.43E 0.65 798.67 445149.65 5868913.11 2519R7 41.78 94 ALl ??7? 01 133.42S 851.18E 0.88 860.60 445211,35 5868907.61 ?<;A<; 16 4176 9468 ?':\?08<; 1':\7.043 894R<;F 0.17 904.21 .4Ll¡:;?5Ll 7Q 2756.68 42.98 96.57 2447.58 148.39S 1009.67E 1.03 1019,78 445369.71 5868891.48 285176 4~48 9471 ?<;1R 8R 15Ll 79~ In7 .7r:: 1.44 1084.90 iIiI <;LI. <tð. LlR ?Q.4<; ,:\Q Ll? QA 94.08 258508 1<;9.713 11~841F 071 1148.99 .4Ll<;LI.QA ':\<; 3040.73 41.66 95.83 2655,57 165.24S 1202.36E 1.86 1213.16 445562.25 5868873.23 ':\1':\<; ':\7 41.08 95.11 272659 17120S ."" ".,r::: 079 1275.70 IA"'''''A A" ,.,. ':\?':\O ?1 Lln R1 QLl QQ 2798.34 176.66S 0.50 1337.72 LlLl<;R8R ?O 3325.34 40.85 93.93 2870.43 181.49S 1388.29E 0.77 1399.76 445748.04 5868855.63 ::I41Q 8':\ Ll1 1 ':\ Q':\R7 2941.75 185.59S A~^ 'n~ 0.~5 1461.69 LlLl<;AOQ ALl "'A"AA"'" n7 ~51447 41 R1 9':\ 7R ':\01? 78 1 AQ R<;~ 0.51 1524.18 44<;87??? 3608.60 41,67 93,90 3083.12 193.82S 1574.95E 0.12 1586.67 445934.59 5868841,93 ~70? R':\ 41 LlQ 9408 3153.46 198.17S 1637.21E 0.23 1649.03 445996.80 1"1 3797.66 411? 9~.95 ':\??48<; ?O? 5R3 1699.78E 0.40 1711.71 446059.34 3892.11 40.75 95.02 3296.20 207.40S 1761.47E 0.84 1773.56 446120.99 5868826.99 ~98874 408':\ 9R.17 ':\':\RQ':\R 213.55S 1824.30E 0.78 1836.68 446183.76 4081.94 4056 9561 ::1440 O? ?19793 1884.74E 0.49 1897.45 446244 15 5868813.70 4177.65 40,37 96.59 3512.84 226.39S 1946.50E 0.69 1959.56 446305.86 5868806.65 427204 407? 9505 ':\<;ALl.<;7 ?':\? RO~ 1.12 2020.92 ."""" ", Ll':\RR ':\? 40.29 95.49 ~656?5 ?':\82~3 "n",., ".,r::: 0<;<; 208214 4460.94 40.38 95.23 3728.38 243.95S 2129.49E 0.20 2143.38 446488.70 5868787.76 Ll<;<;<; <;Q 405Ll 9597 ':\800 40 ?Ll994S 0.53 ??0480 "'''''''7''" "''' LlR<;O 04 LlO 7':\ 96.07 387207 ?5639S 725179F 0?1 2266.31 446610.89 ",.,",.,77. .., 4744.73 40.54 95.64 3943.93 262.69S 2313.13E 0.36 2327.97 446672.18 5868767.68 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips ConocoPhillips Alas!.c.,slot #406 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LI.G Page 3 Well bore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 7-May-2004 "". BAKER HUGHES INTEQ Well MD[ft] Easting Northing 5868721.78 5868702,13 5868664.62 5868650.32 5868634,08 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254.3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips ConocoPhillips Alas~c"slot #406 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LaG Page 4 Well bore: 406 Well path: MWD w/Sag <0-7350'> Date Printed: 7-May-2004 r&ii. BAKER HUGHES INTEQ Hole Sections Start MDft Wellbore Casin s Name All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic 3 RKB 254,3ft above mean sea level) Vertical Section is from O.OON O,OOE on azimuth 96.19 degrees Bottom hole distance is 4023.93 Feet on azimuth 95.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Meltwater! KRU/ 2P OS/23/05 Vancamp - HES o P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0= other (describe in notes) MIT Report Form Revised: 05/19/02 MITP KRU 2P-406 05-23-05.xls 6/6/2005 Re: 2P-406 Plan ahead e e Subject: Re: 2P-406 Plan ahead From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 23 Apr 2004 10:13:30 -0800 To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> dO ~ '-CJd) Thanks Philip. This is as we discussed. Please contact us if anything changes. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, With reference to our telephone conversation of this morning: Currently we are +/- 100 ft MD above the Cairn interval on this well, preparing to carryout a wiper trip. We have been experiencing some connection gas from +/- 3800 ft MD which has varied from 50 to 800 units. Mud weight through this section has been 10.6 to 10.8 ppg. As this gas does not seem to be exhibiting the same characteristics (i.e. pressure / aggressiveness) as that seen on some of the previous wells our goal remains to long string this well assuming our mud weight remains at a reasonable level. However, if we find that the required mud weight to control this connection gas is unacceptable for drilling the reservoir we will topset with a 7" casing string. In either case we would plan NOT to cover this connection gas interval with cement. We feel that to do so would not have a beneficial effect while leaving this interval uncemented will allow us to monitor pressure trends in the formations above the reservoir and still allow remedial action in the future if that becomes desirable. Please let me know if you require further information, Regards Philip 1 of 1 6/24/20048:10 AM Conoc~hillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com March 1, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval for temporary shutdown of operations on Meltwater producer 2P-406 Dear Sir / Madam ConocoPhillips Alaska, Inc. hereby applies for a Sundry approval to temporarily shutdown operations on Meltwater well 2P-406. The rig on this well, Doyon 141, is required for exploration and the current schedule does not allow for finishing 2P406 at this time. 2P-406 will be left with the surface pipe cemented and tested. A kill string will be hung off in the wellhead for freeze protect purposes and the x- mas tree installed. Please find attached for the review of the Commission Form 10-403. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, -"Î'~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ECEi o 1 2004 Ala:;(ka: ;¡ " /\'ir:hWf.¡Q' ORIGINAL e - --- STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ 1, Type of Request: Abandon D Suspend D Operational shutdown 0 Perforate D Variance D Annular Dispos.D Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Other D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4, Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 204-022 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20484-00 7. KB Elevation (ft): 9. Well Name and Number: 28' RKB, 252' AMSL 2P-406 8. Property Designation: 10. Field/Pools(s): ADL 373112 / L 32092 Kuparuk River Field / Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 2656 2373 2571 2310 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108 108 Surface 2622 9.625" 2650 2369 5750 3090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/28/2004 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Yes Date:2/22/2004 WAGD GINJD WINJ D WDSPL D Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact PhiliD Havden @ 265-6481 Printed Name R. Thomas Title Kuparuk Team Leader Signature ·K~~ Phone 265-6830 Date 3/do, , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .304 -¿J ~6 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D GEIV Other: \.-\() ~ \-0 \Q:~0 ~ O((~\C:\.\-\O ~~ ;v1AR 0 1 2004 S""0~~ ~t¿~ o\- '^"~ \. \ Ala:'!(ô .í(, Gas '!' Ap~"d . /J ~ BY ORDER OF Daœ 'ðlft~~ COMMISSIONER THE COMMISSION V '-""" ~ MMU 1006 . - . Form 10-403 Revised 2/2003 OR\G\NAL _afl SUBMIT IN DUPLICATE . . fl lL FRANK H. MURKOW5KI, GOVERNOR AlfASIiA OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 )(.. Kuparuk River Field 2P..4i'S' LI Dw ConocoPhillips (Alaska), Inc. Permit No: 204-022 Surface Location: 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM Bottomhole Location: 1257' FNL, 1116' FWL, Sec. 16, T8N, R7E, UM 333 W. ? AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. ~ase provide at least twenty-four (24) hours notice for a representative of the Commissio to" ess any required test. Contact the Commission's North Slope petroleum field inspect 6$9 3607 (pager). I Sl c relý ;1 BY ORDER.AF.. THE COMMISSION DATED thi~day of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConoccrPhillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com January 21, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Meltwater producer well 2P-406 Dear Sir / Madam ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill onshore production well 2P-406 in the Bermuda sands of the Meltwater oil pool. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for this well. The planned spud date for this well is 02/02/2004. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, .~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEIVED JAN 2 2 2004 Alaska Oil & Gas Cons. Commission Anchorage OR\G\NAL 1a. Type of Work: Drill 0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc, 3. Address: It . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 WGÆ " z. L/ 'U7t7 <I- ExploratoryU Development Oil ~ Multiple Zone D Service D Development Gas D Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 2P-406 6. Proposed Depth: 12. Field/Pool(s): MD: 7336'~· TVD: 5892' ' Kuparuk River Field 7. Property Designation: RedrillU 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 827' FNL, 2401' FWL, Sec. 17, T8N, R7E, UM ' Top of Productive Horizon: ¡4þ (., ..AI::f('373112 £þ 8. Land Use Permit: , 1229' FNL, 812' FWL, Sec. 16, T8N, R7E, UM Total Depth: 1257' FNL, 1116' FWL, Sec. 16, T8N, R7E, UM ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 444361' 16. Deviated wells: Kickoff depth: 400'- 18. Casing Program Size Hole 42" 12.25" 8,5" Casing 16" 9,625" 51/2" 3 1/2" 8.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): ADL 32092 g. Acres in Property: 5760 10. KB Elevation , y- 5869047 Zone- 4 (Height above GL): 252 feet Well within Pool: 2P-415 , 128 17. Anticipated Pressure (see 20 AAC 25.035) ft. Maximum Hole Angle: Max. Downhole Pressure: 2950 psig Setting Depth 41.18° Weight 62.5# 40# 15.5# 9.3# SDecifications Top Bottom Grade Coupling Length MD TVD MD TVD H-40 Weld 80 28 28 108 108 L-80 BTC 2632 28 28 2660 2373 L-80 BTCM 6300 28 28 6328 5133 L-80 EUE8RDM 1008 6328 5133 7336 5892 PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Meltwater Oil Pool 13. Approximate Spud Date: 2/2/2004 14. Distance to Nearest Property: 4023' @ TD 15. Distance to Nearest / Max. Surface Pressure: 2415 psig Quantity of Cement c. f, or sacks (including stage data) Artic Set I (preinstalled) 341 sx ASLite, 235 sx LiteCRETE tail 602 sx of GasBLOK ./ Included above /" (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Length Cement Volume Size MD Perforation Depth TVD (ft): None 20. Attachments: Filing Fee 0 Property Plat D BOP Sketch bJ Diverter Sketch D Drilling Program0 Seabed Report D None Time v. Depth Plot D Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature TVD Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 R. Thomas Contact Philip Hayden @ 265-6481 Title Kuparuk Team Leader Phone 4Ç-·68~o Date l(?.'(O « Preoared bv Phi/in havden \ ~ Commission Use Only :::~::~D~~_ð2.~ AP~:Î;3_ 2OV'8ý"'~ ::::itAPï?;~~tj ~Cí;~VED Conditions of approval: S~s ~equired D Yes ~No Mud log required ~yYefÄ'8Jó ~ 2004 n sulfide measures D Yes ~o Directional survey required ~,~ 1f~ ~ Alaska Oil & Gas Cons. Comm,ISSI'on Other: T~ (f- )?>tIk~- - -, ~ÇOO fsi ",¡ -elK'" "^ Anchor. ~/It/ /..--J /' BY ORDER OF APprOVedbY:! ../ COMMISSIONER THE COMMISSION Date: ð/ /3" ð Form1~F~003. '-' ORIGINAL IsubmLdUPI¿e -- A1I"" tion for Permit to Drill, Well 2P-406 Revision No.O Saved: 20-Jan-04 Permit It - Meltwater Well #2P-406 Application for Permit to Drill Document M()ximizE Well V'gIU~ Table of Contents 1. Well Name ..... ......... ........... ...... ............. ........ ....... ......... ............... .... ........ ....... ........... 2 Requirements of 20 AAC 25.005 (f)........ ........... ............. ..... .... ........................ ................ ....... ................2 2. Location Summary ..... ................... .......... ...... ........ ........ ....... ................ ...... .............. 2 Requirements of 20 MC 25.005(c)(2) ...... .... ..... ..... .......... ........................ .... ........... .................... .... ...... 2 Requirements of 20 AAC 25. 050(b )....... ............... ..................... .......... ..................... .............. ................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 MC 25.005(c)(3) .. ............. .......... ......... ......... ................ .......... ............... .......... ..... 3 4. Dri II i ng Hazards Information... ............. ...... ...... .......... ..................... ....... ........ ......... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 MC 25.005 (c)(5) .................................................................................................. 4 6. Casi n9 and Cementi ngProgram ........... .............. ................ ........ ......... ........ ........... 4 Requirements of 20 AAC 25.005(c)(6) ........... .......... ................. .......... .......... ........ ....... .......... ..... ........... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ... ............ ........ ........ ......................... ........ ......... ............. ....... ...... 4 8. Dri II i ng FI uid Program ............. .................... ...... ........... ............... ....... ......... ............ 5 Requirements of 20 AAC 25.005(c)(B) ......... .............. ........... ....... ......... ......... ..... ..... ..... ... ......... ....... ...... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Production Hole Mud Program (LSND) ... ....... ...... .......... ........ ..... ..... ................. ............. ........................ 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 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 Bonding ............................................................................................... 6 ORIGINAL 2P-406 PERMIT IT. doc Page 1 of 7 Printed: 20-Jan-04 · AW' tion for Permit to Drill, Well 2P-406 Revision No.O Saved: 20-Jan-04 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attach ments ....... .......... ........ ........ ......... ................... ..... ....... .............. ....... ............... 7 Attachment 1 Directional Plan (13 pages) ..............................................................................................7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 7 Attachment 4 Well Schematics (1 page) ................................................................................................ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040{b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2P-406. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface,. referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Dceanic and Atmo::.-pheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I NGS Coordinates Northings: 5,869,047 Eastings: 444,361 827' FNL 2401' FWL, Section 17 TSN, R7E, UM [ RKB Elevation I 252' AMSL [ Pad Elevation I 224' AMSL r' Location at Top of Productive Interval Bermuda Sand NGS Coordinates Northings: 5,868,619 1229' FNL, 812' FWL, Section 16, T8N, R7E, UM 6871 Eastings: 448,050 5 542 5290 Location at Total De NGS Coordinates Northings: 5,868,588 1257' FNL 1116' FWL Section 16 T8N R7E UM Measured De th RKB: 7 336 Eastings: 448,355 Total Vertical De th RKB: 5 892 Total Vertical De th 55: 5 640 and 2P-406 PERMIT IT. doc Page 2 of 7 Printed: 20-Jan-04 ORIGINAL - A¡:;¡...". . ation for Permit to Drill, Well 2P-406 . Revision No.O Saved: 20-Jan-04 (D) other infonT/ation required by 20 MC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated- the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the propos-ed well/ Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified mail,' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035; 20 MC 2S.03~ or 20 MC 25.03~ as applicable/ An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2P-406. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pemlit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application; (4) informatiof) on drilling hazard~ including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potená'al surface pressure based on a methane gradient; The expected reservoir pressures in the Bermuda sands in the 2P-406 area vary from 0.42 to 0.53 psi/ft, .,.., or 8.2 to 10.2 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 2415 psi, calculated as follows: MPSP =(5749 ft)(0.53 - 0.11 psi/ft) =2415 psi .~ (8) data on potential gas zones; Due to the presence of high annular pressures on some of the Meltwater wells (2P-431, 451 & 438) and the occurrence of gas in some of the wells drilled to date in the current program there is the risk of ...... encountering a pressured shallow zone. This interval may be encountered through the C-80 formation to the top of the Bermuda. The original high pressures recorded in these annuli were of concern but as can be seen from the following table a series of annular bleeds together with an observed natural decline in pressures have reduced the potential maximum pressure considerably: Ori inal C-80 Pressure 1751 1541 ...... Well Surface Pressure 1600 1380 Fluid Level 2387 2160 C-80 Equivalent Gradient 13.85 12.23 Surface Pressure 1200 750 Fluid Level 193 1392 Latest C-80 Pressure 1678 1020 4- 2P-431 2P-451 ORIGINAL 2P-406 PERMIT IT. doc Page 3 of 7 Printed: 2D-Jan-04 - AW. .' tion for Permit to Drill, Well 2P-406 Revision No,O Saved: 20-Jan-04 I 2P-438 I 879 I 895 I 1245 9.83 800 I 768 I 1216 9.60 Using the latest annular præss .. e available the highest pressure that would be expected is approximately 1678 psi at 2468 ft TVD or . ppg EMW. Most of the previously drilled Meltwater wells have had an FIT/LOT of approximately pg thus indicating that this pressured interval, should it exist, can be safely controlled with standard w control methods. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zon~ and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the applk.-ation: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(!); 2P-406 will be completed with 9 5/8" surface casing landed above the C-80 mudstone interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in tile application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner; pre- perforated liner, or screen to be install~' Casing and Cementing Program I See also Attachment 3: Cement Summary Hole / / Top 8tm Csgffbg Size Weight Length MDITVO MOITVO 00 (in) (in) (/b/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 Cemented to surface with 104 sx ArticSet I 9 5/8 12 % 40 L-80 BTC 2632 28 / 28 2660 / 2373 cemerrn to $!í'ifa/œ' with 34rSx ASLite Lead, 235 sx LiteCRETE Tail 5 Vz 8 Vz 15.5 L-80 BTCM 6300 28 / 28 6328 / 5133 Cement Top F@ 3 Vz 8 Vz 9.3 L-80 EUE8RD 1008 6328 / 5133 7336 / 5892 o MD/ Mod 08' TVD. Cemented w/ 602 sx GasBLOK 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commi!>-sion and identified in the application: ORIGINAL 2P-406 PERMIT IT. doc Page 4 of 7 Printed: 20-Jan-04 . AP.tion for Permit to Drill, Well 2P-406 Revision No.O . Saved: 20-Jan-04 (7) a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(11)(2); A 21 V4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling /' of 2P-406. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with tile commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25. 03~' Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 95/8" Casim Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.6 <9.2 <9.2* 10.5 Funnel Viscosity 250 250 150-200 55-65 (seconds) Yield Point 35-45 35-45 30- 35 12-15 (eP) pH 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate 6 6 4-6 4-6 (ee / 30 min)) Chlorides (mg/I) <600 <600 <600 <600 *9.6 ppg if hydrates are encountered' Production Hole Mud Program (LSND) 95/8" Casin Initial Value 9.6 22-28 9-9.5 4-6 <12 .:, 9-9.5 4 <12 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an Item already on file with the commission and Identified In the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f),· Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL 2P-406 PERMIT IT.doc Page 5 of 7 Printed: 20-Jan-04 . AP.tion for Permit to Drill, Well 2P-406 . Revision No.O Saved: 20-Jan-04 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(1O) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (iO) for an exploratory or stratigraphic test well, a seismic refradion or reflection analysis as required by 20 MC 25.06i(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (ii) for a well drilled from an offshore platform, mobile bottom-founded struCÚJre, jackcup rig, or floating dn/ling vessel, an analr.:-is of seabed conditions as required by 20 MC 25.06i(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Pemlit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test (conductor has already been installed and cemented). á/O 2. Spud and cljrectionally drill 12 V4" hole to casing point at 66 '!~D /2373' TVD as per directional plan. Run MWD tools as required for directional monitoring an . tools (GR & resistivity) as required for data acquisition. - 3. Run and cement 95/8",40# L-80, BTC casing to surface. Displace cement with mud. Perform top job if require~ \ 4. Re ove ~iverter system and install wellhead and test. Install and test 13 5/8" x 5,000 psi BOP's and test t 500<fþsi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. P ~'1.Í2" bit and 6 V4" drilling assembly, with MWD and LWD (GR, resistiv!tt.& neutron density). RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi.f6r 30 minutes and record results. 6. Drill out cement and 20' of new hole. Perform LOT or FIT to 18.0 ppg EM,. recording results. 7. Directionally drill to 5 V2" X 3 V2" casing point at 7336' MD /5892' TVD. 8. Run 5 1/2", 15.5# L-80, BTC Mod x 3 V2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and // displace with water and mud. Note that the cross over and seal bore extension for the completion will be positioned 200' MD above the Cairn interval, if present, as this is an interval that may be produced later in the life of the field. /" 9. Make up completion string as required and RIH to depth. Locate seaybore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 10. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV ORIGINAL 2P-406 PERMIT IT.doc Page 6 of 7 Printed: 20-Jan-04 e AW· ation for Permit to Drill, Well 2P-406 Revision No.O Saved: 20-Jan-04 11. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Carry out LOT and injection test on the outer annulus. Sweep the annulus with water and freeze protect. 12. Set BPV and move rig off. 13. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). Perforate well and rig down wire line unit. /"" 14. Carry out fracture stimulation. 15. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whetiler the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 2P Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2P Pad, hauled to the Prudhoe Bay'- Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. At the end of drilling operations, an application may be submitted to permit 2P-406 for annular disposal - of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 Directional Plan (13 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) ORIGINAL 2P-406 PERMIT IT.doc Page 7 of 7 Printed: 2D-Jan-04 200 200 0 :;0 0 - G) 200 - .......... +- Z Q) Q) '+- 400 » '--" .J: r- +- :J 600 0 (I) I 800 V 1000 1200j Created by bmlchoel Dote plotted: 15-Jon-2004 Plot Reference is 2P-406 Version f/3. : Coordinates ore in feet reference slot #406. i ¡True Vertical Depths ore reference RKB (Doyon 141).! I IIi. I i .... INTEQ -- o 200 400 600 {\OO I. ý..0'? ¡\(\ -:, (<'ol(OS ~è?~ S~ I ') Bose ~esl. "Ç' 0 E. oc.¡,ose 4.ê SURFACE LOCATION: 827' FNL, 2401' FWL SEC. 17, T8N, R7E ConocoPhillips Alaska, Inc. Structure: Drill Site 2P Field : Meltwater Well : 406 Location North Slope, Alaska ---- "---- ~/' ConocoPhillips 800 1000 1400 1600 East (feet) - > 1800 2000 2200 2400 2600 2800 3000 3200 1200 <:>¡'ò CS\" -49 C'òO ~ ,þO c",O c-:,1 95.28 AZ 96.19 AZIMUTH 3714' (TO TARGET) »>Plane of Proposal>" ~ TRUE -¡1 -:, I~ -¡. 00<;> D \ -¡",.'}; I. ,,,,. TARGET LOCATION: 1229' FNL, 812' FWL SEC. 16, T8N, R7E - 3400 3600 3800 4000 4200 4400 '/-.0 >\-¡\.,' \ I ~ Ò\(0ì ~(<'vèO vèoì C ""e ae({<' . o(\ì ,-¡ Ov e " ",'0\ :\~' \.,,05 0<;> r ?'l. -¡~O:-ì\C-:'D 0 cs~ C -¡I). 406 TD LOCATION: 1257' FNL, 1116' FWL SEC. 16, T8N, R7E e 0 350 700 1050 1400 1750 2100 ...--, +- Q) Q) 2450 4- '--/ ..r:: +- 2800 0... Q) 0 0 3150 Ü :¡:: L- Q) 3500 > Q) :::¡ 3850 L- ~ I V 4200 4550 4900 5250 5600 5950 6300 6650 350 - e ConocoPhillips Alaska, Inc. Structure: Drill Site 2P I RKB Elevation, 252' KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 It 8.00 BldjTrn 3/100 12.67 15.45 18.31 DLS: 3.00 deg per 100 It 21.20 24.12 Base Permafrost 27.05 30,00 32,95 35.91 38.88 mc Base West Sak 9 5/8 CSG C80 TANGENT ANGLE 41.18 DEG Well : 406 Field : Meltwater Location: North Slope, Alaska / 96.19 AZIMUTH 3714' (TO TARGE;'[') ***Plane of Proposal*** ~ !ConocoPhillips Created by bmÎchoel Dote plotted: 15-Jon-2004 Plot Reference is 2P-406 Version '3. Coordinates ore in feet reference slot #406. True Verticol Depths ore reterf!nce RKB (Doyon 1-41). ... .... INTEQ 5 1/2 X 3 1/2 XO T 4.2(T DP Coirm) T4.1 T3 :(Tqp Bermuda) TGT T2 (Bose Bermuda) owe e35 (Top Albion) TD, esg PI. o 700 -r 1050 1400 1750 2100 2450 2800 3150 3500 3850 421!)0 4550 4900 5250 350 Vertical Section (feet) -> Azimuth 96.19 with reference 0.00 N, 0.00 E from slot #406 ORIGINAL ConocoPhillips Alaska, Inc.! ...../ ConocoPhillips Created by Structure : Drill SIte 2P Well : 406 Dote plotted: 15-Jan-2Q04 Plot Reference is 2P-406 Version #3. Field: Meltwater Location : North Slope, Alaska I Coordínotes ore in feet reference slot #406. L- Vertical Depths ore reference RKB (Doyon .i. .... INTEQ r---- ------ -- ===~ PROF~LE COMMENT DATA ==== e ----- Point ----- MO Inc Oir TVO North East V. Sect Oeg/100 0 KOP 400.00 ~. 0.00 0.00 400,00 0,00 0,00 0,00 0.00 :::0 Bld/Trn 3/100 900,00 10.00 120.00 897.4 7 -21.76 37.69 39.82 2,00 - G> I Base Permafrost 1375,33 23.39 101.37 1352.00 -61,21 166.61 172.24 3.00 - EOC 1977.42 41,18 95,28 1859.08 -103.38 483,81 492.13 3,00 Z Base West Sak 2100.89 41.18 95.28 1952.00 -110,87 564.76 573.42 0,00 » 9 5/8 CSG 2660.27 41.18 95.28 2373.00 -144,79 931.53 941.70 0.00 r- C80 2786,50 41.18 95,28 2468.00 -152.45 1014,29 1024,81 0.00 C50 3545,18 41,18 95.28 3039.00 -198.46 1511.72 1524.31 0,00 C40 3921.20 41.18 95,28 3322.00 -221,26 1758.27 1771.87 0,00 C37 4157.71 41.18 95,28 3500.00 -235,60 1913.33 1927.58 0.00 e T7 5587,39 41.18 95.28 4576.00 -322..31 2850.71 2868.84 0,00 5 1/2 x ,3 1/2 XO 6328. Î 0 41.18 95.28 5133.48 -367.23 3336,37 3356.51 (LOa IT4.2(Top Cairn) 6528,1 ° 41.18 95,28 5284.00 -379,36 3467.50 3488.19 0.00 T4.1 6629,08 41.18 95,28 5360.00 -385.48 3533.71 3554.67 0,00 13 (Top Bermuda) TGT &;? 6870.90 41.18 95.28 5542.00 -400,15 3692.26 3713.88 0,00 T2 (Base Bermuda) 7145.94 41.18 95.28 5749.00 -416.83 3872.59 3894.96 0.00 OWC 7169,86 41.18 95,28 5767.00 -418,28 3888.27 3910.71 0.00 C35 (Top Albian) 7249.58 41.18 95,28 5827.00 -423,11 3940.54 3963.19 0.00 TO Cs Pt. 7335.94...... 41.18 95,28 5891.99 ' -428,35 3997.17 4020.05 0.00 Created by bmichoel Dote ploUed : 15-JQrI-20Q4 Plot Reference is 2P~4q6Ver.>:ìQf1. #?L Coordihotes are 10 foot reference· $lotll406c VertfÇ(1 Depths orer¢ference RK6 {Doyon INTEQ UE NO ~ c:::J 0 10 340 330 210 320 40 310 300 290 280 270 2 0 260 2 I 0 I I I I I I 12 I r 1500 ¡ , I II 220 210 200 160 190 180 Normal Plane Iling r F All de hs shown are Measu red dep 0 rence 40 80 120 ~ +- () () 160 '+- "-' ..s:: +- 200 :::;¡ 1300 0 Uì 240 260 320 380 400 440 ConocoP Crected by bm!chOel Date plotted ~ 15-Jor1-2004 Plot Reference is 2P-406 Version #3". Coordinates ore in feet reference slot #406. VertÎ¢(1 Depth9 are reference RKB (Doyon Locotion : North Slope, Structure: Drill Site 2P Field: Meltwater Well : 406 INTEQ East (feet) - > 120 120 440 160 80 40 o 40 80 200 240 280 320 360 400 40 o '- '" 900 --"0--2 00 ~,,--1200 - -. 1 300 - - -..J~O 1500 1600 ~- 1700 1800 1500 4300 \ " 1500 1700 700 ", 1800 " 1600 c. 480 520 -~~ö_ ~/' ConocoPhmips 560 680 800 720 760 600 640 1900 2000 2100 -0_ _ _ _ _ _ @ --.........- Created by Dote plotted, 15-Jon-20Q4 Plot Refereflce is 2P-4Q6 VerSion #3. Coordinates ore ¡n c. Structure: Drill Site 2P Field : Meltwater Well : 406 Location : North Slope, East (feet)·-> 400 600 800 1000 1200 1400 1600 1600 2000 2200 2400 2600 2800 3000 3200 3400 3600 1200 1000 800 ^ 600 I 400 200 o 4400 4606 4500 ~~f ConocoPhiUips 3800 4000 4200 4400 4600 5000 4800 e e ConocoPhillips Alaska, Inc. Drill Site 2P 406 slot #406 Meltwater North Slope, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License 2P-406 Version #3 prop4498 Date printed Date created Las t revised l5-Jan-2004 24-Feb-200l l2-Jan-2004 Field is centred on 44l964.235,586989l.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 lO.393,w150 26 42.932 Slot Grid coordinates are N 5869047.230, 'É 444361.250 Slot local coordinates are 826.02 S 2403.61 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,406 Your ref 2P-406 Version #3 Meltwater,North Slope, Alaska Last revised : 12-Jan-2004 Measured Inclin Azimuth True Vert R E CTANGULA R G RID COO R D S G E OGRAPHI C Depth Degrees Degrees Depth C 0 o R DIN ATE S Easting Northing C 0 o R D I N A T E S 0.00 0.00 0.00 0.00 O.OON O.OOE 444361.25 5869047.23 n70 3 10.39 w150 26 42.93 400.00 0.00 0.00 400.00 O.OON O.OOE 444361.25 5869047.23 n70 3 10.39 w150 26 42.93 - 500.00 2.00 120.00 499.98 0.87S 1. 51E 444362.75 5869046.35 n70 3 10.38 w150 26 42.89 600.00 4.00 120.00 599.84 3.49S 6.04E 444367.27 5869043.70 n70 3 10.36 w150 26 42.76 700.00 6.00 120.00 699.45 7.85S 13.59E 444374.78 5869039.28 n70 3 10.32 w150 26 42.54 800.00 8.00 120 . 00 798.70 13 .94S 24.14E 444385.29 5869033.11 n70 10.26 w150 26 42.24 900.00 10.00 120.00 897.47 21. 76S 37.69E 444398.77 5869025.18 n70 10.18 w150 26 41. 85 1000.00 12.67 112.94 995.51 30.38S 55.31E 444416.32 5869016.44 n70 10.09 w150 26 41. 34 1100.00 15.45 108.35 1092.51 38.85S 78.06E 444439.00 5869007.79 n70 10.01 w150 26 40.68 1200.00 18.31 105.14 1188.19 47.14S 105.87E 444466.74 5868999.29 n70 09.93 w150 26 39.88 1300.00 21.20 102.78 1282.30 55.24S 138.66E 444499.48 5868990.94 n70 09.85 w150 26 38.94 1375.33 23.39 101.37 1352.00 61.21S 166.61E 444527.38 5868984.76 n70 09.79 w150 26 38.13 1400.00 24.12 100.96 1374.58 63.135 176.36E 444537.11 5868982.76 n70 09.77 w150 26 37.85 1500.00 27.05 99.52 1464.76 70.78S 218.85E 444579.54 5868974.79 n70 09.70 w150 26 36.63 1600.00 30.00 98.34 1552.62 78.17S 266.02E 444626.64 5868967.05 n70 09.62 w150 26 35.27 1700.00 32.95 97.36 1637.89 85.28S 317.74E 444678.30 5868959.54 n70 3 09.55 w150 26 33.78 1800.00 35.91 96.51 1720.36 92.09S 373.87E 444734.37 5868952.30 n70 3 09.49 w150 26 32.16 1900.00 38.88 95.79 1799.80 98.58S 434.25E 444794,69 5868945.35 n70 3 09.42 w150 26 30.42 1977.42 41.18 95.28 1859.08 103.38S 483.81E 444844.21 5868940.18 n70 3 09.37 w150 26 29.00 2000.00 41.18 95.28 1876.07 104.75S 498.61E 444859.00 5868938.69 n70 3 09.36 w150 26 28.57 2100.89 41.18 95.28 1952.00 110.87S 564.76E 444925.10 5868932.07 n70 09.30 w150 26 26.66 2500.00 41.18 95.28 2252.38 135.075 826.44E 445186.56 5868905.88 n70 09.06 w150 26 19.13 2660.27 41.18 95.28 2373.00 144.79S 931. 53E 445291.56 5868895.36 n70 08.97 w150 26 16.10 2786.50 41.18 95.28 2468.00 152.45S 1014.29E 445374.25 5868887.07 n70 08.89 w150 26 13.72 3000.00 41.18 95.28 2628.69 165.39S 1154.27E 445514 .12 5868873.06 n70 08.76 w150 26 09.68 3500.00 41.18 95.28 3005.00 195.725 1482.10E 445841.67 5868840.24 n70 3 08.46 w150 26 00.24 3545.18 41.18 95.28 3039.00 198.465 1511.72E 445871.27 5868837.28 n70 3 08.43 w150 25 59.39 3921.20 41.18 95.28 3322.00 221.265 1758.27E 446117.61 5868812.60 n70 3 08.21 w150 25 52.29 4000.00 41.18 95.28 3381.30 226.04S 1809.93E 446169.23 5868807.43 n70 3 08.16 w150 25 50.80 4157.71 41. 18 95.28 3500.00 235.60S 1913.33E 446272.55 5868797.08 n70 3 08.07 w150 25 47.82 4500.00 41.18 95.28 3757.61 256.36S 2137.76E 446496.79 5868774.61 n70 3 07.86 w150 25 41.36 5000.00 41.18 95.28 4133.92 286.68S 2465.59E 446824.34 5868741.79 n70 3 07.56 w150 25 31. 91 5500.00 41.18 95.28 4510.23 317.01S 2793.42E 447151. 90 5868708.98 n70 3 07.26 w150 25 22.47 5587.39 41.18 95.28 4576.00 322.31S 2850.71E 447209.15 5868703.24 n70 3 07.21 w150 25 20.82 6000.00 41.18 95.28 4886.54 347.33S 3121. 25E 447479.46 5868676.16 n70 3 06.96 w150 25 13 .03 6328.10 41.18 95.28 5133.48 367.235 3336.37E 447694.40 5868654.63 n70 3 06.76 w150 25 06.83 6500.00 41.18 95.28 5262.85 377.655 3449.08E 447807.02 5868643.34 n70 3 06.66 w150 25 03.58 6528.10 41.18 95.28 5284.00 379.365 3467.50E 447825.42 5868641. 50 n70 3 06.64 w150 25 03.05 6629.08 41.18 95.28 5360.00 385.48S 3533.71E 447891. 58 5868634.87 n70 3 06.58 w150 25 01.15 6870.90 41.18 95.28 5542.00 400.155 3692.26E 448050.00 5868619.00 n70 3 06.44 w150 24 56.58 7000.00 41.18 95.28 5639.16 407.97S 3776.90E 448134.57 5868610.53 n70 06.36 w150 24 54.14 7145.94 41.18 95.28 5749.00 416.83S 3872.59E 448230.18 5868600.95 n70 06.27 w150 24 51.39 7169.86 41.18 95.28 5767.00 418.28S 3888.27E 448245.85 5868599.38 n70 06.26 wI50 24 50.93 7249.58 41.18 95.28 5827.00 423.11S 3940.54E 448298.08 5868594.15 n70 06.21 w150 24 49.43 , 7335.94 41.18 95.28 5891. 99 428.35S 3997.17E 448354.65 5868588.48 n70 06.16 w150 24 47.80 - All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #406 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 4020.05 on azimuth 96.12 degrees from wellhead. Total Dogleg for wellpath is 42.32 degrees. Vertical section is from wellhead on azimuth 96.19 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid ORIGINAL e e Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Drill Site 2P,406 Meltwater, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-406 Version #3 Last revised : 12-Jan-2004 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- - -- - - - - - - - - -- - - - -- - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - --- - - - - -- - - - - - - - - - - - - - - -- 400.00 400.00 O.OON O.OOE KOP 900.00 897.47 21. 76S 37.69E Bld/Trn 3/100 1375.33 1352.00 61. 21S 166.61E Base Permafrost 1977.42 1859.08 103.38S 483.81E Eoe 2100.89 1952.00 110.87S 564.76E Base West Sak 2660.27 2373.00 144.79S 931. 53E 9 5/8 eSG 2786.50 2468.00 152.45S 1014.29E e80 3545.18 3039.00 198.46S 1511.72E e50 3921.20 3322.00 221.26S 1758.27E e40 4157.71 3500.00 235.60S 1913.33E C37 5587.39 4576.00 322.31S 2850.71E T7 6328.10 5133.48 367.23S 3336.37E 5 1/2 x 3 1/2 XO 6528.10 5284.00 379.36S 3467.50E T4 .2 (Top Cairn) 6629.08 5360.00 385.48S 3533.71E T4.1 6870.90 5542.00 400.15S 3692.26E 2P-406 Top Berm Tgt Rvsd9Jan04 7145.94 5749.00 416.83S 3872.59E T2 (Base Bermuda) 7169.86 5767.00 418.28S 3888.27E owe 7249.58 5827.00 423.11S 3940.54E e35 (Top Albian) 7335.94 5891.99 428.35S 3997 .17E TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - --- - - - - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- 0.00 0.00 O.OON O.OOE 2660.27 2373.00 144.79S 931.53E 9 5/8 eSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Targe t name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 2P-406 Top Berm Tgt 448050.000,5868619.000,999.00 5542.00 400.15S 3692.26E 14-Aug-2003 ORIGINAL e e ConocoPhillips Alaska, Inc. Drill Site 2P 406 slot #406 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-406 version #3 prop4498 Date printed Date created Last revised 13-Jan-2004 24-Feb-2001 12-Jan-2004 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 10.393,w150 26 42.932 Slot Grid coordinates are N 5869047.230, E 444361.250 Slot local coordinates are 826.02 S 2403.61 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,406 Your ref 2P-406 Version #3 Meltwater , North Slope, Alaska Last revised : l2-Jan-2004 Measured Inclin. Azimuth True Vert R E C T AN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I NA T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 0.00 400.00 0.00 N 0.00 E 0.00 0.00 KOP 500.00 2.00 120.00 499.98 0.87 S 1. 51 E 2.00 1. 60 600.00 4,00 120.00 599.84 3.49 S 6.04 E 2.00 6.38 700.00 6.00 120.00 699.45 7.85 S 13 .59 E 2.00 14.36 800.00 8.00 120.00 798.70 13,94 S 24.14 E 2.00 25.51 900.00 10.00 120.00 897 .47 21. 76 S 37.69 E 2.00 39.82 Bld/Trn 31100 1000.00 12.67 112.94 995.51 30.38 S 55.31 E 3.00 58.26 1100.00 15.45 108.35 1092.51 38.85 S 78.06 E 3.00 81.79 1200.00 18.31 105.14 1188.19 47.14 S 105.87 E 3.00 110.33 1300.00 21. 20 102.78 1282.30 55.24 S 138.66 E 3.00 143.81 1375.33 23.39 101. 37 1352.00 61. 21 S 166.61 E 3.00 172.24 Base Permafrost 1400,00 24.12 100.96 1374.58 63.13 S 176.36 E 3.00 182.14 1500,00 27.05 99.52 1464.76 70,78 S 218.85 E 3.00 225.20 1600.00 30.00 98.34 1552.62 78,17 S 266.02 E 3.00 272.89 1700.00 32.95 97.36 1637.89 85.28 S 317.74 E 3.00 325,08 1800.00 35.91 96.51 1720.36 92.09 S 373.87 E 3.00 381. 61 1900.00 38.88 95.79 1799.80 98.58 S 434.25 E 3.00 442.34 1977.42 41.18 95.28 1859.08 103.38 S 483.81 E 3.00 492.13 EOC 2000,00 41.18 95.28 1876.07 104.75 S 498.61 E 0.00 507.00 2100.89 41.18 95.28 1952.00 110.87 S 564.76 E 0.00 573.42 Base West Sak 2500.00 41.18 95,28 2252.38 13 5.07 S 826,44 E 0.00 836,18 2660.27 41.18 95.28 2373.00 144.79 S 931. 53 E 0.00 941.70 9 5/8 CSG 2786.50 41.18 95.28 2468.00 152.45 S 1014.29 E 0.00 1024.81 C80 3000.00 41.18 95.28 2628.69 165.39 S 1154.27 E 0.00 1165.37 3500.00 41.18 95.28 3005.00 195.72 S 1482.10 E 0.00 1494.56 3545.18 41.18 95.28 3039.00 198.46 S 1511.72 E 0.00 1524.31 C50 3921. 20 41.18 95.28 3322.00 221. 26 S 1758.27 E 0.00 1771.87 C40 4000.00 41.18 95.28 3381,30 226.04 S 1809.93 E 0.00 1823.75 4157.71 41.18 95.28 3500.00 235.60 S 1913.33 E 0.00 1927.58 C37 4500.00 41.18 95.28 3757.61 256.36 S 2137.76 E 0.00 2152.94 5000.00 41. 18 95.28 4133.92 286.68 S 2465.59 E 0.00 2482.12 5500.00 41.18 95.28 4510.23 317.01 S 2793.42 E 0.00 2811.31 5587.39 41.18 95.28 4576,00 322.31 S 2850.71 E 0.00 2868,84 T7 6000.00 41.18 95.28 4886.54 347.33 S 3121. 25 E 0.00 3140.50 6328.10 41.18 95.28 5133.48 367.23 S 3336.37 E 0.00 3356.51 5 1/2 x 3 1/2 XO 6500.00 41.18 95.28 5262.85 377.65 S 3449.08 E 0.00 3469.69 6528.10 41.18 95.28 5284.00 379.36 S 3467.50 E 0.00 3488.19 T4.2(Top Cairn) 6629.08 41.18 95.28 5360.00 385.48 S 3533.71 E 0.00 3554.67 T4.1 6870.90 41.18 95.28 5542.00 400.15 S 3692.26 E 0.00 3713.88 2P-406 Top Berm Tgt Rvsd9Jan04 7000.00 41.18 95.28 5639.16 407.97 S 3776.90 E 0,00 3798.87 7145.94 41.18 95,28 5749.00 416.83 S 3872.59 E 0.00 3894.96 T2 (Base Bermuda) 7169.86 41.18 95.28 5767.00 418.28 S 3888.27 E 0.00 3910.71 OWC 7249.58 41.18 95.28 5827.00 423.11 S 3940.54 E 0.00 3963.19 C35 (Top Albian) 7335.94 41.18 95.28 5891.99 428.35 S 3997.17 E 0.00 4020.05 TD, Csg pt. All data is in feet unless otherwise stated. Coordinates from slot #406 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level), Bottom hole distance is 4020.05 on azimuth 96.12 degrees from wellhead. Total Dogleg for wellpath is 42.32 degrees, Vertical section is from wellhead on azimuth 96.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL e e ConocoPhillips Alaska, Inc. Drill Site 2P,406 Meltwater , North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-406 Version #3 Last revised : 12-Jan-2004 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 400,00 400.00 0.00 N 0,00 E KOP 900.00 897.47 21. 76 S 37.69 E Bld/Trn 31100 1375.33 1352.00 61.21 S 166.61 E Base Permafrost 1977.42 1859.08 103.38 S 483.81 E EOC 2100.89 1952.00 110.87 S 564.76 E Base West Sak 2660.27 2373.00 144.79 S 931. 53 E 9 5/8 CSG 2786.50 2468.00 152.45 S 1014.29 E C80 3545.18 3039.00 198.46 S 1511.72 E C50 3921.20 3322,00 221. 26 S 1758.27 E C40 4157.71 3500.00 235.60 S 1913.33 E C37 5587.39 4576.00 322.31 S 2850.71 E T7 6328.10 5133.48 367.23 S 3336,37 E 5 1/2 x 3 1/2 XO 6528.10 5284.00 379.36 S 3467.50 E T4.2(Top Cairn) 6629.08 5360.00 385.48 S 3533.71 E T4.1 6870.90 5542.00 400.15 S 3692.26 E 2P-406 Top Berm Tgt Rvsd9Jan04 7145.94 5749.00 416.83 S 3872.59 E T2 (Base Bermuda) 7169.86 5767.00 418.28 S 3888.27 E OWC 7249,58 5827.00 423.11 S 3940.54 E C35 (Top Albian) 7335.94 5891. 99 428.35 S 3997.17 E TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 2660.27 2373.00 144.79S 931.53E 9 5/8 CSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2P-406 Top Berm Tgt 448050.000,5868619.000,999.00 5542.00 400.15S 3692.26E 14-Aug-2003 ORiG\NAL :!ker Hughes IncorporateÞ Anticollision Report NO GLOBAL SCAN: Using nser defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 7335.94 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Pnilr1liCipal Plan & PLANNED PROGRAM ISCWSA Ellipse Trail Cylinder North EUiilPse Survey Program for Definitive Wellpath Date: 1/14/2004 Validated: No Planned From To Survey ft ft 0.00 7335.94 Planned: 2P-406 Vers#3 V7 Version: 3 Toolcode Tool Name MWD+SAG MWD + Sag correction Summary 2P Pad 414 2P-414 Vers#3a V1 Plan 472.06 475.00 160.84 8.89 151.95 Pass: Major Risk 2P Pad 415 2P-415 VO 1212.56 1250,00 128,31 29,85 98.46 Pass: Major Risk 2P Pad 415 2P-415A VO 1212.56 1250,00 128.31 29,85 98.46 Pass: Major Risk 2P Pad 416 2P-416 Version#O.A VO 637.92 650.00 202.23 11.1 (I) 191.13 Pass: Major Risk 2P Pad 417 2P-417 VO 470.92 475,00 217.92 8.45 209.48 Pass: Major Risk 2P Pad 419 2P-419 V3 Plan: Undefi 470.36 475.00 260.74 8.32 252.43 Pass: Major Risk 2P Pad 420 2P-420 VO 469.99 475.00 279.49 8.04 271.45 Pass: Major Risk 2P Pad 422 2P-422 V7 608.13 625.00 320,93 10.85 310.08 Pass: Major Risk 2P Pad 422 422A VO 608.13 625,00 320.93 10.85 310,08 Pass: Major Risk 2P Pad 424 2P-424 V5 445,70 450.00 360,83 7.62 353.22 Pass: Major Risk 2P Pad 424 2P-424A VO 445.70 450.00 360.83 7,62 353.22 Pass: Major Risk 2P Pad 427 2P-427 VO 445.13 450.00 420.25 7.54 412.71 Pass: Major Risk 2P Pad 429 2P-429 VO 511.98 525,00 458.39 9.1(1) 449.28 Pass: Major Risk 2P Pad 431 2P-431 V1 466.49 475.00 502.77 7.84 494.93 Pass: Major Risk 2P Pad 432 2P-432 V12 444.18 450.00 520,36 8.20 512.16 Pass: Major Risk 2P Pad 434 2P-434 V4 421.87 425.00 562.56 7.39 555.17 Pass: Major Risk 2P Pad 438 2P-438 VO 399,99 400,00 641.20 6,96 634.25 Pass: Major Risk 2P Pad 441 2P-441 VO 463.66 475.00 700.80 8.1(1) 692.70 Pass: Major Risk 2P Pad 445 2P-445 Vers#4 VO Plan: 420,87 425,00 780,30 7.92 i'72.38 Pass: Major Risk 2P Pad 447 2P-447 V6 399.98 400.00 822.95 6.90 816.05 Pass: Major Risk 2P Pad 448 2P-448 V2 399.99 400.00 841,78 7,16 834.62 Pass: Major Risk 2P Pad 448 2P-448A VO 399,99 400.00 841,78 7,16 834,62 Pass: Major Risk 2P Pad 448 2P-448PB1 VO 399.99 400.00 841.78 7,16 834.62 Pass: Major Risk 2P Pad 449 2P-449 Vers#6.b V1 Pia 374,99 375.00 860.83 6,82 854.01 Pass: Major Risk 2P Pad 451 2P-451 VO 325.00 325.00 900.56 5.50 895.07 Pass: Major Risk Meltwater North#1 MWN#1 MWN#1 VO Out of range Meltwater South #1 MWS#1 MWS#1 VO Out of range MWN#2 MWN#2 MWN#2 VO 5433,68 4650.00 717.52 200.5~ 517.00 Pass: Major Risk MWN#2 MWN#2 MWN#2A VO 5049.54 4675.00 368.05 201.21 166,84 Pass: Major Risk ORIGIN¡~L e e MEL TW A TER - DRILLING HAZARDS SUMMARY 12 IA" Open Hole & 9 5/8" Surface Casinf! Interval Event Risk level Mitigation Strategy I Contingency Broach of conductor Low Monitor cellar continuouslv durinQ interval Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weighVviscosity, Use weighted sweeps, monitor fill on connections Drill surface hole into shallow Low Do not exceed the surface hole TD as detailed pressured interval- C-80 in the individual well plans, ensure that all charged stands (in the derrick or in the hole) are accounted for at all times Hole swabbingffight hole on Moderate Circulate hole clean prior to trip, proper hole trips filling (use of trip sheets), pumping out of hole as needed Stuck surface casing Low Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip Stuck pipe Low Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever possible Lost circulation Low Keep hole clean. If losses occur - reduce pump rates and mud rheoloQv, use LCM 8 Iii' Open Hole & 5 Vi' x 3 Iii' Production Casinf! Interval Event Drill through a shallow pressured interval: C-80 to C-37 Insufficient or undetermined LOT Risk level Moderate Moderate High ECD / Tight hole on trips/ Swabbing Moderate Differential sticking Moderate Barite sa Lost circulation Low High ... Miti ation Strate I Contin enc Carry out well control drills. Kill fluid stored on location, contingency 7" casing string on location, hei htened awareness Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 MW e uivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets Keep hole clean, periodic wiper trips, keep pipe movin /rotatin with um s on whenever ossible Good drillin ractices as documented in well Ian Pretreat mud before drilling reservoir section, keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheolo ,use LCM OR1G1NAL Meltwater Drilling Hazards Summary Prepared by Philip Hayden 1/20/2004 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/19/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD < Base of Permafrost at 1,375 ft. MD (1,352 ft, TVD) < Top of Tail at 1,560ft, MD < 95/8",40,0#, L-80 grade BTC, AB Modified in 12 1/4" OH TO at 2,660 ft. MD (2,373 ft. TVD) Mark of Schlumberger Schl.blPg8P Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 225% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 185' below base of permafrost.) Lead Slurrv (minimum pump time 190 min.) ArcticSet III Lite @ 10.7 ppg, -4.28ft3/sk 3 0.7632 ft 1ft x (108') x 1.00 (no excess) = 3 0.3132 ft 1ft x (1375' -108') x 3.25 (225% excess) = 3 0.3132 ft 1ft x (1560' - 1375') x 1.45 (45% excess) = 82.4 ft3 + 1289.7 ft3+ 84 ft3 = 1456.1 ft3 / 4.~~~/sk = Round up t~ sks 82.4 ft3 1289.7 ft3 84 ft3 1456.1 ft3 340.2 sks Have 240 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv (minimum pump time 153 min.) LiteCRETE @ 12.0 ppg - 2.28 ft3/sk 3 0.3132 ft 1ft x (2660' -1560') x 1.45 (45% excess) = 0.4257 ft3fft x 80' JShoe Joint} = 499.6 ft3 + 34.1 ft = 533.7 ft3f2.2~"!SJ.3.1S = Round up t~SkS BHST = 58°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2SF/100 ft. below the permafrost) 499.6 ft3 34.1 ft3 533.7 ft3 234.1 sks PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 30 6.0 18.0 MudPUSH II 7 40 5.7 23.7 Drop bottom plug 4.0 27.7 ArcticSET Lite III 7 260 37.1 64.8 LiteCRETE 5 95 19.0 83.8 Drop plug 4.0 87.8 Water displace 5 20 4.0 91.8 Switch to rig 4.0 95.8 Displacement 7 160.6 22.9 118.7 Bump Plug 3 15 5.0 123.7 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-20, Ty ? 20-25 Centralizers: Recommend 1 per joint throughout tail slurry ORIGINAL Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/19/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2650£205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg, < 95/8",40,0#, L-80 grade BTC, AB Modified at 2,660 ft. MD < 5 1/2", 15.5#, L-80 grade BTC, AB Modified in 8 1/2" OH < Top of Tail at 6,028 ft. MD < X-over at 6,328 ft. MD < Top of Caim Fm, at 6,528 ft, MD < 3 1/2", 9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH TO at 7,336 ft. MD (5,892 ft. TVD) Mark of Schlumberger Icb blrgør Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above top of Cairn formation Tail Slurry (minimum thickening time 134 min.) GasBLOK w/ Class G + D600G, B155, D047, D065, per lab testing 3 @ 15.8 ppg, 1.17 ft /sk 0.2291 ft3/ft x 300' x 1.75 (75% excess) = 0.3272 ft31ft x (7336' - 6328') x 1.75 (75% excess) = 0.0488 ft3/ft x 120' (Shoe Joint) = 120.3 ft3 + 577.2 ft3 + 5.9 ft3 = 703.4 ft3/ 1.1'~,.ft~k = Round up t~ sks BHST = 146°F, Estimated BHCT = 124°F. (BHST calculated using a gradient of 2SF/100 ft. below the permafrost) 120.3 ft3 577.2 ft3 5.9 ft3 703.4 ft3 601.2 sks PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 30 6.0 18.0 MudPUSH II 5 40 8.0 26.0 GasBLOK Slurry 5 125 25 51.0 Drop Combo Plug 5.0 56.0 Displacement 5 143 28.6 84.6 Bump Plug 3 15 3.0 87.6 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv? 16-20, Ty? 30-34 Centralizers: Recommend 1- Yz per joint to 300' above proposed TOC. ORIGINAL Meltwater 2P-406 P.ucer Proposed Completion Schematic 3-1/2" Completion String 30" x 16" 62.6# @ +1- 108' MD (Insulated) Depths are based on Doyon 141 RKB Surface csg. 95/8" 40.0# L-80 BTC +1- 2660' MD I 2373' TVD 5 %" 15.5# L-80 BTCM x 3 %" 9.3# L-80 EUE8RD Mod crossover at +1- 6328' MD I 5133' TVD Future Perforations Production csg 5 %" 15.5# L-80 BTCM x 3 %" 9.3# L-80 EUE8RD Mod +1- 7336' MD I 5892' TVD c~dPh1Dj:ps 3 %" FMC Gen 5 Tubing Hanger, 3 %" L-80 EUE8RD Mod pin down 3 %" 9,3# L-80 EUE8RD Mod Spaceout Pups as Required 3 %" 9.3# L-80 EUE8RD Mod Tubing to Surface 3 %" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 3 %" 9.3# L-80 EUE8RD Mod tubing to landing nipple 4 x 3 %" x 1" Camco 'KBG-2-9' mandrels 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 %" x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 %" Baker 'CMU' sliding sleeve wI 2.813" Camco DS profile, EUE8RD Mod box x pin. 3 %" x 6' L-80 EUE8RD Mod handling pup installed above 3 %" Camco 'D' nipple wI 2.75" No-Go profile. 3 %" x 12' L-80 EUE8RD Mod spacaeout pup installed above, 3 %" x 6' handling pup installed below 3 %" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 %" L-80 EUE8RD Mod box up, 3 %" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 %" BTCM x 3 %" EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) ORIGINAL 01/20/2004 N KRU2 Pro Location SFD 1/22/2004 e e SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS 3760 PERENOSA ANCHORAGEAK 99515 1020. /" , r" DATE 2 ( J Æl¡ i/'¡2 1/-1 ?a4r4/311 , / PAYTOTHE ç rr/ì--c F/- ¡JJ ,-2r-tA !¡fCJ6cL $ ;' i<f~) /~V) ORDER OF ',I I I V V, rl t.-ri ':>~, '- l/, L-{.. ¡/) i I j ;" /, - / f / ~ ,- j / / / ,-;. , ",.1,:/ _",--é),//)/,; __DOLLARS D., ------ Vii£- (/...(>1.A-£'--r~ ' c¡-¿: l/t-¿;£rt; ~-" ~v L!J ~ CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars '-, 200WhllcCIayCent.,D",Now",<,.197" é" /1/1' / ..., __d~~= zii17:lt~ I: 0 3 . .00 . I., 1.,1: 2 .8 I., 7 . ~ 0 7 ~ 2 7 b II- ¡. 0 20 e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME KEU 2P~ ~Lb 2-D c.¡- 0 Z '2 PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. . (If API num ber Production should continue to be reported as last two (2) digits a function· of the original API number, stated are between 60-69) above. Pn.,OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be dearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ,to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception that may occur. DRY DITCH AU dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/]0/02 C\jody\templates Field & Pool KUPARUK RIVER, MELTWATER OIL - 490140 Well Name: KUPARUK RIV U MELT 2P-406 Program DEV Well bore seg 0 PTD#: 2040220 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 0 Administration 1 Permittee attaçhe~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 lease_numberappropri<lte_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _UÐique well_n_ame_and ol.!.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WellJoc<lted inadefine~_ppo'- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WelUoC<lted proper _distance_ from driJling unitb9und~ry _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJoc<lted pr_operdistance_ from otber wells _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_uffiçientaçrea~e_aYail~ble indJilliog unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YeL _ _ _ _ _ _ Spa_cing within the pooJls_1D ~cre~. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jtdeviated, js weJlbore platincJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _Qperator only affeçted party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Operator bas_apprppriate_Qond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit can be iSSl.!.ed wjtbout coÐservaJion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Permit c_an be iSSl.!.ed wJtbout ad_mini~tratÍ\leapprpvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ SFD 1/22/2004 13 Can permit be approved before 15-daywait Yes 14 WeJUoc<lted within area al1d_strat¡uuthorized byJojectipl) Order # (putlO# in_cpmments) (For_ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 _AJI weIJs_withinJI4_l1Jite_area_of reyiew id_entlfied (Fpr~ervjc_eweU onlYL - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e 16 PJe-produ_ced injector; ~ur~tio_n_of pre-pro~uctipl) less_ than 3 montbs (For_service well onJy) _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _AÇMPFïndjng9fConsi$tencyhasbee_nJ~sued_fprJbisproieçt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _Welldrllledfromexjstingpa_dc _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Engineering Appr Date WGA 1/22/2004 Geology Appr SFD Date 1/22/2004 Geologic Commissioner: ovs 18 _C_onductor ~tril1g_PJovided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19S_urfaceca~ing_pJotect~ allkJlown USDW~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ No USDWc _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_otadeQu_ateJoçircutate_o_n_conductor&suJtq;g _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _,A.de.quateexce~s, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 21 _CMTvptadeQu_ateJotie-inJong_stringto_surfcsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyeraJl !<I)own-Pfo_ductiye borizon_s_ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asing design~ ad_equa_te fpr C,T, B_&_perl1Jafrpst _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24Mequ~teJankage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ DoypnHt. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Jta_ re-prill. has_ a_ to,403 for ~bandol1meÐt been apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ New well. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 A~equ.ateweUbore ~epar<ltjo_npropo~e~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdivecter JeCl-uired, does itmeet reguJa_tions _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 DJillil)gfJuid_pro~ramsGhematic_&eCl-uipJistadequ<lte_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _MaxMWJD]_ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 29 _B_OPEs,_dp_they meetreguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BOPEpress rating appropriate; _test to_(pu_t p~ig in_comments) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Test to _35QO_ psi min, MSP _2415. psi. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31C_hoke_l1Janifold compJie~ w/APt RF'-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work wiU occur withputoperatjoJl_shutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 J~ pre~ence of H2S gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Meçha_nlcaLcondJtion pf wells within ,A.OR yerified (for_s_ervjce well ol1lYL _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - e - - - - - - - - - - - - .. - - - - 35 Permit c_an be ISSl.!.ed wlo_ hydrogen_ s_ulfide meaSjJres _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 _D_ata_ PJesented on_ pote_ntial pveJpressure _ZOnes _ _ _ _ _ _ _ _ _ _ _ _ 37Seismic_aJlalysjs_ of shaJlow gas_zpnes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38 _SeabepcOnditipo survey (if off-~hpre) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Conta_ct namelphOl1eJorJI\'eekly prpgre~ueports [exploratpry _onlYI- _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Expected pre~sureJange~ from 8,2,10,2 ppg_EMW. Willbedrille_dwjth :lQ.7 pp~ mud. _ _ _ _ _ _ _ _ _ - _ _ _ NA _ _ _ _ _ _ _ ShaJlow pre~sjJrezPl)es_eJlco_u[1tered .at Meltw.ater ha_ve bee_n_res_trjcte~ _to the we~ter[1 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ portjoJlof the pad~ welt wiIJ be driJIed_ from the east side of _th_e_p_ad._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Date: Engineering Commissioner: Date Public Commissioner Date J)¿b/1- e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding information, infonnation of this nature is accumulated at the end of the fìle under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. e **** REEL HEADER **** LDWG 04/05/28 AWS 01 **** TAPE HEADER **** LDWG 04/05/28 01 *** LIS COMMENT RECORD *** e :¡j ~ö\,il- ð)J.... ) À ~ '-c ~ !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! !! !! ! ! !! ! ! ! ! !! !! !! Extract File: LISTAPE.HED TAPE HEADER MELTWATER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 2 G. SUTING S. LEWIS # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 2P-406 501032048400 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 28-MAY-04 MWD RUN MWD RUN 17 8N 7E 254.20 224.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 # REMARKS: 16.000 9.625 110.0 2650.0 7350.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 03' 10.39" LONG: W150 DEG 26' 42.93" LOG MEASURED FROM D.F. AT 254.2 FT. ABOVE PERM. DATUM (M.S.L. ) COMMENTS: (1) Baker Hughes INTEQ run 1 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with Drill Collar Pressure (DCP) and MPR Resistivity services from 2658 - 7350 feet MD (2375 - 5921 TVD). (2) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Depth of 9 5/8" Casing Shoe - Logger: 2655 feet MD (2373 TVD) Depth of 9 5/8" Casing Shoe - Driller: 2651 feet MD (2369 TVD) (2) The interval from 7303 to 7350 feet MD (5884 - 5921 TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 70 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 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2650.0 STOP DEPTH 7350.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE e e PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 2650.0 MERGE BASE 7350.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-406_5.xtf 150 ConocoPhillips Alaska 2P-406 Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 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 ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 48 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 21 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth 10: F 11 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 e 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 ------- 44 Total Data Records: 448 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2650.000000 7350.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 493 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 e log header data for each bit run in separate files. 2 .2500 START DEPTH 2600.0 STOP DEPTH 7350.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 24-APR-04 MSB 18704 6.75 TC MEMORY 7350.0 2600.0 7303.0 o 38.5 43.5 TOOL NUMBER DIR CCN ORD MPR GRAM $ # e DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # e 99030 CCN 6003 ORD 51687 MPR 67280 SRIG 5078 8.500 2650.0 LSND 10.65 .0 .0 400 .0 .000 .000 .000 .000 142.0 .0 .0 .0 Sandstone .00 .000 .0 o BIT RUN 2 (MWD Run 2). GR/MPR/ORD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (GICC) DRHM - DENSITY CORRECTION (GICC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN 2p-406.xtf LCC 150 CN ConocoPhillips Alaska WN 2P-406 e e FN Meltwater Unit COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 64 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 15 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 15 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 MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 ------- 60 Total Data Records: 1267 I .. e -- Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2600.000000 7350.000000 0.250000 feet **** FILE TRAILER **** Tape S~bfile: 3 1375 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/05/28 01 **** REEL TRAILER **** LDWG 04/05/28 AWS 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes