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Home My WebLink About204-0091. 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): 11539' 2640' 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 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2978' 10655-11020' (below cement plug) 11505' 5574-5698' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 3006' 5870'11530' 16" 9-5/8" 80' 10407' MD 108' 2386' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A 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-424A 5873' 28' 28' 575',1898', 2369', 2620', 3069', 8895', 10599', 10629' 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: le: Leslie Manning certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ame and ure with Date:Leslie.Manning@conocophillips.com (907) 263-3731 Senior CTD/RW O Engineer 15. Well Status after proposed work: OIL WINJ WDSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval:Date: esentative: Date for Operations:12/31/2025 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSSV Type:Packers and SSSV MD (ft) and TVD (ft):Packer: Baker 80-40 Seal Assembly SSSV:None 10404' MD and 5487' TVD N/A 10407' Tubing MD (ft): L-80 Tubing Grade: 3-1/2" Tubing Size: 5574-5698' (below cement plug) Perforation Depth TVD (ft):epth MD (ft): (below cement 5870'11530'5-1/2" x 3-1/2"11505'on ate 2386'3006'9-5/8"2978'e 108'108'16"80'or al CollapseBurstTVDMDSizeLengthg Junk (MD): 2640' Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):D (ft): 5873'28'28'575',1898', 2369', 2620', 3069', 8895', 10599', 10629' PRESENT WELL CONDITION SUMMARY 10. Field:Proposed Pools: Meltwater Oil Pool - SuspendedKuparuk River Field Meltwater Oil Pool - Suspended Current Pools:esignation (Lease Number): ADL0373112, ADL0389058 8. Well Name and Number:g: ation or Conservation Order governs well spacing in this pool? Yes Noquire a spacing exception due to property boundaries? KRU 2P-424AN/A 5.Permit to Drill Number: 6. API Number: 204-009 50-103-20475-01-00 4.Current W ell Class: Exploratory Development Stratigraphic Service 360, Anchorage, AK 99510 ame: s Alaska, Inc. 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 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-013 By Grace Christianson at 10:24 am, Jan 09, 2026 VTL 1/21/26 DSR-1/22/26 10-407 X March 1, 2026 SFD 1/22/2026JLC 1/22/2026 01/22/26 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska January 7, 2026 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached, the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Well KRU 2P-424A (PTD# 204-009). This 10-403 is being submitted to request an extension of the Suspension Expiration Date to March 1, 2026. If you have any questions, please contact me at (907) 263-3731. Sincerely, Leslie Manning Senior CTD/RWO Engineer Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Miled out cement in kill string. 2P-424A 11/2/2025 famaj 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 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC Kill String 5 1/2 4.95 28.0 560.0 559.0 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 3,060.0 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,290.0 Set Depth 10,407.0 Set Depth 5,487.8 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 575.0 573.9 9.58 CIBP K1 CIBP Baker 12/4/2025 0.000 2,640.0 2,216.5 61.85 FISH 33' <*}}}< IN HOLE CTU BHA # 34 (MILL/UR IN 9 5/8" CASING) QUADC O 8/12/2025 0.000 3,060.0 2,412.0 61.83 CUT MSC on rig. 2/3/2025 4.950 3,069.0 2,416.3 61.78 CIBP YJ CIPB 2/3/2025 0.000 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 2P-424A, 1/7/2026 3:44:26 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 Cement Casing; 10,100.0 ftKB APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 Kick-Off Plug; 6,569.0 ftKB GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug Plug Back / Abandonment Plug; 2,620.0 ftKB Cement Plug; 2,369.0 ftKB Cement Plug; 1,889.0 ftKB Cement Casing; 35.0 ftKB CIBP; 575.0 Kill String; 28.0-560.0 CONDUCTOR; 28.2-108.0 Plug & Abandonment; 28.0 ftKB KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 3,005.0 35.0 2,386.2 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 108Drag up (lbs): 125Time started reciprocating: 04:30Time stopped reciprocating: 12:25Annular flow after cement job (Y/N): NCirculating BHT (F): 74Static BHT (F): 58Pressure before cementing (psi): 200Hours circulated between stages: 24Bbls cmt to surf: 231.0Method used to measure density: DensometerMethod used for mixing cement in this stage: TubReturns (pct): FullTime cementing mixing started: 11:50 12/30/2003 8,326.0 10,548.0 4,767.5 5,537.1 Abandonment Plug Cement Found Between Shoe and Collar (Y/N): NCement found on liner tool (Y/N): NPressure before cementing (psi): 1850Hours circulated between stages: 4Bbls cmt to surf: -0- See RemarksMethod used to measure density: DensometerMethod used for mixing cement in this stage: BatchPill below the plug (Y/N): NPlug catcher used? (Y/N): NReturns (pct): 100Tail pipe used (Y/N): YPerforated tail pipe (Y/N): NTail pipe nominal size (in): 3.5 1/9/2004 6,569.0 7,096.0 4,052.5 4,312.6 Kick-Off Plug Pressure before cementing (psi): 1850Hours circulated between stages: 4Bbls cmt to surf: 0Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchPill below the plug (Y/N): NPlug catcher used? (Y/N): NReturns (pct): 100Tail pipe used (Y/N): YTime cementing mixing started: 04:30Perforated tail pipe (Y/N): NTail pipe nominal size (in): 3.5 1/10/2004 10,100.0 11,530.0 5,380.2 5,870.4 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 72Drag up (lbs): 185000Time started reciprocating: 04:45Time stopped reciprocating: 12:00Cement Found Between Shoe and Collar (Y/N): NCement found on liner tool (Y/N): NAnnular flow after cement job (Y/N): NPressure before cementing (psi): 600Hours circulated between stages: 5Bbls cmt to surf: 0Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchReturns (pct): 100Time cementing mixing started: 08:00 1/17/2004 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 8,895.0 10,333.0 4,960.4 5,461.9 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT FOR BALANCED CEMENT PLUG 10/18/2024 2,444.0 3,069.0 2,120.5 2,416.3 Plug Plug Back / Abandonment Plug HES pump 18.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 150 PSI. Drop wiper ball. Pump 150 Bbls of 15.8 PPG PTA cement @ 2.5 BPM, 200 PSI. Drop wiper ball. Pump 9.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 120 PSI. Displace w/ 20 Bbls of 9.8 PPG brine @ 2.5 BPM, 120 PSI. POOH T/ 2469'. Circ out 60 Bbls cement to surface above target depth MILL/UR CEMENT WITH CTU 4 TO 2620', 5/25/25 2/4/2025 2,369.0 2,640.0 2,080.4 2,216.5 Cement Plug Pumped 23.7 bbls of 15.8 ppg Premium cement w/ IsoGuard & MicroBond 10/7/2025 1,898.0 2,369.0 1,770.3 2,080.4 Cement Plug HES pump 10 Bbls of fresh water @ 2.5 BPM, 185 PSI. Pump 38 Bbls of 16.0 PPG PTA cement @ 2.5 BPM, 370 PSI. Pump 1.2 Bbls of fresh water @ 2.5 BPM, 146 PSI. Displace w/ 10.5 Bbls of seawater @ 2.5 BPM, 130 PSI. POOH T/ 1550'. Circ well clean. Tag witnessed by AOGCC rep Josh Hunt. 12/2/2025 28.0 575.0 28.0 573.9 Plug & Abandonment PJSM with HES cement crew, pump cement per program: Pump 30 BBLS of Fresh Water Spacer with surfwash ( .5 gal/bbl each of Musol and Dual B ) Mix 1st tub of cement. Cement Wet Time 15:18 12/4/25 . Grab 2 cup samples (one @ room temp / one in refrigerator). Pump 56 BBL of 15.8# Cement. Close wing valves on IA and OA Flush lines to open top tank ICP= 3bpm @ 80 psi FCP= 3 bpm @ 260 psi Cement in place 16:00 on 12/4/25 Wash up lines to cuttings tank blow down lines 12/4/2025 2P-424A, 1/7/2026 3:44:26 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 Cement Casing; 10,100.0 ftKB APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 Kick-Off Plug; 6,569.0 ftKB GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug Plug Back / Abandonment Plug; 2,620.0 ftKB Cement Plug; 2,369.0 ftKB Cement Plug; 1,889.0 ftKB Cement Casing; 35.0 ftKB CIBP; 575.0 Kill String; 28.0-560.0 CONDUCTOR; 28.2-108.0 Plug & Abandonment; 28.0 ftKB KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A Current Status of the KRU 2P Pad Plug and Abandon Campaign As of 01/13/2026 2P-422A 01/07/2026: Pulled shore can. Will request Final site clearance with 2P-424A and 2P-429. 2P-424A 01/10/2026: Pulled cellar box 01/09/2026: Wellhead cut and removed. Excavation is on hold due to weather conditions. 2P-429 01/11/2026: Pulled cellar box 01/10/2026: Wellhead cut and removed. Excavation is on hold due to weather conditions. 2P-406 Cemented to Surface 01/13/2026: Continue to monitor well pressures per AOGCC request. A new 10-403 will be submitted prior to any further intervention. (Reference Extension Request for further details.) 2P-447 Cemented to Surface 12/31/2025: 30 day pressure monitoring per AOGCC request. Surface Excavation procedures will begin once monitoring is complete. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Manning, Leslie To:Roby, David S (OGC); Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Hobbs, Greg S Subject:RE: [EXTERNAL]RE: DS 2P Suspension Extensions Date:Wednesday, January 21, 2026 9:52:02 AM Some people who received this message don't often get email from leslie.manning@conocophillips.com. Learn why this is important Dave - ConocoPhillips aimed to complete the abandonment of all remaining 2P wells by December 31, 2025, and as of the check in meeting on December 11, 2025, we were striving to meet that goal. However, due to weather conditions and operational delays encountered in late December, full abandonment could not be completed prior to the expiration of the wells suspension status. Following December 31, 2025, we evaluated the status of all remaining 2P wells and contacted the AOGCC to determine appropriate next steps for the work scope. Based on their guidance, we proceeded with submitting suspension extension requests for each well. Regards, Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Friday, January 16, 2026 3:45 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Manning, Leslie <Leslie.Manning@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL]RE: DS 2P Suspension Extensions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Leslie, Please also provide an explanation for why the suspension renewal requests were not submitted until after the suspensions had expired. Thank you, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 _____________________________________________ From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, January 12, 2026 8:35 AM To: Manning, Leslie <leslie.manning@conocophillips.com> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: DS 2P Suspension Extensions Could you please include the work remaining to be completed and the current status of the P&A. Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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-PrivateT41163T41164T41165T41166T41167A2P-50-103-20475-01-00 204-009Kuparuk RiverWLSCMTFINAL FIELD6-Nov-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.21 09:11:58 -09'00' 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 108' 9-5/8" L-80 2386' 5-1/2" L-80 5495' 3-1/2" L-80 5870' 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 10407' MD3-1/2" CASING If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 11/2/2025 204-009/ 325-230/ 325-529 50-103-20475-01-00 KRU 2P-424A ADL0373112, ADL0389058 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM 1351' FSL, 696' FWL, Sec. 21, T8N, R7E, UM L32092/ 32409 1/11/2004 11539' MD/ 5873' TVD 2350' MD/ 2070' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444010 5868966 2155' FSL, 384' FWL, Sec. 21, T8N, R7E, UM 9. Ref Elevations: KB: 28' 447593 447901 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 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, 1/15/2004 CEMENTING RECORD 5861466 1388' MD/ 1345' TVD SETTING DEPTH TVD 5860640 TOP HOLE SIZE AMOUNT PULLED 25' PACKER SET (MD/TVD) 42" 15.5# WT. PER FT.GRADE 28'540 sx AS Lite, 314 sx LiteCrete included above8.5" TUBING RECORD 678 sx Class G w/ GasBlok8.5" Flow Tubing 9.3# 28' 10428' 3006'28' 28' 2444-3069' (milled to 2620') 150 bbls 15.8 ppg PTA Cement 10428' SIZE DEPTH SET (MD) 11530' 25' 5495' 62.5# 40# 108' Gas-Oil Ratio:Choke Size: 0.26 bbl Class G cement Per 20 AAC 25.283 (i)(2) attach electronic information 10404' MD/ 5487' TVD (seal assembly) Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12.25" 15 bbl AS I Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 31 bbls 15.8 ppg Class G Cement8895-10333' 10599-10629' MD SUSPENDED 10655-11020' and 5574-5698' TVD (below cement plug) Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 10:26 am, Nov 06, 2025 Suspended 11/2/2025 JSB RBDMS JSB 112825 xG Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1388' 1345' 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: 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 Jill SimekDN: CN=Jill Simek, E=jill.simek@conocophillips.com, C=USReason: I am the author of this document Location: Date: 2025.11.06 09:29:16-09'00' Foxit PDF Editor Version: 13.1.6Jill Simek Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Miled out cement in kill string. 2P-424A 11/2/2025 famaj 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 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC Kill String 5 1/2 4.95 28.0 2,349.4 2,069.4 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 3,060.0 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,290.0 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 2,640.0 2,216.5 61.85 FISH 33' <*}}}< IN HOLE CTU BHA # 34 (MILL/UR IN 9 5/8" CASING) QUADC O 8/12/2025 0.000 3,060.0 2,412.0 61.83 CUT MSC on rig. 2/3/2025 4.950 3,069.0 2,416.3 61.78 CIBP YJ CIPB 2/3/2025 0.000 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 2P-424A, 11/5/2025 1:07:39 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 Cement Casing; 10,100.0 ftKB APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 Kick-Off Plug; 6,569.0 ftKB GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug – Plug Back / Abandonment Plug; 2,620.0 ftKB Cement Plug; 2,350.0 ftKB Kill String; 28.0-2,349.4 Cement Casing; 35.0 ftKB CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 3,005.0 35.0 2,386.2 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 108Drag up (lbs): 125Time started reciprocating: 04:30Time stopped reciprocating: 12:25Annular flow after cement job (Y/N): NCirculating BHT (F): 74Static BHT (F): 58Pressure before cementing (psi): 200Hours circulated between stages: 24Bbls cmt to surf: 231.0Method used to measure density: DensometerMethod used for mixing cement in this stage: TubReturns (pct): FullTime cementing mixing started: 11:50 12/30/2003 8,326.0 10,548.0 4,767.5 5,537.1 Abandonment Plug Cement Found Between Shoe and Collar (Y/N): NCement found on liner tool (Y/N): NPressure before cementing (psi): 1850Hours circulated between stages: 4Bbls cmt to surf: -0- See RemarksMethod used to measure density: DensometerMethod used for mixing cement in this stage: BatchPill below the plug (Y/N): NPlug catcher used? (Y/N): NReturns (pct): 100Tail pipe used (Y/N): YPerforated tail pipe (Y/N): NTail pipe nominal size (in): 3.5 1/9/2004 6,569.0 7,096.0 4,052.5 4,312.6 Kick-Off Plug Pressure before cementing (psi): 1850Hours circulated between stages: 4Bbls cmt to surf: 0Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchPill below the plug (Y/N): NPlug catcher used? (Y/N): NReturns (pct): 100Tail pipe used (Y/N): YTime cementing mixing started: 04:30Perforated tail pipe (Y/N): NTail pipe nominal size (in): 3.5 1/10/2004 10,100.0 11,530.0 5,380.2 5,870.4 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 72Drag up (lbs): 185000Time started reciprocating: 04:45Time stopped reciprocating: 12:00Cement Found Between Shoe and Collar (Y/N): NCement found on liner tool (Y/N): NAnnular flow after cement job (Y/N): NPressure before cementing (psi): 600Hours circulated between stages: 5Bbls cmt to surf: 0Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchReturns (pct): 100Time cementing mixing started: 08:00 1/17/2004 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 8,895.0 10,333.0 4,960.4 5,461.9 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT FOR BALANCED CEMENT PLUG 10/18/2024 2,444.0 3,069.0 2,120.5 2,416.3 Plug – Plug Back / Abandonment Plug HES pump 18.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 150 PSI. Drop wiper ball. Pump 150 Bbls of 15.8 PPG PTA cement @ 2.5 BPM, 200 PSI. Drop wiper ball. Pump 9.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 120 PSI. Displace w/ 20 Bbls of 9.8 PPG brine @ 2.5 BPM, 120 PSI. POOH T/ 2469'. Circ out 60 Bbls cement to surface above target depth MILL/UR CEMENT WITH CTU 4 TO 2620', 5/25/25 2/4/2025 2,350.0 2,640.0 2,069.8 2,216.5 Cement Plug Pumped 23.7 bbls of 15.8 ppg Premium cement w/ IsoGuard & MicroBond 10/7/2025 2P-424A, 11/5/2025 1:07:40 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 Cement Casing; 10,100.0 ftKB APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 Kick-Off Plug; 6,569.0 ftKB GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug – Plug Back / Abandonment Plug; 2,620.0 ftKB Cement Plug; 2,350.0 ftKB Kill String; 28.0-2,349.4 Cement Casing; 35.0 ftKB CONDUCTOR; 28.2-108.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A DTTMSTART JOBTYP SUMMARYOPS 5/21/2025 CHANGE WELL TYPE MIRU CTU 4. RAN 4.75" MILL & UNDERREAMER (8.75" BLADES). DRY TAG AT 2031' CTMD IN 5-1/2" KILL STRING. POOH PER QUADCO REP TO LAYDOWN UNDERREAMER. RBIH WITH 4.75" MILL, DRY TAG AT 2146', MILL TO END OF 5-1/2" TBG. DRY TAG TOC AT 2432' IN 9-5/8" CSG, BACK REAM 5-1/2 FROM END OF TUBING TO SURFACE. RBIH W/ 4.75" MILL & UNDERREAMER, TAG CEMENT AT 2428' (2444' RKB, +16' CF). MILL CEMENT DOWN TO 2462.5' PUMPING 3.0 BPM, W/ SSW, & GEL SWEEPS. (AVERAGE ROP=5 FPH). MILLING IN PROGRESS. 5/22/2025 CHANGE WELL TYPE CONTINUE MILLING CEMENT FROM 2462 TO 2474' CTMD. RETURN TANKS ARE FULL, POOH TO INSPECT UNDERREAMER BLADES, SWAP UNDERREAMER. WAIT ON AES TO GET TANKS EMPTIED. RBIH WITH MILL/UNDERREAMER, DRY TAG AT 2464'. MILL FROM 2464 TO 2479', POOH TO CHANGE TO 3-1/8" MOTOR, AVG ROP=5.8 FPH RAN 3 1/8" MOTOR, UNDERREAMER, & 4.75" PDC MILL. DRY TAG CEMENT @ 2480', MILLED TO 2588' (AVERAGE ROP= 40 FPH). CONTINUE MILLING IN PROGRESS. 5/23/2025 CHANGE WELL TYPE MILL CEMENT FROM 2588' TO 2646' (AVG ROP=55 FPH WHILE OBM), GETTING 1:1 RETURNS. RUNNING LOW ON SSW, POOH TO CHANGE UNDERREAMER, WAIT ON SSW. RBIH, TAG HIGH AT 2493', UNABLE TO MILL/UNDERREAM PAST 2493'. RAN 3" DJN & DRY TAGGED @ 2480', CAME ONLINE DN CT, PASSED RIGHT BY & WASHED DOWN TO TAG @ 2636'. PUMPED GELL PILL, & ABLE TO WASH DOWN TO 2645'. PUMP SECOND GEL PILL & CHASE UP HOLE TO 2300'. RBIH DRY DRIFTING DOWN TO TAG @ 2647', PAINT FLAG @ 2618', WASH TUBING UP TO 2300', RBIH CLEAN TO FLAG. LOGGED W/ READ 40 CALIPER FROM 2633' TO 2091'. WAITING FOR PROCESSING. IN PROGRESS. 5/24/2025 CHANGE WELL TYPE CALIPER DATA SHOWS RATTY UNDER GAUGE PILOT HOLE FROM 2475' TO 2635'. UNDEREAMER ARMS ARE NOT OPEN TO 8.75". W/ 2.88 MOTOR, UDERREAMER, AND 4.75" MILL, REPEAT UNDERREAM PASS 2450 TO 2560' AT MUCH SLOWER ROP 3-6 FPH (UNABLE TO KEEP UP WITH RETURNS/FLUID), PUH INTO KILL STRING & ABLE TO DRY DRIFT DOWN TO TAG @ 2537'. IN PROGRESS. 2P-424A Off Rig Suspend Summary of Operations 5/25/2025 CHANGE WELL TYPE RAN UNDERREAMER WITH BLANK BLADES TO ACT AS CENTRALIZER ABOVE MOTOR, 2.88" MOTOR, UNDERREAMER BELOW MOTOR W/ 8.75 & 7.30" BLADES, & 4.75" MILL. REPEAT UNDERREAM PASS FROM 2460' TO 2584' (124'). STALLED AT 2584', COIL PRESSURED UP, UNABLE TO GET BACK TO FREE SPIN PRESSURE. WITH RETURN TANKS NEAR FULL, HAD TO POOH. FOUND PARTED COIL, HELICALLY BUCKLLED, LEAVING 36' BHA AND UNDETERMINED LENGTH OF COIL STUB LOOKING UP (SEE ATTACHMENTS) MAKE TWO ATTEMPTS TO GET OVER FISH @ 2545' W/ 4.60" CUT LIP BURN SHOE OVERSHOT W/ 2" GRAPPLE (ON SECOND ATTEMPT MARKS ON INSIDE OF OVERSHOT INDICATES GETTING PARTIALLY OVER FISH). CLEAN UP OVERSHOT & RIH W/ SAME. IN PROGRESS. 5/26/2025 CHANGE WELL TYPE RAN 4.60" CUT LIP BURN SHOE OVERSHOT W/ 2" GRAPPLE. ROTATED ON TOP OF FISH FOR 25 MIN W/ NO OVER PULL @ 2545' (OVERSHOT NEVER GOT OVER FISH). RAN 4.75" IMPRESSION BLOCK, NOTHING DEFINITIVE. RAN 4' WASH PIPE W/ 4.75" BURN SHOE ON BOTTOM. BURN OVER FISH FROM 2444' TO 2447.7' TILL BOTTOMED OUT. MADE TWO ATTEMPTS TO FISH W/ 4.60" CUT LIP GUIDE & OVERSHOT W/ 2.88" GRAPPLE (1ST RUN DID NOT GET OVER FISH, SECOND RUN ROTATED WHILE ON TOP OF FISH & APPEARED TO MOVE BESIDE TOF DOWN TO 2551') RAN 4.75" IMPRESSION BLOCK & SAT DOWN 2' HIGH ABOVE FISH @ 2543'. MAKE UP BURN OVER SHOE W/ TATTLE TAIL PINS IN PROGRESS. 5/27/2025 CHANGE WELL TYPE RIH 4-1/2" WASH PIPE W/ 4-3/4" CUTRITE BURNSHOE BOTTOM W/ TATTLE TAIL PINS TO TOP OF FISH @ 2544', MADE 3.5' (LENGTH OF WASH PIPE), AND TOOLS INDICATE WE WERE NOT OVER FISH (NO PINS SHEARED). RAN 3.5" JSN & DRY TAG @ 2551'. CLEAN OUT W/ SSW AND GEL SWEEPS TO 2558', CHASE SWEEPS TO 1800', 2X. ROLL WELL TO CLEAN FRESH WATER. RUN READ VIDEO LOG, DISPLACE COIL TO METH, LOG VIDEO PASSES FROM 2500' TO 2558'. VIDEO WAS CLEAR ON 1ST DOWN PASS UNTILL LENS SMEARED BY A CHUCK OF CEMENT AT 2557'. ABLE TO SEE LOWSIDE CEMENT DEBRIS/SHEETH, COULD NOT SEE FISH (*** NOTE: TOP OF FISH IS MOST LIKELY AT 2584', DEPTH OF LAST MOTOR STALL***) FREEZE PROTECT WELL FROM 2000' WITH 30 BBLS METH AND 10 BBLS SLICK DIESEL. TEST 7" COMBI BOP'S ON WELL. RDMO 5/28/2025 CHANGE WELL TYPE RDMO 7/20/2025 CHANGE WELL TYPE (P&A) MITOA (FAIL) @ 750 PSI, ESTABLISHED OA LLR @ 7 GPM 7/30/2025 CHANGE WELL TYPE TRAVEL TO 2P PAD. JOB IN PROGRESS. 7/31/2025 CHANGE WELL TYPE 7" COMBI BOP FAILS SLIP PULL TEST @ 38K. BOP TECH REPLACES SLIP/PIPE RAM SET. BOP FAILS SLIP PULL TEST @ 30K. 7" COMBI REMOVED FROM SERVICE STANDBY WHILE WAITING ON REPLACEMENT 5-1/8" COMBI BOP UNIT TO BE REDRESSED AND CERTIFIED FOR 2" COIL. 8/1/2025 CHANGE WELL TYPE STANDBY WHILE WAITING FOR REPLACEMENT BOP UNIT. WEEKLY BOP TEST. JOB IN PROGRESS. 8/2/2025 CHANGE WELL TYPE RUN 4 5/8" BURN SHOES WITH TATTLE TALES AND DRESS OFF MILL. CLEAN ON FISH, POOH AND INSPECT MILLS. APPREARS THAT WASHPIPE IS FULLY SWALLOWING OVER FISH AND GET SLIGHT 2 7/8" WEAR ON DRESS OFF MILL. APPEARS THAT THERE ARE ONLY A COUPLE INCHES OF COIL LOOKING UP ON TOP OF FISH. MAKE UP VENTURI AND WASH ON TOP OF FISH. VENTURI COMES OUT FULL OF CEMENT. MAKE UP 4.69" CUT LIP W/ 2.88" GRAPPLE AND FISHING MOTOR. CATCH AND RETRIEVE COIL TUBING MILLING BHA FISH AT 2350'. JOB IN PROGRESS. 8/3/2025 CHANGE WELL TYPE FREEZE PROTECT FROM 2500' WITH 62 BBL OF DIESEL. RIG DOWN. JOB SUSPENDED FOR PLAN FORWARD. 8/6/2025 CHANGE WELL TYPE RAN XRV, 2.88 BICO MUD LUBE MOTOR, HAILEY UNDERREAMER (8.75" UPPER & 7.0" LOWER BLADES), & 4.70" PDC MILL DRY TAG @ 2549' CTMD. MILL/UNDERREAM THRU PREVIOUS MILLED AREA FROM 2480' DOWN TO 2553' & 1 FPM. MILL/UNDERREAM DOWN TO 2578' @ 1 FPM (STALL). HARD MILLING FROM 2578' TO MIDNIGHT DEPTH OF 2581.4' (WITH 4 ADDITIONAL STALLS / AVERAGE ROP 4 FPH). 8/7/2025 CHANGE WELL TYPE CONTINUE MILLING W/ XRV, 2.88 BICO MUD LUBE MOTOR, HAILEY UNDERREAMER (8.75" UPPER & 7.0" LOWER BLADES), & 4.70" PDC MILL. MILLED/UNDERREAM FROM 2581.4' TO 2582.6' (PULLED OOH DUE TO MULTIPLE PUMP EQUIPMENT FAILURES & POTENTIAL BHA ISSUES). MILL/UNDERREAM TO 2602.6' GET 3 STALLS. RAN 2.7 JSN, DRY TAGGED @ 2591', PUMPED GEL PILL, & CHASED OOH (BECAME DETAINED INSIDE KILL STRING @ 2237' FOR 1 HOUR BEFORE GETTING FREE). IN PROGRESS. 8/8/2025 CHANGE WELL TYPE RAN XRV, 2.88 BICO MUD LUBE MOTOR, HAILEY UNDERREAMER (8.3" UPPER & 7.0" LOWER BLADES), & 4.625" BEAR CLAW MILL. DRY TAG @ 2587' CTMD. MILLED (13') FOR A TOTAL OF 7 HRS W/ 20 STALLS & AVERAGE ROP OF 1.8 FPH DOWN TO 2600' CTMD. IN PROGRESS. 8/9/2025 CHANGE WELL TYPE PERFORM WEEKLY BOP TEST, TRIM 100' OF CT (18,675' ON REEL), MAKE UP CONNECTOR, AND PREPARE TOOLS FOR TOMORROW. IN PROGRESS. 8/10/2025 CHANGE WELL TYPE DRY TAG @ 2591' CTMD & MILL W/ RIH W/ XRV, 2.88 BICO MUD LUBE MOTOR, HAILEY UNDERREAMER (8.5" UPPER & 8.47" LOWER BLADES), & 4.625" 5 BLADE PDC MILL. MILLED FOR A TOTAL OF 7 HRS (MADE 24') W/ 15 STALLS & AVERAGE ROP OF 3.4 FPH DOWN TO 2615' CTMD. (BECAME DETAINED WHILE PULLING OOH @ 2428' CTMD FOR 2.5 HRS BEFORE GETTING FREE, ALSO ESTABLISHED INJECTIVITY TO FORMATION @ .75 BPM @ 775 PSI AT THE SAME TIME). IN PROGRESS. 8/11/2025 CHANGE WELL TYPE RIGGED UP REVERSE OUT SKID TO OA, EXTRA IRON, & SECOND PUMP. RIH W/ XRV, 2.88 BICO MUD LUBE MOTOR, & 4.625" 5 BLADE PDC MILL DRY TAG CEMENT @ 2633' CTMD MILLED 1' & STALLED @ 2634' @ 3.5 BPM. CIRCULATE BOTTOMS UP, RECIP FROM END OF KILL STRING BACK DOWN TO 2633'. CIRCULATED & RECIPROCATE FROM BOTTOM OF KILL STRING TO 1500'. RBIH DOWN TO 2180' AND CONFIRM CIRCULATION DOWN OA & UP KILL STRING X CT ANNULUS @ 1:1 RETURNS. CONFIRM ABILITY TO PUMP DOWN CT & OA SIMULTANEOUSLY W/ 1:1 RETURNS TO SURFACE. PREP TOOLS FOR RESTART IN AM. IN PROGRESS. 8/12/2025 CHANGE WELL TYPE RAN 2.88 BICO MUD LUBE MOTOR, HAILEY UNDERREAMER (8.31" UPPER & 8.15" LOWER BLADES), & 4.625" 5 BLADE PDC MILL DRY TAGGED @ 2612', MILLED/MOVED EASILY DOWN TO 2630', UNDERREAMED UP, AND WHILE PULLING UP HOLE NORMAL WT 6K STALLED @ 2580' WITH NO OVER PULL AND RAPID CP LOSS OF 1050 PSI. UNABLE TO GO DOWN. POOH AND DISCOVERED WE PARTED PIPE @/NEAR CONNECTOR (BHA LEFT IN HOLE=33.1'= CONNECTOR-MILL). SEE ATTACHMENTS. 8/13/2025 CHANGE WELL TYPE RAN MOTOR W/ 4.63" BURN SHOE DRY TAGGING @ 2534', BURN DOWN TO 2539' (MARKS ON OUTSIDE OF BURNSHOE INDICATE BESIDE FISH) RAN W/ SAME ASSEMBLY DRY TAGGING @ 2535', PICKED UP, AND STARTED STACKING WT @ 2532'. BURN DOWN TO 2540' (MARKS INSIDE DRIVE SUB INDICATE GETTING 4' OVER TOP OF FISH). PERFORM CHAIN INSPECTION, REPLACE PACKOFFS, & MAKE UP TOOL FOR FISHING IN THE MORNING. IN PROGRESS. 8/14/2025 CHANGE WELL TYPE MAKE MULTIPLE ATTEMPTS TO FISH CT TOOLSTRING W/ MOTOR & 4.69" CUT LIP OVERSHOT W/ 2.88" GRAPPLE @ 2540' CTMD; RAN MOTOR & 4.625" BURNSHOE W/ TATTLE TAIL PINS,TAGGED UP ON FISH @ 2540', AND MOVED DOWN TO 2636' W/ MARKS ON OUTSIDE OF BURN SHOE AND TATTLE TAIL PINS SHEARED 10" INSIDE BOTTOM OF SHOE. (PUMPED 45 BBLS OF DIESEL DOWN OA TAKING RETURNS TO SURFACE) 8/15/2025 CHANGE WELL TYPE RAN XRV, MOTOR, & 4.625" BURNSHOE DOWN TO 2640' CTMD (TATTLE TAILS PINS SHEARED 9" UP INSIDE BOTTOM W/ MARKS ON OUTSIDE OF BURN SHOE); RAN XRV, MOTOR, AND 4.69" CUT LIP OVERSHOT W/ 2.88" GRAPPLE DOWN TO 2610' (NO MARKS ON INSIDE OF OVER SHOT & MARKS ON OUTSIDE OF OVERSHOT GETTING BESIDE FISH); RAN 4.625" BURNSHOE DOWN TO TAG @ 2637' & MAKE HOLE DOWN TO 2647' (DRAG FREE COMING OFF BOTTOM) UNABLE TO INJECT INTO OA, UNABLE TO PUMP RATE TAKING RETURNS UP KILL STRING (SQUEEZED IN ANOTHER 15 BBLS OF DIESEL DN OA). FISH DID NOT ENTER BURN SHOE & MARKS ON OUTSIDE INDICATING GETTING BESIDE FISH. RIH W/ 2.88 JSN DOWN TO 2000' & FREEZE PROTECT KILL STRING W/ DIESEL JOB SUSPENDED FOR PLAN FORWARD. 9/12/2025 RECOMPLETION PRE-CEMENT INJECTIVITY TEST. ABLE TO PUMP 2 BPM @ 800 PSI. JOB COMPLETE. 10/6/2025 CHANGE WELL TYPE MIRU CTU 4 W/ 19,000' OF 2.0"COIL. MU CEMENT BHA AND PT ON WH ASSY, NIGHT CAP BOP'S. PLAN TO START JOB IN AM. JOB IN PROGRESS 10/7/2025 CHANGE WELL TYPE RIH W/ 2.0" BDN, TO 2640' RKB, DID NOT TAG FISH CIRCULATE 30 BBL SURFACTANT WASH FROM 2640' RKB. LAY IN 10 BBL CALCIUM CHLORIDE PILL FROM 2640' - 2495'. SQUEEZE 20 BBL SODIUM SILICATE PILL TO FORMATION. PUMP 23.7 BBLS OF 15.8 PPG CLASS G PREMIUM CEMENT, SQUEEZED 2.5 BBLS DOWN PAST FISH, LAY IN 21.2 BBLS FROM 2460' - 2360' RKB (EST TOC). RDMO CTU 4 WAIT 48 HOURS FOR WITNESSED TAG & TEST. JOB IN PROGRESS. 10/16/2025 CHANGE WELL TYPE RUN 1.75" DD BAILER W/ F-BTM, SD @ 2161' RKB, AOGCC WITNESS CALLED GOOD TAG, TB TO PERFORM MIT ((FAILED TEST)) ** JOB COMPLETE ** 11/2/2025 CHANGE WELL TYPE RIH WITH MOTOR AND 4.75" PDC BIT. DRY TAG AT 2,143' CTMD (2,163' RKB). MILL THROUGH POOR QUALITY CEMENT DOWN TO END OF KILL STRING AT 2,350' RKB. CHASE RETURNS OUT OF HOLE AND FREEZE PROTECT KILL STRING. AT SURFACE, BULLHEAD 10 BBL DOWN KILLSTRING AT 2.5 BPM AND WHP INCREASES BY 500 PSI AND OA PRESSURE ONLY INCREASES BY 100 PSI. LIMITED COMMUNICATION BETWEEN INSIDE AND OUTSIDE OF KILL STRING. READY FOR E-LINE LOGGING. 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): 11539' 2640' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/25/2025 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2978' 10655-11020' (below cement plug) 11505' 5574-5698' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 3006' 5870'11530' 16" 9-5/8" 80' 10407' MD 108' 2386' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Cy Eller Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Cy.Eller@conocophillips.com (907) 265-6049 Associate RWO/CTD Engineer KRU 2P-424A 5873' 2350' 2070' 2350', 2620', 3069', 8895', 10599', 10629' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:16 am, Nov 06, 2025 325-681 A.Dewhurst 10NOV25 DSR-11/6/25 10-407 X X VTL 11/19/2025 x BOP test to 2500 psig Annular preventer test to 2500 psig x 11/19/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 5, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Approval to Plug & Abandon 2P-424A (PTD # 204-009). 2P-424A was a producer that has been shut in since July of 2020. This well has been suspended with a reservoir cement plug and an intermediate cement plug. A surface shoe cement plug to isolate the C80 from the wellbore was placed on-rig with Nordic 3, but the subsequent pressure test to verify the plug failed. During attempts to remediate this surface shoe cement plug with coiled tubing, two coiled tubing BHAs were lost in hole. The first BHA was able to be retrieved, the second BHA was unable to be retrieved. A balanced cement plug that was placed on top of the coiled tubing BHA following Sundry # 325-529 has also failed a pressure test, and cement was left in the kill string ~200 MD higher than planned. A cleanout to the bottom of the kill string was performed. A CBL is planned to identify the top of cement stringers around the kill string. To complete the abandonment of this well, CPAI is requesting approval to mill out cement to the top of the coiled tubing BHA, then cut and pull the 5-1/2 kill string from the TOC identified by CBL with Nabors 7ES. An injectivity test will then be performed to determine if the remainder of the 5-1/2 kill string must be retrieved. If injectivity is achieved, a cement retainer will be placed in the 9-5/8 casing above the kill string. If injectivity is not achieved, the remainder of the 5-1/2 kill string will be retrieved and a cleanout to the top of the coiled tubing BHA will be performed to attempt to gain injectivity. Cement will then be pumped to remediate the surface casing shoe cement plug before the final surface abandonment is performed. If you have any questions or require any further information, please contact me at 907-265-6049 or James Ohlinger at 907-265-1102. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 2P-424A P&A Procedure PTD #204-009 Pre-Rig Work Remaining 1. Mill cement/cleanout to bottom of kill string - Completed 2. Attempt to gain kill string x SC annulus circulation 3. Pull CBL from ~2349 RKB to surface to identify TOC in annulus 4. Prepare well for rig arrival Rig Work MIRU 1. MIRU Nabors 7ES on 2P-424A. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. If kill string x SC annulus communication is achieved pre-rig, circulate seawater and complete 30-minute NFT. Verify well is dead. a. If kill string x SC annulus communication cannot be achieved, record shut in pressures on the kill string and kill string x SC annulus. Bleed pressures to zero and complete 30- minute NFT. Verify well is dead. 3. ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. a. No BPV will be set for ND/NU due to two tested mechanical plugs in wellbore providing barrier to reservoir in addition to four cement plugs. Remove Cement to Coiled Tubing BHA (fish) 4. MU 4-3/4 tri-cone milling BHA. RIH and remove cement to ~2640 RKB (previous slickline tag at top of fish). 5. MU MSC, RIH and cut 5-1/2 kill string above TOC identified by CBL. 6. Pull and lay down 5-1/2 casing from cut. Perform Injectivity Test 7. Shut in and perform injectivity test. a. If injectivity is achieved, skip to Set Cement Retainer section. b. If injectivity is not achieved, continue with the following section. Retrieve Remainder of 5-1/2 Kill String 8. MU and RIH with fishing BHA. Engage top of 5-1/2 kill string and jar free. POOH and lay down 5-1/2 string. a. If CBL shows excessive cement on backside of kill string, RIH with burnover shoe and wash pipe and burn over kill string to remove cement prior to attempting to fish. 9. MU milling BHA. RIH and remove cement from 9-5/8 casing to ~2640 RKB (previous slickline tag at top of fish). 10. Shut in and perform injectivity test. a. If injectivity is achieved, skip to Set Cement Retainer section. b. If injectivity is not achieved, skip to Set Balanced Cement Plug section. Set Cement Retainer 11. After confirming injectivity, MU and RIH with cement retainer for 9-5/8 casing. Set above 5- 1/2 kill string at ~2150 RKB, or ~2630 RKB depending on when injectivity was achieved. Page 2 of 4 2P-424A P&A Procedure PTD #204-009 Page 3 of 4 12. Pump 12 bbls, or 2 bbls, plus excess, cement through retainer. Release from retainer and place 50 of cement on top of retainer. a. Cement volume will change depending on cement retainer set depth. Set Balanced Cement Plug 13. If attempts to gain injectivity were unsuccessful after kill string was removed and 9-5/8 casing was cleaned out to top of fish, RIH with drillpipe. Tag top of cement/fish at ~2640 RKB. 14. Pick up ~5 and pump to verify circulation. Pump 23 bbls cement, plus excess, to place ~150 TVD of cement on top of coiled tubing BHA. Slightly under displace cement and pull drillpipe slowly to above final TOC. Circulate to remove excess cement as needed. Test Cement Plug 15. Wait on cement. 16. Tag cement and PT to 1,500 psi for 30 minutes with State witness. Execute Final Abandonment Plug 17. POOH laying down drillpipe. 18. TIH with workstring. 19. Land workstring in casing hanger profile. 20. Circulate cement surface to surface until full cement returns observed. RDMO 21. ND BOPE. NU dry hole tree. a. This step may be performed before pumping final abandonment plug for operational efficiency. 22. RDMO. Execute Final Abandonment Surface Excavation 1. DHD perform drawdown test of workstring and annulus. 2. Bleed off any trapped pressure from dry hole tree. 3. Remove tree in preparation for excavation and casing cut. 4. Have shoring box installed during excavation as needed to prevent loose ground from falling into excavation. 5. Cut off wellhead and all casing strings at 4 feet below original ground level. 6. Perform top job if needed to ensure cement is in all casing strings. AOGCC witness and photo document required. 7. Send casing head with stub to materials shop. Photo document. 8. Weld ¼ thick cover plate (16 OD) over all casing strings with the following information bead welded into the top. Photo document and AOGCC witness required. a. ConocoPhillips b. KRU 2P-424A c. PTD# 204009 Witness required before top job. 2P-424A P&A Procedure PTD #204-009 Page 4 of 4 d. API# 50-103-20475-01-00 9. Remove cellar. Backfill cellar with gravel as needed. Backfill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. 11. RDMO. 12. Report that final P&A has been completed to AOGCC. Photo document final location condition after completing work. General Well Information: Estimated Start Date: 11/25/2025 Current Operations: Suspended Well Type: Producer Wellhead Type: FMC Gen V. 11 5M casing head top flange. 11 5M tubing head top flange. 7- 1/16 5M dry hole tree. Scope of Work: Mill cement and cleanout to top of coiled tubing BHA. Cut and pull 5-1/2 kill string from TOC identified by CBL. Perform injectivity test, then set cement retainer in 9-5/8 casing and remediate C80 cement plug, or retrieve remaining 5-1/2 kill string and mill cement/cleanout to top of coiled tubing BHA then perform injectivity test and set cement retainer. Remediate C80 cement plug, then pump final abandonment plug and execute final abandonment. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Well Data: Meltwater Formation: Reservoir pressure 2/21/18 = 2038 psi @ 5640 TVD MASP = 1474 psi / 0 psi (Cemented) C-80 Formation: OA Pressure = 468 psi (11/24/22) (diesel fluid level at 339 TVD) MASP = 971 psi / 0 psi (Cemented) Surface casing shoe cement plug TOC (prior to coiled tubing cleanout) = 2161 SLMD Coiled tubing BHA (fish) = 2640 RKB Personnel: Workover Engineer: James Ohlinger (907-265-1102 / James.J.Ohlinger@conocophillips.com) Intervention Engineer: Jill Simek Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Miled out cement in kill string. 2P-424A 11/2/2025 famaj 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 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC Kill String 5 1/2 4.95 28.0 2,349.4 2,069.4 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 3,060.0 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,290.0 Set Depth 10,407.0 Set Depth 5,487.8 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 2,640.0 2,216.5 61.85 FISH 33' <*}}}< IN HOLE CTU BHA # 34 (MILL/UR IN 9 5/8" CASING) QUADC O 8/12/2025 0.000 3,060.0 2,412.0 61.83 CUT MSC on rig. 2/3/2025 4.950 3,069.0 2,416.3 61.78 CIBP YJ CIPB 2/3/2025 0.000 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 2P-424A, 11/5/2025 1:07:39 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 Cement Casing; 10,100.0 ftKB APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 Kick-Off Plug; 6,569.0 ftKB GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug Plug Back / Abandonment Plug; 2,620.0 ftKB Cement Plug; 2,350.0 ftKB Kill String; 28.0-2,349.4 Cement Casing; 35.0 ftKB CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE 2P-424A Existing Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.06 62.5 H-40 Welded Surface Casing 3005.8 2386.5 9.625 8.83 40 L-80 BTC Kill String 2349.4 2069.4 5.5 4.95 15.5 L-80 BTC-M Production Casing (5.5" Section) Top - 3060 Btm - 10428 Top - 2416 Btm - 5870 5.5 4.95 15.5 L-80 BTC-M Production Casing (3.5" Section) Top - 10428 Btm - 11530 Top - 5870 Btm - 6428 3.5 2.99 9.3 L-80 EUE-M Tubing Top - 3290 Btm- 10422 Top - 2522 Btm - 5867 3.5 2.99 9.3 L-80 EUE-M Surface Casing 3006' RKB Production Casing Conductor Plug #1 -Reservoir TOC 10,599' RKB CIBP 10,629' RKB Tubing Cut: 3,290' RKB CIBP 3069' RKB Production Casing Cut: 3,060' RKB FISH: 2640' MD (33' CTU BHA) Production Casing Calculated TOC: 8,535' RKB Surface Casing TOC: Surface CIBP Plug #2 - Intermediate TOC 8,895' RKB BOC 10,330' RKB Surface Shoe Cement Date Placed: 2/5/2025 TOC: 2,444' RKB Kill String 2349' RKB 2nd Surface ShoeCement Plug Date Placed: 10/7/2025 Planned TOC: 2,360' RKB TOC tag prior to milling with CTU: 2,161' RKB 2P-424A Proposed P&A - Cmt Retainer Above Kill String COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.06 62.5 H-40 Welded Surface Casing 3005.8 2386.5 9.625 8.83 40 L-80 BTC Kill String 2349.4 2069.4 5.5 4.95 15.5 L-80 BTC-M Production Casing (5.5" Section) Top - 3060 Btm - 10428 Top - 2416 Btm - 5870 5.5 4.95 15.5 L-80 BTC-M Production Casing (3.5" Section) Top - 10428 Btm - 11530 Top - 5870 Btm - 6428 3.5 2.99 9.3 L-80 EUE-M Tubing Top - 3290 Btm- 10422 Top - 2522 Btm - 5867 3.5 2.99 9.3 L-80 EUE-M Surface Casing 3006' RKB Production Casing Conductor Plug #1 -Reservoir TOC 10,599' RKB CIBP 10,629' RKB Tubing Cut: 3,290' RKB CIBP 3069' RKB Production Casing Cut: 3,060' RKB FISH: 2640' MD (33' CTU BHA) Production Casing Calculated TOC: 8,535' RKB Surface Casing TOC: Surface CIBP Plug #2 - Intermediate TOC 8,895' RKB BOC 10,330' RKB Surface Shoe Cement Date Placed: 2/5/2025 TOC: 2,444' RKB Kill String 2349' RKB 2nd Surface Shoe Cement Plug Date Placed: 10/7/2025 Planned TOC: 2,360' RKB TOC tag prior to milling with CTU: 2,161' RKB Cmt Retainer ~2150' RKB 2P-424A Proposed P&A - Kill String Removed COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.06 62.5 H-40 Welded Surface Casing 3005.8 2386.5 9.625 8.83 40 L-80 BTC Kill String 2349.4 2069.4 5.5 4.95 15.5 L-80 BTC-M Production Casing (5.5" Section) Top - 3060 Btm - 10428 Top - 2416 Btm - 5870 5.5 4.95 15.5 L-80 BTC-M Production Casing (3.5" Section) Top - 10428 Btm - 11530 Top - 5870 Btm - 6428 3.5 2.99 9.3 L-80 EUE-M Tubing Top - 3290 Btm- 10422 Top - 2522 Btm - 5867 3.5 2.99 9.3 L-80 EUE-M Surface Casing 3006' RKB Production Casing Conductor Plug #1 -Reservoir TOC 10,599' RKB CIBP 10,629' RKB Tubing Cut: 3,290' RKB CIBP 3069' RKB Production Casing Cut: 3,060' RKB FISH: 2640' MD (33' CTU BHA) Production Casing Calculated TOC: 8,535' RKB Surface Casing TOC: Surface CIBP Plug #2 - Intermediate TOC 8,895' RKB BOC 10,330' RKB Surface Shoe Cement Date Placed: 2/5/2025 TOC: 2,444' RKB Cmt Retainer ~2630' RKB 2P-424A Proposed P&A - Balanced Plug COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.06 62.5 H-40 Welded Surface Casing 3005.8 2386.5 9.625 8.83 40 L-80 BTC Kill String 2349.4 2069.4 5.5 4.95 15.5 L-80 BTC-M Production Casing (5.5" Section) Top - 3060 Btm - 10428 Top - 2416 Btm - 5870 5.5 4.95 15.5 L-80 BTC-M Production Casing (3.5" Section) Top - 10428 Btm - 11530 Top - 5870 Btm - 6428 3.5 2.99 9.3 L-80 EUE-M Tubing Top - 3290 Btm- 10422 Top - 2522 Btm - 5867 3.5 2.99 9.3 L-80 EUE-M Surface Casing 3006' RKB Production Casing Conductor Plug #1 -Reservoir TOC 10,599' RKB CIBP 10,629' RKB Tubing Cut: 3,290' RKB CIBP 3069' RKB Production Casing Cut: 3,060' RKB FISH: 2640' MD (33' CTU BHA) Production Casing Calculated TOC: 8,535' RKB Surface Casing TOC: Surface CIBP Plug #2 - Intermediate TOC 8,895' RKB BOC 10,330' RKB Surface Shoe Cement Date Placed: 2/5/2025 TOC: 2,444' RKB Kill String ~2335' RKB Proposed Surface Shoe Remedial Cement Plug Planned TOC: ~2,343' RKB 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 Exp Date 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11539'2640' 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 (907) 263-4131 Staff Well Interventions Engineer KRU 2P-424A 5873' 1541' 1481 2620', 3069', 8895', 10599', 10629' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Jill.Simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst 10407' MD 108' 2386' 108' 3006' 5870'11530' 16" 9-5/8" 80' 2978' 10655-11020' (below cement plug) 11505' 5574-5698' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): Wellbore schematic BOP Sketch 9/10/2025 Date: 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:59 am, Aug 29, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.08.28 16:28:13 -08'00' 325-529 DSR-9/9/24VTL 9/8/2025 A.Dewhurst 02SEP25 December 31, 2025 X All conditions on original approved sundry apply 10-407 X No further extensions will be approved. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 08:43:11 -08'00'09/10/25 RBDMS JSB 091125 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska August 27, 2025 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached, the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2P-424A (PTD# 204-009). This 10-403 is being submitted to request procedure changes to the existing Sundry Approved P&A procedure (Sundry# 325-230), and to request an extension of the Sundry deadline, to December 31, 2025. If you have any questions, please contact me at 263-4131. Sincerely, Jill Simek Staff Well Interventions Engineer 2P-424A Plug and Abandon Revised Procedure PTD #204-009 Sundry #325-230 Page 1 of 2 2P-424A is a suspended producer, idenƟĮed for P&A as part of ConocoPhillips 2P pad abandonment program. Currently, the well is suspended with 2 cement plugs and a WRP. A third cement plug was aƩempted, on-rig, to isolate the C80 from the wellbore; however, this plug has failed and will require remedia Ɵon. To date, steps 1-2 of the original approved Sundry procedure have been performed. During cement milling (step 3), the milling BHA has been lost in hole twice. AŌer the Įrst Lost In Hole incident, ConocoPhillips was able to retrieve the BHA and conƟnue milling. However, aŌer cement was milled to approximately 2,673Ō KB, the BHA was lost again, and further Įshing aƩempts have been unsuccessful. Permission is requested to proceed to step 4 and cement from Top of Fish, instead of the CIBP. The revised procedure changes the base of the C80 plug from ~3,019Ō KB to ~2,640Ō KB (top of FISH) and reduces the cement plug from 500Ō to 280Ō. Changes are highlighted below in green. C80 Cement Plug AƩempt (Rig) Design o 150 BBL 15.8 Class G Cement o Displace with 9.8 PPG Brine Summarized Operational Procedure o Pump surface casing shoe cement plug. o POOH cement string to 2469’ RKB. Circulate out excess cement (60bbls). Result o Wash in hole, tag 2444’ RKB 10K WOB o Attempt to pressure test (1500psi). Failed with linear leak off rate Procedure Pull WRP, Mill Cement, Place New Cement (Coil) 1. MIRU. 2. RIH and pull WRP at 1,541ft KB. 3. RIH and mill cement to ~2,673ft KB (bottom of FISH). 4. RIH with coil and place ~280ft cement plug from ~2,640ft KB (top of FISH) to ~2,360ft KB. a. A Variance is requested to 20 AAC 25.112(a)(1)(A) requiring cement 100’ below hydrocarbon bearing zones. It is our intention to remove failed cement to ~346’ above existing CIBP, then to place ~280’ new cement from TOC into the surface casing. b. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to mill out the cement plug once pumped. 5. RDMO. Wait on Cement. Tag and Pressure Test (Slickline) 6. Notify the AOGCC Inspector of timing for pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 7. MIRU. 8. RIH and tag TOC (witnessed). 9. Perform MIT on production casing (witnessed). 10. Perform DDT on production casing (witnessed). 11. RDMO. Set IBP (Eline) 1. MIRU. 2. RIH and set IBP at ~2,360ft KB. 3. RDMO. Surface Cement Plug (Pumping) 4. MIRU 5. Pump ~166bbls permafrost cement in kill string and surface casing. 6. RDMO. Wait on cement. Variance approved. Variance approved.VTL 9/8/2025 VTL 9/8/2025 2P-424A Plug and Abandon Revised Procedure PTD #204-009 Sundry #325-230 Page 2 of 2 Wellhead Excavation / Final P&A: 7. Confirm tubing and annulus pressures are at 0psi. 8. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 9. Remove the tree, in preparation for the excavation and casing cut. 10. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 11. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 12. Send the casing head w/ stub to materials shop . Photo document. 13. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 2P-424A PTD #: 204-009 API #: 50-103-20475-01-00 14. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 15. Obtain site clearance approval from AOGCC. RDMO. 5-½” Kill String set @ 2349' RKB Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 2P-424A P&A Schematic - Current Conductor: 16" Conductor 108' KB 1 3 4 6 5 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB (2386' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB !"#!""$%&& '() & !*"+ &)', (-."!!"/012 3 * 4!"" 1,1)),)5&(& 2!"012 3 * 4!" )5&, ' -3 6 )5()&& Plug #1 – Reservoir TOC ±10600' RKB C80 @ 3140' KBC80 @ 3140' KB Plug #2 – Intermediate TOC ±8895' RKB BOC @ ±10330' RKB Surface Shoe Cement TOC ~2673' RKB BOC @ ±3069' RKB 2 5-½” Kill String set @ 2349' RKB 1l.g b4 of 8 @ S. r#Gae Bf 8 c2349' RKB Production Casing Cement: k4kC5 mmls u# k5Cdb TGs BluaO 8e, ent 8Gla. lGte6 of 8 @ d"535' KB 2P-424A P&A Schematic - Proposed Conductor: k0x 8un6. atur kLd' KB 1 3 4 6 5 Production Casing: 5C5x M 3C5x @ kL"42d' KB" k5C5b M 9C3b" D-dL Bo 8 -’ f – Set @ kk"53LC4( KB T-3 Peforations: @ kL"055' ) kk"L2L' KB /305'V Surface Casing: 9-5Edx" 4Lb" D-dL Bo8 Set @ 3"LL5Cd' KB /23d0' oU–V Production Tubing: 3 ½”" 9C3b D-dL 7P7-dr6 ’ f – Set @ kL"4Lv' KB !"#!""$%&& '() & !*"+ &)', (-."!!"/012 3 * 4!"" 1,1)),)5&(& 2!"012 3 * 4!" )5&, ' -3 6 )5()&& 1l. g bk ) Reser±uir of 8 I kL0LL' RKB 8dL @ 3k4L' KB8dL @ 3k4L' KB 1l.g b2 ) hnter, e6iGte of 8 I dd95' RKB Bf 8 @ I kL33L' RKB S. r#Gae S~ue 8e, ent of 8 c20v3' RKB Bf 8 @ I 3L09' RKB 2 1l.g b3 of 8 c230L' RKB Bf 8 c204L' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Recover coil fish 2P-424A 8/3/2025 famaj 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 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC Kill String 5 1/2 4.95 28.0 2,349.4 2,069.4 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 3,060.0 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,290.0 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 2,640.0 2,216.5 61.85 FISH 33' <*}}}< IN HOLE CTU BHA # 34 (MILL/UR IN 9 5/8" CASING) QUADC O 8/12/2025 0.000 3,060.0 2,412.0 61.83 CUT MSC on rig. 2/3/2025 4.950 3,069.0 2,416.3 61.78 CIBP YJ CIPB 2/3/2025 0.000 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 2P-424A, 8/28/2025 4:11:40 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug – Plug Back / Abandonment Plug; 2,620.0 ftKB Kill String; 28.0-2,349.4 CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,895.0 10,333.0 4,960.4 5,461.9 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT FOR BALANCED CEMENT PLUG 10/18/2024 2,444.0 3,069.0 2,120.5 2,416.3 Plug – Plug Back / Abandonment Plug HES pump 18.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 150 PSI. Drop wiper ball. Pump 150 Bbls of 15.8 PPG PTA cement @ 2.5 BPM, 200 PSI. Drop wiper ball. Pump 9.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 120 PSI. Displace w/ 20 Bbls of 9.8 PPG brine @ 2.5 BPM, 120 PSI. POOH T/ 2469'. Circ out 60 Bbls cement to surface above target depth MILL/UR CEMENT WITH CTU 4 TO 2620', 5/25/25 2/4/2025 2P-424A, 8/28/2025 4:11:40 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 FISH; 2,640.0 Plug – Plug Back / Abandonment Plug; 2,620.0 ftKB Kill String; 28.0-2,349.4 CONDUCTOR; 28.2-108.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Simek, Jill To:Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL]2P424A and 2P-422A P&As - proposed WBS Date:Monday, September 8, 2025 4:13:53 PM Attachments:2P-422A P&A Schematic - Current rev1.pdf 2P-422A P&A Schematic - Proposed rev1.pdf 2P-424A P&A Schematic with FISH rev1 - Current.pdf 2P-424A P&A Schematic with FISH rev1 - Proposed.pdf Hi Victoria, Amended WBS attached. For each well, I included “Current” and “Proposed”. Let me know if you have further questions. Jill From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, September 3, 2025 7:53 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]2P424A and 2P-422A P&As - proposed WBS CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jill, Could you please provide the updated WBS(proposed) that was included in the original sundries for both these P&As? Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-27_22647_2P-424A_EVCamera_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22647 KRU 2P-424A 50-103-20475-01 EV Camera 27-May-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 204-009 T40526 6/4/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.04 08:22:38 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11539'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) 263-4131 Staff Well Interventions Engineer KRU 2P-424A 5873' 1541' 1481 1541', 2444', 8895', 10599', 10629' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Jill.Simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst 10407' MD 108' 2386' 108' 3006' 5870'11530' 16" 9-5/8" 80' 2978' 10655-11020' (below cement plug) 11505' 5574-5698' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 5/1/2025 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:59 pm, Apr 15, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.04.14 16:59:30 -08'00' 325-230 X 10-407 X DSR-4/17/25SFD 4/21/2025 9/30/2025 VTL 4/21/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.22 10:36:21 -08'00'04/22/25 RBDMS JSB 042225 !" # $% & ' ( ) $% *+ , - .' '' + '/' !" # 01%22301$ 4 5 6$42 $ %& 778 96:";2. *9% , # ! :";20%;!72 *01%% ,- + '() ( *+ ! 0 <="> "=8!"01 0;2 ? "=8@?%06;2 "=8 @1%%@?$ A (B')7@106;2 a. A Variance is requested to 20 AAC 25.112(a)(1)(A) requiring cement 100’ below hydrocarbon bearing zones. It is our intention to remove failed cement to ~50’ above existing CIBP, then to place ~500’ new cement from TOC into the surface casing. b. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to mill out the cement plug once pumped. 1 "5<7! ###$ , ! 9 C74= * 74) ! C- ' , D <="> $ "=8)7* , 6 <=) * , 0% 55) * , 00 "5<7 $-./ ! 0 <="> "=8 =2@?9%;2 ? "5<7 $0 ! <="> 1 @099 + 9 "5<7! '1 /2 3 45 6" D % $ C74= + * 74) ! C- ' , 6 "'.' 0% E.'' ' 00 F GHI* ,(74 ( 0 J / 0? !KH+'*09H75,' 74! "( 1 # 78 " -"9:;9 0 "'2+ '/ 2+' 01 7 '74"5<7 5-½” Kill String set @ 2349' RKB WRP @ 1541' RKB Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 2P-424A P&A Schematic - Current Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB (2386' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB 6 ! "#$% "&'( ( )*+, - . +%+##%#/"0" 0 1 , *+, - . #/"% &- 2 1 #/0#"" $ &3# 0#( 45 6 #/0#0" Plug #1 – Reservoir TOC ±10600' RKB C80 @ 3140' KBC80 @ 3140' KB Plug #2 – Intermediate TOC ±8895' RKB BOC @ ±10330' RKB Surface Shoe Cement TOC 2444' RKB (2120' TVD) BOC @ ±3069' RKB 5-½” Kill String set @ 2349' RKB BP ~2360' RKB Plug #4 TOC @ Surface BOC ~2360' RKB Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 2P-424A P&A Schematic - Proposed Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB (2386' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB 6 ! "#$% "&'( ( )*+, - . +%+##%#/"0" 0 1 , *+, - . #/"% &- 2 1 #/0#"" $ &3# 0#( 45 6 #/0#0" Plug #1 – Reservoir TOC ±10600' RKB C80 @ 3140' KBC80 @ 3140' KB Plug #2 – Intermediate TOC ±8895' RKB BOC @ ±10330' RKB Surface Shoe Cement TOC milled to ~3019' RKB BOC @ ±3069' RKB Plug #3 TOC ~2519' RKB BOC ~3019' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update post RWO 2P-424A 3/7/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC Kill String 5 1/2 4.95 28.0 2,349.4 2,069.4 15.50 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 3,060.0 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 3,290.0 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 1,541.0 1,480.6 30.17 WRP WRBP Yellow Jacket 2/6/2025 0.000 3,060.0 2,412.0 61.83 CUT MSC on rig. 2/3/2025 4.950 3,069.0 2,416.3 61.78 CIBP YJ CIPB 2/3/2025 0.000 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 2P-424A, 4/14/2025 2:06:17 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 Cement Plug; 2,444.0 ftKB Kill String; 28.0-2,349.4 WRP; 1,541.0 CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 8,895.0 10,333.0 4,960.4 5,461.9 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT FOR BALANCED CEMENT PLUG 10/18/2024 2,444.0 3,069.0 2,120.5 2,416.3 Cement Plug HES pump 18.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 150 PSI. Drop wiper ball. Pump 150 Bbls of 15.8 PPG PTA cement @ 2.5 BPM, 200 PSI. Drop wiper ball. Pump 9.5 Bbls of 10 PPG spacer w/ Surf wash @ 2.5 BPM, 120 PSI. Displace w/ 20 Bbls of 9.8 PPG brine @ 2.5 BPM, 120 PSI. POOH T/ 2469'. Circ out 60 Bbls cement to surface above target depth. 2/4/2025 2P-424A, 4/14/2025 2:06:17 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 3,060.0-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 CIBP; 3,069.0 CUT; 3,060.0 SURFACE; 28.2-3,005.8 Cement Plug; 2,444.0 ftKB Kill String; 28.0-2,349.4 WRP; 1,541.0 CONDUCTOR; 28.2-108.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: 28 ft Total Depth: 11359 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3006 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2" X 3 1/2" O.D. Shoe@ 11530 Feet Csg Cut@ 3060 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 10407 Feet Tbg Cut@ 3290 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 3069 ft 2444 ft 15.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 2120 1690 IA 2100 1800 OA 2120 1740 Initial 15 min 30 min 45 min Result Tubing 1800 1560 IA 1850 1600 OA 1820 1580 Remarks: Attachments: The rig tagged cement at 2444 ft MD with 10,000 lbs down weight. No movement. There were 6 attempts to get a passing MIT on the cement plug with no success; none of the tests reached the 15 minute mark without exceeding the allowed 10% pressure loss. Several components of surface equipment were checked for leaks with no issues found. No tests heldp for 30 minutes. I have captured the last two attempts that were made above. February 6, 2025 Guy Cook Well Bore Plug & Abandonment KRU 2P-424A Conoco/Phillips Alaska PTD 2040090; Sundry 324-677 none Test Data: F Casing Removal: Kevin Barr F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0206_Plug_Verification_KRU_2P-424A_gc 9 9 9 99 99 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: 2025.02.11 15:21:38 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 11539'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 1/2/2025 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2978' 10655-11020' (below cement plug) 11505' 5574-5698' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 3006' 5870'11530' 16" 9-5/8" 80' 10407' MD 108' 2386' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Shane Germann Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: shane.germann@conocophillips.com (907) 263-4597 Senior CTD/RWO Engineer KRU 2P-424A 5873' 8895' 4960' 8895', 10599', 10629' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 971 By Grace Christianson at 3:41 pm, Dec 02, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.12.02 14:44:27-09'00' Foxit PDF Editor Version: 13.0.0 324-677 X AOGCC Witnessed BOP and Annular Test to 2500 psi. AOGCC Witnessed tag and PT TOC. See attached "Conditions of Approval" JJL 12/23/24 X X 10-407 June 30, 2025 SFD 12/2/2024 DSR-12/16/24MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.23 13:55:44 -09'00'12/23/24 RBDMS JSB 122424 KRU 2P-424A Abandonment Conditions of Approval: 1. A variance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata. 2.A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. The plug must pass a State Witnessed pressure test and tag according to 20 AAC 25.112(g). 3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. 4. A failed pressure test of the surface casing shoe plug requires the submission of a new sundry (10-403) to cover the rigless abandonment scope if planned. Completion of workover operations under the original sundry will be complete and a 10-407 Well Completion or Recompletion Report and Log must be ϐiled 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 ϐiled 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. ariances granted provide for at least equally effective plugging of the well and prevention of ϐluid movement into sources of hydrocarbons or freshwater. 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This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for the Willow development project in 2026. This well was suspended via reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately execute final abandonment. Well Data Meltwater Formation: x Reservoir pressure 2/21/2018 = 2038 psi @ 5640’ TVD x MASP = 1474 psi C-80 Formation: x OAP = 468 psi (11/24/22) (diesel fluid level at 339’ TVD) x MASP = 971 psi Intermediate plug TOC = 8895’ MD Tubing cut depth = 3290’ MD Well Name Previous plug tag depth (RKB)PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-424A 8895' Pass 10/25/2024 100 psi 200 psi 920 psi 10/31/2024 Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 2P-424A Well Suspension Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB (2386' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D'ĞŶsdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϱΖ Ϯ ĂŵĐŽ^EŝƉƉůĞ>ĂŶĚŝŶŐEŝƉƉůĞ EŽ'Ž ϰϵϲ͘ϴΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ 'ŽWƌŽĨŝůĞ;ůŽƐĞĚϭϭͬϵͬϮϬϬϵͿ ϭϬ͕ϯϰϯ͘ϮΖ ϰ ĂŵĐŽEŝƉƉůĞǁͬEŽ'ŽWƌŽĨŝůĞ ϭϬ͕ϯϱϵ͘ϮΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌ ϭϬ͕ϰϬϯ͘ϯΖ ϲ ĂŬĞƌϭϴϬͲϰϬ^ĞĂůƐƐĞŵďůǇ ϭϬ͕ϰϬϰ͘ϯΖ Plug #1 – Reservoir TOC ±10600' RKB C80 @ 3140' KBC80 @ 3140' KB Plug #2 – Intermediate TOC ±8895' RKB BOC @ ±10330' RKB Surface Casing Plugs – Rig Date: 12-2-2024 Prepared by: Shane Germann Estimated Start Date: 1-2-2025 MIRU 1. MIRU on 2P-424A. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead before proceeding. 3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI. a. Will not set BPV due to two tested cement plugs below providing two barriers to formation. b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams 4. Circulate tubing and IA to brine. Retrieve Tubing 5. MU landing joint and BOLDS. 6. Pull tubing from pre-rig cut to surface and LD. Execute First Surface Casing Abandonment Plug 1. Set bridge plug in production casing 100’ below surface casing shoe 2. Cut production casing 50’ below surface casing shoe 3. Circulate OA to brine and complete 30-minute NFT. a. Punch holes in production casing at the surface casing shoe if unable to achieve circulation from production casing cut. 4. MU landing joint for production casing hanger and conƱrm casing is free from cut. a. Contingency: If unable to pull production casing from original cut depth i. Perform second cut inside surface casing shoe ii. Pull casing down to upper cut and laydown iii. PU DP and Ʊshing assembly iv. TIH and engage cut stub of prod casing. Fish stub free. v. Retrieve to surface. LD DP 5. Pump cement plug through the production casing cut. Utilize 31 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 5-1/2” casing is 150’ – 200’ MD above target TOC and space out with a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư- rig remediation. Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 2P-424A Well Surface Shoe Cement Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB (2386' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ&D,ĂŶŐĞƌ Ϯϱ͘ϱΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϭϭϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ'Ž WƌŽĨŝůĞ;ůŽƐĞĚϭϭͬϵͬϮϬϬϵͿ ϭϬ͕ϯϰϯ͘ϮΖ ϰ ĂŵĐŽEŝƉƉůĞǁͬEŽ'ŽWƌŽĨŝůĞ ϭϬ͕ϯϱϵ͘ϮΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌ ϭϬ͕ϰϬϯ͘ϯΖ ϲ ĂŬĞƌϭϴϬͲϰϬ^ĞĂůƐƐĞŵďůǇ ϭϬ͕ϰϬϰ͘ϯΖ Plug #1 – Reservoir TOC ±10600' RKB C80 @ 3140' KBC80 @ 3140' KB Plug #2 – Intermediate TOC ±8895' RKB BOC @ ±10330' RKB Plug #3 – Surface Shoe TOC 2681' RKB (2236' TVD) BOC @ ±3110' RKB Base of 5.5” Casing 350'-400' MD Inside Surface Shoe Execute Final Abandonment Plug 8. Land workstring in casing hanger proƱle. 9. Circulate cement surface to surface until full cement returns observed on surface. See table below for cement volumes. RDMO 10. ND BOPE. NU dry hole tree. a. Note: this step may be performed prior to pumping Ʊnal surface to surface abandonment plug. 11. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 3060 3110 Open Hole 8.5 0.06460 3.2 Displacement of Prod Casing Stub Included in BBL/FT calc 3005 3060 Open Hole 8.5 0.07018 3.9 2681 3005 Surface Casing 8.83 0.07574 24.5 31.5 Total Volume of Plug Surface Casing 23 2681 Surface Casing 8.83 0.07016 186.5 Displacement of Prod Casing Included in BBL/FT calculation Execute Final Abandonment Surface Excavation 12. DHD to perform drawdown test on tubing, IA, and OA 13. Remove well house. 14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system. 15. Remove tree in preparation for excavation and casing cut. 16. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level. 18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 19. Send the casing head with stub to materials shop. Photo document. 20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 2P-424A c. PTD #: 204-009 d. API #: 50-103-20475-01-00 21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground level. 22. Obtain site clearance approval from AOGCC. RDMO. 23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location condition after work is completed Plug #4 – Surface TOC 25' RKB BOC @ ±2681' RKB Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 2P-424A Well Final P&A Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB (2386' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ&D,ĂŶŐĞƌ Ϯϱ͘ϱΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϭϭϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ'Ž WƌŽĨŝůĞ;ůŽƐĞĚϭϭͬϵͬϮϬϬϵͿ ϭϬ͕ϯϰϯ͘ϮΖ ϰ ĂŵĐŽEŝƉƉůĞǁͬEŽ'ŽWƌŽĨŝůĞ ϭϬ͕ϯϱϵ͘ϮΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌ ϭϬ͕ϰϬϯ͘ϯΖ ϲ ĂŬĞƌϭϴϬͲϰϬ^ĞĂůƐƐĞŵďůǇ ϭϬ͕ϰϬϰ͘ϯΖ Plug #1 – Reservoir TOC ±10600' RKB C80 @ 3140' KBC80 @ 3140' KB Plug #2 – Intermediate TOC ±8895' RKB BOC @ ±10330' RKB Plug #3 – Surface Shoe TOC 2681' RKB (2236' TVD) BOC @ ±3110' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Punch Tbg 2P-424A 10/20/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 496.8 496.4 6.16 NIPPLE 4.520 CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 2,613.5 2,204.0 61.74 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 2,000.0 1,845.1 44.40 TUBING PUNCH TUBING PUNCH INTERVAL 2000' - 2003' W/ 2" TBG PUNCHER 10/20/2024 2.992 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.5 2,204.0 61.74 1 GAS LIFT DMY INT 1 0.0 1/18/2004 Fishn eck is stripp ed 0.000 5,357.1 3,476.6 62.05 2 GAS LIFT DMY INT 1 10/12/2024 7,325.0 4,414.2 66.75 3 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 9,126.8 5,040.1 69.97 4 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 10,293.5 5,448.1 69.57 5 GAS LIFT DMY INT 1 10/13/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 2P-424A, 12/2/2024 2:36:46 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 SURFACE; 28.2-3,005.8 GAS LIFT; 2,613.5 TUBING PUNCH; 2,000.0 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 8,895.0 10,333.0 4,960.4 5,461.9 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT FOR BALANCED CEMENT PLUG 10/18/2024 2P-424A, 12/2/2024 2:36:46 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 SURFACE; 28.2-3,005.8 GAS LIFT; 2,613.5 TUBING PUNCH; 2,000.0 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A ϮWͲϰϮϰϭϮĂůĐƵůĂƚĞĚWdKΛϴϱϯϱ͛Z<^^ŚŽĞΛϯϬϬϱ͛Z</WΛϯϭϭϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϲϴϭ͛Z<WƵƚΛϯϬϲϬ͛Z<ϴϬdŽƉΛϯϭϰϬ͛Z<ϴϬĂƐĞΛϱϯϭϬ͛Z< 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 108' 9-5/8" L-80 2386' 5-1/2" L-80 5495' 3-1/2" L-80 5870' 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 678 sx Class G w/ GasBlok8.5" 10407' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/31/2024 204-009/ 324-490 50-103-20475-01-00 KRU 2P-424A ADL0373112, ADL0389058 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM 1351' FSL, 696' FWL, Sec. 21, T8N, R7E, UM L32092/ 32409 1/11/2004 11539' MD/ 5873' TVD 8895' MD/ 4960' MD P.O. Box 100360, Anchorage, AK 99510-0360 444010 5868966 2155' FSL, 384' FWL, Sec. 21, T8N, R7E, UM 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 1/15/2004 CEMENTING RECORD 5861466 1388' MD/ 1345' TVD SETTING DEPTH TVD 5860640 TOP HOLE SIZE AMOUNT PULLED 447593 447901 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 28'540 sx AS Lite, 314 sx LiteCrete 9.3# 28' 10428' 3006'28' 28' 8895' (SW TOC)-10333' 31 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 10655-11020' and 5574-5698' 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: 10404' MD/ 5487' TVD (seal assembly) 9. Ref Elevations: KB: 28' 10428' SIZE DEPTH SET (MD) 11530' 25' 5495' 62.5# 40# 108' 25' PACKER SET (MD/TVD) 42" 12.25" 15 bbl AS I Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:50 pm, Nov 19, 2024 Suspended 10/31/2024 JSB RBDMS JSB 112924 DSR-4/7/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1388' 1345' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - Suspended Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.11.19 14:48:34-09'00'Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 10/16/2024 CHANGE WELL TYPE PUNCH TUBING: 10327' - 10330', CCL TO TOP SHOT = 8.2', CCL STOP DEPTH = 10318.8'. PERFORM CIRCULATION TEST. PUMP 20 BBLS DIESEL DOWN TBG AT 2.0 BPM, 1000 PSI . U-TUBE. READY FOR CEMENT 10/18/2024 CHANGE WELL TYPE INTERMEDIATE BALANCED CEMENT PLUG. LOAD TBG & IA WITH 9.8 PPG KWF. PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT AND DISPLACED CEMENT WITH 77 BBLS OF FLUID PLACING ESTIMATED TOC ~8830' RKB. READY FOR ELINE TO PUNCH HOLES AND CIRC IN FREEZE PROTECT IN 48 HOURS. 10/20/2024 CHANGE WELL TYPE PUNCH TUBING AT 2000' - 2003' RKB. CIRCULATE 47 BBLS DIESEL DOWN TBG UP IA FOR FREEZE PROTECT. JOB COMPLETE, READY FOR SLICKLINE STATE WITNESSED TAG AND TEST 10/25/2024 CHANGE WELL TYPE STATE WITNESSED (KAM ST JOHN) TAG TOC @ 8895' SLM. LRS PERFORM PASSING WITNESSED CMIT TO 1500 PSI. READY FOR E-LINE TBG CUT. 10/31/2024 CHANGE WELL TYPE CUT TUBING AT 3290' W/ 2.5" HUNTING JET CUTTER (DATE SHIFT CODE: 08/01/24A), LOG CORRELATED TO TUBING TALLY DATED 18-JAN-2002, CCL TO CUTTER = 2.7', CCL STOP = 3287.3' RKB. JOB IS COMPLETE 2P-424A Plug and Abandon Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Punch Tbg 2P-424A 10/20/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 496.8 496.4 6.16 NIPPLE 4.520 CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 2,613.5 2,204.0 61.74 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 2,000.0 1,845.1 44.40 TUBING PUNCH TUBING PUNCH INTERVAL 2000' - 2003' W/ 2" TBG PUNCHER 10/20/2024 2.992 3,290.0 2,521.8 61.66 CUT 2.5" JET CUT OF TUBING HUNTIN G 2.5" JET 10/31/2024 2.992 10,327.0 5,459.8 69.57 TUBING PUNCH TUBING PUNCH INTERVAL 10,327' - 10,330' W/ 2" TBG PUNCHER 10/16/2024 2.992 10,330.0 5,460.9 69.57 TUBING PUNCH TUBING PUNCH, 3.5G KNOCKOUT CHARGES @ 6 SPF, O DEG PHASING 9/8/2024 2.992 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.5 2,204.0 61.74 1 GAS LIFT DMY INT 1 0.0 1/18/2004 Fishn eck is stripp ed 0.000 5,357.1 3,476.6 62.05 2 GAS LIFT DMY INT 1 10/12/2024 7,325.0 4,414.2 66.75 3 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 9,126.8 5,040.1 69.97 4 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 10,293.5 5,448.1 69.57 5 GAS LIFT DMY INT 1 10/13/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 2P-424A, 11/12/2024 5:21:15 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 FLOAT SHOE; 11,529.8- 11,530.4 FLOAT COLLAR; 11,344.1- 11,344.8 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB SBE; 10,408.4-10,427.8 SEAL ASSY; 10,404.3 LOCATOR; 10,403.3 NIPPLE; 10,359.2 SLEEVE-C; 10,343.2 TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 SURFACE; 28.2-3,005.8 FLOAT SHOE; 3,004.1-3,005.8 FLOAT COLLAR; 2,920.4- 2,921.9 GAS LIFT; 2,613.5 TUBING PUNCH; 2,000.0 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 HANGER; 28.2-29.9 HANGER; 25.5 HANGER; 25.4-28.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 8,895.0 10,333.0 4,960.4 5,461.9 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CLASS G CEMENT FOR BALANCED CEMENT PLUG 10/18/2024 2P-424A, 11/12/2024 5:21:16 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 FLOAT SHOE; 11,529.8- 11,530.4 FLOAT COLLAR; 11,344.1- 11,344.8 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB SBE; 10,408.4-10,427.8 SEAL ASSY; 10,404.3 LOCATOR; 10,403.3 NIPPLE; 10,359.2 SLEEVE-C; 10,343.2 TUBING PUNCH; 10,330.0 TUBING PUNCH; 10,327.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 Cement Plug; 8,895.0 ftKB GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 CUT; 3,290.0 SURFACE; 28.2-3,005.8 FLOAT SHOE; 3,004.1-3,005.8 FLOAT COLLAR; 2,920.4- 2,921.9 GAS LIFT; 2,613.5 TUBING PUNCH; 2,000.0 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 HANGER; 28.2-29.9 HANGER; 25.5 HANGER; 25.4-28.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A ORIGINATED TRANSMITTAL DATE: 11/12/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5151 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5151 2P-424A 50103204750100 Tubing Cut Record 31-Oct-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-009 T39764 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.12 10:02:35 -09'00' 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: 11539 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 3006 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5-1/2" X 3-1/2" O.D. Shoe@ 11530 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 10407 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 10330 ft 8895 ft 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1760 1710 1690 IA 1775 1730 1710 OA 970 970 970 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): Good tag of cement top at 8895 ft MD; good sample in bailer. CMIT TxIA - pumped 1.2 bbls, returned 1.1 bbls. October 25, 2024 Kam StJohn Well Bore Plug & Abandonment KRU 2P-424A ConocoPhillps Alaska Inc. PTD 2040090; Sundry 324-490 none Test Data: Casing Removal: rev. 3-24-2022 2024-1025_Plug_Verification_KRU_2P-424A_ksj 9 9 9 9 9 9 99 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 3 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.20 16:44:13 -09'00' ORIGINATED TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5133 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 5133 2P-424A 50103204750100 Tubing Puncher Record 20-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 204-009 T39709 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.22 10:44:17 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5122 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 5122 2P-424A 50103204750100 Tubing Puncher Record 16-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 204-009 T39703 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 15:18:47 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 9/10/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5042 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5042 2P-424A 501032047501 Tubing Puncher Record 8-Sep-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-009 T39538 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 11:29:45 -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 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): 11539'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Well Interventions Engineer KRU 2P-424A 5873' 10599' 5555' 10599', 10629' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst 10407' MD 108' 2386' 108' 3006' 5870'11530' 16" 9-5/8" 80' 2978' 10655-11020' (below cement plug) 11505' 5574-5698' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 9/10/2024 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.08.22 08:25:58-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor By Grace Christianson at 11:17 am, Aug 23, 2024 X 10-407 X June 30, 2025 VTL 9/3/2024 SFD 8/28/2024 DSR-8/26/24 0 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.03 16:30:59 -08'00'09/03/24 RBDMS JSB 090524 2P-424A Intermediate Plug Date Wrien: 8-22-24 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-424A was a producer shut-in in late 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well was suspended in 2024. The objective of this procedure is to pump and intermediate cement plug before rig P&A in Q4 2024. Well Data Reservoir pressure 2/21/2018 = 2038 psi at 5640’ TVD = 0.36 psi/ft MASP = 1474 psi Last tag 11129’ RKB on 2/9/2020 with gauge ring Ensure all mandrels have dummy valves installed in them before pumping cement Procedure Wireline & Pumping 1. Punch tubing at ±10330’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±240 bbls KWF c. ±31 bbls cement d. ±77 bbls KWF 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 8830’ MD 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 5. Cut tubing at ±3290RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 10330 3.5" 9.3# 2.99" 0.0087 10330 89.7 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 10330 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 10330 123.0 84.0 from punch depth Tubing Cement 8830 10330 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 8830 10330 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 2P-424A Well Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 141.5 bbls of 15.8# Gas Block Cement Calculated TOC @ 8,535' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 10,428' KB, 15.5# x 9.3#, L-80 BTC-MOD Set @ 11,530.4’ KB T-3 Peforations: @ 10,655' – 11,020' KB (365') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,005.8' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd MOD Set @ 10,407' KB 6 Item Depth - tops (KB) 1 FMC Gen V Tubing Hanger 25.5' 2 Camco DS Nipple Landing Nipple No Go 496.8' 3 Baker CMU Sliding Sleeve w/ No Go Profile (Closed 11/9/2009)10,343.2' 4 Camco D Nipple w/ No Go Profile 10,359.2' 5 Baker G-22 Locator 10,403.3' 6 Baker 180-40 Seal Assembly 10,404.3' Plug #1 – Reservoir TOC ±10600' RKB Plug #2 – Intermediate TOC ±8830' RKB BOC @ ±10330' RKB 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: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on top of CIBP 2P-424A 7/26/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 496.8 496.4 6.16 NIPPLE 4.520 CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 2,613.5 2,204.0 61.74 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.5 2,204.0 61.74 1 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 5,357.1 3,476.6 62.05 2 GAS LIFT GLV INT 1 1,935.0 10/6/2016 0.156 7,325.0 4,414.2 66.75 3 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 9,126.8 5,040.1 69.97 4 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 10,293.5 5,448.1 69.57 5 GAS LIFT DMY INT 1 0.0 7/18/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 2P-424A, 8/14/2024 1:16:09 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 FLOAT SHOE; 11,529.8- 11,530.4 FLOAT COLLAR; 11,344.1- 11,344.8 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB SBE; 10,408.4-10,427.8 SEAL ASSY; 10,404.3 LOCATOR; 10,403.3 NIPPLE; 10,359.2 SLEEVE-C; 10,343.2 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 SURFACE; 28.2-3,005.8 FLOAT SHOE; 3,004.1-3,005.8 FLOAT COLLAR; 2,920.4- 2,921.9 GAS LIFT; 2,613.5 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 HANGER; 28.2-29.9 HANGER; 25.5 HANGER; 25.4-28.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 2P-424A, 8/14/2024 1:16:09 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 FLOAT SHOE; 11,529.8- 11,530.4 FLOAT COLLAR; 11,344.1- 11,344.8 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB SBE; 10,408.4-10,427.8 SEAL ASSY; 10,404.3 LOCATOR; 10,403.3 NIPPLE; 10,359.2 SLEEVE-C; 10,343.2 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 SURFACE; 28.2-3,005.8 FLOAT SHOE; 3,004.1-3,005.8 FLOAT COLLAR; 2,920.4- 2,921.9 GAS LIFT; 2,613.5 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 HANGER; 28.2-29.9 HANGER; 25.5 HANGER; 25.4-28.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 108' 9-5/8" L-80 2386' 5-1/2" L-80 5495' 3-1/2" L-80 5870' 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 10404' MD/ 5487' TVD (seal assembly) 9. Ref Elevations: KB: 28' 10428' SIZE DEPTH SET (MD) 11530' 25' 5495' 62.5# 40# 108' 25' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 10599-10629' MD 0.26 bbl Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 10655-11020' and 5574-5698' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information PACKER SET (MD/TVD) 42" 12.25" 15 bbl AS I 28'540 sx AS Lite, 314 sx LiteCrete 9.3# 28' 10428' 3006'28' 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 1/15/2004 CEMENTING RECORD 5861466 1388' MD/ 1345' TVD SETTING DEPTH TVD 5860640 TOP HOLE SIZE AMOUNT PULLED 447593 447901 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 50-103-20475-01-00 KRU 2P-424A ADL0373112, ADL0389058 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM 1351' FSL, 696' FWL, Sec. 21, T8N, R7E, UM L32092/ 32409 1/11/2004 11539' MD/ 5873' TVD 10599' MD/ 5555' MD P.O. Box 100360, Anchorage, AK 99510-0360 444010 5868966 2155' FSL, 384' FWL, Sec. 21, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/9/2024 204-009/ 323-492 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 678 sx Class G w/ GasBlok8.5" 10407' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 2:56 pm, Aug 14, 2024 Suspended 8/9/2024 JSB RBDMS JSB 081624 xGDSR-8/27/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1388' 1345' 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 14:13:51-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Estimated TOC) 10,585.0 2P-424A 7/26/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on top of CIBP 2P-424A 7/26/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 10,407.0 Set Depth … 5,487.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 496.8 496.4 6.16 NIPPLE 4.520 CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 2,613.5 2,204.0 61.74 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 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) 10,629.3 5,565.0 69.97 CIBP CIBP MID-ELEMENT AT 10,630' RKB, OAL = 1.37' 7/16/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.5 2,204.0 61.74 1 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 5,357.1 3,476.6 62.05 2 GAS LIFT GLV INT 1 1,935.0 10/6/2016 0.156 7,325.0 4,414.2 66.75 3 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 9,126.8 5,040.1 69.97 4 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 10,293.5 5,448.1 69.57 5 GAS LIFT DMY INT 1 0.0 7/18/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 2P-424A, 8/14/2024 1:16:09 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 FLOAT SHOE; 11,529.8- 11,530.4 FLOAT COLLAR; 11,344.1- 11,344.8 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB SBE; 10,408.4-10,427.8 SEAL ASSY; 10,404.3 LOCATOR; 10,403.3 NIPPLE; 10,359.2 SLEEVE-C; 10,343.2 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 SURFACE; 28.2-3,005.8 FLOAT SHOE; 3,004.1-3,005.8 FLOAT COLLAR; 2,920.4- 2,921.9 GAS LIFT; 2,613.5 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 HANGER; 28.2-29.9 HANGER; 25.5 HANGER; 25.4-28.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,599.0 10,629.3 5,554.7 5,565.0 Cement Plug Slickline dump bailed cement on top of the CIBP. Estimated TOC @ 10,585'. 7/26/2024 2P-424A, 8/14/2024 1:16:09 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 FLOAT SHOE; 11,529.8- 11,530.4 FLOAT COLLAR; 11,344.1- 11,344.8 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 FRAC; 10,850.0 IPERF; 10,850.0-10,862.0 APERF; 10,655.0-10,880.0 CIBP; 10,629.3 Cement Plug; 10,599.0 ftKB SBE; 10,408.4-10,427.8 SEAL ASSY; 10,404.3 LOCATOR; 10,403.3 NIPPLE; 10,359.2 SLEEVE-C; 10,343.2 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 SURFACE; 28.2-3,005.8 FLOAT SHOE; 3,004.1-3,005.8 FLOAT COLLAR; 2,920.4- 2,921.9 GAS LIFT; 2,613.5 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 HANGER; 28.2-29.9 HANGER; 25.5 HANGER; 25.4-28.0 KUP PROD 2P-424A ... WELLNAME WELLBORE2P-424A DTTMSTART JOBTYP SUMMARYOPS 7/8/2024 CHANGE WELL TYPE DRIFT & TAG ( 2.65" CENT) @ 10998' SLM. ATTEMPT TO DRIFT FOR CIBP (RAN INTO ICE / SAND / PARRAFIN) @ 1410' SLM. ATTEMPT TO RIH W/ 2.80'' G- RING BUT LOCK OUT SPANGS DUE TO ICE, LDFN. LRS TO HOT FLUSH WELL TONIGHT. JOB IN PROGRESS 7/9/2024 CHANGE WELL TYPE HOT FLUSH TBG WITH 30 BBLS DSL @ 200*F FOR SLICKLINE TO MELT/CLEAR ICE/PARRAFIN, READY FOR SLICKLINE. 7/9/2024 CHANGE WELL TYPE ATTEMPT TO DRIFT FOR CIBP BUT SAT DOWN @ 4966' SLM. RIH W/ 2.70 G- RING UNABLE TO PASS 4966' MD PARAFFIN IN SPANGS AND TOOLS, CUT PARAFFIN FROM 4966' SLM TO 4988' SLM, JOB PAUSED FOR HOT FLUSH. 7/11/2024 CHANGE WELL TYPE HOT FLUSH TBG WITH 60 BBLS OF 200*F DIESEL. READY FOR SLICKLINE. 7/11/2024 CHANGE WELL TYPE DRIFT W/2.69" DMY CIBP DRIFT TO 10,996' SLM. PULL OV FROM STA # 5 @ 10293' RKB. READY FOR FLUID PACK & CIBP. 7/15/2024 CHANGE WELL TYPE PUMP 95 BBL CISW & 18 BBL DIESEL DOWN TBG, 112 BBL CISW & 34 BBL DIESEL DOWN IA.RIH & SIT DOWN AT 8300', UNABLE TO GET TOOLS MOVING DOWNHOLE, BEGIN LOSING HOLE ATTEMPTING TO GET RESTARTED, POOH & INSPECT TOOLS, FIND PARAFFIN, WELL LEFT SI. JOB IN PROGRESS. 7/15/2024 CHANGE WELL TYPE HOT FLUSH TBG PUMPED 140 BBLS 200* DSL DOWN TBG JOB COMPLETE 7/16/2024 CHANGE WELL TYPE PUMP 95 BBLS CISW & 18 BBLS DIESEL DOWN TBG SET CIBP MID-ELEMENT AT 10,630' LRS PERFORM CMIT-TxIA TO 2000 PSI (PASS) JOB COMPLETE, READY FOR SL 7/18/2024 CHANGE WELL TYPE S/D ON ICE PLUG @ 3248' RKB INADVERTANTLY DUMPING CEMENT, BAIL OUT CEMENT, BAIL OUT ICE PLUG, DRIFT AND TAG CIBP @ 10,630', STALL OUT @ 3330' RKB WHILE TRYING TO BRUSH CEMENT OFF WALLS, RUN 2.795" GRING TO D NIPPLE @ 10,359' RKB, SET DMY VALVE @ 10,293' RKB, MIT-T TO 2100 PSI PASSED. JOB IN PROGRESS. 7/24/2024 CHANGE WELL TYPE DRIFT TO CIBP @ 10629' RKB, DUMP BAIL THREE BAILERS ( 10' X 2.5'') OF CEMENT ON TOP OF CIBP @ 10629' RKB (ESTIMATED CEMENT DEPTH @ 10619' RKB), LDFN. JOB IN PROGRESS 7/25/2024 CHANGE WELL TYPE DUMP BAIL FOUR BAILERS ( 10' X 2.5'') OF CEMENT ON TOP OF CEMENT TAG @ 10610' RKB ( ESTIMATED TOP OF CEMENT @ 10595' RKB) LDFN. JOB IN PROGRESS 7/26/2024 CHANGE WELL TYPE TAG CEMENT @ 10585' RKB, WAIT 3 DAYS AND READY FOR SW TAG & TEST. 8/9/2024 CHANGE WELL TYPE BAIL SAND BRIDGE FROM 2435' RKB TO 2445 RKB, STATE WITNESS TAG STATE WITNESS (AUSTIN McLEOD) TOC @ 10599' RKB. MIT-T TO 1500 PSI, PASS. READY FOR NEXT P&A STEPS. 2P-424 Suspend Summary of Operations 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: 11539 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: X P&A: NA Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ NA Feet Surface: 9-5/8" O.D. Shoe@ 3006 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@ 11530 Feet Csg Cut@ NA Feet Liner: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing: 3-1/2" O.D. Tail@ 10407 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 10629 ft MD 10599 ft MD 8.6/6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1750 1660 1620 IA 740 735 730 OA 905 905 905 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 (10629 ft MD ft MD) was dumped bailed on 7/26/24. Using your generic 2-1/4 inch slickline string they tagged the plug at 10599 ft MD (inclination 70°) with multiple hard set downs. A passing MIT was then done to a target of 1500psi. Top perforation at 10655 ft MD. August 9, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-424A ConocoPhillips Alaska, Inc. PTD 2040090; Sundry 323-492 none Test Data: MITT P Casing Removal: rev. 3-24-2022 2024-0809_Plug_Verification_KRU_2P-424A_am 9 9 9 9 9 9 9 9 9 9 9 9 9 999 9 9 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.24 15:00:11 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11539' 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 9/20/2023 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2978' 10655-11020' 11505' 5574-5698' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 3006' 5870'11530' 16" 9-5/8" 80' 10407' MD 108' 2386' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-424A 5873' 11129' 5734' 1474 None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:25 pm, Aug 29, 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: 2023.08.29 09:52:30-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 2P-424A Suspension Date Wri en: 21 Aug 2023 Execu on Date: Sept 20, 2023 Prepared by: Katherine OConnor (214-684-7400) Background & Objec ve 2P-424A was a producer shut-in in late 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 2/21/2018 = 2038 psi at 5640 TVD MASP = 1474 psi Last tag 11129 RKB on 2/9/2020 with gauge ring Procedure Wireline & Pumping 1. Tag TD. If unable to get within 50 of perforations, contact Katherine OConnor 2. Fluid pack tubing with KWF and freeze protect 3. Set CIBP @ ±10,630 RKB (must be set within 50 of the top of perforations) 4. Perform MIT-T to 2000 psi, record results 5. Dump bail at least 30 of cement on top of CIBP 6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 7. RIH and tag TOC, approx. 10,600 RKB (MUST BE AOGCC WITNESSED) 8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 9. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 109' of Rathole) 11,129.0 2P-424A 2/9/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated Tag Depth 2P-424A 2/9/2020 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.5 Set Depth 10,407.0 Set Depth 5,487.8 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 496.8 496.4 6.16 NIPPLE 4.520 CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 2,613.5 2,204.0 61.74 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 3.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.5 2,204.0 61.74 1 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 5,357.1 3,476.6 62.05 2 GAS LIFT GLV INT 1 1,935.0 10/6/2016 0.156 7,325.0 4,414.2 66.75 3 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 9,126.8 5,040.1 69.97 4 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 10,293.5 5,448.1 69.57 5 GAS LIFT OV INT 1 0.0 10/26/2019 0.156 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 2P-424A, 8/25/2023 9:18:34 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 APERF; 10,655.0-10,880.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 SURFACE; 28.2-3,005.8 GAS LIFT; 2,613.5 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 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: ___________________ 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): 11539'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 9/20/2023 3-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2978' 10655-11020' 11505' 5574-5698' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 3006' 5870'11530' 16" 9-5/8" 80' 10407' MD 108' 2386' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-009 P.O. Box 100360, Anchorage, AK 99510 50-103-20475-01-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10404' MD and 5487' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-424A 5873' 11129' 5734' 1474 None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:23 pm, Aug 29, 2023 323-492 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: 2023.08.29 09:52:30-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor December 31, 2024 VTL 10/3/2023 DSR-8/29/23 10-407 X Suspend SFD 9/7/2023 X *&:JLC 10/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.03 11:26:19 -08'00'10/03/23 RBDMS JSB 100323 2P-424A Suspension Date Wrien: 21 Aug 2023 Execuon Date: Sept 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-424A was a producer shut-in in late 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 2/21/2018 = 2038 psi at 5640’ TVD MASP = 1474 psi Last tag 11129’ RKB on 2/9/2020 with gauge ring Procedure Wireline & Pumping 1. Tag TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 2. Fluid pack tubing with KWF and freeze protect 3. Set CIBP @ ±10,630’ RKB (must be set within 50’ of the top of perforations) 4. Perform MIT-T to 2000 psi, record results 5. Dump bail at least 30’ of cement on top of CIBP 6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 7. RIH and tag TOC, approx. 10,600’ RKB (MUST BE AOGCC WITNESSED) 8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 9. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 109' of Rathole) 11,129.0 2P-424A 2/9/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated Tag Depth 2P-424A 2/9/2020 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam NOTE: 2P-424 drilled & immediately sidetracked for 2P-424A 1/18/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.2 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.2 3,005.8 2,386.5 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 10428' 5 1/2 4.95 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.5 Set Depth … 10,407.0 Set Depth … 5,487.8 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 496.8 496.4 6.16 NIPPLE 4.520 CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 2,613.5 2,204.0 61.74 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 5,357.1 3,476.6 62.05 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,325.0 4,414.2 66.75 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 9,126.8 5,040.1 69.97 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,293.5 5,448.1 69.57 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 10,343.2 5,465.5 69.55 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE w/ NO GO PROFILE - CLOSED 11/9/2009 2.810 10,359.2 5,471.1 69.52 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR 4.490 BAKER G-22 LOCATOR 3.010 10,404.3 5,486.9 69.45 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 3.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,613.5 2,204.0 61.74 1 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 5,357.1 3,476.6 62.05 2 GAS LIFT GLV INT 1 1,935.0 10/6/2016 0.156 7,325.0 4,414.2 66.75 3 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 9,126.8 5,040.1 69.97 4 GAS LIFT DMY INT 1 0.0 1/18/2004 0.000 10,293.5 5,448.1 69.57 5 GAS LIFT OV INT 1 0.0 10/26/2019 0.156 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,655.0 10,880.0 5,573.8 5,650.3 T-3, 2P-424A 9/4/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3, 2P-424A 2/15/2004 6.0 IPERF 2.5" HSD Guns 10,880.0 10,940.0 5,650.3 5,670.6 T-3, 2P-424A 8/26/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,940.0 10,970.0 5,670.6 5,680.8 T-3, 2P-424A 8/25/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 10,970.0 11,000.0 5,680.8 5,690.9 T-3, 2P-424A 8/24/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3, 2P-424A 8/23/2015 6.0 APERF 2.5" HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 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) 10,850.0 10,862.0 1 FRAC 2/16/2004 0.0 0.00 0.00 2P-424A, 8/25/2023 9:18:34 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10428'; 25.4-11,530.4 APERF; 11,000.0-11,020.0 APERF; 10,970.0-11,000.0 APERF; 10,940.0-10,970.0 APERF; 10,880.0-10,940.0 IPERF; 10,850.0-10,862.0 FRAC; 10,850.0 APERF; 10,655.0-10,880.0 GAS LIFT; 10,293.5 GAS LIFT; 9,126.8 GAS LIFT; 7,324.9 GAS LIFT; 5,357.1 SURFACE; 28.2-3,005.8 GAS LIFT; 2,613.5 NIPPLE; 496.8 CONDUCTOR; 28.2-108.0 KUP PROD KB-Grd (ft) 35.30 RR Date 1/10/2004 Other Elev… 2P-424A ... TD Act Btm (ftKB) 11,539.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032047501 Wellbore Status PROD Max Angle & MD Incl (°) 70.82 MD (ftKB) 8,267.06 WELLNAME WELLBORE2P-424A Annotation Last WO: End DateH2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE 2-0 D O') S • 2.(3X0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 ‘o it3/2oiS M.K.BENDER Anchorage, Alaska 99501 C 1 0 8 !v RE: Perforation Record: 2P-424A C Run Date: 9/1/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2P-424A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20475-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: . ,�.•---�""""'�'~ Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. S f j Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MALIL414L-4) 64R-eat • 2(.3X5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 dpi tBEND�53�201 ; K. R Anchorage, Alaska 99501 OCT Q 8 2515 RE: Perforation Record: 2P-424A Run Date: 8/23/2015 AO '_ ,, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2P-424A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20475-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: �-�-- Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. %WED '"` Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: rx)/442-0"4-01) 6-0-0-eat STATE OF ALASKA ALQA OIL AND GAS CONSERVATION COI /SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate 17 Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other: 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1' Exploratory r 204-009 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic "' Service 50-103-20475-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 373112,389058 KRU 2P-424A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Meltwater Oil Pool 11.Present Well Condition Summary: Total Depth measured 11539 feet Plugs(measured) none true vertical 5873 feet Junk(measured) none Effective Depth measured 11148 feet Packer(measured) none true vertical 5738 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 /108 V 108 SURFACE 2978 9.625 3006 2387 PRODUCTION 11505 5.5 11530 5871 RECEDED SEP 292015 Perforation depth: Measured depth: 10655-11020' True Vertical Depth: 5574'-5698' �� 2015AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 10407 MD, 5488 TVD Packers&SSSV(type,MD,and TVD) NO PACKER NIPPLE-CAMCO DS NIPPLE LANDING NIPPLE NO GO @ 497 MD and 496 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 126 779 51 -- _ 281 Subsequent to operation 281 1101 124 -- 316 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fr. Exploratory r Development j-; Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Tyson Wiese(,263-4250 Email Tyson.M.Wiese(cr�,conocophillips.com Printed Name T/{son Wi e Title Sr. Wells Engineer Signature Phone:263-4250 Date Q Ji Q,,,(4913 vn:- 4/Z q//c- /0 /ic/0 X04% RBDMS J( SEP 2 9 2015 Form 10-404 Revised 5/2015 Submit Original Only KUP PROD • 2P-424A ConocoPhillips m Well Attributes Max Angle&MD TD Alaska.In . Wellbore APguWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Otto(ftKB) [....alfa" 501032047501 MELTWATER PROD 70.82 8,267.06 11,539.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2P-424A,9/22/201510:13.40 AM SSSV:NIPPLE 18 12/11/2012 Last WO: 35.30 1/10/2004 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 10,856.0 11/25/2014 Rev Reason:PERFORATIONS hipshkf 9/22/2015 i8 = 8 Casing Strings HANGER,25 5 .2..1-j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).. WELen(I Grade Top Thread it - CONDUCTOR 16 15.062 28.2 108.0 (08.0 62.50 H-40 WELDED Illaii Casing Descriptwn OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) -Set Depth(ND)..WI/Len(I..Grade -Top Thread SURFACE 9 5/8 8.835 28.2 3,005.8 2,386.5 40.00 L-80 BTC 1{ G Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 51/2 4.950 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD �mau.@ 10428' CONDUCTOR 282-108.0-A, Tubing Strings 'N"-A-A-~Tubing Description -String Ma...ID(in) Top(ftKB) Set Depth(ft..t Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 25.5 10,407.0 5487.8 9.30 L-80 EUE8RDMOD NIPPLE;496.8 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Mein Item Des Com (in) 25.5 25.5 0.00 HANGER FMC GEN V TUBING HANGER 3.500 GAS LIFT:2,613.5 496.8 496.4 6.16 NIPPLE CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 10,343.2 5,465.5 69.55 SLEEVE-C BAKER CMU SLIDING SLEEVE w/NO GO PROFILE- 2.810 CLOSED 11/9/2009 10,359.2 5,471.1 69.52 NIPPLE CAMCO D NIPPLE w/NO GO PROFILE 2.750 10,403.3 5,486.5 69.45 LOCATOR BAKER G-22 LOCATOR 3.010 10,404.3 5.486.9 69.45 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Perforations&Slots Shot 1 Dens Top(ND) Btm(ND) (shots/f SURFACE;202-3025.8-� F Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10.655.0 10,880.0 5,573.8 5,650.3 T-3,2P-424A 9/4/2015 6.0 APERF 2.5"HSC 6SPF,60 DEG PHASING,11.6 GRAM _ MILLENIUM DEEP PENTRATING GAS LIFT;5,357.1 CHARGES 10,850.0 10,862.0 5,640.2 5,644.2 T-3,2P-424A 2/15/2004 6.0 IPERF 2.5"HSD Guns E- 10,880.0 10,940.0 5,650.3 5,670.6 T-3,2P-424A 8/26/2015 6.0 APERF 2.5"HSC 6SPF,60 DEG PHASING,11.6 GRAM MILLENIUM DEEP PENTRATING GAS LIFT,7.324.9 rCHARGES 10,940.0 10.970.0 5,670.6 5,680.8 T-3,2P-424A 8/25/2015 6.0 APERF 2.5"HSC 6SPF,60 DEG PHASING,11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES GAS LIFT,9,126.6 0 10,970.0 11,000.0 5,680.8 5,690.9 T-3,2P-424A 8/24/2015 6.0 APERF 2.5"HSC 6SPF,60 DEG PHASING,11.6 GRAM MILLENIUM DEEP PENTRATING CHARGES 11,000.0 11,020.0 5,690.9 5,697.7 T-3,2P-424A 8/23/2015 6.0 APERF 2.5"HSC 6SPF,60 DEG PHASING,11.6 GAS LIFT,10,293.51 MILLENIUM DEEP GRAM PENTRATING CHARGES f- Stimulations&Treatments Min TopMax Btm Depth Depth Top(TVD) Btm(ND) SLEEVE-C;10,343.2 l (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,850.0 10,862.0 5,640.2 5,644.2 FRAC 2/16/2004 PLACED 210,841 k OF 16/20 6 Mandrel Inserts NIPPLE,10,3592 St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com '1 2,613.5 2,204.0 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 9 [ - 2 5,357.1 3,476.6 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.156 1,935.0 11/26/2014 9 3 7,325.0 4,4142 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 LOCATOR;10,403.3 9 SEAL ASSY;10,404.3 4 9,126.8 5,040.1 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 9 5 10,293.5 5,448.1 CAMCO - KBG-2- 1 GAS LIFT -OV INT 0.156 0.0 11/26/2014 9 Notes:General&Safety End Date Annotation 1/18/2004 NOTE:2P-424 drilled 8.immediately sidetracked for 2P-424A 1/13/2011 NOTE:View Schematic w/Alaska Schematic9.0 APERF;10,655.0-10,880.0-_ _ (PERF;10,850.0.10,662.0 FRAC;10,850.01 ..-- -.7m .- ..y is APERF;10,880.0-10.940.0 --...4 APERF;10,940.0.10,970.0--. APERF;10,970.0-11,000.0.-. APERF;11,000.0-11,020.0 PRODUCTION 555/3.5"fa 10428',25.4-11,530.4 2-44A WELL WORK SUMMARY • DATE SUMMARY 8/5/2015 N2 FCO to surface attempted but unable to get satisfactory returns as wellbore went on vac due to very weak BHP. Eventually RIH and performed Fluff n' Stuff from 10,865'to hard tag @ 11,261' RKB. Well freeze protected and ready for Slickline. *****Job in Progress***** Note: Hit very sticky paraffin @ 2,427'to 2,600'. 8/14/2015 GAUGED TBG TO 2.78"TO 10359' RKB. DRIFTED TBG WITH 2.60"x 23' DUMMY PERF GUN TO 10813' SLM. DRIFTED WITH 10' x 2.5"TO 10847' SLM. TARGET DEPTH: 11020'. IN PROGRESS. 8/17/2015 WORKED 10'x 2.5" BAILER IN FRAC SAND TO 10847' SLM; TARGET DEPTH 11020'. IN PROGRESS. 8/18/2015 UNABLE TO DRIFT PAST 10848' SLM W/2.5" BAILER; DRIFT DOWN TO 11273' SLM W/ 10'X 2" BAILER. ATTEMPT & UNABLE TO PASS THROUGH OBSTRUCTION @ 10854' SLM W/2.55" OR 2.35" GAUGE RINGS. IN PROGRESS. 8/19/2015 DRIFT DOWN TO 11254' SLM W/ 10' X .25" &2.50" BAILERS; ATTEMPT TO DRIFT W/ 24'X 2.5" SPENT PERF GUN & UNABLE TO MAKE PASS 11000' SLM; BRUSH n' FLUSH TBG & UNABLE TO MAKE IT PASS 8458' SLM (LIKELY DRAGGED UP FILL FROM PREVIOUS DRIFT); DRIFT W/ 10'X 2.5" BAILER, WORKED THROUGH OBSTRUCTED AREA @ 8458' SLM, &TAG @ 11257' SLM. (RECOVERED SMALL AMOUNT OF SAND & FEW ROCKS IN BAILERS) IN PROGRESS. 8/20/2015 DRIFT W/ 13' X 2.5" SPENT PER GUN DOWN TO 11257' SLM; STILL UNABLE TO DRIFT PAST 10902' SLM W/24'X 2.5" PERF GUN; DRIFT DOWN TO 11257' SLM W/20' X 2.25" DRIFT. READY FOR E-LINE (perf). IN PROGRESS. 8/23/2015 PERFORATED 11000' - 11020' WITH TWO 10' HSC 6SPF, 60 DEG PHASING, 11.6 GRAM MILLENNIUM DEEP PENETRATING CHARGES. CORRELATED TO BAKER HUGHES MPRG LOG DATED 16 -JAN -2004. JOB IN PROGRESS. 8/24/2015 PERFORATE 10970' - 11000' USING THREE, TEN FOOT, 2.5" HSC 6 SPF, 60 DEG PHASING, 11.6 GRAM DEEP PENETRATING MILLENNIUM CHARGES. CORRELATED TO BAKER HUGHES MPRG LOG DATED 16 -JAN -2004. JOB IN PROGRESS. 8/25/2015 PERFORATE 10940' - 10970' USING THREE, TEN FOOT, 2.5" HSC, 6 SPF, 60 DEG PHASING 11.6 GRAM MILLENNIUM DEEP PENETRATING CHARGES. LOG CORRELATED TO BAKER HUGHES MPRG LOG DATED 16-JAN-2004. JOB IN PROGRESS 8/26/2015 PERFORATED 10880'- 10940' USING 2.5"6SPF, 60 DEG PHASING, 11.6 GRAM MILLENNIUM DEEP PENETRATING CHARGES. CORRELATED TO BAKER HUGHES MPRG LOG DATED 16-JAN-2004. JOB SUSPENDED UNTIL MORE CHARGES ARRIVE IN DEADHORSE. 9/1/2015 PERFORATE 10820' - 10880' USING TWO 20' GUNS AND 10' GUNS IN TANDEM USING 2.5" HSC 6 SPF, 60 DEG PHASING 11.6 GRAM MILLENNIUM DEEP PENETRATING CHARGES. LOG CORRELATED TO BAKER HUGHES MPRG LOG DATED 16-JAN-2004. 9/2/2015 PERFORATE 10790' - 10820', 10760'- 10790', 10730'- 10760' USING 2.5" HSC 6SPF, 60 DEG PHASING, 11.5 GRAM, MILLENNIUM DEEP PENETRATING CHARGES. CCL TO TOP SHOT: 7.8'. LOG CORRELATED TO BAKER HUGHES MPRG LOG DATED 16-JAN- 2004. 9/3/2015 PERFORATED SECTION 10,730 - 10,700, AND 10,700 - 10,670 Using HSC/2.5 Millenium SDP SPF/ Phasing: 6 spf/60 degree, for each gun zero to top shot 7.8' 9/4/2015 PERFORATED INTERVAL 10655-10670. FIRED AT A CCL STOP DEPTH OF 10647.2', WITH A CCL TO TOP SHOT OFFSET OF 7.8'. BECAME STUCK AT 10315'. PULLED OUT OF WEAKPOINT. ** FISH LEFT IN HOLE. LENGTH =41.5', WEIGHT = 340 LBS AND MAX OD = 2.5"** 9/5/2015 ATTEMPTED LATCH ELINE TOOLSTRING @ 10,327' SLM (METAL DEBRIS IN P/T). TAGGED FISH WITH PUMP BAILER @ 11,222' SLM (RECOVERED METAL SLAG), RAN BRUSH /MAGNET ASSY' (RECOVERED METAL SLAG), UNABLE TO PASS 10,959' SLM. IN PROGRESS. 9/6/2015 RECOVERED METAL DEBRIS & SAND @ 10,955' SLM. JOB SUSPENDED. 9/17/2015 BAILED THROUGH BRI D @ 10954' SLM (PASS THROUGH SEVL MORE TIMES W/ NO PROBLEM) & BA ETAL DEBRIS/FILL @ 11218' SLM opourN MARKS ON BAILER BOTTOM). IN PROGRESS. 9/18/2015 RECOVERED LOST E/L TOOL STRING @ 11,218' SLM. JOB COMPLETE. e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~-Lf - - 00 q. Well History File Identifier Organizing (done) D Two-sided ""11111111111111I D Rescan Needed III 11111I11 II 1I11II RES CAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: D Diskettes, No. D Maps: D Greyscale Items: D Other, No/Type: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: (_Maria~ Date 3/1,'7/ob 151 V\1~ 1111111111111111111 Project Proofing BY: ~ Date 3/IS/ D0· 151 mp Scanning Preparation + ~ = TOTAL PAGES~ P (Count does not include cover 5 eet) BY: Date: 151 11111111111111 1111I Production Scanning Stage 1 Page Count from Scanned File: !:f!l- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:3/lS/ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO IS/V'\1 P NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned III 1111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked III "1111111 "11111 10/6/2005 Well History File Cover Page.doc • Wallace, Chris D (DOA) From: Dethlefs, Jerry C[Jerry.C.Dethlefs @conocophillips_com] Sent: Thursday, September 19, 2013 11:16 AM To: Wallace, Chris D (DOA); Regg, James B(DOA) Cc: Dethlefs, Jerry C; Nenahlo, Thomas L Subject: Meltwater 2P-424A(PTD 204-009) Report of suspected IA x OA communication Follow Up Flag: Follow up Flag Status: Flagged Chris and Jim: Meltwater well 2P-424A(PTD 204-009) is an MI gas lifted producer that has recently required bleeding the OA in an attempt to keep a differential between the IA and OA pressures as per CPAI Well Operating Guidelines. On Tuesday a TIFL and production casing packoff test failed on the well.These mechanical issues are suspected to be the source of the OA pressure fluctuations and we are addressing them as follows: Slickline will attempt repairs on the gas lift design; and we are planning troubleshooting the packoff assembly. Attached is a 90-day trend plot and welibore schematic diagram for your information. Let me know if you have any questions. 2P-424A is one of the producers that we will discuss at the meeting that we requested with you regarding our upcoming plans at Meltwater.Tommy Nenahlo and I are available for the proposed meeting early next week and we look forward to setting up a time that will accommodate your schedules. Jerry Dethlefs t pio 2P-424A 2P-424A 90 Day Diagram.pdf Trend Plot 9-18... SCANNED DEC 2 32013 Well Integrity Director ConocoPhillips Alaska Office:907-265-1464 Cell:907-268-9188 1 • • - CHOKE FTP - FTT IAP OAP T/I/O Plot-2P-424 , . . , . . , . . . . 200 1000 = 150 800 E m a 600 ' _ 100 Y 400 = v .- rj — 50 200 'r' 0 0 18-Jun-13 01-Jul-13 14-Jul-13 27-Jul-13 09-Aug-13 22-Aug-13 04-Sep-13 17-Sep-13 Date r, KUP • 2P-424A ConocoPhillips c=44 Well Attributes AMax Angle&M DTD WI Name Alaska.Inc. Wellbore APIIUWI Field Name Well Status Inc!(`) MD(ftKB) Act Btm(ftKB) Larx><oi+hiil,ps 501032047501 MELTWATER PROD 70.82 8,267.06 11.539.0 Comment H2S(ppm) Data Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:NIPPLE 18 12/11/2012 Last WO: 35.30 1/10/2004 Well Confi9'.-2P-424A,6126/2013 8:54'.30 AM Scnemeec-Actuel Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 10,867.0 3/10/2013 Rev Reason:TAG lehallf 6/26/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String String Top Thrd CONDUCTOR 16 15.062 282 108.0 108.0 62.50 H-40 WELDED 1 ...... PP Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String String Top Thrd HANGER.25 SURFACE 9 5/8 8.835 28.2 3,005.8 2,386.7 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 51/2 4.950 25.4 11,530.4 5,870.5 15.50 L-80 BTC-MOD . 5.5"x3.5"/6 10428' I Tubing Strings I Tubing Description String O. String ID...Top(ftKB) Set Depth If Set Depth(TVD)...1St ring Wt r St 1 ng String Top Thrd TUBING I 31/2 I 2.992 255 10.4070 54878 j 9,30 j L801 EUE8RDMOD CONDUCTOR. - - - "-- Y 28-108 Completion Details Top Depth NIPPLE,497 - (TVD) Top lncl Nom^. ill Top(ftKB) (ftKB) F) Item Description Comment ID(') 25.5 25.5 -0.21 HANGER FMC GEN V TUBING HANGER 3.500 II 496.8 496.4 6.16 NIPPLE CAMCO DS NIPPLE LANDING NIPPLE NO GO 2.875 GAS LIFT 10,343.2 5,465.4 69.41 SLEEVE-C BAKER CMU SLIDING SLEEVE w/NO GO PROFILE-CLOSED 2.810 2,814 11/9/2009 10,359.2 5,471.0 69.42 NIPPLE CAMCO D NIPPLE w/NO GO PROFILE 2.750 I 10,403.3 5,486.5 69.45 LOCATOR BAKER G-22 LOCATOR 3.010 10,404.31 5 486.9' 69.45`SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date Ich,.. Type Comment VI 10,850.0 10,862.0 5,640.2 5,644.2 T-3,2P-424A 2/15/2004 6.0 IPERF 2.5"HSD Guns SURFACE, A I Bottom 28-3'008 Min Top Max Btm Top Depth Depth Ek Depth Depth (TVD) (TVD) (kKB) (ftKB) 5.640.2', 5.644 2 Type Date Comment kKB OMB) GAS LIFT, 10,850.0 10.862.0 FRAC _2.162004 PLACED 210,841#OF 16/20 5,357 Notes:General&Safety . End Date _- Annotation IX 1/18/2004 NOTE:2P-424 drilled 8 immediately sidetracked for 2P-424A I1/13/2011 NOTE:View Schematic w/Alaska Schematic9.0 a GAS LIFT, ],325 a I a.. GAS,127 ir 9,127 a GAS LIFT, 10,294 ill B E SLEEVE-C, 10,343 M NIPPLE.10,359 - IN I I O LOCAT OR,R. T SEAL ASSY, 10,404 Mandrel Details 1 Top Depth Top Port e (ND) Inc/ OD Valve Latch Si ze TRO Run N...lop(kKB) TVD) (°) Make Model (in) San, Type Type (in) (psi) Run Date Cont... 1 2,613.5 2,203.8 61.77 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 2 5,357.1 3,476.6 62.05 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 3 7,325.0 4,414.2 66.75 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 IPERF, 4 9,126.8 5,040.1 69.97 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 1/18/2004 -10,550 FRAC,10,550 5 10,293.5 5,448.1 69.57 CAMCO KBG-2-9 1 GAS LIFT OV INT 0.313 0.0 11/12/2009 FRAC, PRODUCTION 5.5'03.5"/9 10425', 25-11,530 . • TD(2P-424A), 11,539 H A • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit, NSK -69 PO Box 196105 Anchorage, AK 99519 -6105 ConocoMillip's Phone: (907)659 -7535 Fax: 659 -7314 December 4, 2009 R ECEIVED DEC 0 8 2009 Tom Maunder, P.E Al Oil & Gas Cons. Commis Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission Anr.,hnra0t� 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has changed the Artificial Lift method in a Meltwater Production well. Enclosed you will find 10 -404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for Meltwater well 2P -424A (PTD 204 -009). This report records the conversion from Surface Powered Jet Pump to Gaslifted artificial lift method. If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659 -7535. Sincerely, OL� Robert D. Christensen Attachments RECEIVED DEC 0 8 2000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas C ons. C01'runission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q ❑ SPJP to Gaslift Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 204 -009 3. Address: Stratigraphic ❑ Service ❑ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20475 -01 7. KB Elevation (T: Well Name and Number: RKB 2P -424A Prope Designation: . Field /Pool(s): Kuparuk River Unit �� Kuparuk River Field / Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 11539' feet true vertical 5873' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 16" 108' 108' SURFACE 2753' 9 -5/8" 3005' 2386' PRODUCTION 11278' 5 -1/2" 11530' 5870' PRODUCTION 840' 3 -1/2" 1092' 1073' Perforation depth: Measured depth: 10850 - 10862' true vertical depth: 5640 -5644' Tubing (size, grade, and measured depth) 3 -1/2 L -80, 10422' MD. Packers & SSSV (type & measured depth) 80 -40 Seal Assembly 10407' SSSV =Nip 4997' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure I Tubina Pressure Prior to well operation 215 44 164 1612 1 287 Subsequent to operation 327 24 1 127 1180 1 281 14. Attachments . Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Develop El Service ❑ Daily Report of Well Operations X Well Status after proposed work: Oi10 Gas❑ WAG❑ GINJ❑ WINJ ❑ WDSPL❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact B. Christensen/ D. Humphrey Printed Name o ert D. Chri ensen Title Production Engineering Specialist Signature Phone: 659 -7535 Date la i �� UAA iz >,Ck� Form 10-404 Revised 04/2004 Submit Original Only 2P -424A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/10/09 PULLED 2.81" CS LOCK & JET PUMP (S /N PH -1037) @ 10343' RKB, NO EROSION. SET 2.75" CAT SV @ 10359' RKB. IN PROGRESS. 11/11/09 CIRCULATED IA & TBG TO 210 BBL DSL. CLOSED CMU @ 10343' RKB. MITIA 3500 PSI, PASSED. PULLED DV @ 10294' RKB. IN PROGRESS. 11/12/09 SET 5/16" OV @ 10294' RKB. PULLED 2.75" CAT SV @ 10359' RKB. TAGGED @ 10879' SLM, EST. 3' RATHOLE. COMPLETE. 11/14/09 Commenced Gaslifted production KU P 11111111111111a, 2P -424A ConocoPhillips ell Attributes x Angle & MD rD al.isn,f, Ira. Wellnore APlAIWI Field Name Well Statue In °) MD(RKB) Act Bfm (IIKB) 501032047501 MELTWATER PROD 70.82 8,267.06 11,539.0 Comment H2S (ppm) Data Annotation End Date 1 13rd (R) RID Release Data Wall Cann zP -sz4 1lrzsrzooe t4r.n PM SSSV: NIPPLE 45 10/21/2007 Last WO: 35.30 1/10/2004 Schsmalk- Nal Annatation Depth (ftKS) End Data Annotation Laal Moe By End Oate Last Tag: SLM 10,879.0 11/1212009 Rev Reason: Pull Pump/Close CMU /GLV C/O Imosbor 11/25/2009 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Deacrlp0on (in) (In) Top(ttKB) (RKB) (RKB) (Itni t) Orade String Top Thrill CONDUCTOR 16 15.062 0.0 108.0 108.0 62.50 H-40 WELDED SURFACE 95/8 8.697 0.0 3,005.0 2,386.4 40.00 L-80 BTC HANGER,25 PRODUCTION 51/2 4.950 0.0 11,530.0 5,870.4 15.50 L-80 BTCM PRODUCTION 31/2 2.992 0.0 1,092.0 1,073.0 9.30 L-80 EUE -MD CONDUCTOR, Tubing Strings fOB string Oo string ID set Depth Set Depth (TVD) StrinD Wt string Tubb ng0eacrlptlon IIN IIN Top (RKB) (RKB) IRKS) ( Grade String Top Thrd TUBING 1 31/2 2.992 25.01 10,422.01 5,493.1 9.30 1 L -80 EUE8RDMOD NIPPLE. 497 Other In Hole All Jewel : Tubing Run & Retrievable Fish etc.'' Top Depth (TVD) Top Incl Top (RKB) III ( °) Daecrlp8on Comment Run Data ID (1n) 25 25.0 -0.21 HANGER 3.5" FMC Gen V TUBING HANGER 1/1812004 3.500 PRODUCTION, 1,oez 497 496.6 6.17 NIPPLE CAMCO'DS' LANDING NIPPLE 1/1872004 2.875 2,614 2,204.0 61.77 GAS LIFT CAMCO1KBG -2 -9/1 /DMY /INT /// Comment: STA 1 1/18/2004 2.900 5,357 3,476.6 62.05 GAS LIFT CAMCO/KBG -2 -9/1 /DMY /INT /// Comment: STA2 111812004 2.900 GAS LIFT, 7,325 4,414.2 66.75 GAS LIFT CAMCO/KBG-2 -9/1 /DMY /INT// /Comment: STA3 1/18/2004 2.900 2,614 9,127 5,040.1 69.97 GAS LIFT CAMCO/KBG -2 -9/1 /DMY /INT / / / Comment: STA4 1/18/2004 2.900 10,294 5,448.3 69.57 GAS LIFT CAMCO /KBG- 2- 9 /1 /OVANT /.313 // Comment: STA 5 11/1212009 2.900 SURFACE 005 10,343 5,465.3 69.41 SLEEVE-C BAKER CMU SLIDING SLEEVE W INO GO PROFILE - 1118/2004 2.810 CLOSED 11/9/2009 10,359 5,470.9 69.42 NIPPLE CAMCO'D' NIPPLE W /NO GO PROFILE 1/18/2004 2.750 GAS 10,403 5,486.4 69.45 LOCATOR BAKER G-22 LOCATOR SEAL ASSEMBLY 1/1812004 3.000 5311 10,407 5,487.8 69.45 SEAL 80-00 SEAL ASSEMBLY W /HALF MULE SHOE 1/1812004 3.000 10,422 5,493.1 69.46 TTL 1/18/2004 2.990 Perforations & Slots I shot TOp (TV DI St. (TV D) Dena Top ltsee) Btm RKB) (RKB) (RKB) Zone Dab 1-11 Type Comment 10,8501 10,8621 5,640.2 5,644.2 T -3, 2P -424A 2/15/2004 1 6.0 IPERF 2.5" HSD Guns Stimulations & Treatments GAS LIFT BOROm 7.325 Min Top Mex Btm Top Depth Depth Depth Depth (TVD) (TVD) (RKB) (RKB) (RKS) (RKB) Type Data Comment 10,850.01 10,862.01 640.2 5,644.2 FRAC 12116t2004 I PLACED 210,841 # OF 16/20 Notes: General & Safe End Date I Annotation 1/18/2004 NOTE: 2P -424 drilled & immediately sidetracked for 2P424A GAS L FT 9 121 I GAS LIFT 10 294 SLEEVE C 10343 1 i t NIPPLE, 10 359 I l LOCATOR. 10 403 SEAL, 10, 401 TTL 10422 IPERF, 10,650-10,862 FRAC, 10,850 PRODUCTION, 11,530 To(ZP- 424/), f 1,536 I • • (f~~LL. L~i.7 ~~/~#~~~~~~~ , ~ ~~_ P~coAcri~ Diaynosric SesvicES, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907~ 859-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTi') The technical data listed belaw is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. AtCn: Robert A. Richey 130 West Ir~ternational Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1 J Caliper Report 04Aug-09 2) Caliper Report 0&Aug-09 ,--%?\ . ~-~ ' j r7~-'(.../ ~_..i J;J ; ~ '~: :~ C~, ~~~~~ ~~~~ 2P-~124A 1 Report / EC~ 2P-415A 1 Report / E~ ~ ~,~~,u r t,, ~eW ~,~:rv'~lti~r'~wa:sr ~.~1~-.. . ~ ~tJ:#;i ;, , ,, j r! i~ 1 r : Signed : ~ ,i' ~;~ ,r _, v~. Print Name: 75-0 50-103-20383-01 , ; G j'i j ~ ~~~ i ~ ~ Date _ r _~ . . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 9951$ PHONE: {907~245-8951 FAx: (907)245-88952 E-MAIL : a J; _„ j WEBSITE , r::t, *' r" ,--r C:~Documents and Settings\OwnerlDesktop\Transmit_Conoco.doc~c 1~ ~ ~ _ ~ ~ ~ Memory Mult'rFinger Caliper & MTT Log Results ~ummary Company: ConocoPhillips Alaska, inc. Well: 2P-424A Log Date: August 4, 2009 Field: Meltwater Log No. : 7355 State: Alaska Run No.: 2(MiT & MTT) API No.: 50-103-20475-d1 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log intvl.: Surtace Pipe1 Use: Tubing and Production Casing Bot. Log Intvl.: 10,492 Ft. (MD) Pipe2 Desc.: 5_5" 15.5 Ib BTCM Top Log Intvl.: 2,980 Ft. (MD) (MTT only) Pipe2 Use: Production Casing Bot. Lag Infirl.: 10,492 Ft. (MD) (MTT only) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This Caliper/MTT data is tied into the `D' Nipp/e @ 10,359' (Driller's Depth). This is the second time this well has been logged with a PDS Caliper and a 12 Arm Magnetic Thickness Tool (MTT}. The MT7 responds to the total thickness of inetal of the 3.5" tubing and 5.5" / 3.5" production casing. A single 10Hz pass was made at 20 fpm. The additional metal volume of tite 9.625' surface casinp prevented the normal functioninp of the MTT. so no interoretable results are availa6/e from the enQl ofthe 9.625" surface casinr~ ro surtace• INTERPRETATION OF CALIPER LOG RESULTS: This log was run to assess the condition of the tubing and production casing with respect to intemal corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and production casing iogged are in good condition, with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. ~ This is the second time a PD5 catiper has been run in this well and the 3.5" tubi~g has been logged. A comparison of the current and previous log (August 13, 2007) indicates no change in the internal condition of the tubing during the time beiween lo~s. A comparison graph illustrating the difference of maximum recorded pertetrations on a joint-by joint basis between the current anr! previous log is inctuded in this repo~t. ' 3.5" TUBING ~ CASING - MAXIMUM RECORDED WALL PENETRATIONS: ~ No significant wall penetrations (> 18%} are recorded throughout the tubing and casing logged. 3.5" TUBiNG ~ CASING - MAXIMUM RECORDED CROSS-SECTIQNAL METAL LOSS: ,' No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing and casing logged. 3.5" TUBING ~ CASING - MAXIMUM RECORDED ID RESTRICTIONS: I' No si niflcant I.D. restrictions are recorded throu hout the tubin and casin 1 ed. , 9 5 9 ~99 ' ProActive Diagnostic Services, Inc. / F.O. Box 1369, Skaffard, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.cam Frudhoe Bay Field Office Phone: !907) ~59-2307 Fax: (9Q7) 659-2314 1 ~ ~~~,~ (~y~ ~~1 ~~l ;3~1 . ~ COMPARISON TI~ PREVIOUS MTT LOG RESULTS: A comparison of the current 10Hz pass to the previous 10Hz pass (August 13, 2007) indicates no significant change in metal thickness during the time between logs. The current log was pulled at 20 fpm while the previous Iog was run at 40 fpm. The stower logging speed used for the current log resu{ts in a much more stable tool response to m~tal votume surrounding it, and may be a sign~cant factor to any differences between the two consecutive logs. INTERPRETATION OF MTT LOG RESULTS : The 10Hz MTT log results cover the interval ftom 2,980' to 10,492'. The MTT log results indicate no intenials of significant overall metal loss (>4%) throughout the interval logged below the 9.625° surtace casing, ranging consistently 2-4%within the interval ~7,180' --8,960'. Most of the fluctuation in metal volume observed appears to be related to differences in manufactured tolerances in the tubing and casing joints. A plot of average metal thickness relative to the calibration points on a joint-by joint basis is included in this repott. Changes in metal volume are relative to the cafibration points at 4,017' and 10,465', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing and 5.5" / 3.5" production casing. A maximum overaJl metal volume loss of 4°/a is indicated in tubing joint 274 (8,552' - 8,582'), which appears to be associated with a thinner tubing joint. The MTT recordings exhibit varying isolated even# pattems, resembling lines af isolated metal loss, bands of isoiated me#al loss and some areas of widespread / general isvlat~d metal loss. Some periodic tool surge is indicated throughout the logged interval, which may exaggerate some of the individual sensor readings. However, these patterns of isolated metal loss indicatians point to potential areas of minor volumetric metal loss to fhe outside of the tubing or more significant damage to the production casing. Details of the current 10Hz MTT reco~dings, a~ong with the 2007 Delta Metal Thickness curve, over the intervafs (5,490'-5,840'), {7,995'-8,350') and (8,910'-9,040') are included in this report to show these patterns. The percent circumferential metal loss expressed in this summary is a percentage of the total metal the tool is responding to, which includes influences from the 3.5" and 5.5° pipe. I# all of the metal loss is specific to the 3.5" tubing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. The metaf loss indicated could be from either or both the 3.5" tubing or 5.5" production casing. Field Engineer: Wm. McCrossan Analyst: C. Waldrop {Ml'1) / HY. Yang & J. Burtan (MTT) Witness: C.Kennedy ProActive Diagnostic Services, Inc. / P.~. Box 1369, Stafford, TX 77497 Phone: (281) ar (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field OfFice Phone: (907) 659-2307 Fax: (90?} 659-2314 ~ ~ Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (-6.4' - 104753') Well: 2P-424A Field: Melcwater Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 4, 2009 ~ Approx. Tool Devia6on ^ Approx. Borehole Profite j ~ ~ ~ 50 ` 1524 GI_M 1 ~ 100 3099 150 4652 0 ~ GLM 2 v ~ ~ ' " ~ .__ Z 200 - 6221 Q ~ ~ , a, o p GLM 3 250 7797 GLM 4 300 9384 GLM 5 332 10475 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) f3ottom of Survey = 332 ^ • Maximum Recorded Penetration <--~'~. ~~ Comparison To Previous Well: 2P-424A Survey Date: August 4, 2009 Field: Meltwater Prev. Date: August 13, 2007 Company: ConocoPhillips Alaska, Inc Tool: UW MFC 24 No. 218370 Country: USA Tubing: 3.5" 93 Ib L-BO EU68RD MOU OVPI'IdV Max. Rx. Pen . (mils) 0 5 0 1 00 1 50 2 00 25 0 0.1 72 °3 35 47 59 71 83 92 ion 116 728 140 152 ` w E 164 Z 173 0 185 ^ 197 209 221 233 242 2 54 266 278 - 290 299 311 323 329 # August 4, 2009 ^ August 13, 2007 ~ ~ ---- PDS Report Overview 1 sa. Body Region Analysis Well: 2P-424A Survey Date: August 4, 2009 Field: Meltwater Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fngers: 24 Anal st: C. Waldrop lubing: Nom.OD Weight Grade & Thread Nom.lU Nom. Upset Upper len. Lower len. 3.5 ins 93 f L-80 EUE-8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins PenMration and Metal Loss (°~6 wall) ~ penetra6on body ~ metal loss body 2 50 200 150 100 50 ~ 0 t~o 1 to 1% 10`% 10 to 20 to 40 to over 20% AO% 85% 85% Number of ~oints anal sed rotal = 349 pene. 0 225 loss 108 241 124 0 0 0 0 0 0 0 Damage Configuration ( body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (°~ wall) ~ penetration body ;.:,~,;; metal (oss body 0 50 100 0 GLM 1 98 GLM 2 196 GLM 3 GLM 4 GLM 5 Bottom of Survey = 332 Analysis Overview page 2 • , PDS REPORT JOINT TABULATION SHEET Pipc: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: 2P-424A Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 4, 2009 Joint No. Jt. Depth {R.) I'~~n. ~ t~,sc>t (In~.) Pen. f3ody (Ins.) Pcn. °~~ Mctal I c~ss ~~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 -6 ~~ 0.01 2 1 2.93 PUP 1 -4 ~ ~ OA2 ~~ 5 2.94 28 ~~ OA ~) 5 .93 3 59 i) 0.03 1 1 -1 2.93 4 91 t~ 0.02 ~) -1 2.94 5 121 l1 0.02 t~ 2.96 6 153 U 0.01 5 ' 2.95 7 184 ~~ 0.03 1 1 4 2.93 8 216 ~~ 0.03 11 t~ 2.96 9 247 ~~ 0.0 ' 4 2.93 10 2 79 U 0.02 7 ~ 2.95 11 3 9 U 0.03 I Z (~ 2.95 12 340 l~ 0.03 12 ~~ 2.95 13 371 ~~ 0.03 I1 5 2.95 14 402 ~) 0.02 ti ~ 2.95 15 433 U U.03 I3 i, 2.94 15.1 465 U 0 U ~~ 2.88 Camco DS-Ni le 16 466 U OA2 ~t -1 2.93 17 498 t~ 0.03 I 2 2.96 18 529 U 0.03 1_; ~~ 2.94 19 561 ~ ) 0.01 ~ 2.92 20 592 i~ 0.02 ~~ ~ 2.95 21 624 U 0.03 13 2.95 22 654 U 0.03 12 -t 2.94 3 685 U OA3 11 .94 24 716 U 0.04 14 ! 2.93 2 747 U 0.01 6 _' 2.91 26 779 ~~ 0.01 6 ~; 2.94 27 810 U OA2 9 _~ 2.94 28 841 l~ 0.02 7 1 2.94 29 87 t~ 0.03 12 ' .93 30 904 u 0.02 f~ 2.93 31 9 5 ~~ 0.03 11 ~, 2.94 32 967 ~~ 0.03 I ~~ ~ 2.92 33 998 t l 0 03 I~ 2.96 34 1029 O 0.03 11 1 2.91 35 1060 ~l 0.03 11 1 2.93 36 1091 l~ 0.01 6 1 2.93 37 1122 ~? 0.02 7 ~' 2.93 38 1152 ~~ 0.02 ~) I 2.93 39 1184 i~ 0.03 13 ~? 2.92 40 1215 11 0.03 11 i 2.91 41 1246 u 0.02 ~~ I 2.92 42 1277 ~~ 0.02 9 I 2.93 43 1306 (1 0.0 7 I .93 44 1338 U 0.01 5 ~' 2.93 45 1369 ~~ 0.03 lU 1 2.93 46 1400 u 0.03 1l1 i 2.94 47 1432 ~'~ 0.04 14 -1 2.93 48 14fi 3 0.02 ~~ 2.92 Penetralion Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 P-424A Meitwater ConocoPhillips Alaska, Inc USA August 4, 2009 Joint No. Jt. Depth (Fk) I'~~n. I1E~,~•~ (In~ 1 Pen. Body (Ins.) Pc~n. `%, 1~1c~t,al loss ~~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1493 ~~ 0.02 t~ _' 2.93 50 1524 u 0.02 ~~ _' .94 51 1556 ~~ 0.01 t> 1 2.93 52 1587 l1 0.02 ' ~ 2.94 53 1619 ~~ 0. 1 (, ' 2.9 54 1650 U 0.0 t3 I 2.91 55 1680 O 0.02 i 2.95 56 1712 t~ 0.02 - 2.92 57 1743 t~ 0.02 - 2.93 58 1774 ~~ 0.03 I3 ~ 2.93 59 1806 t t 0.03 1~ .94 60 183 7 ~~ 0.01 (> 1 2. 1 61 1867 ~~ 0.01 4 ~' 2.92 62 1898 ~~ 0.01 (~ ~~ 2.95 63 1930 ~~ 0.03 lU (~ 2.94 64 1961 ~ i 0.01 4 I 2.94 6 1993 U 0.02 - I 2.94 66 2023 u OA t~ 2.95 67 2054 u 0.01 (~ i~ 2.94 68 2085 t ~ 0.02 7 1 2.90 69 2114 l) 0.02 ~~ 2.92 70 2146 l1 0.01 6 ' 2.91 71 2177 ll 0.01 6 ~~ 2.93 72 2208 ~~ 0.02 ts I 2.94 73 239 t~ .01 i~ I .94 74 2271 u 0.01 ~~ I 2.93 75 230 c ~ 0.02 7 2.91 76 2333 u 0.01 -1 I 2.93 77 2365 U 0.03 1 Z 2.93 78 2396 i~ 0.03 1 t ' 2.92 79 42 7 ~) 0.03 1 1 ' 2.92 80 2459 ~~ 0.03 1 Z I 2.92 81 2490 ~~ 0.01 5 _' 2.91 82 2521 ~~ 0.01 6 _' 2.91 83 2553 ~) OA2 7 ' 2.92 83.1 2582 ~) OA2 £9 2.94 PUP 83.2 2588 U 0 U U N A G M 1 Lat h~ 12:30 83.3 2594 U 0.01 S ~' 2.96 PUP 84 2600 U 0.01 6 I 2.93 85 2631 t~ 0.03 1_~ I 2.93 6 2662 l) 0.01 5 ' .93 87 2694 t) 0.02 ti ! 2.95 88 2725 ~t 0.03 1, ~ 2.91 89 2757 ~~ 0.02 ~3 I 2.92 90 2788 ~~ 0.03 1' I 2.94 91 2819 ~~ 0.02 ~i I 2.92 92 2851 U 0.01 6 I 2.95 93 2882 u 0.02 7 ? 2.93 94 2914 ~ 1 0.03 1"3 .94 95 2945 u 0.01 5 2.92 Penetration Body ~ Metal Loss Body Page 2 i • PDS REPORT JOINT TABULATION SHEEf Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: 2P-424A Body Wall: 0254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 4, 2009 Joint No. Jt. Depth (Ft.) I'c~n. t1E~s<~t (In~.) Pen. Body (Ins.) Pcii. % ~1~~i,~l I~>tis "~~~ Min. I.D. (Ins.) Comments Damage Profile (%wali) 0 50 100 6 2974 ~ ~ 0.02 ~~ ' 2.92 97 005 t~ 0.02 ~ 2.92 98 3036 ~~ 0.03 II .' 2.9 99 3067 i~ 0.02 ~ ' 2.92 100 3099 ~~ 0.03 1~' 2.92 101 3130 i) 0.02 8 ~~ 2.91 102 3160 i~ 0.03 I~ 1 2.93 103 3192 t~ 0.02 7 1 2.94 104 32 3 i! 0.02 t~ 4 2.95 105 3254 ~ 1 0.03 1 ~' ~ .93 106 3285 l~ 0.03 1~1 ? 2.94 107 3316 U OAl 6 Z 2.91 108 3348 u 0.03 11 I 2.9 109 3380 t~ 0.03 1 Z I 2.90 110 3411 U 0.01 t~ ? 2.93 111 3442 u 0.02 ~> ' 2.92 112 3473 U 0.02 ti ' 2.91 113 3504 U OA 9 _' 2.88 114 3535 ~~ 0.02 ' ' 2.91 115 3567 U 0.03 11 ~ 2.90 116 3597 ~1 0.04 14 I 2.93 117 3628 U 0.03 1~' I 2.93 118 3660 ~~ 0.01 5 ' 2.91 119 3691 U 0.02 f3 Z 2.93 120 3722 11 0.01 6 _' 2.93 121 3753 ~~ 0.04 14 ; 2.93 122 3784 t~ 0.03 11 _' 2.95 123 3814 ~) 0.03 1U 1 2.92 124 3846 t) 0.03 1I _' 2.92 125 3877 i~ 0.04 1 ts 2.93 126 3909 ( ~ 0.03 I l) I 2.91 127 3940 t) 0.04 14 i 2.91 128 3971 U 0.03 11 2.92 129 4003 U 0.03 11 ~' 2.92 130 4034 ~) 0.01 5 1 2.93 131 4065 ~ i 0.02 9 ~' 2.93 132 4096 t~ 0.01 5 I 2.94 133 4127 ~~ 0.02 f3 _' 2.92 134 4157 ~~ 0.03 1 U 2 92 135 4188 u 0.02 ~> I 2.93 136 4219 u 0.01 6 1 2.93 137 4251 U 0.03 13 ~~ 292 138 4281 u 0.01 ~ ~' 2.93 139 4312 l1 0.03 12 ~' 2.92 140 43a4 ~~ 0.03 11 i 2.93 141 4375 i~ 0.03 1 l) ' 2.91 142 4406 U 0.02 7 ' 2.91 143 4437 ~~ 0.03 1O ~ 2.92 144 4469 ~~ 0.04 1 5 ~ 2.91 145 4499 ~'~ Q01 ' 2.92 ~ Penetration Body Metal Loss Body Page 3 . • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: 2P-424A Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nomina) i.D.: 2.992 in Country: USA Survey Date: August 4, 2009 Joint No. Jt. Depth (Ft.) Pc~n. Up,~~t (In4.) Pen. Body (Ins.) f'c~n. °~ ~1c~t,~l I~>,s .~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 1UU 146 4530 U 0.01 (> 2.93 147 4561 ~) 0.02 9 -t 2.95 148 4593 t~ 0 02 9 ~ 2.R1 149 4622 ~~ 0.03 13 ; 2.94 150 4652 U 0.01 i 1 2.95 51 4683 ~) 0.02 `~ 1 .90 15 4714 U 0.03 II 1 2.92 153 4745 U 0.02 2.90 154 4777 ~) 0.03 1t) 2.93 155 4808 u 0.03 l;i -1 2.93 156 4839 i) 0.03 11 I 2.93 157 4870 U 0.03 0 I 2.91 158 4901 c 1 0.03 1 l1 _' 2.91 159 4932 i~ 0.02 ~> 2.94 160 4963 c) 0.02 ' s 2.92 161 4994 O 0.03 1 1 1 2.92 162 502 3 ~) 0.03 1 ~' .93 163 5055 U 0.03 II 1 2.91 164 5086 t~ 0.02 7 Z 2.92 165 5117 (~ 0. 2 ~) ~' 2.92 166 5148 u 0.03 13 ~3 293 167 5179 l~ 0.02 7 2 2.93 168 5209 t 1 0.03 1 1 1 2.91 169 5240 U 0.02 ti 1 2.91 170 5272 O 0.02 tf I 2.96 171 5303 l) 0.03 ~I1 I 2.92 171.1 5334 O 0.0 7 I 2.95 PUP 171.2 5340 U 0 (1 l1 N A GLM 2 Latch ~ 4:30 1713 5347 ~1 0.01 b 2 2.95 PUP 172 5352 t) 0.03 1O 2 2.92 173 383 ~> 0.03 1 U 1 2.90 174 5413 U 0.02 ~) I 2.91 175 5445 (t 0.04 14 1 2.92 U6 5476 ~) 0.04 15 ; 2.93 177 5506 U 0.01 6 ~? 2.93 178 5536 U 0.01 3 ,1 2.91 179 5568 u 0.03 11 1 2.91 180 5599 U 0.02 ~) _' 2.91 181 5631 U 0.02 ~~ ~~ 2.90 182 5661 ~) 0.03 12 I 2.91 1 3 5692 l1 0.02 7 ? 2.91 184 5723 (1 0.03 11 ~' 2.94 185 5755 (~ 0.02 ~) 2.91 186 5786 ~~ 0.04 14 ~~ 2.92 187 5818 U 0.02 ~~ 1 2.92 188 5849 l) 0.02 ti 2.91 189 5880 (? 0.01 4 1 2.89 190 5912 u 0.02 ~) ? 2.91 191 5941 i~ 0.03 I U 1 2.90 192 5972 ,'~ 0.02 t3 ~ 2.93 ,~ Penetralion Body Metal Loss Body Page 4 ~ • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: 2P-424A Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 4, 2009 )oint No. Jt. Depth (Ft.) I'~~n. ilF~sc~i (In>.) Pen. Body (Ins.) f'c~n. % ~letal loss ~~ Min. I.D. Qns.) Comments Damage Profile (%wall) 0 50 100 19 6003 O 0.02 tS ' 2.91 194 6033 ~~ 0.03 10 I 2.93 195 6065 ~~ 0.03 11 ' 2.91 196 6097 ~~ 0.03 1 l) ? 2.89 197 6128 ~~ 0.03 11 i~ 2.92 198 6159 (~ 0.02 7 I 2.93 199 6190 l~ 0.04 1 5 .91 200 6221 U 0.04 1 b 1 2.92 201 6253 ~~ 0.02 ti I 2.94 202 6284 ~~ 0.01 d ~~ 2.91 203 6315 t~ 0.03 1 1 ? 2.91 204 6347 U 0.03 11 1 2.93 205 6378 tt 0.03 11 I 2.92 206 6409 ~~ 0.04 1 i i 2.91 207 6440 l~ 0.02 9 ' 2.91 208 6471 ~~ 0.0 7 I 2.91 209 6503 t~ 0.03 ~l ~ !~ 2.91 210 6534 t~ 0.02 7 ' 2.92 211 6565 U 0.01 i Z 2.90 212 6595 (~ 0.03 1~~ 1 2 91 213 6626 ~~ 0.02 t3 1 2.92 214 6656 U 0.02 ~) ? 2.91 215 6687 U 0.02 ~ 2.93 216 6718 l1 0.02 ~) 1 2.91 217 6749 U 0. 3 ~ Z 2.9 218 6781 i 1 0.02 7 I 2.92 219 6812 t I 0.04 17 -~ 2.90 220 6842 ~~ 0.02 ~ ' 2.92 221 6873 ~~ 0.03 I U 2 2.91 222 6904 ~ 1 0.02 7 Z 2.92 223 6935 c) 0.03 11 I 2.92 224 6964 i~ 0.02 f3 ! 2.92 225 6995 O 0.04 1 f> 2.95 226 7026 U 0.02 i I 2.94 227 7058 (1 0.03 tU 1 2.91 228 7090 t) 0.02 £3 ' 292 229 7121 u 0.02 9 ? 2.91 230 7152 U 0.02 ~3 1 2.92 231 7183 ~t 0.03 11 ? 2.90 232 7214 t) 0.01 4 1 2.94 233 7245 ~~ 0.03 12 ? 2.93 234 7276 ~) 0.03 10 -~ 2.91 234.1 7308 U 0.04 I4 ! 2.92 PUP 234.2 7312 l) 0 U ~' N A GLM 3 Latch @ 1:30 2343 7319 u 0. 1 ' i 2.96 PUP 235 7326 i~ 0.04 I f, 4 2.93 236 7357 ~~ 0.03 I U i 2.91 237 7389 ~~ 0.02 9 z 2.93 238 7420 U .04 16 3 2.93 239 7452 l) 0.03 12 _' 2.92 Penetration Body Metal Loss Body Page 5 ~ • PDS REPORT )OINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: 2P-424A Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 4, 2009 Joint No. Jt. Depth (Ft.) P~~n. ~JE>~e~t Iln,.) Pen. Body (Ins.) Pen. "'~ ~1<~t,~l I uti~ ~, Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 240 7483 ~~ 0.02 7 -t 2.95 241 7514 ~~ 0.03 1~ ' 2.91 242 7545 U 0.01 5 _' 2.94 243 7576 U 0.04 1 i ~ 2.92 244 7608 t) 0.04 I i 2.91 245 7640 l~ 0.0 12 3 2.95 246 7670 ~~ 0.03 11 ~l 2.93 247 7702 u 0.02 E9 1 2.93 248 7733 U 0.04 15 S 2.93 249 776 ~~ 0.03 13 4 2.93 S 7797 n 0.02 t3 1 2.94 251 7828 i~ 0.03 IU I 2.93 252 7859 tl 0.02 ~> ; 2.94 53 7 91 ~~ 0.02 ~~ I 2.92 254 7922 ~~ 0.02 ~~ _' .93 55 7953 U 0.03 11 ~ 2.93 256 7985 U 0.04 16 -i 2.92 257 8016 ~~ 0.04 15 I 2.92 258 8048 i) 0.01 5 2.94 259 8079 u 0.03 1 Z -1 2.91 260 8111 ~? 0.02 ~ 1 2.88 261 8143 (1 0.01 t, _' 2.92 262 8175 i? 0.03 I1 ~ 2.92 263 8205 ~~ 0.02 9 =1 2.93 4 237 U 0.03 ll) -~ 94 265 8268 U 0.03 1~? ~ 2.91 266 8299 ~? 0.01 i I 2.93 267 8331 ~1 0.03 1Z ~~ 2.93 268 8363 ~~ 0.03 1 1 3 2.93 269 8394 ~~ 0.02 1 2.94 70 8425 U 0.03 1I 5 2.93 271 8457 u 0.02 ~) ~t 2.94 272 8488 0 0.03 10 I 2.93 273 8520 0 0.04 1~ 4 2.93 274 8551 U 0.03 11 2.93 2 75 8583 n 0.02 7 I 2.93 276 8614 t) 0.04 1 i (, 2.91 277 8645 t~ 0.03 1I S 2.92 278 8678 ~! 0.02 ~) ' 2.92 279 8709 !~ 0.03 I' _' 2.90 280 8740 (~ 0.0 ~~ I 2. 2 281 8772 U 0.01 (> > 2.93 282 8803 ~) .03 12 d 2.93 283 8835 ~~ 0.01 ~ I 2.94 2 4 8866 t) 0.02 ~) -~ 2.93 285 8897 ~1 0.01 4 1 2.94 286 8929 U 0.01 5 I 2.95 287 8959 ~~ 0.02 ~~ 2.92 288 8991 0.03 ' ! 2.92 289 9022 ~ 0.03 ~~~ 2.93 ~ Penetration Body Metal Loss Body Page 6 ~ • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD MOD Well: 2P-424A Body Wall: 0.254 in Field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 4, 2009 Joint No. Jt. Depth (Ft.) I'c~n. t JF~;c~t (In~.) Pen. Body (Ins.) P~~n. ",~, ~~Ic~t,il I o~s "4, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 290 9055 t) 0.03 1U _' 2.91 291 9085 U 0.01 i I 2.9 291.1 9117 t) 0.02 ,' 1 2.96 PUP 291.2 9122 ~) 0 (~ u N A GI.. 4 Latch N A 2913 9128 ~~ 0.03 11 ~ 2.96 PUP 29 9134 U 0.04 14 2 2. 8 293 9166 U 0.01 ~ 1 .90 294 9197 U 0.04 14 Z 2.92 295 9229 U 0.02 tS ~' 2.91 296 9260 U 0.02 £9 ~s 2.91 297 9291 U .01 6 ~' 2.92 298 9322 u 0.01 6 ~~ 2.91 299 9353 ~ 1 0.02 ts I 2.92 300 9384 ~? 0.02 .93 301 9416 U 0.01 ~~ _' 2.91 02 9447 l1 0.01 I 2.92 303 9478 U 0.04 i b ' 2.90 304 9510 ~~ 0.02 ~ I 2.94 305 9541 ~> 0.01 6 l 2.92 306 9570 ~~ 0.~2 4 2 2.89 307 9600 ~ ~ 0.02 ~) ' .90 308 9633 ~) 0.03 I U 2.91 309 9663 U 0.02 9 I 2.89 310 9695 ~1 0.03 11 <' 2.90 311 9726 ~) 0.02 7 ? 2.9 312 9757 U 0.03 12 ? 2.90 313 9788 ~~ 0.02 t3 _' 2.91 314 9820 t~ 0.04 14 ' 2.92 315 9851 ~~ 0.03 11 _' 2.92 316 9883 ~~ 0.02 ti I 2.90 317 9914 t~ 0.02 ~1 2.91 318 9945 t~ 0.03 I( i ~ 2.92 319 9977 U 0.03 II _' 2.90 320 10008 (1 0.02 7 ' 2.93 321 1 036 t) 0.02 f~ 1 2.92 322 10068 l~ 0.02 7 ' 2.90 32 100 9 t~ 0.02 7 I 2.91 324 10130 ~~ 0.01 6 ~' 2.93 325 10162 ~~ 0.02 ti ~' 2.93 326 10193 c~ 0.04 1-3 2.93 327 0 25 i~ 0.01 5 2.93 328 10256 ~? 0.02 £3 2.92 328. 10 82 t~ 0.01 2 I 2.91 PUP 328.2 10289 (1 0 U t) N A GLM 5 Latch N A 3283 10298 u 0.02 ~) _' 2.91 PUP 329 10306 ~~ 0.01 E~ 1 2.92 329.1 10337 ~~ 0.03 I~' -1 2.90 PUN 329.2 10344 i! 0 i~ U 2.81 Baker CMU Slidin Sleeve 329.3 10347 ~~ 0.01 ~' ~ 2.95 PUP 329.4 10353 ~? 0.03 2.91 PUN ~Penetration Body Metal Loss Body Page 7 ~ + PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8KD MOD WeIL• 2N-424A fiody Wall: 0.254 in field: Meltwater Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 4, 2009 )oint No. Jt. Depth (Ft.) I'~~n. I lp,<~i (Irn.) Pen. Body (Ins.) {'c~n. `%> :~Ic•ial I~»s "'~~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 329.5 10359 ~1 0 U ~ 2.75 Camco D-Ni le W No Go Profile 329.6 10361 ~~ 0.04 15 2.90 PUP 330 10366 ~~ 0.02 tt I .93 330.1 10396 ~! 0.02 '~ ~~ .90 PUP 330.2 10403 U 0 U t~ 3.00 Baker G-22 Locator 330.3 10433 ~~ 0 e~ ii 3.00 80-40 Seal Assembl W Half Mule Shoe 330.4 10439 t~ 0 (~ ~~ 2.99 3.5" Tubin Tail 330.5 10441 ~~ 0.01 ~' I 2.92 PUP 331 10444 ~~ 0.03 1O _' 2.91 To of 3.5" Production Casin 332 10475 ~~ 0.03 1 t I 2.93 _ Penetration Body Metal Loss Body Page 8 ~ • l OHz Average Recorded Metal Thickness Relative to Calibration Point 3.5" Tubing /5.5" Production Casing Well: 2P-424A Field: Meltwater Co-npany: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 4, 2009 ^ D ecrease . In crease 100 3099 125 3877 150 4652 GLM 2 175 5445 200 6221 ~ ` ~ a , ~ - LL ~ 225 6995 ,c Z s c GLM 3 ' Q- w o p 250 7797 275 8583 GLM 4 300 9384 325 10162 GLM 5 sia~ny s~e r aNippie LocaMr 1 Seal Assemd / lTl y 332 10475 - 50% 0 5 0% C hange in Metal Thick ness (% ) Bottom of Survey = 332 0 ing pparent Line of Isolated Metal Jt. ~61 8180 Tubing Jt. 262 Collar 82Q0 Tubing Jt. 263 8~'"?0 8~40 Tubing Jt. 264 A parent Line of Isolated Metal 8260 Coliar80 Tubing Apparent Line of Isolated Jt. ~65 Tubin~ Apparent Line of Isolated Metal Loss Jt. ~66 8320 Casiny Callar Tubin Colla - ~-- ~•~ - Tubing Line Spee Jt-'67 - 2009 Delta Metal Thickness ?0 ~007 Delta Mtl. Thickness (%) 20 ~.6 MTTP01 (rdd) 1~.6 -20 2009 Delta Mtl. Thickness (%) 20 -6.~ MlTP1~ (rad) 3.8 0 Line Speed (ft/min) -200 Deta~ 10Hz MTT Recordings Showing ~spread Isolated Metal Loss 2P-424A August 5, 2~09 P(MA[:fIVE DI~M06TIC SERV~CES~ INC. Database File: d:lwarriorldata12fr24~a1plotslplot1.db Dataset Pathname: runllOHzPas Presentation Format: 26 BW~1 Dataset Creation: Fri Aug 07 11:18:~11 2009 Charted by: Depth in Feet scaled 1:24fl -20 2007 Delta Mtl. Thickness (%) ~0 2.6 MTTP01 (rad) 1~.6 -20 2009 Delta Mtl. Thickness (%) 20 -6.2 MTTP12 (rad) 3.8 D Line Speed (ft/min) -200 ~ Tubing Jt. 285 Uelta Metal Thicknes~ Collar, Collar Metal Thickn ~ Tubing Jt. 286 ~ Tubing Jt. 287 Collar 8980 90Q~ Tubing Jt. 288 Collar ~ 9020 Tubing Jt. ~89 -20 2~07 Delta Mtl. ThicknPSS (%) 20 2.~ -20 2009 Delta Mtl. Thickness (%) 20 -G.2 ~ Line Speed (ftlmin) -200 MTTP~1 (rad) 1?.6 MTfP1~ (rad) 3.8 D~of 10Hz MTT Recordings Showing ~ids of isolated Metal Loss 2P-424A August 5, 2009 PnoAetlve DLaqHOSric Sewviea, Ine. Database File: d:lwarriorldata12fr242a1~1otslplot3.db Dataset Pathname: runl10HzPas Presentation Format: 2.6 bw Dataset Creation: Fri Aug 07 11:18:41 2009 Charted by: Depth in Feet scaled 1:240 -20 ~007 Delta Mtl. Thickness (%) 20 2.6 MTTPd1 (rad) 12.6 -20 2009 Delta Mtl. Thickness (%) 20 -6.2 MTTP12 (rad) 3.8 0 Line Speed (ft/min) -200 Tubi ng Jt. 176 55Q0 Tubing Jt. 177 5520 Casing Collar Delta Metal ThicknE JJ4O Tubing Jt. 178 5560 Collar 5580 Tubing Jt. 179 g Collar Tubing Jt. 184 :~~~u 5640 Tubing Jt. 18~ ~ ~g~r Tubing Jt 182 5680 Collar 5700 Tubing Jt. 183 57~0 Tubing Jt. 184 Col lar; 40 5760 Tubing Jt. '185 5780 Collar 5800 Tubing Jt. 186 5820 Casing Collar Tubin~ Jt. 187 tiann. -20 2f107 D~It~ Mtl. Thickness (%) 20 -~0 2009 Delta Mtl. Thickness (%) 20 0 Line Speed (ftlmin) -200 ?.6 MTTPQ1 (rad) 12.fi -6.2 MTi'P12 (rad) 3.8 ' ~ ~ ConocoPhillips Alaska, Inc. •KRU 2P-424A ~' 2P~24A API: 501032047501 Weil T : PROD An le TS: d TUBING (0.104Y1, OD:3 500 SSSV Type: NIPPLE Orig COfil ~IlOfl: 1/18l2004 Angle @ TD: 70 deg @ 11539 . . io:z.esz) Annular Fluid: Last W/O: Rev Reason: U ate Pum # SURFACE Reference L: 28' RKB Ref L Date: Last U te: 4/11/2006 «~~`'~ °D 9 6~ Last Ta : 10865 TD: 11539 fiKB ' wt:ao.oo~ Last T Date: 8/15/2005 Max Hole An le: 71 d 8267 Casin Strin - A LL STRING S Descri tion Size To Bottan ND Wt Grade Threed CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED ,R~~~ SURFACE 9.625 0 3005 2386 40.00 L-80 BTC ~0.10427 ' PRODUCTION 5.500 0 10427 5495 15.50 L-80 BTCM , oo:s.5oo, ^ ~ PRODUCTION 3.500 10427 11530 5870 9.30 L-80 EUE-MD wrisso~ Tub' Strin - TU81 (3 ' 3ize To Bottom TVD Wt Grede Thread 3.500 0 10422 5493 9.30 L-80 EUESRDMOD Perforations Summ ~$ ~;~ ___ Interval ND Zone Ste Ft SPF Date T Comment ~ndrel/DUnmy 10850 - 10862 5640 - 5644 12 6 2/15/2004 IPERF 2.5" HSD Guns van-e z 5357 5 58 ^ I S6mulations & Treatrnents ( - , 3 OD:4.725) IIIt6rH8I ~BY9 T Comment 10850 - 10862 2/16/2004 FRAC PLACED 210 841 # OF 16/20 Ges 'ft M endrela Nelves Gas ~irt St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt '"d^elmummy v N 3 1 2614 2204 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 a e (732~r7326, . I 2 5357 3477 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/20Q4 oo:a.~25) , 3 7325 4414 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 I 4 9127 5040 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 5 10294 5448 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 5/21/2005 Olfier lu s ui . etc. - JEWELR ~s ~~n De th TVD T e Descri tion ID '"`*~~'""'"y Valve 4 25 25 HANGER 3_5" FMC Gen V TUBING HANGER 3.500 ~siz~-s~2a, 497 497 NIP CAMCO'DS' LANDING NIPPLE 2.875 OD:4.~25~ 10343 5465 SLEEVE-O BAKER CMU SLIDING SLEEVE W/NO GO PROFILE - OPEN SLEEVE 5/21 /2005 2.810 I ! 10343 5465 PUMP 3" RC JET PUMP 9-A RATIO (#9 NOZZLE 8#9 THROAT) SER # PH-1122. SET 10326' LM 10343' RKB set 9/4/2005 0.000 ~s ~~ ~~~~mY 10359 5471 NIP CAMCO 'D' NIPPLE W/NO GO PROFILE 2.750 val~5 ^ 1 10403 5486 LOCATOR BAKER G-22 LOCATOR SEAL ASSEMBLY 3.000 10~10~~ OD 4 ~25 J 10407 5488 XO PRODUCTION CASING CROSSOVER COUPLING 5.5" TO 5" 5.000 . . ~ ' 10407 5488 SEAL 80~0 SEAL ASSEMBLY WMALF MULE SHOE 3.000 10422 5493 TTL 2.990 10427 5495 XO CROSSOVER SUB 5" TO 3.5" 3.500 SLEEVE-O 11529 5870 SHOE WEATHERFORD MODEL 402 SURE SEAL FLOAT SHOE 2.992 ia~ia~aa, Generel No~es °°:4.5°°~ Date Note ~ ' 1/18/2004 TREE: FMC / GEN V/ WKM 3-t/8" / 5 K TREE CAP CONNECTION: OTIS 3" NIP 1035310360, OD:4.500) ' RODUCl10N 70427-11530, OD3.500, Pert 108~,~410862) i • • ~. -~-~~ MICROFILMED. 03101/2008 DO NOT PLACE ANY N EW MATERIAL UNDER THIS PAGE F: ~I.aserFichelCvrPgs_Inserts\Microfilm_Marker. doc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 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 attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report / EDE 2P - 424A MTT / Caliper Report 13-Aug{)7 ~~;CANNED SEP 0 7 20D7 doL{ ..-d)C1 -fJ:: /5'3'fJ3 Signed: ¿I (t. {It .. ~--RECE'VEO - -- . SE? 0 47.007 Date: C'\ & G'''''' ("')\\S Commission 1\laska)\ 0'> V\ . Anchowqe Print Name: i'- It (t~ N {,I {? 1]/~(\jtt..J¿.t!( PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:IMo.<ter_ Copy _00_ PDSANC- 20xxlZ _ W ordIDistnòu!ionlTransnúttal SheetslTransrnit _ Original.doo I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper & Mag.netic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2P-424A Log Date: August 13,2007 Field: Kuparuk Log No. : 8618 State: Alaska Run No.: 1 API No.: 50-103-20475-01 Pipe1 Desc.: 3.5" 9.3 Ib EUE Top Log IntvI1.: Suñace Pipe1 Use: Tubing Bot. Log IntvI1.: 10,427 Ft (MD) Pipe2 Desc.: 5.5" 15.51b BTCM Top Log Intvl1.: 3,005 Ft (MD) (MTT only) Pipe2 Use: Tubing Bot. Log Intvl1.: 10,427 Ft. (MD) (MTT only) Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This CaliperlAfTT data is tied Into the 'D' Nipple @ 10,359 ft. (Driller's Depth). This is the first log of this well to be made with the PDS 24-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface ofthe 3.5" tubing in this well while the Magnetic Thickness Tool responds to the total thickness of metal ofthe 3,5" tubing, and 5.5" production casing within the logged interval. The MTT portion ofthis log covers 3,005' to 10,427'. The additional metal volume added by the 9.625" surface casing above this interval exceeds the MTT's capability to record accurately. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not positively distinguishing in which pipe string the change in metal thickness occurs. Generally, intermittent high-frequency metal loss indications are attributed to metal loss of the tubing or inner-most string, and metal loss to outer concentric strings will be denoted by lower frequency shifts in the average metal loss of all twelve sensors combined. In this log, the MTT was calibrated down hole (3,490'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 5.5" production casing. INTERPRETATION OF CAliPER LOG RESULTS FOR 3.5" TUBING: This log was run to assess the condition of the 3.5" tubing interval with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing interval logged appears in good condition with respect to internal corrosive damage, with only shallow corrosion and pitting of less than 18% wall thickness recorded throughout the logged interval. No areas of significant cross...sectional metal loss or 1.0. restrictions are recorded throughout the interval logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 3.5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded. ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 0ECE\VED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.c0lf". Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 SEP 0 4 Z001 . "^n Commission Alaska 011 & Gas VU"S' ~, (\('n,,\r"lQe ¡.;: I I I I I I I I I I I I I I I I I I I . . 3.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 7%) are recorded. 3.5" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. INTERPRETATION OF MTT LOG RESULTS: A graph of the average metal loss assessed from the MTT data on a joint-by-joint basis is included in this report. The MTT log results indicate no intervals of significant overall metal loss (>8%) throughout the interval logged below the 9.625" surface casing. The interval between GLM's 3 and 4 (7,320' - 9,120') indicates a consistent metal loss reading ranging from 3% to 7%, which appears to be slightly worse than the remainder of the logged interval. The MTT recordings over this interval point to some minor damage on the outside of the lower side of the tubing over this interval. A detail of the MTT recordings over the interval 7,668 to 7,842 are included in this report. There are no recordings that point to significant metal loss to the production casing throughout the logged interval. Increased metal volume is indicated at the GLM's and the Jewelry at the bottom of the tubing interval. I Field Engineer: K. Miller Analyst: M. Lawrence I J. Burton Witness: C. Kennedy ProActive Diagnostic Services! Inc I P.O. Box 1369/ Stafford! TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I I Pipe 1 I I I I I I I I I I I I I I I Bottom of I I Profile Correlation of 3.5 in eLM 1 150 eLM 2 Q) ..0 E :;:¡ z 200 .... c: ·õ eLM 3 250 eLM 4 eLM 5 = 331 to Well: Field: 2P-424A Kuparuk Inc. USA August 13, 2007 Approx. Tool Deviation Borehole Profile 50 100 300 331 o 50 Profile wall) I Tool Deviation -4 1524 3100 4653 ...: u.. .5 6221 7797 9385 10430 100 I I I We!!: Field: 2P-424A Kuparuk Alaska, ¡ne. I USA I Nom.OD 3.5 ins 93 Grade & Thread L..ßO I Penetration and Metal loss wall) penetration metal loss I I I o to 1% 10 to 20 to 40 to over 20"/" 40% 85% 85% 1 to 10% o o I I Configuration ( 50 I 40 30 20 I 10 I o isolated general line ring pitting corrosion corrosion corrosion I o I I I I ew 13, 2007 UW MfC 24 No. 212330 1.69 24 M. Lawrence Nom'!D 2.992 ins len. 12.0 ins Nom. Upset 3.5 ins Damage Profile (% penetration body o o metal loss body 50 GLM 1 GLM2 GlM3 GLM4 GLM 5 Bottom of Survey ~ 331 Overview page 2 lower len. 12.0 ins 100 I NT TABU SHEET I I I Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2P-424A Kuparuk ConocoPhmips Alaska, ¡nc. USA August 13, 2007 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. .v.."" No. Body !.D. Comments (% (Ins.) 0 50 100 1 ~d±±2.94 Shallow corrosion. ill 2 27J: 6 2.93 3 59 0.031: 2.91 4 90 0.03 1 2.94 5 120 0.03 7.94 6 152 0.03 7513 7 183 0.03 2.93 8 215 (I 0.04 2.95 Shallow corrosion. 9 246 (I 0.03 2.91 Shallow corrosion 10 778 (I f§t 2.93 11 308 (I i Shallow corrosion. 12 340 0.03 13 370 0.03 1 Shallow corrosion. 14 401 0.03 1 15 433 0.03 :ft= 2.93 Shallow corrosion. 15.1 464 0 0 (I 2.88 OS LANDING NIPPLE 16 466 0 0.03 2.94 E 17 4q7 (I 0.04 14 7.94 Shallow corrosion. 18 529 (I 004 2.93 Shallow corrosion. I 19 560 0 0.02 2.93 20 592 2.93 Shallow corrosion. 21 623 0.04 2.93 Shallow corrosion. 22 654 0.04 =Þ 2.93 Shallow corrosion. 23 685 0.03 2.93 24 715 =- 2.91 Shallow corrosion. 25 747 ) 2.90 26 778 0.02 2.91 27 810 002 II 28 841 0.02 29 873 0.03 30 904 0.02 31 935 0.03 32 966 0.03 33 998 0.04 . Shallow corrosion. 34 1029 { 0.03 ~ 35 1060 C 0.02 36 1091 C 0.04 itliml. 37 1122 o I 0.02 2.90 38 1152 0 0.02 q J 2.92 39 1184 0 0.03 2 2.91 40 1215 0 0.03 6 2.92 41 1246 0 0.02 TIH 42 1277 0 0.03 ) 43 1306 n om 1 2.91 44 1337 0.02 2.92 45 1369 ) 2.92 46 1400 :I 2.94 Shallow DiWm<:. 47 1432 0 J 4 2.93 Shallow nittinº. 48 1463 0 9 I 2.93 I I I I I I I I I I Body Metal loss Body I Page 1 I I I I REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID,: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: 2P424A Kuparuk ConocoPhillips USA August 13, 2007 Ine. Coun try: Survey Date: I I I I I I Joint Jt. Depth Pen. Pen. Pen. ,'Aetal Min. Profile No. \:::~t)t w. Comments wall} (Ins.) (Ins.) 0 50 100 49 1493 ±!±ft 2.92 '>0 1524 2.93 51 1'>S 2.90 52 15f' 0.02 293 <:< 1 ¡:; 1 2.91 54 1650 'WrnL 5'; 16ft1 2.94 . '>6 1712 14 2.92 Shallow corrosion. itI 0.0 2.95 58 1M 2.en _t2 2.95 J 1837 ~ --1j1 1867 Shallow corrosion. f5 1899 o 0.0311 I'll 1930 n 0.011 '1 Shallow oiWI1\!. 64 1962 n 0.01 1 291 6<; 19fi n 0.04 2 2.91 Shallow niWnQ. 66mm 2.93 67 2.92 Shallow corrosion. h8 2.91 69 2115 11 2.91 70 2146 0.02 9 293 71 '/177 ~ 10 ¡ 2.93 72 2209 2.93 71 ')2 40 0714 4 m"hal! o"ion 74 2271 0.02 7<; 2303 0 003 2.91 76 2334 0 0.D3 2.90 77 2365 0 0.04 2.92 Shallow corrosion. 78 2397 () 0.02 2.93 79 I 2428 n 0.02 1 2.92 80 2459 I 2.9'1 ¡a C1t=± 2490 2.90 2522 .ì 2.93 fÚ 2553 ;¡ 2.93 83.1 2582 .2 2.94 PUP 83.7 2588 0 () N/A GLM 1 {latch @ 1 :OOì 83.3 2595 0.03 1 2 2.94 PUP 84 2hon H-8* 'j 2q2 85 2631 n 2.93 86 2663 i=!=t 4 2.93 Shallow níWOIl. 87 2694 2.92 811 2726 ! 2.90 89 0.03 I j I 2.92 Shallow oiUiml. qo 2789 ~ 2.93 91 2820 2.92 ShaIJow piWml. 92 28'17 ( 2.93 93 2æ3 ( ~ Hit q4 95 2946 n O.oz () 2.æ I I I I I I I I I I Body Metal !.{)SS Body 2 I I I I I I I I I I I I I REPORT JOINT TABULATION SH 3.5 in 9.3 ppf L-BO 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 2P-424A Kuparuk ConocoPhiilips USA August 13, 2007 Inc. I I I I I I Joint Jt Depth IJ';:~:.'! Pen. Pen. i 1',·11'1;11 Min, Profile No. LO. Comments (%w all) (Ins.) 0 50 100 96 2.91 ¡Wrl2. 97 3006 9R 3037 0 99 3068 0 0.02 f 100 3100 () 0.03 1'/, Shallow nittii'm. 101 1131 0 0.01 93 102 1161 i 0.03 I .92 103 3192 ¡ f)O'~ 1 .92 104 3224 0 15 0.02 m. 105 3255 I ~ 106 32R6 107 3117 ( O.Õ? 108 3149 2.92 109 3381 1 2.R9 Efttt 3412 1.93 3443 2.92 3474 91 113 114 3536 115 '{56B 11 ¡:; 3598 0 2 2.90 Shallow oiWmz. 117 31'>10 0 ¡ 4 2.92 118 3661 () I ;7 I 2.91 119 3692 0 f-- t±+= 120 3723 '} f-- 121 3754 ~ ~ 122 378'> ! 4 123 3815 0.02 fJ 2.93 124 3847 i , 2.93 125 3878 1 2.92 Shallow corrosion. !" 126 3909 ( 2.91 127 3941 I 0.02 2.93 128 3972 ( 0.02 2.93 129 4004 C 0.03 2.93 130 4035 0.02 2.93 131 4065 ~ 10 2 2.93 132 4096 i 2.91 Shallow niWoa. 133 4127 0.02 2.93 134 4157 0.02 2.92 135 4189 0.02 2.93 116 4220 o.œ 2.92 137 4251 0.03 2.93 138 4282 0.02 2.93 139 4313 0.03 2.93 140 4344 0.02 2.93 141 4376 0.02 2.93 142 AAf17 0.01 7 2.91 143 4438 I 0.02 t9SI: 144 4470 ( 0.03 3 Shallow corrosion. 145 4500 0 0.Q3 ;.> Body Meta! loss Body 3 I I I I LATfON SH 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: 2P-424A Inc. USA August 13, 2007 I I I Joint Jt Depth Pen. Pen. Pen, J'v1etaì Mill. .~ . Profile No. ~::~~f;t W. Comments 0 50 100 31 0 I Shallow corrosion. 149 Shallow corrosion. 150 2.93 Shallow corrm:iol1. 151 4683 0.02 152 4715 0.02 q II 0.02 q 154 477 0.03 ~ 55 480: OJ)) Shallow oittimr. ) 0.03 12 4902 0.03 13 Shallow ÐittinR. 159 4932 0.03 ¡ 12 160 4963 -1- 2.9 161 4994 1 I ( 5087 ( 5118 5149 Shallow corrosion. 5179 5209 O. I 1 Shallow nittin!.!. 5241 10. 171 5303 2.92 171.1 5334 PUP 171.2 5337 0 ! GlM 2 (Not Available) 171.3 534Q 0.01 2::94 PUP 172 S354 ( OJ!2 2 1.9S 173 sun 0.02 2.92 174 S414 0_03 2.92 175 5445 0.03 2.92 176 5477 - Shallow corrosion. 177 5507 ti S569 .......... Shallow oitûml. 180 5600 181 S631 ! 182 5661 Shallow !ill 181 n 184 7:'4 185 ' 7' ,6 186 7116 -1 '-- Shallow oittÎnll_ 187 5818 ( 0.02 188 5850 ( 0.02 2.91 189 5681 { ¡g 2.90 190 5912 ( ( 1!= 191 5941 192 5972 ( I I I I I I I 4 I I I I I I I I I I I I I I I I I I I JOINT TABULATION 3.5 in 9.3 ppf l-OO 0.254 in 0.254 in 2.992 in We!!: 2P-424A field: Alaska, Inc. USA 13, 2007 Joint Jt Depth PerL Pen. PerL Mr-tal Min. Profile No. (Ft.) \: ~~:r; I 1.0. Comments (% wall) (Ins.) (Ins, ) 0 50 100 193 6004 ~ . 1q4 (;034 2 19'1 6065 196 6097 197 6128 0 I 0.03 2.9~ 198 6160 \ 0.02 199 6190 ) 2.91 200 ~. 701 0.03 202 0 203 6116 204 634} 0 0.0 205 6378 I) ~ 206 6409 1 I 5:91 ~ 0.03 1m 0.02 209 002 210 6534 I 0.03 OJ í 2.91 711 6566 0.02 2.90 212 i 1';596 0.03 13 I) 7.91 . ¿hallow corrosion. 6626 0.02 H I,)CJ1 214 6656 ! ~' 2.90 II\!! 215 6688 I 2.91 216 6719 ! 2.91 Shallow nitti"º'. 717 67'10 fun I ::I 7.Q1 . . 218 6781 0.03 11 i *I 219 6812 0.03 12 I Shallow niWnQ. 220 6842 0.04- 4- Shallow nittil1'1l. 221 6874 II 222 6904 ') <n II!! 223 6935 ~ 224 6965 225 6995 2.95 Shallow corrosion. 226 7026 0 2.91 Shallow nittinQ. 7'7 7058 =±i1 228 7090 0.02 1 279 LmL 0.03 )91 ,h"!low corrosion iii 210 7152 gf 7 q1 iii 231 7184 0., H, 7.92 pittina in unset iii 232 7214 ) 2.94 iii 233 7245 "_ 234 7277 mOo02 PittinQ in urn:et tN1 7308 0.03 PUP Sh~¡¡ow nittina .2 7314 0 ! G!.M 3 (latch @ 1 :30) 234,3 7311'1 0 ( PI¡P 235 7327 0 ! 236 7357 0 . 2 237 7389 0 0 2.92 . 2~8 7420 0 004 "i )t 2.93 "hallow corrosion. 239 7452 0 0,02 fj 0 2.93 Body Meta! loss Body 5 I I I I I I I I I I I I I I I I I I I JOINT TABULATION SHEET Wall: Upset Wall: Nominall.D.: 3.5 in 9.3 ppf L-OO 0.254 in 0.254 in 2,992 in We!!: Field: 2P-424A Ine. Survey USA August 13, 2007 Joint }t Depth Pen. Pen. Pen. !\ite\al Min. Profile No. '(:::::n;' !.D. Comments (Ins. (Ins.) 0 50 100 240 7483 I O. A :> 2.94 ti 7515 ( .91 7545 I 3 Shallow oittinll. 243 7577 I 244 7608 I 0 2 245 7640 0 2 '41 7671 0.06 ') set '4 7702 0 11 I 3 'Ai , 7734 () 0.02 B I '¡ 2.95 '4' 7765 () 2.91 Shallow corrosion. , 50 7797 251 7828 Pitûn2 in uoset. 253 2.92 Shallow oittioo. 254 7922 O. 25 .93 Pittín17 În ImSf't 255 7954 0.02 '7 .93 256 7986 .93 2S7 0017 I 9 Sh..llow oining. 258 8048 0 . q 259 8079 0 2.9 260 8111 0 2.92 261 8142 I 2.93 Shallow corrosion, 262 8174 I 0 0.0' 2.92 263 B20h I 0 0.02 I 2.93 264 B237 ++= ì 2514 265 8268 0 2.92 266 8299 "7 2 2.92 267 8331 t 2.92 268 8363 i2 2 2.93 269 8394 2 2.94 270 8425 I 2,92 271 8457 I 2.93 272 8488 I O. n 2.91 Shallow nÎUin2. 273 8520 ( o. I ~ 274 8551 I 0.03 275 8583 I 0.02 276~ i1 2.9" 277 8645 2.93 Shallow oitl:Îoo. 278 8678 !-- 291 Shallow corrosion. 279 8709 2,94 280 8741 2.CJ2 281 8772 0 2.92 282 8803 2.91 283 8835 0 I 2.93 284 8866 0 Ct 2.91 285 8896 0 I 2.93 Shallow corrosion. 286~ =%= 2.90 287 2.92 288 8991 I 292 289 ! 9022 0 I 2.93 6 I I JOINT TABULATION SH Well: Field: Company: 2P-424A 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in ConocoPhí!iíps Alaska, Ine. USA August 13, 2007 Survey I I I I I J~:~ Jt ~~fth \::~~::;t ¡p;;;; p", ",,,' t£ 290 9054 01 2.90 291 goB5 n 0.0 2.91 291.1 911 7 n 0.03 2.95 291,2 (H23 0 m 291.3 9129 0.04 292 9133 0.02 293 9166 0.04 2.91 Shallow corrnsion. 294 9197 0.02 2,93 ~9~ ~:~R=J~ ~:~~ 2 7 9 91 2.93 2' 18 9322 0 2.92 2'19 9353 It Ï\02 2.94 300 9385~ 2.94 301 9416 2.91 Shallow corrosion. 302 9447 ~7 2.92 303 9478 U . I¡ i; 2.91 Shallow mrmsion. E4 ~16 M 2~ 305 9541 0.03 ~ Shallow corrosion. 306 9570 O.O? ~ 307 %( 11 0 2.92 30R 96 1 0 5 2.93 309 f.j 1 2 2.91 310 fi' ') 2.94 311 7 6 .0 =* 312 9757 0 0.03 Shallow níttir1l1. 313 9789 oiìri~ .92 314 9820 [) n fn1 ¡ ! 2.91 Shallow corrosion. 315 9851 t!: ~ It. Deoosits. 316 9883 ~ 317 99141 2.92 318 9944 0.02) 2.92 319 9q77 0.02 q I 2.91 320 0.04 1 r; I 2,92 321 10036 0.04 1 r; I 2.92 322 10068 .~91 323 10099 .94 324 10131 .2 2.94 ">25 1016;1 1 2.94 326 10193 4 2.94 Shallow corrosion. 3')7 10225 0.04.1 2.92 Sh~lIow corrosion, 328 10256 Ho.031 ') 2.93 328.1 10')86 0.01 e 328.2 10)9;1 0 GLM 5 (NotAvaílableì 3283 1rnnn ---L.!lllil PUP 329 10307 ----\-J1Ql ~29.1 =HI=t 0.05 329.2 I] ° (2.81 SUDING SLEEVE 329.3 103M 0 001 2.96 I PUP 329.4 10351 () 0.01 2.91 PUP Comments PUP CI M 4 (Latch @ 4:0Oì PUP Shallow corrosion. I I I I I I I Shallow oiWrn;¡:. Shallow oiffil1ll. Shallow corrosion. I I I Page 7 .~ Profile wall) o 50 100 : 21 !iii Body Metal Los!> I I lATION SH JOINT 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 Well: Field: 2P-424A Kuparuk ConocoPhillips Alaska, ¡ne. USA August 13, 2007 Wall: Upset Wail: Nominal 1.0.: Survey Date: I I Joint No. Comments y I I I I I I I I I I I I I 8 o Body Metal Loss Body I I Recorded Relative Point 3.5 in - 10429.8'} Well: Field: 2P-424A I I Inc. Country: Date: USA August 13, 2007 Decrease Increase 100 3100 125 3878 150 4653 GLM 2 175 5445 200 6221 W .,.; ..Q E I..L :;¡ 225 6995 .5 z I 1: GLM 3 2. 250 7797 275 8583 GLM 4 300 9385 I I I I I I GLM 5 325 10162 331 -50% o in Metal Thickness 10430 50% Bottom of Survey'" 331 I I I I I I clas. . MTT 10 ..... .." . - ~ DIAÆ¡""""",,, 51"..,,.,,,,,,,- 1_. -'" Database File: "".d. ...... .... Dataset Pathname: ~ ¡~ ,... ~ " If 1111 III Presentation Format mt!: zoom - Dataset Creation: 1418:40:162007 Charted in Feet scaled 1 :120 =100 1õõT - MPCMN ("/(1) 1 MTIP01 (rad) 51 0 Line Speed (ftlmin) -200 -45.2 MTIP12 (rad) 4.8 3.4 fing02 (in) 1.4 I V ! ~ Tu b¡ng~ Collar~ ( ,,J C bna' IS. ,~v t - 7680 - !--. ...... .Line "'-- Jt -- ---- -- }- 246 -. ~ -"I\,I<::! .~ I [ T f- Þ f: f- - ¡ 7700 p 'ubing ~. -'! f--:; ~ Jt 247 r- ie 1=1 l ~as¡1 ." t -, )(j Coliar 7720 ":I .) - ¡,.. ~-- -- -- --. Wi' t f1rl Tul ling Collar _. ~--"'-~-- - ,- Minor - ~~ h ent I I I I I I I ____m_............___.___m_ I Jt 248 þ f ~~- ~" ~ --- - I -"~- - 7760 ~ I ubi! g CùH¿¡ I , =f f----.i--- iiÞ ----f--- - I; f I f--- -. Jt If - 249 I - 7780 I - '-. ----- ¡ I I ~~+_ - -_ui , I -- Tutlng_::,.. ft -~ :> I ti 7800 - I Ii _a.,"" Co'",r ~ I+- - Une )oed e- -- r I ! Tubing Jt -- -- '- ----- .~-- f---- -- 250 - I \ « 7820 I , T""ngL4~ - - I -' r -- -- -- ---. I -- ¡r Flnœrl-< Tubing J1: 251 I 7840 '" I d 100 MPCMN (%) 100 1 MTTP01 (rad) 51 I J Line Speed (ft/min) ~200 ~45.2 M I W',~ (rad) 4.8 34 fing02 (in) 1.4 I I I I I I I I KRU 2P424A I I I GasUft I I I FMC !GEI'-! V ¡WKM !6 K mEe CAP CONNECTION: OTIS 3" NIP I I I I I I , ROOUCTlON Perf 10S00-10862} -- ConocJJ'hillips Alaska RE :F ~ ~ n ~¡ ;; :.~;/ ! ¡ I ~ 0"-'':'- 1) 5 2006 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ ~.~ 0.j~_. ~ frn~3$~Cn & ~¿83 ~- - Þ~~1~h[)r2ge June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 $CANNED JUL Q ~7 2D05 ;)..0+-0°' 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. .~ ::210 Perry Klein ConocoPhillips Problem Well Supervisor (" <.. ~ e.. '- Ó. d J..e... o6/~ùlo6 Attachment '-" ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Corrosion Well Initial top Vol. of cement Final top of Cement top Royfill404B inhibitor/ Name PTD# of cement pumped cement off date RG2041 vol vol. sealant date ft bbls ft qal qal 5/19/2006 2P-406 2a4-022 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' 5/1/2006 _5.7 . g', 5/1812006 2P-419 204-017 1 0.0 1 na 6.7 0 5/18/2006 :lP420 201-182 . 3.5 0.0 3.5 na - -7.1 17.3 . 5/1812006 2P-422a 202-067 13.5 2.3 2.5 5/1/2006 7.1 10.7 5/18/2006 '2P-424a 204-009 4.5 0.0 4.5 . na 5.7 17.6 5/18/2006 2P-427 202-018 10 1.6 2.5 5/1/2006 7.1 13.7 5/18/2006 :2é'~29 ,,:.{ - 201-102. . 2 0.0 2 na 3.8 5.7 5118/2006 2P-431 202-053 13 1.9 2.5 5/1/2006 7.1 10.1 5/18/2006 2P-432 202-091 8.5 0.9 2.5. 5/112006 5.7 13.8 5/1812006 2P-434 203-153 14 2.0 2.5 5/1/2006 5.7 6.2 5/18/2006 2P-438 201.~ 5 0.0 5 -na· 5.7 21.9 5/1812006 . 2P-441 202-107 15 2.0 2.5 5/1/2006 7.1 13.1 5/18/2006 2P-443 204-032 3.5 0.0 3.5 nà 8.7 11.4 5/18/2006 2P-447 203-154 2.5 0.0 2.5 na 9.5 0 5/18/2006 2P-448a 202-005 1.5 0.0 1.5 na 9.5 0 5/1: 8/2006 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 ) ConocóPhillips Alaska \'""" ~;(:;F .l:~ ,.....;;;7 :"'::c;II.'O U\\\ l'ì t,,;"ì mi& G~~) C:ÙJ~1);1, Àm~hiQ ~ j]ff~lE! P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 t!) {)4 - () D9 June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUN 2 ~1 200B Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfill 404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05,2006. SchlumbergerWell Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18th, 19th and 31 S\ 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. L ConocoPhillips Problem Well Supervisor Attachment ) ) ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Initial top Vol. of cement Final top of Cement top of cement ft '4'.',·', 5.5 '7:5 ,., 1 , :' 'S';!t'·,' 13.5 '4~5;,:' ";'" 10 '''2'' ':' ~ ' ' 13 ,a.S~,' ",. 14 ,S:', , " (',:' 15 ,,~'5' ',', 2.5 ,,',1..5 ,- 3 Jo, , '-- ;::'t2'·ot'::ì1.'üt ,:' ". ' . """ ~~~'I ,_ ~ 2P-415 ~:,/i;jPïS¡*-~ ":"",' ' i: 'I'~C.~~~" . " 2P-419 t·':\~t~b~': "::,}', 2P-422 ~":'~~:p'" :~.": ~':~;-':"~"" :¡.~~, 2P-427 ,:,"2P4J29~, :'; ..' 2P-431 :.',2e~2;:;:":',··' 2P-434 ':'~2~-4ŠS,"! :\' 2P-441 ~,,,,~,'~A':.it'3: ",,':': ' ' A.F7~. :.'....¡' . 2P-447 ,,:2R~, 2P-449 , 2P~t ", pumped bbls "0;0,' 0.0 ·ô/i· 0.0 ""oür ..' 2.3 :', -:,O'}O> ."" -, ' ' 1.6 'I ",O(Ó" " 1.9 O~9", . 2.0 '.'O'~Ò,': . .,,' , 2.0 ,,:(}~Ó :. 0.0 . ":,0:6 ' 0.0 '. 201:' cement ft -,:4,' ..1' 5.5 . ·':·.·:2~5· ".. 1 :::'.':3.5: . 2.5 ,::'4.5,:, 2.5 . ',:>2,:~' , 2.5 "'\25.","· ',' 2.5 :0::5 :'~: 2.5 . \,. :,,~ .~;3;5,' , , 2.5 "4~5,,: .." '. 3 2.5 ' Kuparuk Field June 6,2006 off date na' na ,5J1"J20Ð6,. na ,,: iíå¡i .'. 5/1/2006 .. " '~", ..,' :,,""nEf 5/1/2006 ",' ,:-riå.:,- 5/1/2006 .511"/2006; ..: 5/1/2006 . ,:",:tlå "'::'.' 5/1/2006 . ',: ,'ocf ,," na ,na ,:. ' na . '51.1/2006' RG2041 voi I gal "'5.:7 , 7.1 ::5.,;;7' " 6.7 "I.", :lA,,::'" 7.1 '. '5]," 7.1 . ",', . '3·;8:' 7.1 ¡".''S.7',. 5.7 ':;: ':~::5~i,; 7.1 ~ ".,ä.7 ." 9.5 '9.S; , 5.7 " ','7;1· Royfil/4048 vol. µal .' ·17.1:: . 30.9 ',,':9':,: . o ,. ,,1:1..3.,., 10.7 ,t7Jr: 13.7 ': '5~7': 10.1 1:3~'8"" 6.2 ':'21L9" 13.1 . ·1}.4 ' o o " 11.5 '6~5 . . ' Corrosion inhibitor/ sealant date 5/19/2006 , 51t9120øa '::', 5/19/2006 .,~, '.~"6í:,'::: 5/18/2006 , ..:I'·":5ftQt~D::<:>, " '~~~;"'''' 5/18/2006 , : ,:5J.~Uf20Ò6:~';' 5/18/2006 ,"5' :Hci'2~' ':, ","'" ,VJjQJ~ U'~~;r ,''; 5/18/2006 , .::,51:1.8Q._<:;"!,: 5/18/2006 ,':sr_ootr:, /f. 5/18/2006 . ; '51' i812" ", 0'06' " .., ' .' '.',' '. ,",.. . ,'.... .;. '. ',. .:',: ~ 5/18/2006 , ..: . . ,5l1812aQ6"':: 5/31/2006 5f1Ø12006',., . I ç M~ v~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2040090 Well Name/No. KUPARUK RIV U MELT 2P-424A Operator CONOCOPHILLlPS ALASKA INC 5f L\.d.. / I J "^- .t{) d Y API No. 50-103-20475-01-00 MD 11539 r TVD 5873""- Completion Date 2/15/2004-../ Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No Directional SÄ.~ REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Den/Neu Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Data Type 1- ..._--~- ~ Electr Digital Dataset Med/Frmt Number . Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments ~------_._,- 6877 11539 Open 2/6/2004 2 Blu 7"/1) 3010 11539 Open 4/21/2004 CALIPER CORRECTED NEUTRON, OPTIMIZED ROTATIONAL DENSITY RWD DSN 12652 2 Blu ¡//Ð 3010 11539 Open 4/21/2004 CALIPER CORRECTED NEUTRON, OPTIMIZED ROTATIONAL DENSITY RWD DSN 12652 2 Blu l1þ 3010 11539 Open 4/21/2004 MPR, GR, RWD, DSN 12652 2 Blu ìVi) 3010 11539 Open 4/21/2004 MPR, GR, RWD, DSN 12652 . 3010 11539 Open 4/21/2004 MPR, GR, RWD, DSN 12652 3010 11539 Open 4/21/2004 MPR, GR ORD, Sample Interval Set Start Stop Sent Received Number Comments Name _...._~--~._--- Directional Survey Neutron ! ì I Lk;; Neutron Induction/Resistivity I ! I Rpt LIS Verification ~< _Tf ~ ~Ne","" I nd uction/Resistivity Well Cores/Samples Information: Name Permit to Drill 2040090 MD 11539 TVD 5873 ADDITIONAL INFOR~N Well Cored? Y ~ Chips Received? 'YTFr'"" Analysis '-vTÑ"' Received? DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Well Name/No. KUPARUK RIV U MELT 2P-424A Operator CONOCOPHILLlPS ALASKA INC Completion Date 2/15/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? "', (dIN GJN Formation Tops Comments: -~_._-----~~-_.- API No. 50-103-20475-01-00 UIC N .~ I Date: ~~_._--~ -~------------- Compliance Reviewed By: _~~ r-~XiM7;-- . . . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 l:¡. f\ ",I' .~ \ j uthl 0 1J1Þ'fðS June 5, 2005 Oil (~, ,'L. ... L:::, Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 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-mA (PTD# 204-009),and 2P-443 (PTD # 204-032) <I )..</11- 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. Sincerely, ~ Problem Well Supervisor . Attachments -fl' . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell D Pull Tubing D Opera!. ShutdownD Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 252' 8. 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 Other J ;.: i Y, n. ..""J.,~ Waiver D Tim~.E;xter~ion D ~'{'-',. ,"t ~",,~:; ,:' ¡ Re-enter SU~~~~dêd W~h EJ Exploratory Service D D 5. Permit to DrillNu¡f¡bér~ 204-009 6. API Number: 50-103-20475-01 9. Well Name and Number: 2P-424A 10. FieldlPool(s): Kuparuk River Field I Meltwater Oil Pool measured 11539' feet true vertical 5873' feet measured feet true vertical 6276' feet Length Size MD 108' 16" 108' 2753' 9-518" 3005' 10175' 5-1/2" 1 0427' 1103' 3-1/2" 11530' Plugs (measured) Junk (measured) TVD Burst Collapse Measured depth: 10850-10862' RBDMS SF,' t JUN a '1 2005 true vertical depth: 5640-5644' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10422' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 497' 12. Stimulation or cement squeeze summary: Intervals treated (measured) NIA 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 160 240 105 797 250 Subsequent to operation 286 444 340 1936 273 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 L veland @ 659-7224 MJ Lovela Problem Wells Supervisor 907 -659-7224 Date 5- ,-,/ '\ ¡ J L Submit Original Only . 2P-424A DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary - Convert from GL to Suñace Powered Jet Pump 5/20/2005 PULLED OGLV FROM STA# 5 @ 10294' RKB. SET 2.75 CSA-2 PLUG @ 10359' RKB. LRS CIRCULATING DOWN lA, UP TBG, AND DOWN FLOWLINE (225 TOTAL BBLS). LRS ALSO CMIT TBG X IA 5/21/2005 SET 1" BTM LATCH DGLV IN STA # 5 @ 10294' RKB. MIT IA TO 3000 PSI ( PASSED ). OPEN CMU @ 10343' RKB. PULLED CSA-2 PLUG @ 10359' RKB. SET 2.81 CS LOCK W/ 3" R.C. JET-PUMP (SER # PH-1122 ) HAS A 12-A RATIO: # 12-NOZZLE / # 12-THROAT )-( 631/2" OAL) IN CMU @ 10343' RKB. '" . . ConocoPhillips Alaska1 Inc. KRU 2P-424A 2P-424A - API: 501032047501 Well Tvpe: PROD Angle !â) TS: dea '(i) TUBING (0-10422, SSSV Type: NIPPLE Oriq Completion: 1/18/2004 AnQle (éì) TD: 70 dec ¡Q) 11539 OD:3.500, Annular Fluid: Lasl W/O: Rev Reason: Set DMY. Set 10:2.992) Pump Reference Loa: 28' RKB Ref Log Date: Last Update: 5/27/2005 Last TaQ: 10886 1D: 11539 ftKB Last Taa Date: 5/10/2005 Max Hole AnQle: 71 deg @ 8267 Casina Strina - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread SURFACE CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED (0-3005, r SURFACE 9.625 0 3005 2386 40.00 L-80 BTC OD:9.625, ~ PRODUCTION 5.500 0 10427 5495 15.50 L-80 BTCM wt:40.00) .: ii; PRODUCTION 3.500 10427 11530 5870 9.30 L-80 EUE-MD ., I' Tubina Strina - TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 10422 I 5493 I 9.30 I L-80 I EUE8RDMOD RODUCTION Peñorations Summary (0-10427, Interval I TVD I Zone 1 Status I Ft I SPF I Date Type I Comment OD:5.500, 1 0850 - 10862 5640 - 5644 I I I 12 I 6 12/15/20041IPERF 12.5" HSD Guns wt:15.50) 1 Stimulations & Treatments Interval I Date I Tvpe I Comment ! 10850 - 10862 I 2/16/2004 I FRAC I PLACED 210 841 # OF 16/20 .-. Gas Lift Mandrels/Valves i ". St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv .. ! , Mfr Run Cmnt ). .~ 1 2614 2204 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 1 2 5357 3477 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 3 7325 4414 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 4 9127 5040 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 1/18/2004 III 5 10294 5448 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 5/21/2005 Other (I luas e uiD. etc.) - JEWELRY Depth TVD Tvpe Description ID I· 1 25 25 HANGER 3.5" FMC Gen V TUBING HANGER 3.500 ~ , , I 497 497 NIP CAMeO 'DS' LANDING NIPPLE 2.875 I , 10343 5465 SLEEVE-O BAKER CMU SLIDING SLEEVE WINO GO PROFILE - OPEN SLEEVE 2.810 ~f 5/21/2005 10343 5465 PUMP 2.81" CS LOCK w/3" R.C. JET PUMP (SN #PH-1122) 12-A RATIO: #12 0.000 , .. NOZZLE, #12 THROAT, OAL 63'5" set 5/21/2005 I 10359 5471 NIP CAMeO 'D' NIPPLE WINO GO PROFILE 2.750 i 10403 5486 LOCATOR BAKER G-22 LOCATOR SEAL ASSEMBLY 3.000 , 10407 5488 XO PRODUCTION CASING CROSSOVER COUPLING 5.5" TO 5" 5.000 SLEEVE-O 10407 5488 SEAL 80-40 SEAL ASSEMBLY W/HALF MULE SHOE 3.000 0343-10344, fV 10422 5493 m 2.990 OD:4.500) 10427 5495 XO CROSSOVER SUB 5" TO 3.5" 3.500 i i 11529 5870 SHOE WEATHERFORD MODEL 402 SURE SEAL FLOAT SHOE 2.992 iiii ....................................... ....i..·..................·...· i/ ii ....................... ii Date Note 1/18/2004 TREE: FMC / GEN V / WKM 3-1/8" / 5 K NIP ¡II TREE CAP CONNECTION: OTIS 3" 0359-10360, OD:4.500) i I·· .... I ! .; .n_ . i RODUCTION . -,- ~ I 0427-11530, r-i OD:3.500, +- r+- Perf :.,- f--O,- 0850-10862) -7 ~ .... 11III.. Producer MITIA Pre GL to JP Conversion . . Subject: Producer MITIA Pre GL to JP Conversion From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Sat, 04 Jun 2005 15:42:07 -0800 To: Thomas Maunder <tom_maunder@admin.state.akus>, James Regg <jimJegg@admin.state.akus>, bob _ fleckenstein@admin.state.akus 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 MITP KRU 2P-424A 05-21-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2P-406 05-23-05.xls KRU 2P-406 05-23-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MITP KRU 2L-311 05-28-05.xls KRU 2L-311 Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 6/6/2005 7:56 AM 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; and Jim_Regg@admin.state.ak. OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Meltwater/ KRU/ 2P OS/21/05 Zemba - H ES o P Well P.T.D. Notes: Well P.T.D. Notes: Well P.TD. 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 2P-424 jet pump MITIA 05-21-05.xls 5/27/2005 -- , . ... RECEIVED Transmittal Form £, 2 1 2004 "ill BAKER HUGHES rl¡~ska Oil & Gas ~nb :...onum~ì(ìf !ìncl1oragb INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 ,/ '}- ,d- ~) 11/ r Attention: --Lis~ '.¥etl'œ-' Reference: 2P-424A Contains the following: I LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary I blueline - MPR Measured Depth Log I blueline - MPR TVD Log I blueline - CCN-ORD Measured Depth Log I blueline - CCN-ORD TVD Log LAC Job#: 605575 Date: Mar 30, 2004 Date: * Received PLEASE ACKNOWL DGE 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 e ConocóP'hillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 16, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-424A (APD # 204-009) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-424A. 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 OR\G\. 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 0 Abandoned 0 Suspended 0 WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Sïr¿t. 1~.wDJ 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: ~2004 'A 204-009 3. Address: 6. Date Spudde~~. III ~ 13. API Number. P. O. Box 100360, Anchorage, AK 99510-0360 December 27, 2003 50-103-20475-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: I Surface: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM January 15, 2004 2P-424A At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 2155' FSL, 384' FWL, Sec. 21, T8N, R7E, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Meltwater Oil Pool 1351' FSL, 696' FWL, Sec. 21, T8N, R7E, UM 11148' MD 15738' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 444010 , 5868966 . Zone-4 ' 11539' MD I 5873' TVD .- ADL 373112/389058 y- TPI: x- 447593 y- 5861446 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 447901 . y- 5860640 . Zone-4 Land nipple @ 497' L32092 I 32409 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of NIA feet MSL Permafrost: 1388' MD 21. Logs Run: kÞp: '870' '"1:::> G RIRes/Den/Neu 0/19<1 ' ~;> 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# B Surface 108' 42" 15bblASI 9.625" 40# L-80 Surface 3006' 12.25" 540 sx AS Lite, 314 sx LiteCrete 5.5" X 3.5" 15.5/9.3# L-80 Surface 11530' 8.5" 678 sx Class G w/GasBlok 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 (MD) 3.5" 10422' none 10850' - 10862' MD 5640' - 5644' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10850'-10862' 210841 # of 16/20 proppant behind pipe 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) March 8, 2004 Producing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 3/11/2004 23.5 hours Test Period --> 444 2214 192 not available 5438 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 304 psi not available 24-Hour Rate -> 415 2257 193 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". fC(:¡;i'-(:'~:ii~\mq NONE \ ~'Î~?-'Á \¡ VEn(ßU II ~. ---··A·_.::::::J r"·'f""'··,··'·"'··.."'·¥·-' O~ r; \f\ 't'o. f '} Submit in duplicate tØllSBFl _23~f Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. Ust intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2P-424A T3 T2 10622' 11470' 5562' 5850' NIA 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 Title: p~~ KUDaruk Team Leader "S- l>~'\) Date lÞll'(OY 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 10-407 Revised 2/2003 OR 1 Î '" ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 1 of 12 ConocoPhillips Alaska Operations Summary Report 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 From - To Hours 12/26/2003 06:00 - 09:00 09:00 - 12:00 12:00 - 16:00 16:00 - 17:00 17:00 - 19:00 19:00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:30 12/27/2003 23:30 - 00:00 00:00 - 02:00 02:00 - 00:00 3.00 MOVE 3.00 MOVE 4.00 MOVE Code MOVE MOVE MOVE MOVE MOVE MOVE 1.00 MOVE RURD MOVE 2.00 WELCT RIGUP 2.50 DRILL RIGUP 0.50 WELCT BOPE RIGUP 0.50 DRILL SFTY RIGUP 1.00 DRILL PULD SURFAC 0.50 DRILL DRLG SURFAC 2.00 DRILL PULD SURFAC 22.00 DRILL DRLG SURFAC 12/28/2003 00:00 - 13:00 13.00 DRILL DRLG SURFAC 13:00 - 13:30 0.50 DRILL CIRC SURFAC 13:30 - 14:30 1.00 DRILL DRLG SURFAC 14:30 - 15:30 1.00 DRILL CIRC SURFAC 15:30 - 16:00 0.50 DRILL CIRC SURFAC 16:00 - 17:30 1.50 DRILL TRIP SURFAC 17:30 - 18:30 1.00 DRILL CIRC SURFAC 18:30 - 20:00 1.50 DRILL TRIP SURFAC 20:00 - 22:00 2.00 DRILL PULD SURFAC 22:00 - 23:00 1.00 CASE RURD SURFAC 23:00 - 00:00 1.00 CASE RUNC SURFAC 12/29/2003 00:00 - 04:30 4.50 CASE RUNC SURFAC 04:30 - 07:30 3.00 CEMEN CIRC SURFAC 07:30 - 08:00 0.50 CEMEN PULD SURFAC 08:00 - 00:00 16.00 WAlTON WOW SURFAC 12/30/2003 00:00 - 09:00 09:00 - 09:15 09:15-11:15 9.00 WAlTON WOW SURFAC 0.25 CEMEN PULD SURFAC 2.00 CEMEN CIRC SURFAC Start: Rig Release: Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: 12/26/2003 1/18/2004 Description of Operations Move rig off 2P-447. Spot rig over 2P-424, Pits, Pump, Motor, Boiler complexs Spot Rockwasher, Pipe shed, Hook up Air, Water, Steam & Glycol service lines, Rig up tank farm. Work on and complete rig acceptance check list. Accept rig @ 16:00 hrs 12/26/03 Take on water, Nipple up 21-1/4" Diverter, Mix spud mud. Change saver sub to 4-1/2" IF, Load pipe shed w/18 joints 5" drill pipe & pick up same. Function test Diverter system, Test waived by AOGCC Jeff Jones. Held dog house pre- spud meeting with all rig personnel. Fill conductor and check for leaks, Tag Ice plug @ 36', Make up Bit, Motor & 1 stand HWDP. Clean out ice from conductor fl 36' to 108'. Make up Short NMDC, NM Stab, NMXO, MPR, NMXO, Orient motor, Program MWD, Pick up NMDC & RIH to 108'. Drill f/108' to 2108' (1920' TVD) AST= 7.5 hrs., ART= 8.3 hrs., WOB 20/25K, RPM 80, 650 gpm @ 2100 psi, UP 100K, DN 98K, ROT 100K, TO 6K on & off btm. (Note: Had 1805 units gas @ 1831 ')Pumping sweeps as needed to maintain clean hole. Drill f/21 08' to 2961' AST = 1.8 hrs., ART = 8.1 hrs., WOB 30K, RPM 100, 650 gpm @ 2300 psi, UP 105K, DN 90K, ROT 98K, TO 7K on, 6K off, Ave BGG 80 units. Monitor well, Circ btm's up at 633 gpm @ 2000 psi, 100 RPM. Drill f/2961' to 3010' AST = 0 hrs., ART = .9 hrs., WOB 30K, RPM 100, 650 gpm @ 2300 psi, UP 105K, DN 90K, ROT 98K, TO 7K on, 6K off, BGG 80 units. Pump Hi-vis sweep, Circ & condo mud at 633 gpm @ 2000 psi, 100 RPM. Monitor well, Circ btm's up. Back ream out to 1850' at rate of 525 gpm @ 1500 psi, 80 RPM. Circ hole clean WI 525 gpm @ 1400 psi, 100 RPM. Pump dry job, POOH to BHA @ 200'. POOH wI BHA, Down load MWD, Lay down motor & bit. Rig to run 9-5/8" casing. PJSM, Run 9-5/8" casing. Finish running total of 77 joints 9-5/8", 40#, L-80 BTC casing to 2977', Make up Hanger & landing joint, Land csg @ 3005'. Circ & condo mud with Frank's fill up tool, Stage rate up to 5.0 bpm @ 290 psi, No Mud lost, No trip gas, BGG 5 units. Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell circ swedge. Circ & cond mud, Pump rate of 3.5 bpm @ 90 psi, Reciprocate pipe 15', Wait on weather and Dowell cement unit due to Phase III weather. Note: Dowell cement van ran off road due to weather during convoy to rig. Circ & cond mud, Pump rate of 3.5 bpm @ 90 psi, Reciprocate pipe 15', UP 125K, DN 108K, Wait on weather and Dowell cement unit due to Phase III weather. Rig down Dowell circ swedge, Rig up Dowell cmt head. Circ & cond mud, Pump rate of 3.5 bpm @ 90 psi, Reciprocate pipe 15', UP 125K, DN 108K, Rig up Dowell pump truck, Position vacuum trucks, Printed: 3/11/2004 1 :48:28 PM page 2 of 12 ConocoPhillips Alaska Operations Summary Report 2.00 CEMEN CIRC SURFAC PJSM wI all personnel. 2.75 CEMEN PUMP SURFAC Turn over to Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 4.5 bpm @ 80 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 4.2 bpm @ 120 psi, Shut down and drop btm plug, Mix & pump 540 sxs (428.0 bbls) Lead ArcticSet III Lite cmt mixed at 10.7 ppg wI additives at rate of 6.5 bpm @ 170 psi, Followed by 314 sxs (150.0 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI additives at rate of 5.6 bpm @ 220 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 197.0 bbls 10.4 ppg mud (total of 217.0 bbls to bump plug) at rate of 7.0 bpm @ 490 psi, Slowed rate to 3.0 bpm @ 285 psi for last 10 bbls of displacement, Bump plug wI 1000 psi, Floats held- OK, CIP @ 14:00 hrs 12/30/03, Had good returns thru out job, Reciprocate csg. 15' until MudPUSH to surface then pipe got tight, Had 231.0 bbls good cmt returns to surface. Rig down Dowell cmt, Lay down landing joint. Clear rig floor of Casing & cementing equip. Nipple down Diverter system. Nipple up FMC Gen 5 wellhead, Test seals to 1000 psi-OK. Nipple up BOPE & set wear bushing. Pick up 90 joints 5" drill pipe from pipe shed, POOH & stand back in derrick. Pull wear bushing, Install test plug. Rig & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 low & 3500 psi high, Test waived by AOGCC Jeff Jones, Rig down test equip., Set wear bushing. Pick up 90 joints 5" drill pipe, POOH & stand back in derrick. Repair hydralic hose on top drive. Finish POOH & stand drill pipe back in derrick. PJSM, Make up BHA, Orient motor, Program MWD, Load RA sources, RIH wI NMDC's. RIH wI HWDP, Surface test MWD- OK. Pick up 57 jts 5" drill pipe from pipe shed to 2880'. Break eire, Wash down to Float collar @ 2920'. Stand back 1 stand drill pipe, Rig & test 9-5/8" csg to 3500 psi fl 30 min.-OK. Drill out Float collar @ 2920', Cmt, Shoe @ 3005', 20' new hole to 3030' ART = 0.6 hrs. Pump sweep, Change over to new 10.5 ppg LSND mud w/5 ppb Fine LCM. Perform FIT of 18.0 ppg EMW with 932 psi, 2386' TVD, 10.5 ppg mud. Drill fl 3030' to 3120' ART = 1.0 hrs WOB 10K, RPM 80, 500 gpm @ 2000 psi, UP 11 OK, DN 82K, ROT 97K, TO 6K, ECD's 11.8 ppg, Ave. BGG 30 units Note: Dutter annulas pressures are as follows Well Pressure 2P-432 750 2P-434 250 2P-447 0 12.00 DRILL DRLG PROD Drill f/3120' to 3870' ART = 8.1 hrs AST = 0.6 hrs WOB 5/20K, RPM 90, 550 gpm @ 2200 psi, UP 11 OK, DN 70K, ROT 85K, TO 3/9K on I 3/6K off, Ave. ECD's 11.8 to 12.0 ppg, Ave. BGG 35 units Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Sub Code Code Phase 12/30/2003 09:15 -11:15 11:15-14:00 14:00 - 15:00 1.00 CEMEN SURFAC 15:00 - 15:30 0.50 CEMEN SURFAC 15:30 - 17:00 1.50 WELCT SURFAC 17:00 - 18:00 1.00 WELCT SURFAC 18:00 - 20:00 2.00 WELCT SURFAC 20:00 - 23:30 3.50 DRILL SURFAC 23:30 - 00:00 0.50 WELCT SURFAC 12/31/2003 00:00 - 06:30 6.50 WELCT SURFAC 06:30 - 09:45 3.25 DRILL RIRD SURFAC 09:45 - 11 :45 2.00 RIGMNT RGRP SURFAC 11 :45 - 12:30 0.75 DRILL PULD SURFAC 12:30 - 15:30 3.00 DRILL PULD SURFAC 15:30 - 16:00 0.50 DRILL TRIP SURFAC 16:00 - 18:00 2.00 DRILL TRIP SURFAC 18:00 - 18:30 0.50 DRILL CIRC SURFAC 18:30 - 20:00 1.50 DRILL DEOT SURFAC 20:00 - 21 :45 1.75 DRILL DRLG PROD 21:45-22:15 0.50 DRILL CIRC PROD 22:15 - 23:00 0.75 DRILL FIT PROD 23:00 - 00:00 1.00 DRILL DRLG PROD 1/1/2004 00:00 - 12:00 Start: Rig Release: Rig Number: 12/26/2003 1/18/2004 Spud Date: 12/26/2003 End: 1/18/2004 Group: Description of Operations ---.----..----.--- Printed: 3/11/2004 1 :48:28 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1/1/2004 12:00 - 00:00 1/212004 00:00 - 13:15 Page 3 of 12 ConocoPhillips Alaska Operations Summary Report 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 H II C d I Sub I Phase ours 0 e Code I 12.00 DRILL DRLG PROD 13.25 DRILL DRLG PROD 13:15 - 13:45 0.50 DRILL CIRC PROD 13:45 - 16:00 2.25 DRILL TRIP PROD 16:00 - 16:30 0.50 DRILL CIRC PROD 16:30 - 17:00 0.50 DRILL TRIP PROD 17:00 - 17:45 0.75 DRILL TRIP PROD 17:45 - 18:30 0.75 DRILL CIRC PROD 18:30 - 20:00 1.50 DRILL TRIP PROD 20:00 - 23:00 3.00 DRILL PULD PROD 23:00 - 00:00 1.00 RIGMNT RSRV PROD 1/3/2004 00:00 - 02:00 2.00 DRILL PULD PROD 02:00 - 03:45 1.75 DRILL PULD PROD 03:45 - 04:30 0.75 DRILL PULD PROD 04:30 - 07:15 2.75 DRILL TRIP PROD 07:15 - 08:15 1.00 DRILL REAM PROD 08:15 - 00:00 15.75 DRILL DRLG PROD 1/4/2004 00:00 - 12:00 12:00 - 00:00 1/5/2004 00:00 - 16:00 16:00 - 16:45 16:45 - 18:45 18:45 - 19:30 19:30 - 20:45 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 16.00 DRILL DRLG PROD 0.75 DRILL 2.00 DRILL 0.75 DRILL 1.25 DRILL CIRC PROD WIPR PROD CIRC PROD WIPR PROD Start: Rig Release: Rig Number: 12/26/2003 1/18/2004 Spud Date: 12/26/2003 End: 1/18/2004 Group: Description of Operations Drill fl 3870' to 4640' ART = 9.0 hrs AST = 0.2 hrs WOB 5/20K, RPM 90, 550 gpm @ 2250 psi, UP 115K, DN 85K, ROT 98K, TO 9K on 16K off, Ave. ECD's 11.8 to 12.0 ppg, Ave. BGG 35 units Drill fl 4640' to 5661' ART = 9.4 hrs AST = 0.3 hrs WOB 5/20K, RPM 90, 550 gpm @ 2850 psi, UP 11 OK, DN 90K, ROT 107K, TO 6/10K on / 7/1 OK off, Ave. ECD's 11.8 to 12.2 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 ppb fine LCM in mud, Ave. BGG 30 units, Had LWD failure @ 5661'. Pump Hi-vis sweep & circ hole clean. Monitor well- static, Pump out of hole to 4086'. Circ btm's up & hole clean at rate of 550 gpm @ 2700 psi, (Had excess amount of clay cakes over shakers). POOH to 3725' - Hole tight 15K over & swabbing. Pump out of hole to 2997' . Circ btm's up @ 2997', Monitor well- OK, Pump dry job. POOH on elevators to BHA. PJSM, Remove A.A. Sources, Down load MWD tools, Trouble shoot LWD failure (Found short in Density/Neutron tool), Lay down BHA, Check bit. Slip & cut drilling line. Make up BHA #3, Bit, motor, MWD, LWD, Orient motor. Had bad communication with tool due to dirty connection, Break and reservice connections, Finish making up BHA, Program same. PJSM, Load RA Sources. RIH wI HWDP, Surface test MWD tools- OK, RIH to 5540' with no problems. Make MAD Pass f/5540' to 5661', Pump Hi-vis sweep, Trip gas 131 units. Drill f/5661' to 6730' ART= 9.2 hrs AST= 2.1 hrs WOB 5/20K, RPM 90,560 gpm @ 3050 psi, UP 150K, DN 97K, ROT 115K, TO 8/11 K on I 11 K off, Ave. ECD's 11.8 to 12.0 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 ppb fine LCM in mud, Ave. BGG 15-25 units. Drill fl 6730' to 7600' ART = 8.4 hrs AST = 0.8 hrs WOB 1 0/15K, RPM 90,570 gpm @ 2800 psi, UP 180K, DN 107K, ROT 123K, TO 11K on I 11 K off, Ave. ECD's 11.8 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 to 7 ppb fine LCM in mud, No mud lost, Ave. BGG 30 units. Drill fl 7600' to 8384' ART = 6.4 hrs AST = 1.6 hrs WOB 10/20K, RPM 90,560 gpm @ 3100 psi, UP 205K, DN 109K, ROT 140K, TO 11/15K on 115K off, Ave. ECD's 11.8 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 to 7 ppb fine LCM in mud, No mud lost, Ave. BGG 30 units. Drill fl 8384' to 9343' ART = 10.4 hrs AST = 1.4 hrs WOB 10/20K, RPM 90,560 gpm @ 3200 psi, UP 225K, DN 110K, ROT 146K, TO 14/18K on 117K off, Ave. ECD's 11.7 ppg, Pumping Hi-vis weighted sweeps every 3 to 4 stands, Mud wt. 10.5 ppg, Maintaining 5 to 7 ppb fine LCM in mud, No mud lost, Ave. BGG 20 units. Note; Top of Cairn (T4.1) @ 5356' TVD, 9339' MD Pump Hi-vis weighted sweep, & circ hole clean, Monitor well- Static. POOH fl wiper trip, Pump out to 7800' - Hole in very good shape. Circ btm's up @ 7800'. Monitor well, POOH to 5658' on elevators - hole in very good shape. Printed: 3/11/2004 1 :48:28 PM Page 4 of 12 ConocoPhillipsAlaska Operations~ummaryReport Legal Well Name: 2P-424 Common Well Name: 2P-424 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date I From - To 1 Hours I Code I îoUJe Phase , , 1/5/2004 20:45 - 23:00 2.25 DRILL WIPR PROD 23:00 - 00:00 1.00 DRILL CIRC PROD 1/6/2004 00:00 - 00:30 00:30 - 12:00 0.50 DRILL CIRC PROD 11.50 DRILL DRLG PROD 1m2004 00:00 - 00:45 0.75 DRILL TRIP PROD 00:45 - 02:00 1.25 DRILL CIRC PROD 02:00 - 02:15 0.25 DRILL OBSV PROD 02:15 - 07:30 5.25 DRILL TRIP PROD 07:30 - 08:30 1.00 DRILL PULD PROD 08:30 - 08:45 0.25 DRILL SFTY PROD 08:45 - 10:45 2.00 DRILL PULD PROD 10:45-11:15 0.50 DRILL PULD PROD 11 :15 - 12:30 1.25 RIGMNT RSRV PROD 12:30 - 14:00 1.50 RIGMNT RSRV PROD 14:00 - 16:30 2.50 DRILL OTHR PROD 16:30 - 17:00 0.50 ABAND RURD ABANDN 17:00 - 17:30 0.50 ABAND OTHR ABANDN 17:30 - 18:45 1.25 ABAND PULD ABANDN 18:45 - 00:00 5.25 ABAND TRIP ABANDN 12:00 - 20:30 8.50 DRILL DRLG PROD 20:30 - 21 :00 0.50 DRILL CIRC PROD 21:00 - 22:15 1.25 DRILL DRLG PROD 22:15 - 22:45 22:45 - 00:00 0.50 DRILL CIRC PROD 1.25 DRILL TRIP PROD Start: Rig Release: Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: 12/26/2003 1/18/2004 Description of Operations Monitor well, RIH f/5658' to 9343', Wash f/9288' to 9343'. Circ btm's up (Trip gas 70 units), Pump Hi-vis weighted sweep, Circ hole clean, Begin reducing mud weight to 10.2 ppg. Note; 2P-432 OA pressure= 700 psi, 2P-434 OA pressure= 200 psi, 2P-447 OA pressure= 0 psi. Fin circ out weighted hi-vis sweep after wiper trip Drilled 8 1/2" hole from 9,343' to 9,933' MD/5,632' TVD (590') ART 7.6 hrs, AST 0.6 hrs, 10-20K wob, 90 rpm's, 135 spm, 572 gpm, off btm pressure 2,800 psi, on btm 3,100 psi, off btm torque 15K ft-Ibs, on btm 18K ft-Ibs, rot wt 145K, up wt 256K, dn wt 111 K, ave BGG 20 units, pumped wt'd hi-vis sweeps every 3-4 stds with no change in cuttings, 10.3 ppg MW , ave ECD 11.3 ppg, Est Top of Cairn sand at ,9,339' MDI 5,356' TVD Drilled from 9,933' to 10,478' MD/5,894' TVD, (545') ART 6.6 hrs, Est Top of Bermuda sand at 9,997' MD/5,656' TVD, ave BGG 20 units, max gas from Bermuda sand, 470 units at 10,094', conn gas ranged from 5-15 units over BGG with 10.3 ppg MW and no mud loss Pumped wt'd hi-vis sweep while evaluating logs, pumped 30 bbl sweep at 2 Ib over MW Drilled from 10,478' to 10,548' MD/5,930' TVD (T.D.) ART 0.6 hrs, fin circ out sweep wIdrig with no increase in cuttings, drilled with 5-15K wob, 90 rpm's, 133 spm, 564 gpm, off btm press 2,900 psi, on btm 3,100 psi, off btm torque 18K ft-Ibs, on btm 19K ft-Ibs, 10.3 MW, ave ECD 11.2 ppg, ave BGG 20 units, rot wt 160K, up wt 270K, dn wt 106K Monitored well-static and circ btms up at 564 gpm at 2,900 psi Backreaming out of hole at drlg rate from 10,548' to 9,825' with no problems Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi Cont to back ream out of hole from 9,825' to 9,190' at 90 rpm's, 572 gpm at 2,800 psi with no problems, monitored well-static Circ 2.5x btms up at 9,190' and circ hole clean at 110 rpm's, 590 gpm at 2,700 psi, ave BGG 20 units Monitored well-static POOH wet 10 stds to 8,260' with no problems, pumped dry job and cont POOH to BHA at 1,114', SLM no corr. monitored well-static LD Ghost reamer, pump out sub, 2 jts HWD & Jars and stood back HWDP & flex DC's Held PJSM on removing radioactive sources Removed radioactive sources, downloaded MWD and LD BHA #3, cleared rig floor Pulled wear bushing Serviced rig, top drive, saver sub and grabber for top drive Slip & cut 61' of drfg line, changed out deadman nut's and bolts Evaluating logs, decision made to sidetrack well RU to run 3 1/2" Tbg cement stinger Installed wear bushing PU & MU 16 jts of 3 1/2" 9.3# L-80 EUE Mod tbg for cement stinger with muleshoe and XO's to 5" DP, Total length 502.34', RD 31/2" handling equipment TIH with 3 1/2" stinger on 5" DP to 9,275', broke circ every 20 stds W/RIH, string pu wt 170K, dn wt 103K Recieved extension on BOP test from Jeff Jones with AOGCC to test Printed: 3/11/2004 1 :48:28 PM ConocoPhillips Alaska Operations Summary Report Page 5 of 12 Legal Well Name: 2P-424 Common Well Name: 2P-424 Spud Date: 12/26/2003 Event Name: ROT - DRILLING Start: 12/26/2003 End: 1/18/2004 Contractor Name: n1334@ppco.com Rig Release: 1/18/2004 Group: Rig Name: Doyon 141 Rig Number: Date From - To H I Cd! Sub Phase Description of Operations ,ours 0 e Code 1/7/2004 18:45 - 00:00 ABANDN BOP's after setting cement plugs Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi 1/8/2004 00:00 - 01 :00 ABANDN Cont to RIH with 3 1/2" cement stinger on 5" DP, PU 16 add. jts of DP & tagged btm at 10,548' 01 :00 - 03:00 2.00 CEMEN CIRC ABANDN Circ and conditioned mud for setting cement plug, staged pump rate up to 13 bpm, 546 gpm at 1,500 psi, rotated DP at 50 rpm's on up stroke with 15K ft-Ibs torque, circ and evened MW at 10.4 ppg in & out, max gas at btms up 74 units, ave BGG 25 units and no mud loss, rot wt 137K, up wt 195K, dn wt 107K,Held PJSM with rig crew and Dowell on setting of plugs and batch mixed cement while circ hole 03:00 - 03:15 0.25 CEMEN RURD ABANDN LD 1 single of DP & MU pump-in sub and cement line 03:15 - 03:45 0.50 CEMEN PLUG ABANDN Turned over to Dowell, pumped 5 bbls FW and tested lines to 3,500 psi, cont to pump 10 bbls FW (15 total) then pumped 45 bbls, 216 sxs of Class "G" cmt with add. at 15.8 ppg and 1.17 yield, ave 3.5 bpm while pumping, initial press 680 psi, final 550, slowed rate to 2 3/4 bpm at 300 psi, followed cmt with 2 bbls FW, continued to reciprocate pipe while pumping cmt 03:45 - 04:30 0.75 CEMEN DISP ABANDN Displaced cement with rig pump, pumped 173 bbls of 10.4 ppg mud to balance plug, pumped at 4.5 bpm, initial press 350 psi, max press 700 psi, slowed rate last 10 bbls to 2.75 bpm at 500 psi, shut down with CIP @ 04:30, Est. TOe at 10,090' 04:30 - 05:15 0.75 CEMEN TRIP ABANDN POOH slow 9 stds from 10,548' to 9,700' at 1 std/2.5 min, plug balanced 05:15 - 07:45 2.50 CEMEN CIRC ABANDN Attempted to circ hole clean at 9,700', rotated at 50 rpm's with 13K ft-Ibs torque on up stroke, 130K rot wt and staged pump rate up to 546 gpm at 2,000 psi, began to see mud loss w/circ, slowed pump to 420 gpm at 1,300 psi and losses stab, at btms up began to get back cement contaminated mud and losses increased, slowed pump rate to 106 gpm at 460 psi when lost full returns, max MW out 10.3 ppg, mud thick & clabbored up at flow line when returns were lost, lost 234 bbls while attempting to circ btms up, shut down with 460 psi back pressure on DP 07:45 - 09:00 1.25 CEMEN TRIP ABANDN Beld off 460 psi on DP to -0- psi, well breathed back 72 bbls from DP 09:00 - 10:15 1.25 CEMEN TRIP ABANDN POOH from 9,700' to 7,800', attempted to est circ at 2.5 bpm, 106 gpm's at 460 psi with no returns 10: 15 - 11: 15 1.00 CEMEN TRIP ABANDN POOH from 7,800' to 5,900', calc hole fill, 14 bbls actual 7.5 bbls, attempted to circ hole at 106 gpm at 460 psi with no returns 11:15-13:00 1.75 CEMEN TRIP ABANDN POOH from 5,900' to 4,030', calc hole fill 8.1 bbls, actual 3.5 bbls, attempted to circ hole at 4,030' at 106 gpm at 450 psi with no returns 13:00 - 14:00 1.00 CEMEN TRIP ABANDN POOH from 4,030' to 2,960', attempted to circ hole at 106 gpm at 450 psi and had slight returns 14:00 - 14:30 0.50 CEMEN TRIP ABANDN POOH from 2,960' to 1,475' 14:30 - 15:30 1.00 CEMEN CIRC ABANDN Est circ at 106 gpm, circ out thick cmt contaminated mud and a large amount of clay, staged pump rate up to 12 bpm (504 gpm) at 450 psi, circ & cond mud to 10.2 ppg and circ clean with no mud loss 15:30 - 15:45 0.25 CEMEN TRIP ABANDN RIH with 3 1/2" cement stinger on 5" DP from 1,475' to 2,450' (11 stds) 15:45 - 16:15 0.50 CEMEN CIRC ABANDN Est circ at 6 bpm (252 gpm) at 200 psi, circ out contaminated mud then staged pump rate to 12 bpm at 700 psi, circ a total of 2x btms up, last btms up at 12 bpm and clean at shakers and no mud loss 16:15 - 16:30 0.25 CEMEN TRIP ABANDN RIH from 2,450 to 3,377' (11 stds) 16:30 - 17:30 1.00 CEMEN CIRC ABANDN Est circ at 6 bpm (252 gpm) at 250 psi, circ out contaminated mud then staged pump rate to 13 bpm (546 gpm) at 850 psi, circ a total of 2x btms up, last btms up at 13 bpm and clean at shakers and no mud loss Printed: 3/11/2004 1 :48:28 PM ConocoPhillips Alaska Operations Summary Report Page 6 of 12 Legal Well Name: 2P-424 Common Well Name: 2P-424 Spud Date: 12/26/2003 Event Name: ROT - DRILLING Start: 12/26/2003 End: 1/18/2004 Contractor Name: n1334@ppco.com Rig Release: 1/18/2004 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub I Phase Description of Operations Code. 1/8/2004 17:30 - 17:45 0.25 CEMEN TRIP ABANDN RIH from 3,377' to 4,400' (11 stds) 17:45 - 19:15 1.50 CEMEN CIRC ABANDN Est circ at 6 bpm (252 gpm) at 250 psi, circ out contaminated mud at btms up then increased pump rate to 13 bpm (546 gpm) at 1,050 psi, circ a total of 2x btms up 19:15 - 19:30 0.25 CEMEN TRIP ABANDN RIH from 4,400' to 5,424' (11 stds) 19:30 - 20:45 1.25 CEMEN CIRC ABANDN Est circ at 6 bpm (252 gpm) at 250 psi, circ out contaminated mud at btms up, increased pump rate to 13 bpm (546 gpm) at 1,250 psi, circ a total of 2x btms up and clean at shakers 20:45 - 21 :00 0.25 CEMEN TRIP ABANDN RIH from 5,424' to 6,424' (11 stds) 21:00 - 22:15 1.25 CEMEN CIRC ABANDN Est circ at 6 bpm (252 gpm) at 350 psi, at btms up, had fewer clay patties back at btms upand cleaned up quicker, increased pump rate to 13 bpm (546 gpm) at 1,250 psi, circ a total of 2x btms up, ave 10-20 units BGG 22:15 - 22:45 0.50 CEMEN TRIP ABANDN RIH from 6,424' to 7,740' (14 stds) 22:45 - 00:00 1.25 CEMEN CIRC ABANDN Est circ at 6 bpm (252 gpm) at 450 psi, at btms up had very little contaminated mud, only 1" to 2" clay patties, increased pump rate to 13 bpm (546 gpm) at 1,550 psi, circ a total of 2x btms up and last btms up at 13 bpm, with no mud loss and 10.2 ppg mud in & out, ave 10-20 units BGG, up wt 147K, dn wt 95K Lost 255 bbls mud last 24 hrs Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi Recieved add. extension on BOP test from Jeff Jones with AOGCC to test BOP's after setting cement plugs 1/9/2004 00:00 - 00:15 0.25 CEMEN CIRC ABANDN Fin circ 2nd btms up at 7,740' at 13 bpm at 1,550 psi and clean at shakers 00:15 - 00:45 0.50 CEMEN TRIP ABANDN RIH from 7,740' to 9,047' (14 stds) 00:45 - 02:00 1.25 CEMEN CIRC ABANDN Est circ at 252 gpm at 550 psi, at 1 st btms up circ out contaminated mud, staged pump rate to 546 gpm at 1,725 psi, circ 2x btms up and clean at shaker with no mud loss. 02:00 - 02:45 0.75 CEMEN TRIP ABANDN RIH from 9,047', washed down and tagged TOe at 9,936', set 15K wt on plug and had 400 psi increase in pump pressure 02:45 - 05:00 2.25 CEMEN CIRC ABANDN Est circ at 189 gpm at 475 psi, staged rate up to 546 gpm at 1,800 psi, at btms up had small amount of clay patties and contaminated mud, max gas at btms up 292 units, ave bgg 10-20 units, up wt 204K, dn wt 104K, held PJSM with crew and Dowell on setting cmt plug and batch mixed cement 05:00 - 05:30 0.50 CEMEN RURD ABANDN Stood back 1 std of 5" DP, MU 2 singles with pump in sub and cement line 05:30 - 06:00 0.50 CEMEN PUMP ABANDN Turned over to Dowell, pumped 5 bbls FW and tested lines to 3,500 psi, cont to pump 10 bbls FW (15 total) then pumped 45 bbls, 216 sxs of Class "G" cmt with add. at 15.8 ppg and 1.17 yield, ave 3.75 bpm while pumping, initial press 725 psi, final 425 psi, followed cmt with 2 bbls FW, reciprocate pipe while pumping cmt 06:00 - 06:45 0.75 CEMEN DISP ABANDN Displaced cement with rig pump, pumped 161 bbls of 10.2 ppg mud to balance plug, pumped at 4.5 bpm, initial press 225 psi, max press 700 psi, slowed rate last 10 bbls to 3 bpm at 500 psi, shut down with CIP @ 06:40, Calc TOe in 8 1/2" hole at 9,295' 06:45 - 07:30 0.75 CEMEN TRIP ABANDN LD 2 jts 5" DP and POOH slow at 1 std/2.5 min from 9,936' to 9,047', well balanced 07:30 - 08:45 1.25 CEMEN CIRC ABANDN Circ btms up at 9,047' after setting cmt plug, est circ at 6 bpm at 625 psi, staged up to 7 bpm at 800 psi, no cmt contaminated mud at btms up Printed: 3/11/2004 1 :48:28 PM ConocoPhillips Alaska Operations Summary Report Cont to circ hole clean after cmtg, staged pump rate up to 420 gpm at 1,200 psi, circ hole while W.O.C. RIH from 9,047', washed down and tagged TOC @ 9,168', set 15K down on plug and had 350 psi increase in pump pressure Circ and cond mud for cement plug #3, staged pump rate up to 420 gpm at 1,200 psi, no mud loss, held PJSM and batch mixed cement while circ MU Pump in sub and cement line Turned over to Dowell, pumped 5 bbls FW and tested lines to 3,500 psi, cont to pump 10 bbls FW (15 total) then pumped 45 bbls, 216 sxs of Class "G" cmt with add. at 15.8 ppg and 1.17 yield, ave 4 bpm at 600 psi, followed cmt with 2 bbls FW, reciprocate pipe while pumping cmt 0.50 CEMEN DISP ABANDN Displaced cement with rig pump, pumped 146 bbls of 10.2 ppg mud to balance plug, pumped at 4.5 bpm, ave 600 psi, slowed rate last 10 bbls to 2 bpm at 380 psi, shut down with CIP @ 16:00, Calc TOe in 81/2" hole at 8,527' 1.00 CEMEN TRIP ABANDN LD single with pump in sub and POOH slow at 1 std/2.5 min to 8,210' 7.00 CEMEN CIRC ABANDN Est circ at 6 bpm, circ btms up after cement job and had no cement back with 60 bbls of contaminated mud, staged pump rate up to 510 gpm at 1,850 psi while circ hole clean with 10.2 ppg mud, W.O.C. and waiting on Dowell to deliver cement for kick-off plug, PU wt 170K, DN wt 95K, ave BGG 10 units, Access road and pad in phase 2 condition at 21 :00 hrs, Jeff Jones with AOGCC was to come out and witness tag of cement plug but waived witnessing due to weather Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi 0.75 DRILL CIRC ABANDN Cont to circ hole at 510 gpm at 1,850 psi and 10.2 ppg mud while W.O.C. and waiting on Dowell to deliver cement for kick-off plug, PU wt 170K, DN wt 95K, ave BGG 10 units, Access road and pad in phase 2 condition 0.50 DRILL TRIP ABANDN RIH from 8,210', est circ at 1.5 bpm and tagged TOe at 8,326', (200' above calc top) had 400 psi increase in pressure with 20K wt on plug, shut pump down and held 20K on plug for 15 min, Jeff Jones with AOGCC was to come out and witness tag of cement plug but waived witnessing due to weather POOH from 8,326' to 7,592' to spot weighted hi-vis pill, Dowell arrived location with kick-off plug cement Pump and spotted 35 bbl, weighted (1# over mw) hi-vis pill from 7,592' to 7,100', pumped at 4.5 bpm at 475 psi POOH from 7,592' to 7,096' Circ 1 complete circ at 7,096', Est circ at 6 bpm at 650 psi and staged rate up to 8 bpm at 900 psi, had no wt'd hi-vis pill at btms up with 10.2 ppg mud in & out MU pump in sub and cement hose, batch mixed cement Dowell pumped 5 bbls FW, tested lines to 3,500 psi, pumped 5 add. bbls FW, then pumped 37 bbls, 207 sxs of class "G" cement at 17.0 ppg and 1.0 yield, ave 4.5 bpm at 600 psi, followed with 1.5 bbls water, reciprocated pipe, up wt 145K, dn wt 93K 0.50 CEMEN DISP ABANDN Rig displaced cement with 112 bbls of 10.2 ppg mud to balance plug, ave 4.5 bpm at 500 psi, slowed to 1.5 bpm at 350 psi, CIP at 05:30 hrs, calc TOe in 81/2" hole at 6,569' 0.75 DRILL TRIP ABANDN POOH 8 stds slow from 7,096' to 6,353', pulled at 1 std/3 min's, plug balanced Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 I Sub From - To Hours I Code Code Phase 1/9/2004 08:45 - 11 :00 2.25 CEMEN CIRC ABANDN 11 :00 - 11 :15 0.25 CEMEN TRIP ABANDN 11:15-14:30 3.25 CEMEN CIRC ABANDN 14:30 - 15:00 0.50 CEMEN RURD ABANDN 15:00 - 15:30 0.50 CEMEN PUMP ABANDN 15:30 - 16:00 16:00 - 17:00 17:00 - 00:00 1/10/2004 00:00 - 00:45 00:45 - 01:15 01 :15 - 01 :45 0.50 DRILL TRIP ABANDN 01 :45 - 02:45 1.00 DRILL CIRC ABANDN 02:45 - 03:15 0.50 DRILL TRIP ABANDN 03:15 - 04:30 1.25 DRILL CIRC ABANDN 04:30 - 04:45 0.25 CEMEN RURD ABANDN 04:45 - 05:00 0.25 CEMEN PUMP ABANDN 05:00 . 05:30 05:30 - 06:15 Page 7 of 12 Start: Rig Release: Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: 12/26/2003 1/18/2004 Description of Operations Printed: 3/11/2004 1 :48:28 PM ConocoPhillips Alaska Operations Summary Report Page 8 of 12 Legal Well Name: 2P-424 Common Well Name: 2P-424 Spud Date: 12/26/2003 Event Name: ROT - DRILLING Start: 12/26/2003 End: 1/18/2004 Contractor Name: n1334@ppco.com Rig Release: 1 /18/2004 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 1/10/2004 06:15 - 08:30 2.25 DRILL CIRC ABANDN Circ btms up after cement job at 6 bpm at 750 psi, reciprocated pipe on up stroke, at btms up had 75 bbls of cement contaminated mud, max wt out 10.8 ppg, cont to circ hole and circ add. btms up, staged pump rate to 9 bpm at 1,600 psi 08:30 -10:15 1.75 DRILL TRIP ABANDN Monitored well-static, pumped dry job and POOH from 6,353' to 3,103', inspected DP on trip out and found cement inside DP at 3,103' 10:15 - 12:30 2.25 DRILL PULD ABANDN RU & POOH LD 87 jts of 5" DP with cement built up inside from 1/8" to 1/4" 12:30 - 14:30 2.00 DRILL PULD ABANDN RU & POOH LD 16 jts of 31/2" tbg stinger, also had cement inside, cleared rig floor & pulled wear bushing 14:30 - 19:30 5.00 WELCT BOPE PROD RU & tested BOPE, tested valves, manifold and rams to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, Installed wear bushing & RD Note: Jeff Jones W/AOGCC waived witnessing of BOP test 19:30 - 23:00 3.50 DRILL PULD PROD MU 81/2" Bit #3 on BHA #4 and RIH to 199', oriented & initialized MWD, held PJSM and loaded Radioactive sources 23:00 - 00:00 1.00 DRILL TRIP PROD TIH with HWDP & BHA #4 to 1,114' and MU ghost Reamer Access road and pad still in phase 2 Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi 1/11/2004 00:00 - 00:15 0.25 DRILL PULD PROD Fin MU BHA #4, Shallow tested MWD 00: 15 - 03:30 3.25 DRILL PULD PROD PU 102 jts of 5" dp from pipe shed & TIH to 4,300' with BHA #4 and broke circ. 03:30 - 04:30 1.00 DRILL TRIP PROD TIH from 4,300' to 5,300' with dp out of derrick, inspected & rattled pipe and ck ok 04:30 - 04:45 0.25 DRILL CIRC PROD Circ 1 dp cap to clear dp and check MWD, 420 gpm at 1,800 psi, 60 rpm's with 6K ft-Ibs off btm torque 04:45 - 05:15 0.50 DRILL TRIP PROD TIH from 5,300' to 6,312' 05:15 - 06:45 1.50 DRILL CIRC PROD Circ and cond mud at 6,312', circ out contaminated mud and circ hole clean at 460 gpm at 2,200 psi, circ 2x btms up, with 10.2 ppg mw had 11.0 ECD clean hole 06:45 - 09:00 2.25 DRILL REAM PROD Washed down from 6,312' to tag TOC, washed at 106 gpm at 350-600 psi, washed down to 6,957' and did not tag firm cement, calc TOC was at 6,569', 09:00 - 10:15 1.25 DRILL CIRC PROD Circ and cond mud at 6,957, circ out contaminated cement at 460 gpm at 2,250 psi with no firm cmt at btms up, rot wt 117K, up wt 168K, dn wt 98K, 60 rpm's with 8K ft-Ibs off btm torque, PU to 6,870' KOP 10:15 - 00:00 13.75 DRILL DRLG PROD Time drilling 8 1/2" hole for open hole sidetrack from 6,870' MD/4, 194' TVD to 6,931' MD/4,224' TVD (61 ') AST 13 hrs, 0-5K wob, 560 gpm at 3,000 psi, rot wt 117K, up wt 168K, dn wt 98K, building new 10.2 ppg LSND mud in pits while drilling, ave BGG 15-20 units Outer Annulus Pressures: 2P 432-700 psi, 2P 434-250 psi, 2P 447 -0- psi 1/12/2004 00:00 - 01 :00 1.00 DRILL DRLG PROD Cont to Time drill 8 1/2" hole from 6,931' to 6,940', AST 1 hr, displaced out mud in hole with new 10.2 ppg LSND mud, check shot survey showed well to be sidetracked 01 :00 - 12:00 11.00 DRILL DRLG PROD Drill, slide & survey per directional plan from 6,940' to 7,665' MD/4,539' TVD, (725') ART 4.2 hrs, AST 3.6 hrs, 5-15K wob, 90 rpm's, 560 gpm, off btm pressure 2,950 psi, on btm 3,000 psi, off btm torque 10K ft-Ibs, on btm 11 K ft-Ibs, rot wt 126K, up wt 182K, dn wt 107K, 10.2 ppg mw, ave ECD 11.2 ppg, ave BGG 45 units, conn gas 10 units over BG 12:00 - 00:00 12.00 DRILL DRLG PROD Drill from 7,665' to 8,352' MD/ 4,776' TVD (687') ART 9.2 hrs, AST -0-, 5-10K wob, 90 rpm's, 560 gpm, off btm pressure 2,950 psi, on btm Printed: 3/11/2004 1 :48:28 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1/12/2004 12:00 - 00:00 1/13/2004 00:00 - 12:00 12:00 - 20:30 ConocoPhillips Alaska" Operations Summary Report, .. 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 I Sub Hours I Code Code Phase ! 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 8.50 DRILL DRLG PROD 20:30 - 21 :30 1.00 DRILL CIRC PROD 21 :30 - 23:00 1.50 DRILL WIPR PROD 23:00 - 00:00 1.00 DRILL CIRC PROD 1/14/2004 00:00 - 01 :00 1.00 DRILL WIPR PROD 01 :00 - 03:30 2.50 DRILL WIPR PROD 03:30 - 05:00 1.50 DRILL CIRC PROD 05:00 - 12:00 12:00 - 00:00 1/15/2004 00:00 - 11 :00 7.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 11.00 DRILL DRLG PROD Page 9 of 12 Start: Rig Release: Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: 12/26/2003 1/18/2004 Description of Operations 3,100 psi, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, rot wt 134K, up wt 193K, dn wt 108K, 10.2 ppg mw, ave ECD 11.35 ppg, ave BGG 50 units, conn gas 10 units over BG Outer Annulus Pressures: Changed out gauges to reconfirm pressures, 2P 432 -0- psi, 2P 434 -380 psi, 2P 447 -0- psi Note production has installed additional instrumentation on wellheads Drilled 81/2" hole from 8,352' to 9,280' MD/5,092' TVD, (928') ART 7.8 hrs, AST 1.1 hrs, 5-15K wob, 90 rpm's, 560 gpm, off btm press 3,050 psi, on btm 3,300 psi, off btm torque 13K, on btm 14K, rot wt 133K, up wt 21 OK, dn wt 107K, 10.2 ppg mw, ave ECD 11.4 ppg, ave BGG 50-70 units Drilled from 9,280' to 9,930' MDI 5,320' TVD (650') ART 5.5 hrs, AST .9 hrs, 10-15K wob, 90 rpm's, 560 gpm, off btm pressure 3,050 psi, on btm 3,200 psi, off btm torque 14.5K ft-Ibs, on btm 16K ft-Ibs, rot wt 145K, up wt 220K, dn wt 108K, 10.2 ppg mw, ave ECD 11.4 ppg, ave BGG 70 units, max gas 116 units, conn gas 10 units over BG, pumping weighted hi vis sweeps 2# over MW every 5 stds with 10-20% increase in cuttings Pumped wt'd hi-vis sweep and circ out, had 20% increase in cuttings from sweep, circ 1.5x btms up at 560 gpm at 3,200 psi and 100 rpm's Monitored well 10 min-static, backreamed out of hole from 9,930' to 8,820' at 100 rpm's 560 gpm at 3,000 psi with no problems Circ hole clean at 8,820', circ at 560 gpm, 2,950 psi and 90 rpm's, max gas at btms up 150 units, ave BGG 50-60 units Outer Annulus's 2P-447 -0-, 2P-434 360 psi, 2P-432 Put on Line with 700 Psi on Ann. Monitored well @ 8,820', well-static, POOH on elevators wet from 8,820' to 6,685', had 40K drag at 7,160', worked thru and ck ok, cont POOH thru sidetrack to 6,685' with no problems RIH from 6,685' to 9,840', oriented and RIH thru sidetrack with no problems, no other problems RIH to 9,840' Washed 90' to btm at 9,930', pumped weighted hi vis sweep and circ out of hole at 560 gpm at 3,000 psi and 100 rpm's with no increase in cuttings from sweep, max gas at btms up 139 units, ave BGG 50 units, max ECD 11.6 ppg down to 11.2 ppg Drilled 81/2" hole from 9,930' to 10,394' MD/5,483' TVD (464') ART 5 hrs, 8-18K wob, 100 rpm's, 550 gpm, off btm pressure 3,100 psi, on btm 3,300 psi, off btm torque 14K, on btm 15.5K, rot wt 141 K, up wt 247K, dn wt 109K, 10.2 ppg mw, ave ECD 11.4 ppg, ave BGG 70 units Began adding 7 ppb LCM to mud while drilling Cairn sand, 3 ppb G-Seal, 3 ppb Mix II fine and 1 ppb nut plug med, no difinitive top seen for Cairn sand Drilled from 10,394' to 11,044' MDI 5,705' TVD (650') ART 7.5 hrs, AST.8 hrs, 5-15K wob, 110 rpm's, 560 gpm, off btm pressure, 3,000 psi, on btm 3,250 psi, off btm torque 19.3K ft-Ibs, on btm 19.4K ft-Ibs, 4% lubes in mud, rot wt 150K, up wt 270K, dn wt 105K, 10.2 ppg mud, ave ECD 11.3 ppg, with 7 ppb LCM, pumping weighted sweeps every 5 stds with 0-10% increase in cuttings back. Geologist top for Bermuda at 10,620' MD/5,562' TVD (30' TVD High) max gas from Bermuda 1462 units from 10,735' ave BGG 150-200 units, no connection gas Outer Annulus's 2P-432 620 psi, 2P-434 500 psi, 2P-447 -0- Drilled 8 1/2" hole from 11,044' to 11,539' MD/5,873' TVD (T.D.) (495'), Printed: 3/11/2004 1 :48:28 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ConocoPhillips Alaska Operations Summary Report 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 Page 10 of 12 Start: Rig Release: Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: 12/26/2003 1/18/2004 Date Sub From- To Hours Code Code Phase Description of Operations 1/15/2004 00:00 - 11 :00 11 :00 - 11 :30 11 :30 - 12:30 12:30 - 14:30 14:30 - 15:30 15:30 - 18:45 18:45 - 19:00 19:00 - 00:00 1/16/2004 00:00 - 00: 15 00:15 - 01:00 01 :00 - 01 :45 01 :45 - 03:30 03:30 - 04:15 04:15 - 05:15 05:15 - 05:30 05:30 - 06:00 06:00 - 07:30 07:30 - 10:30 10:30 - 11:00 11 :00 - 12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 17:15 11.00 DRILL 0.50 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 3.25 DRILL 0.25 DRILL 5.00 DRILL 0.25 DRILL 0.75 DRILL 0.75 DRILL 1.75 DRILL 0.75 DRILL 1.00 DRILL 0.25 DRILL 0.50 DRILL 1.50 DRILL 3.00 DRILL 0.50 DRILL 1.00 CASE 2.00 CASE 0.50 CASE 2.75 CASE DRLG PROD OBSV PROD CIRC PROD WIPR PROD WIPR PROD CIRC PROD OBSV PROD TRIP PROD TRIP PROD CIRC PROD TRIP PROD CIRC REAM PROD PROD TRIP OBSV CIRC TRIP PROD PROD PROD PROD PULD PROD PULD PROD RURD PROD RUNe PROD RURD PROD RUNe PROD ART 8.9 hrs, 5-15K wob, 90-110 rpm's, 550 gpm, off btm pressure 3,200 psi, on btm 3,350 psi, off btm torque 21.5K ft-Ibs, on btm 22-23K ft-Ibs, 4% lubes in mud, 10.2 ppg mw, ave ECD 11.3 ppg, pumping wt'd hi-vis sweeps every 5 stds with no increase in cuttings, rot wt 148K, up wt 290K, dn wt 105K, ave BGG 55 units at T. D. Monitored well 15 min-static, got slow pump rates at T.D. Circ btms up after monitoring well, circ at 570 gpm at 3,400 psi and 110 rpm's, max gas at btms up 224 units Wiped hole from 11,539' to 9,650', backreamed out f/11,539' to 10,212' at 550 gpm, 3,150 psi and 100 rpm's, then POOH on elevators to 9,650' with no problems RIH to 11,450', washed 89' to btm at 11,539', no problems RIH Pumped weighted (2# over MW) hi-vis sweep and circ hole clean, circ at 550 gpm, 3,150 psi, 120 rpm's, no increase in cuttings from sweep, max gas at btms up 235 units, ave BGG 55 units, circ 3x btms up, rot wt 148K, pu wt 280K, dn wt 105K Monitored well 15 min-static POOH to run csg, pumped out at 550 gpm at 3,050 psi from 11,539' to 10,119', monitored well-static, POOH on elevators wet 15 stds to 8,727' with no problems, monitored well-static and pumped dry job, cont POOH, no problems thru sidetrack at 6,685' began seeing 20-30K add. drag, POOH to 6,190' and no change, (To RIH to 6,685 & Circ 2x btms up, last wiper trip was to 6,685') Outer Annulus's 2P-432 600 psi, 2P-434 500 psi, 2P-447 -0- Ran back in hole from 6,190' to 6,685' due to 25K addition drag Circ hole clean at 6,685', circ at 585 gpm, 3,000 psi at 110 rpm's, large amount of cuttings back at btms up, max gas 225 units, circ add. btms up Cont POOH from 6,685' to 5,940' and cont to see 25K add. drag at 5,940' Precautionary back reamed out of hole from 5,940' to 4,549' at 550, 2,500 psi and 90 rpm's Circ hole clean at 4,549', initial rate of 550 gpm at 2,500 psi, ECD's increased to 12.1 ppg and began having mud losses, lost 25 bbls, slowed pump to 420 gpm at 1,800 psi and gained mud back, circ out large amount of cuttings and circ clean POOH wet from 4,549' to 3,050', (95/8" csg shoe) Monitored well at shoe-static CBU at shoe, 420 gpm at 1,200 psi, no gas at btms up, pumped dry job POOH from 3,050' to 190', monitored well at HWDP well-static, POOH and stood back HWDP & flex De's, LD ghost reamer Held PJSM on removing radioactive sources, removed radioactive sources, downloaded MWD and LD BHA #4 Pulled wear bushing RU Doyons csg equipment to run 3 1/2" x 5 1/2" monobore csg, cleared rig floor Ran 3 1/2" 9.3# L-80 EUE-M csg to 1,092', MU float shoe, 6 jts of 31/2" csg, float collar, 1 jt csg with plug catcher, threadlocked conn below fit collar and pumped thru float equip & ck ok, RIH with 28 jts of 31/2" to 1,092' (35 jts 3.5" 9.3# L80 EUE total) RU 5 1/2" csg equipment with Franks fill-up tool MU 3 1/2" x 5 1/2" XO assembly with seal bore extension and RIH with Printed: 3/11/2004 1 :48:28 PM 21:00 - 22:15 22:15 - 00:00 1/17/2004 00:00 - 04:30 04:30 - 04:45 04:45 - 05:30 05:30 - 10:30 10:30 - 11 :30 11 :30 - 12:45 12:45 - 13:15 13:15 - 14:15 14:15 - 00:00 1/18/2004 00:00 - 01:15 01: 15 - 01 :30 01 :30 - 10:00 10:00 - 11:30 Page 11 of 12 ConocoPhillips Alaska Operations Summary Report RUNe PROD CIRC PROD RUNC PROD 1.25 CASE CIRC PROD 1.75 CASE RUNe PROD 4.50 CASE RUNe PROD 0.25 CASE CIRC PROD 0.75 CEMEN RURD PROD 5.00 CEMEN CIRC PROD 1.00 CEMEN PUMP PROD 1.25 CEMEN DISP PROD 0.50 CEMEN RURD PROD 1.00 CASE OTHR PROD 9.75 DRILL PULD PROD 1.25 CMPL TN RURD CMPL TN 0.25 CMPL TN SFTY CMPL TN 8.50 CMPL TN RUNT CMPL TN 1.50 CMPL TN SOHO CMPL TN Start: Rig Release: Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: Legal Well Name: 2P-424 Common Well Name: 2P-424 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 I I 'Sub, Date_.~~~m - To i Hours I Code, Code Phase 1/16/2004 14:30 - 17:15 2.75 CASE 17:15 - 17:45 0.50 CASE 17:45 - 21:00 3.25 CASE 12/26/2003 1/18/2004 Description of Operations 51/2" 15.5# L-80 BTC-M csg to 2,979' Circ btms up at 2,979' (9 5/8" csg shoe @ 3,005') Cont RIH with 5 1/2" csg, RIH 40 jts then washed down 5 jts, RIH to 6,720' (165 its total of 31/2" & 5 1/2" csg) Circ btms up at 6,720' conditioning mud, staged pump rate to 5 bpm at 630 psi, reciprocated csg with full returns, csg up wt 100K, dn wt 70K Cont RIH with 5 1/2" csg to 8,430', no problems going thru sidetrack at 6,870',205 total its in hole, up wt 125K, dn wt 75K, no other problems RIH Outer Annulus's 2P-432 620 psi, 2P-434 500 psi, 2P-447 -0- Cont running 5 1/2" csg, washed down 5 its from 8,430' to 8,605', cont RIH with csg with no problems, MU landing it and landed csg with float shoe at 11,530', float collar at 11,344' and plug catcher at 11,313', ran a total of 35 its 31/2" 9.3# L-80 EUE-M, XO assembly W/SBE and 242 jts 5 11/2" 15.50# L-80 BTC-M csg, Totallenght including hanger & float equipment 11,505.02' Circ hole thru fill-up tool while RD tongs RD Franks fill-up tool, blow down top drive and MU cement head Circ and cond mud for cementing, staged pump rate up to 6 bpm at 600 psi, reciprocated pipe, up wt 185K, dn wt 72K, lower mw from 10.3 and YP 21 to 10.2 ppg mw and 15 YP with full returns, circ 3x btms up conditioning mud, held PJSM on cementing and batch mixed cement while circ. Turned over to Dowell and pumped 10 bbls of 8.3 ppg CW 100, tested lines to 4,000 psi, cont pumping 50 bbls of CW 100 (60 total), ave 3.5 bpm at 500 psi, pumped 30 bbls of Mudpush at 11.0 ppg, ave 5 bpm at 750 psi, pumped tail cement, pumped 141.5 bbls, 678 sxs of class "G" gasblok cmt at 15.8 ppg and 1.17 yield with additives, ave 5 bpm, initial press 950 psi, final press 700 psi, shut down, washed cement lines to rig floor and dropped tandem top & btm darts Displaced cement with 255 bbls of 8.5 ppg seawater, ave 7 bpm, initial press 460 psi, slowed rate to 2.5 bpm last 15 bbls, saw darts go thru XO/SBE, final press 1,000 psi, bumped plugs on calc displacement, pressured up to 1,600 psi and held for 5 min, bled off and ck floats and floats held, reciprocated pipe until 41 bbls of displacement to go and landed csg, had full returns throughout job, CIP at 12:28 hrs 1-17-04, est TOe at 10,100' RD cement head and landing it Installed FMC 5 1/2" pack-off and tested to 5,000 psi for 15 min RU & LD 5" DP from derrick, LD 264 Jts, found cement built up inside 105 jts of 5" LD Note: John Crisp W/AOGCC waived testing of BOPE till after rig move Outer Annulus's 2P-432 650 psi, 2P-434 500 psi, 2P-447 -0- Well 432 is online RU Doyon's 3 1/2" tbg handling equipment and cleared rig floor Held PJSM with Saker Rep, Tong operator and rig crew on running completion Ran 31/2" completion per well plan for producer, ran Saker 80-40 GBH-22 seal assembly, Cameo "D" Nipple, and CMU sliding sleeve with 330 jts of 3 1/2" 9.3#, L-80. EUE-M tbg, 5-3 1/2" x 1" KBG 2-9' GIM's with with DCK shear valve in btm mandrel, RIH to 10,374', Est circ and RIH locating top of seal assembly, spaced out tbg, MU hanger and landing it. Printed: 3/11/2004 1:48:28 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 12 of 12 ConocoPhillips Alaska 'Operations Summary Report 2P-424 2P-424 ROT - DRILLING n1334@ppco.com Doyon 141 Date From - To I Hours Code îouJe Phase I 11 :30 - 13:30 2.00 CMPL TN CIRC CMPL TN 1/18/2004 13:30 - 14:00 14:00 - 15:30 Start: 12/26/2003 Rig Release: 1/18/2004 Rig Number: Spud Date: 12/26/2003 End: 1/18/2004 Group: Description of Operations _____.__._._. _n_ _"."_...___"._______...__ Circ out dirty seawater, circ 480 bbls, 2x btms up of seawater to clean out well, tbg up wt 10SK, dn wt 63K 0.50 CMPL TN SOHO CMPL TN Landed tbg with btm of seals at 10,422' and locator seal assembly at 10,403', "D" nipple with 2.75" no go @ 10,3S9', CMU sliding sleeve with 2.810" DS profile @ 10,343' DCK shear valve @ 10,293', Cameo "DS" nipple with 2.87S" no go at 497', RILDS Total Lenght of completion assembly 10,378.76' not including seals 1.50 CMPL TN DEQT CMPL TN RU & tested 31/2" tbg to 3,500 psi for 30 min, bled tbg to 1,SOO psi, pressure tested S 1/2" csg to 3,SOO psi for 30 min, good tests, bled tbg down and sheared RP valve Note John Crisp W/AOGCC waived witnessing of test LD landing jt and set TWC ND BOP stack NU 11" SM adapter with 3 1/2" SM Tree and tested tree to 5,000 psi for 15 min, pulled TWC Freeze protected well with SO bbls of diesel, allowed well to U-tube Installed TWC and cleaned out around cellar, secured well Outer Annulus's 2P-432 7S0 psi, 2P-434 SOO psi, 2P-447 -0- 15:30 - 16:30 1.00 CMPL TN RURD CMPL TN 16:30 - 18:00 1.50 WELCT NUND CMPL TN 18:00 - 20:30 2.S0 CMPL TN NUND CMPL TN 20:30 - 23:00 2.50 CMPL TN FRZP CMPL TN 23:00 - 00:00 1.00 CMPL TN OTHR CMPL TN NOTE: performed LOT on 9 S/8" x 51/2" ANN, LOT to 15.5 ppg, with 640 psi, 10.3 ppg mud and 2,386' TVD, flushed annulus with 300 bbls water and freeze protected with 80 bbls diesel Released Rig @ 24:00 Hrs 1-18-04 to move to 2P-447 Completion Printed: 3/11/2004 1 :48:28 PM e e Well Name Date Summary 2P-424A 02/13/04 DRIFTED TBG W/12' X 2.5" DUMMY GUN TO 11005' RKB, SET 2.75" CATCHER @ 10359' RKB, PULLED 1" DCK SHEAR OUT VALVE @ 10294' RKB, JOB IN PROGRESS.D [Tag, Pressure Data] 2P-424A 02/14/04 SET 1" DV @ 10294' RKB, MIT TBG TO 1500 PSI, MIT IA TO 3500 PSI, TESTED GOOD, PULLED CATCHER @ 10359' RKB.D [PT Tbg-Csg] 2P-424A 02/14/04 INCOMPLETE OPERATION. COULD NOT GET DOWNHOLE THROUGH DEVIATION. ORDER 2.5" HSD GUN AND REATTEMPT JOB TOMORROW. NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN.D 2P-424A 02/15/04 PERFORATE THE INTERVAL: 10850-10862 USING 2.5" HSD GUNS LOADED v WITH 2506 HYPERJET, RDX CHARGES. 2P-424A 02/16/04 PUMP FRACTURE TREATMENT USING 30# X-LINKED GEL AT 30 BPM, REDUCING PUMP RATE TO 26 BPM AT END OF JOB DUE TO EXCESS PIPE FRICTION. PUMPED A TOTAL OF 237,776# OF 16/20 CERAMIC PROPPANT, PLACING 210,841# BEHIND PIPE WITH 10 PPA ON PERFS. 2P-424A 02/21/04 PERFORMED A POST FRAC FILL CLEAN OUT TO A DEPTH OF 11,180' CTM APROX 11,200' RKB. WELL IS CURRENTLY FREEZE PROTECTED TO 11,200' RKB. RETURNS 1-1 THROUGHOUT THE PROGRAM. 2P-424A 02/24/04 DRIFTED TBG TO 11,148' RKB, EST. 286' RATHOLE. MEASURED BHP @ 10856' RKB: 2780 PSI. ATTEMPTED PULL DV @ 10294' RKB. IN PROGRESS.D [Tag, Pressure Data, GLV] 2P-424A 02/25/04 PULLED DV, SET 5/16" PORT OV @ 10294' RKB. RETURN WELL TO DSO TO BOL. D [GLV] 2P-424A 03/03/04 TAGGED HYDRATES AT 3476'CTMD TAGGED BOTTOM AT 11240'CTMD LAYED IN DIESEL FROM 10350'CTMD LEFT WELL SHUT IN. HANDED WELL OVER TO PTS FOR FLOW BACKD [Hydrates-Ice, Vortech] Conocd'hillips ConocoPhillips Alasklc.,Slot #424 Drill Site 2P, Meltwater,North Slope, Alaska éJCY-I-CO~ SURVEY U.G Page 1 Well bore: 424A Well path: MWD wlSag <6940 - 11539'> Date Printed: 3-Feb-2004 J'i. BAKER HUGHES INTEQ - ... 1~lbOr!! 424A I Created 13-Jan-2004 I Last Revised 18-Jan-2004 ~Wéll ~ I Govemment ID I ~~~~::~~~~ Slot Name Installation· Drill Site 2P 441964.238 r~:~, I Eastina I Northino 441964 238 ·····1 ' ....:'......:.,..:.......... " .. ..,...,.......'.::. ..:.......<J..:...... .. ........:....... ................. .. ".... .. ......:'<.::......... ......:.......::.............. .. .......:........-.. : <................ .... ".. .. .....:..... ..................... ',' .. ',' :.... .. .." .... '.:...',.. ',' " ...........,...,........... ......::'.., :.,", ....'.........::<..',.,,'..>:.. ...... .. ',.,":. ,',.. ,,·c'.·,':.:···.:.. .. ',"'.. '"....... :.:. :.....,.:.'...:..........;>'.'>,..., ',':., :.".:.. .. .. ,,' .... .,'," " .......,..........,.. ...... ··.·..c. ........ ......... . . ·.··........·.·.·..,...·.....0 ,.".........:.... ..... :..> North Alionment 586989146J ~ =:ERICAN D@JM 1977 '","ml True Creåted B Alaska Oil & Gas Cons Com . . . mlS$IOn Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 9189.78 Feet on azimuth 154.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~~'b\\,,~ y ConocoPhillips ConocoPhillips Alasklc.,Slot #424 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LI.G Page 2 Well bore: 424A Well path: MWD w/Sag <6940 - 11539'> Date Printed: 3-Feb-2004 ".. BAKER HUGHES INTEQ WeIlDathlGricJ'iR.eØôrt ... .......... .i/· .... .. . . MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing dea/100ftl Sectionlftl f',R77 'I, f',? nF 148.1 ~ 4197.7: <I.?'If', nf',~ 0.00 4878.1 n. f',Ç)<l.n n' !)f', RP 1<1.R ?! <I.??Ç) !)I A?R1 a7C R ?f1 <l.Ç)'I? 1 6968.9 56.81 149.2 4245.3 4302.65 2460.24E 2.88 4956.3 446438.8 5864645.9 7nf',? nl !)R !)7 1!)1 f',' 4295.1 4371.1m 2.89 5035.01 71!i4 'II f',17f 1!)!) 4' 4'\41 nl AAA? ~ac ""'> "". 4.91 5114.7! 7246.8 65.2C 158.0 4382.4 4518.69 2567.28E 4.54 5196.9 446544.2 5864429.1 7'1'1Ç) 41 f',7 nA 1!)Ç) n~ <I.<I.1Ç) Ç), A<:a7 <:<:c 2.24 5280.7' '''''"7 " 1, 74'\2.f',: f',7.7f 1!)Ç)7! 44!)!).7! 4f',7R.nf',~ 2f',?R.!)nF 1.n? !)'If',!) !)I 446604.2: 5864269.3 7525.2 68.8e 161.3~ 4490.0 4759.24 2657.15E 2.02 5450.1 446632.3 5864187.9 7f',1741 f',R Ç)f 1f',n.Rr 4!)?'\.1 4P.4n !i4~ 0.6C 5534.5: 446659.5: 5 7709.4, 69.14 161.'\f 4!)!)6.0! 4Ç)? 1 R6~ ?71?R!)F 06? !)61R.RI 446f',Rf',.R: 7803.1 69.2£ 161.1C 4589.3 5004.78~ 2741.02E 0.3 5704.7 446714.3 5863941.8 789621 696r 161.1 46220: <:nR7 "Inc 0.'1:1 !)7Ç)n.'\, 1 7988.7, 69.7£ 161.14 4654.1 5169.37~ 021 5875.4 44f',769.4' !)86'\776.R 8081.8 70.1C 160.8 4686.0. 5252.01 2825.82E 0.4 5961.2 446797.3 5863694.0 817411 704f 1616r 47172' <:"I"IA "11 n R9 f',04f',!): AA~R?A 71 !)Rf','If',11 !) 8267.0! 70.8~ 160.7~ 4748.0 ""-17 ?f',C 09f 61'\251 <I.<I.~R<:?<I.· 8361.0 70Af 160.2< 4779.1 5500.88 2911.72E 0.6 6219.7 446881.4 5863444.5 8452.3! 70.'\7 160.of 48097: <:<:R1 7~C 02:1 f','I04 'II R!)<l.f', 'I: 70.5£ 160.0~ 4841.1 "f',f'," n'l~ 2971.14E 0.2~ 6'\915: n 8638.6! 70.1" 161.0t 4872.2 5747.05 3000.11E 1.1 6477.0 446967.9 5863197.7 8732.41 69.71 159.41 49044: "R?a a<l.C 17f 65f','I7: AA~aa7 11 !)Rf','I114 f', 8825.7~ 69.9:: 158.6~ 4936.6 5911.72~ 3061.21E 0.71' 66502! ~ 8918.5( 69.8" 159.34 4968.5 5993.01 3092.39E 0.6 6736.2 447058.4 5862951.1 9011.4! 69.8f 158.4 5000.5: nn7<1. <l.n' '\12'\81E 0.8P 68224 <: 9103.3! 70.0C 158.8~ 5032.0. 6154.841 3155.18E O.4f 6907.7: 0 9196.5 69.8 160.4~ 5064.0 6236.90 3185.55E 1.6 6994.0 447149.8 5862706.6 9288.3' 69.67 161.3C 5095.7 f',"I1R "Inc :1[ :1. ,~t 08f 7078.6 44717741 Ç)'IR1 7~ f',Ç) R1 161.3. 5128.1 ~An1 "I<:C 'I?<l.1 P.4¡ O.1f 7164.5: 4472048: 5862!i41.7 9474.8 69.84 161.9 5160.2 6484.24 3269.39E 0.6C 7250.1 447231.8 5862458.7 9567.31 69.54 161.21 5192.3: f',"f',f', "R~ 0.71' 7'\'\5 1 1 Ç)f',f',n 'II f',Ç) 41 1f',n'li !)??<I. Ç}, ~~AR R1 0.81' 7420.7 7 9753.7 69.6C 160.6 5257.& 6731.31 3354.68E 0.31' 7506.7 447315.2 5862211.0 Ç)P.4<1. <I., f',Ç) ?1 1f',n if !)?RÇ) !): ~R11 ?~C '>'>R'> 1'>< 0.6¡¡ 7590.21 I> 99'\8 '\1 f',Ç) oç 1!)Q Ç)A !)'I22 Ç)' nRa"l 7RC n ?f 7f',7f', n. 1 10031.3 69.2~ 159.0 5355.9 6975.15 3443.54E 0.9E 7762.~ 447402.~ 5861966.5 6Ç)4~ 1!)Ç) 1: !)'IRR 4: 7n<:<:nRC '>A"7A '>A< n 19 7P.47 <I.' R 69.44 159.31 !i421.41 71 '\7P.4~ 011' 79'\42: 10310.1 69.6C 159.4~ 5453.9 7219.21 3536.1OE 0.2e 8019.9 447493.0 5861721.8 694f 159.7f !i4861 7'\0001 "I<:nn 1m n'IA R104 Ç)! 447!)2241 o. 69.5. 159.5f 5518.7 7381.9m 0.21 81910: 44755221 10588.4 69.9 159.8f 5551.0 7463.78 3626.68E 0.5 8277.0 447581.8 5861476.6 10681.3 70.0:: 159.5C 55828: 7""-" n"l~ 0'\1' 8'\6'\1 447611 51 ~ 70.1:: 159.7~ 5614.1 7~?~ 7'>C 0.32 8448.3: 447641 .O! 10866.0 70.2t 158.9 5645.5 7708.35 3717.79E 0.84 8534.4 447671.1 5861231.4 70.2C 158.67 5677.0! 77RO O'l~ 0'\1 8620.81 70.3. 158.7~ 5708. 71 7R7? ?R~ 'I7R1 "m 0.14 8708.2: 11145.3 70.2" 158.8f 5739.9 7953.46 3813.0OE 0.11' 8794.2 447764.5 5860985.6 . ,,,'>,, A' 70.11 157.91 5771 S Rn"IA R?~ 097 88808! 11'1'11 1 7n'l7 156.9~ 5802.8: 8115.351 1.03 8967.'\' '> 11423.0 70.1C 158.4t 5833.9 8195.44 3911.59E 1.58 9053.1 447861.3 5860743.0 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 9189.78 Feet on azimuth 154.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ..... ConocoPhillips ConocoPhillips Alasklc.,Slot #424 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 3 Wellbore: 424A Well path: MWD w/Sag <6940 - 11539'> Date Printed: 3-Feb-2004 "~i. BAKER HUGHES INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 9189.78 Feet on azimuth 154.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ./ ConocoPhillips ConocoPhillips AlasAc.,slot #424 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LI.G Page 4 Well bore: 424A Well path: MWD w/Sag <6940 - 11539'> Date Printed: 3-Feb-2004 r&~. BAKER HUGHES INTEQ HdleSeetlons Start All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 149.99 degrees Bottom hole distance is 9189.78 Feet on azimuth 154.53 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ conOCOPhilliPS~,_ API: 501032047501 SSSV Type: NIPPLE TUBING (0-10422, OD:3.500, ID:2.992) SURFACE (0-3005, OD:9.625, Wt:40.00) 'RODUCTION (0-10427, OD:5.500, Wt:15.50) Gas Lift ¡ndrelJDummy V;)I\"'12 (5:J!i7-!i:l!iH. OD4nS! G;·¡s L:', :lflllr(!I,"DoJlIIl'IY Valve 3 ,7:;25-732(; O~ 4 72~ì Ga!:ol Lift merel DU'Tln'v Va'va 4 ;tl1::>1·U128. UD:-11/~ii .. ~ G¡.¡~ !.In Mallc:ri:lV;'ilJl:! 5 '1i\2C1~_1!)2~)r;, \ ., Ö:)·~. ,~~~ _n .. ~I -... .....!. I I N:!:)---·_· ! III . . :1 :):;59- ~ O:U10. OD4.!iOO) SE^L ---- :1~~407-'0422. .... .. ... 00 :l 9BO) XO . :1:1427-·1Î~2n. OD ~ ~,OJ I 'RODUC;ION' _._m. .-.. :1t:4//11!J:W. OD::i.!j;JO. Pmf :1Gô5l)·'OHl1:¿ì I ~,'C :10ar,/)-:mW21 TOD Bottom TVD Wt o 108 108 62.50 o 3005 2386 40.00 o 10427 5495 15.50 10427 11530 5870 9.30 . TOD 1 Bottom I TVD Wt I Grade I Thread o I 10422 1 5493 9.30 I L-80 I EUE8RDMOD Interval I TVD I Zone I Status I Ft SPF I Date I Tvoe I Comment 10850 - 10862 I 5640 - 5644 I 1 I 12 6 12/15/20041 IPERF 12.5" HSD Guns TVDe I Comment I PLACED 210 841 # OF 16/20 V Mfr V Type V OD Latch Port TRO Annular Fluid: Reference Loa: 28' RKB LastTaa: 11148 Last TaQ Date: 2/24/2004 Casina Strina - ALL STRINGS DescriDtion CONDUCTOR SURFACE PRODUCTION PRODUCTION Size 3.500 I 1 Interval 10850 - 10862 . KRU 2P-424A Well Type: PROD Orig 1/18/2004 Completion: Last W/O: Angle (Ci) TS: deg (Ci) Angle @ TD: 70 deg @ 11539 Rev Reason: Post FCO tag, Perf, FRAC set OV Last Uodate: 3/1/2004 Ref Loa Date: TD: 11539 ftKB Max Hole Angle: 71 dea (Ci) 8267 Size 16.000 9.625 5.500 3.500 Grade H-40 L-80 L-80 L-80 Thread WELDED BTC BTCM EUE-MD Date 2/16/2004 FRAC Man Type St MD TVD Man Mfr 1 2614 2204 CAMCO 2 5357 3477 CAMeO 3 7325 4414 CAMCO 4 9127 5040 CAMCO 5 10294 5448 CAMCO "",..,,,\ DeDth TVD TVDe 25 25 HANGER 497 497 NIP 10343 5465 SLEEVE-C 10359 5471 NIP 10403 5486 LOCATOR 10407 5488 SEAL 10407 5488 XO 10422 5493 TTL 10427 5495 XO 11529 5870 SHOE DMY DMY DMY DMY OV ;. Descriotion 3.5" FMC Gen V TUBING HANGER CAMCO 'DS' LANDING NIPPLE BAKER eMU SLIDING SLEEVE WINO GO PROFILE CAMCO 'D' NIPPLE WINO GO PROFILE BAKER G-22 LOCATOR SEAL ASSEMBLY 80-40 SEAL ASSEMBLY W/HALF MULE SHOE PRODUCTION CASING CROSSOVER COUPLING 5.5" TO 5" Date Run 1/18/2004 1/18/2004 1/18/2004 1/18/2004 2/2512004 » Vlv Cmnt KBG-2-9 KBG-2-9 KBG-2-9 KBG-2-9 KBG-2-9 1.0 1.0 1.0 1.0 1.0 INT INT INT INT INT 0.000 0.000 0.000 0.000 0.313 o o o o o CROSSOVER SUB 5" TO 3.5" WEATHERFORD MODEL 402 SURE SEAL FLOAT SHOE ID 3.500 2.875 2.810 2.750 3.000 3.000 5.000 2.990 3.500 2.992 Date I Note 1/18/20041 TREE: FMC I GEN V / WKM 3-118" 15 K ITREE CAP CONNECTION: OTIS 3" \ RE' BOP-Doyon141-011004 . S:ubject: RE: BOP~DoÝòn141-011004 , From: rig 141 <rig 141 @doyondril1i1Œ~.cOl11> Date: Man, 12 Jan2004,09:21:38 ..,Q;900 ..... ì~:.Ja111es Regg <ji111_regg@admi~t~~ëJ~s> , { I . Pr1J i=I- 2&\ -00 ( Clean out screens and retest next time out of the hole. Pat Krupa Doyon Rig 141 Toolpusher -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, January 12, 2004 8:44 AM To: rig141 Cc: Admin AOGCC Prudhoe Bay Subject: Re: BOP-Doyon141-011004 Looks like your accumulator recharge time (to full pressure) has increased above the maximum 4 minutes allowed in AOGCC policy. Please check this and advise what you will do (or have done) to repair. Jim Regg AOGCC rig141 wrote: -HoM. J:r\Sf---t~ kfporl-s / Wee~~\j EDf íLs+ Repørk '. 1 of 1 TESr Ì)~TE '/10104 I Z-}"3'1 () ,'5 1'2"/26/03 i?/Zl-/03 12-/17/03 'Z/ 'ò/ 03 1z1~J03 ¡tZ6/03 'I {'?lð3 It 1z..1 B IDIs.llJ3 tð!Z"4D3 ID/ZI/D3 /01 <;/Ds -- ~. -- - - _. -'. - -" --- -..- - - -, ~ - _.- -. - -- -. - - - - -.-- -- -- ._. - - - '- A"'CC4MU~ <¡;4So1ë='M. "' -RiLL f~~ue¡; ol3iT74t!:":¡Eß ¿, +~ù7 '3 ~ z.. z.. '3 ( 42- '3:37 3:2D 3:34 (Mill: s.€c. ) 3:0 g 6'.32- 3. ~ 20 6'.23 '3 ,40 :S:Z5 3~0'1 3~z....5 1/12/20044:03 PM /~ .a.. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ¡¡m reQQ@admin.state.aK.US aogcc_prudhoe _bay@adm¡n.state.ak.us bo!:U¡eckenste~n@admín .state. ak. us Rig No.: 141 DATE: 1/10/2004 Rig Phone: 659-7115 Rig Fax: 659-7103 Op. Phone: 659-7170 Op. Fax: 659-7103 , Contractor: Doyon Rig Rep.: Patrick F. Krupa Operator: Conoco Phillips Rep.: Fred Herbert Field/Unit & Well No.: Kuparuk 2P-424a Location: Section: 17 Operation: Drlg: Yes Test: Initial: Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: Good PTD On Location Yes Standing Order Posted Yes BOP STACK: Quantity 1 1 1 1 1 1 1 Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual Yes Yes Yes Yes Yes Well Sign Dr!. Rig Hazard Sec. Size 13 5/8"X 500C 3.5X6 5 Blind 31/8 x 5000 31/8 x 5000 31/8 x 5000 N/A Alarm Yes Yes Yes Yes Yes PTD # 204-009 Township: 8N Workover: Weekly: X Annular: 250/3500 TEST DATA Meridian: UM Range: 7E Explor.: Other: Valves: 250/5000 P/F Yes Yes Yes FLOOR SAFETY VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P P/F P P P P P P P CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 2950 Pressure After Closure 1700 200 psi Attained 43 sec. Full Pressure Attained 4 min 07 secs. Blind Switch Covers: All stations Nitgn. Bottles (avg): 5(éQ2100DSi Test Results Number of Failures: .Q Test Time: 4.5 Hours Components tested All Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ¡¡m reçm@admín.state.ak.us Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES x NO c - Oper./Rig Waived By Jeff Jones c - Database Date 01/09/04 Time 2000hrs. c - Trip Rpt File Witness Patrick F. Krupa c - Inspector Test start 14:30 Finish 19:00 BOP Test (for rigs) BFL OS/29/03 2004-011 O_BOP _Doyon141_KRU_2P-424A.xls . Tf~TfŒ lID~ ~~~ ~ . / J / I ¡ I / I FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field 2P-424A ConocoPhillips (Alaska), Inc. Permit No: 204-009 Surface Location: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM Bottomhole Location: 1354' FSL, 671' FWL, Sec. 21, T8N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, /íl. /} ~. I / II ¡ ~--ß./,-P-//O"--J ~!(--, Sarah Palin 0 Chair BY ORDER OF THE COMMISSION DATED this 9th day of January, 2004. cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocJ'"Phillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com January 9, 2004 REcaVED JAN 0 0 ~¡, 2004 '-'QtI¡'*eo..,,-~. '~ b, Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill sidetrack well 2P-424A Dear Sir / Madam ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for sidetrack well 2P-424A. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for this well. 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 . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 . kIf"') ~v o ~ 1a. Type of Work: Drill IE'" RedrillU 1 b. Current Well Class: ExploratoryU Development Oil ~ Multiple Zone D Re-entry D Stratigraphic Test D Service D Development Gas D Single Zone 0 2. Operator Name: 5. Bond: ld Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2P-424A 3. Address: 6. Proposed Depth: 12. FieldlPool(s): .I v' P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11539' TVD: 5912' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Plfterty Designation: ,/ , pc Meltwater Oil Pool Surface: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM .~373112/389058 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2136' FSL, 392' FWL, Sec. 21, T8N, R7E, UM ADL 32092/32409 1/9/2004 Total Depth: 9. Acres in Property: 14. Distance to 1354' FSL, 671' FWL, Sec. 21, T8N, R7E, UM _S1-tð Nearest Property: 3144' @ Target 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 444010' y- 5868966 Zone- 4 (Height above GL): 252 ,¡ feet Well within Pool: 2P-422 , 46,93 16. Deviated wells: . J lj) 17. Anticipated Pressure (see 20 AAC 25.035) ./ Kickoff depth: ~f'7éft/ Maximum Hole Angle: 68.9° Max. Downhole Pressure: 2350 psig I Max. Surface Pressure: 1788 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 80 28 28 108 108 ArticSet I (preinstalled) 12.25" 9.625" 40# L-80 BTC 2977 28 28 3005 2386 As per APD 203-203 8.5" 5.5" 15.5# L-80 BTCM 9829 28 28 9857 5307 931 sx of GasBLOK 8.5" 3.5" 9.3# L-80 EUE8RDM 1682 9857 5307 11539 5912 Included above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total ~;;~It~ Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) ~9.3"o 83.:2, ~ S3.2b .L/ ,., -. - ~/ Casing Length Size Cement Volume MD TVD Structural ftEeE·, .- Conductor 80 /~ If IfJllJ.}£ì:J1 / f)1I'q.¡I~ JINl /()c' f .1 vr J/Of Surface .........// / 9'~'" i{:J!" ¡ . .' Nc. J~ 'dAA ~~,.k fit..()O~ r '!2...'X.£... Intermediate . . .ILlN fI 0 ?nn R Production <..vv"t Liner .' ,t·c»¡r..rñw f'.-_:..._, .." Perforation Depth MD (ft): Perforation Depth TVD (ft): ~\,I'''..rn~_.-Jfl None None 20. Attachments: Filing Fee 0 BOP SketchW Drilling Programld Time v. Depth Plot U Shallow Hazard Analysis U Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22, I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Philip Hayden @ 265-6481 Printed Name R. Thomas Title Kuparuk Team Leader Signature R~~ Phone LGÇ- 6830 Date \/9.10'7 Prenared hv Philin havrftm Commission Use Only Permit to Drill ¡'œ5I API Number: I Permit Approval ,0\\ See cover letter Number: ')D( " ~ 50- !L)3-;2j) l 75~ò I Date: \~ for other requirements Conditions of approval : Samples required D YeS~NO Mud log required D Yes ~ No Hydrogen sulfide measures D Yes ~ No Directional survey required EYes D No Other: ~SO O~S\~\.i1'\\ ~~""" ~\> -\<z""'-\, Original Signed By \ ~ Sarah Palin BY ORDER OF ¡q Approved by: COMMISSIONER THE COMMISSION Date: Form 10-401 Revised 3/2003 . ORIGINAL Submit in duplicate · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 - 1 a. Type of Work: Drill 0 RedrillU 1b. Current Well Class: ExploratoryU Development Oil ~ Multiple Zone 0 Re-entry 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2P-424A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11539' TVD: 5912' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 910' FNL, 2050' FWL, Sec. 17, T8N, R7E, UM ALK 373112/389058 Meltwater Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2136' FSL, 392' FWL, Sec. 21, T8N, R7E, UM ADL 32092/32409 1/9/2004 Total Depth: 9. Acres in Property: 14. Distance to 1354' FSL, 671' FWL, Sec. 21, T8N, R7E, UM 5760 Nearest Property: 3144' @ Target 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 444010 y- 5868966 Zone- 4 (Height above GL): 252 feet Well within Pool: 2P-422 , 46.93 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff depth: 300 ft. Maximum Hole Angle: 68.9° Max. Downhole Pressure: 2350 psig I Max. Surface Pressure: 1788 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 80 28 28 108 108 ArticSet I (preinstalled) 12.25" 9.625" 40# L-80 BTC 2977 28 28 3005 2386 As per APD 203-203 8.5" 5.5" 15.5# L-80 BTCM 9829 28 28 9857 5307 931 sx of GasBLOK 8.5" 3.5" 9.3# L-80 EUE8RDM 1682 9857 5307 11539 5912 Included above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 10548 5930 8326 8326 4887 Casing Length Size Cement Volume MD TVD Structural Conductor 80 16" ArticSet I (preinstalled) 108 108 Surface 2977 95/8" 428 bbls AS Lite, 150 bbls LiteCrete 3005 2386 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): None None 20. Attachments: Filing Fee 0 BOP SketchL Drilling Program ~ Timev. Depth PlotU Shallow Hazard Analysis I:l Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Philip Hayden @ 265-6481 Printed Name R. Thomas Title Kuparuk Team Leader Signature Phone Date Pmn"f ï h"vrjRn Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 50- Date: for other requirements Conditions of approval : Samples required DYes 0 No Mud log required DYes 0 No Hydrogen sulfide measures DYes 0 No Directional survey required DYes 0 No Other: BY ORDER OF Approved by: COMMISSIONER THE COMMISSION Date: Form 10-401 Revised 3/2003 . Submit in duplicate · A_tion for Permit to Drill, Well 2P-424A .. Revision No.O Saved: 9-Jan-04 Permit It - Meltwater Sidetrack Well #2P-424A Application for Permit to Drill Document Moxir'l'1izE W~II I/.glu ~ Table of Contents 1. Well Name.... ...... ...................... ..... ................ ........... .......... ......... ................. ........ ..... 2 Requirements of 20 AAC 25.005 (f)....................... ...... ............... .... ........................................................ 2 2. Location Sum mary ........ ..... ..... ..... .................. ......... ........ ....... ......... ..... ........ ............ 2 Requirements of 20 AAC 25.005(c)(2) .... ........... ....................... .............................................................2 Requirements of 20 AAC 25. 050(b )..... ............. ........... ........................ ....... ...................... ........ .............. 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) .......... ............. ........ ........... ..... ...... ................... ................ ........... 3 4. Drill i ng Hazards Information ........... ............... ...................... ................... ........... ..... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng andCementi ng Program ......... ............ .............. ... ........ ................... ............ 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 ..... ....... ............... ......................... ........................ ................. 4 Requirements of 20 AAC 25.005(c)(B) ...... .... ..................................... ............ .............. ............ ....... ....... 4 Production Hole Mud Program (LSND) ...................... ............ ............ ....................................................4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 1 O. Seismic Analysis ......... ..Ii.... ................ .............. ..... ............ .................... ................ ... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bondi ng ...............................................................................................5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 ORIGINAL 2P-424A PERMIT /T.doc Page 1 of 6 Printed: 9-Jan-04 II A.· tion for Permit to Drill, Well 2P-424A Revision No.O Saved: 9-Jan-04 13. Proposed Drilling Program .....................................................................................5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments .......... ..... .......... ..................... ......... ............... ........... ............ ................ 6 Attachment 1 Directional Plan (10 pages) .............................................................................................. 6 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 6 Attachment 3 Cement Loads and CemCADE Summary (1 page) .........................................................6 Attachment 4 Well Schematic (1 page) .................................................................................................. 6 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 sutfìx to the name designated for the well by the operator and to the number assigned to the well by the commission. The sidetrack well for which this Application is submitted will be designated as 2P-424A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pemllt to Dr/II 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 govemmental section lines. (8) the coordinates of the proposed location of the well at the surface; referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration;, (C) the proposed depth of the well at the top of each objectìve formation and at total depth;, Location at Surface NGS Coordinates Northings: 5,868,966 Eastings: 444,010 ,/ I 910' FNL, 2050' FWL, Section 17, T8N, R7E, UM ./ I RKB Elevation I 252' AMSL I Pad Elevation I 224' AMSL Location at Top of Productive Interval Bermuda Sand NGS Coordinates Northings: 5,861,427 2136' FSL, 392' FWL, Section 21, T8N, R7E, UM Eastings: 447,601 Measured De th RKB: Total Vertical De th RKB: Total Vertical De th 55: 10 649 5592 5340 Location at Total De NGS Coordinates Northings: 5,860,644 Eastings: 447,877 1354' FSL 671' FWL Section 21 T8N R7E UM " Measured De th RKB: 11 539 Total Vertical De th RKB: 5 912 Total Vertical De th 55: 5 660 ,/ c/ and (D) other information required by 20 MC 25.0S0(b),· ORIGINAL 2P-424A PERMIT /T.doc Page 2 of 6 Printed: 9-Jan-04 e AR.- lion for Permit to Drill, Well 2P-424A Revision No.O Saved: 9-Jan-04 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 proposed 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 (8) 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 (SOPE) as required by 20 AAC 25.03!i 20 AAC 25.03~ or 20 AAC 25.037, as applicable/ An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2P-424A. 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) information on drilling hazard~ including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient/ The expected reservoir pressures in the Bermuda sands in the 2P-424A area vary from 0.27 to 0.42 psi/ft, or 5.1 to 8.1 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 1788 psi, calculated as follows: MPSP =(5767 ft)(0.42 - 0.11 psi/ft) =1788 psi .¡ (8) data on potential gas zones/ This well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ 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 DJiII must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integnty test~ as required under 20 AAC 25.030(f)/ A procedure is on file with the commission for performing LOTs. For 2P-424A the 9 5/8" surface casing has been tested to 18 ppg EMWon 12/31/2003. ORIGINAL 2P-424A PERM/T /T.doc Page 3 of 6 Printed: 9-Jan-04 - A.· tion for Permit to Drill, Well 2P-424A Revision No.O Saved: 9-Jan-04 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 items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted line0 pre- perforated line0 or screen to be installed; Casing and Cementing Program I See also Attachment 3: Cement Summarv Hole Top 8tm Csgffbg Size Weight Length MOfTVO MOfTVO 00 (in) (in) (lb/ft) Grade Connection (ti) (ft) (ft) Cement Proaram 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 Cemented to surface with ArticSet I 9 5/8 12 V4 40 L-80 BTC 2977 28 / 28 3005 / 2386 Cemented to Surface as per APD 203-203 5'/2 8 V2 15.5 L-80 BTCM 9829 28 / 28 9857 / 5307 Cement Top planned @ 3 V2 8 V2 9.3 L-80 EUE8RD 1682 9857 / 5307 11539/5912 9557' MD/ Mod 5199' 1VD. Cemented w/ 931 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 items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 03~ unless this requirement is waived by the commission under 20 MC 25.035(h)(2); 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)(B) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Production Hole Mud Program (LSND) 95/8// Casin 7 Shoe to TD Initial Value Final Value Density (ppg) 10.2 10.2 Yield Point 22-28 10-15 (cP) pH 9-9.5 9-9.5 API Filtrate 4-6 4 (cc/30min)) HTHP @ 15Cf' (cc)) <12 <12 ,/ ORIGINAL 2P-424A PERMIT IT.doc Page 4 of 6 Printed: 9-Jan-04 e A,*tion for Permit to Drill, Well 2P-424A . Revision No.O Saved: 9-Jan-04 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 item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel? a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); '7 Not applicable: Application is not for an exploratory or stratigraphic test well. v 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dnll must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (10) for an exploratOlY or stratigraplJic test we/~ a seismic refraction or reflection analysis as requked by 20 AAC 25.061(a); 1 Not applicable: Application is not for an explorato'ry 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 Item~ except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesse? an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the applicaúon: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following item~ 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 Schematic. 1. Drill off cement plug if one is placed in the well bore or come off the low side of the hole and sidetrack well with a planned kick-off point of 6870' MD./ ¡/ 2. Directionally drill to 5 112" x 3 V2" casing point at 11539 MD / 5912' TVD. Run LWD logging equipment with GR, resistivity, and density-neutron ¡/ 3. Run 5 V2", 15.5# L-80, STC Mod x 3 V2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and displace with water. 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. 4. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 5. Install SPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull SPV ORIGINAL 2P-424A PERMIT IT.doc Page 5 of 6 Printed: 9-Jan-04 e Aillf.tion for Permit to Drill, Well 2P-424A ., Revision No.O Saved: 9-Jan-04 6. 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. 7. Set BPV and move rig off. 8. 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. 9. Carry out fracture stimulation. 10. 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 item~ except for an item already on tHe with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator 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-424A for annular disposal of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 Directional Plan (10 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (1 page) Attachment 4 Well Schematic (1 page) ORIGINAL 2P-424A PERMIT IT. doc Page 6 of 6 Printed: 9-Jan-04 Cr<XJte<.l by Dote plotted ~ a.~Jan-2004 Plct Reference Î$ 2P-424A Sf Verl!1A COQrdÌMtes are În feet rafer$ne:8 slot #424. RKB(Ooyon 1250 1500 1750 [ KOP LOCATION:' 138' FSL, 829' SEC. 17, T8N, 2000 ConocoPhillips Alaska, Inc. Structure: Drill Site 2P Well: 424A Field : Meltwater Location East (feet) -> 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 4000 ../ ConocoPhillips 5000 5250 4250 4500 4750 5000 5250 5500 5750 (f) 0 6000 r--. 6250 -+, (!) (!) -+ "---"" 6500 I V 6750 7000 7250 7500 7750 8000 8250 8500 149.99 AZIMlTTH 8~j30' (TO TAHGET) ***Plone of ProposfJl¥** TRUE 5 n(Top Bermuda) Target Bermuda) TO 3800 4000 4200 4400 4600 4800 0 5000 P --- I- (J) 5200 > (J) 5400 \/ 5600 5800 6200 Dote pJotted: 8-Jcn-2004 Ph:ÜReference is 2P",,4,24A SrV~r#LA. Coórdinotes ore irdeet refer(:i¡')c:e slot #424, (Doyon Canoe ~/ ConocoPhillips Structure : Drill Site 2P Field : Meltwater LOGation : Narth 149.99 AZIMUTH 8330' (TO TARGET) *,¡,*Pione of Proposal*** TANGENT ANGLE 68,90 DEG 5 1/2 x 3 1/2 XO T3(Top Ben11uda) Target owe T2(Base Bermuda: TO 5200 5400 5600 5600 6000 6200 6400 6600 6600 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 9200 Vertical Section (feet) > Azimuth 149.99 with reference 0.00 N, 0.00 E from slot #424 4600 4800 I ConocoPhillips Alaska, Inc.¡ Created by Date plotted: 8-Jon-2004 Plot Reference is 2P-424A Sf VerNI,A. Coordinates ore in feet reference slot 1424, Vertical Depths: are reference RKB (Doyon Structure : Dr!ll Site 2P Field : Meltwater We!l : 424A ~ ConocoPhillips Location : North Slope, Alaska -de INTEQ ==== PROF~LE COMMENT DATA ==== e ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 0 :::0 KOP - Tie In ~ 6870.00 62.02 148.26 4194.28 -4230.55 2415.81 487 1 .66 0.00 - GJ End 4/100 Drop 6920.00 60.14 149.05 4218.46 -4267.92 2438.58 4915.41 4.00 - Z End Initial 3/100 BIID 7014.58 62.00 151.50 4264.22 -4339.81 2479.60 4998.18 3.00 ):> r- EOC 7363.73 68.90 160.17 4409.43 -4629.28 2608.75 5313.44 3.00 5 1/2 x 3 1/2 XO 9857.07 68.90 160.17 5307.00 -6817.57 3397.75 7602.98 0.00 e T4.2(Top Cairn) 10057.07 68.90 160.17 5379.00 -6993.11 3461.04 7786.64 0.00 T4.1 10154.30 68.90 160.17 5414.00 -7078.44 3491.80 7875.92 0.00 T3(Top Bermuda) TargID 10648.76 68.90 160.17 5592.00 -7512.40 3648.27 8329.96 0.00 OWC 11134.89 68.90 160.17 5767.00 -7939.05 3802.10 8776.35 0.00 T2(Base Bermuda) 11348.78 68.90 160.17 5844.00 -8126.78 3869.79 8972.77 0.00 TD ¡!; 11538.78 68.90 160.17 5912.40<- -8293.53 3929.91 9147.23 0.00 Crectedby þmlchoe! Do1e p!otled: 8-490-2004 Pklt Reference is 2P"""'¡'Z4ASrVe.r1A Coordinol.ßs ore Înfset fef(¡;fßf1Ce$jp:t: #414-_ Vertical (Doyon 600 900 2100 1200 1:;00 1800 ~ '::', onocoPhillips Alaska, structure: Drill Site 2P Well : 424A Field : Meltwater Location : North East (feet) -> 2400 2700 3000 3300 3600 ~ ~. 4500 " " \ 4500 \, \ \ \ \ \ \ \ 4800~ \ \ \ \ \ \ \ 5100, \ \ \ \ \ \ 5400 \ \ \ \ \ \ \ 5700 \, \ \ \ \ \ 5100 Inc. 3900 4200 4800 5700 ""'// ConocoPhillips 4:;00 5100 " " 4800 :;100 5400 3600 3900 4200 4:;00 4800 :;100 , ~ :;400 :;700 6000 (/) 0 C -+ 6300 :::r ,.--... -. () 6600 CD -+ '-" I 6900 V 7200 7500 7800 8100 8400 8700 9000 9300 e e ConocoPhillips Alaska, Inc. Drill Site 2P 424 slot #424 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-424A ST Ver#l.A prop5600 Date printed Date created Last revised 8-Jan-2004 8-Jan-2004 8-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 9.571,w150 26 53.022 Slot Grid coordinates are N 5868966.260, E 444010.429 Slot local coordinates are 909.675 2053.38 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,424 Your ref 2P-424A ST Ver#l.A Meltwater,North Slope, Alaska Last revised : 8-Jan-2004 Measured Inclin Azimuth True Vert R E C TANGULAR G RID COO R D S G E 0 G RAPHI C Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C o 0 R DINAT E S 6870.00 62.02 148.26 4194.28 4230.55S 2415.81E 446393.70 5864717.83 n70 2 27.95 w150 25 43.50 6900.00 60.89 148.73 4208.62 4253.02S 2429.58E 446407.30 5864695.26 n70 2 27.73 w150 25 43.11 6920.00 60.14 149.05 4218.46 4267.92S 2438.58E 446416.18 5864680.29 n70 2 27.58 w150 25 42.85 7000.00 61. 71 151.13 4257.34 4328.53S 2473.43E 446450.56 5864619.43 n70 2 26.99 w150 25 41.85 7014.58 62.00 151. 50 4264.22 4339.81S 2479.60E 446456.65 5864608.10 n70 2 26.88 w150 25 41. 67 7100.00 63.64 153.71 4303.24 4407.27S 2514.55E 446491.08 5864540.38 n70 2 26.21 w150 25 40.66 7200.00 65.60 156.22 4346.10 4489.13S 2552.75E 446528.66 5864458.24 n70 2 25.41 w150 25 39.56 7300.00 67.61 158.66 4385.81 4573.88S 2587.94E 446563.20 5864373.24 n70 2 24.57 w150 25 38.55 7363.73 68.90 160.17 4409.43 4629.28S 2608.75E 446583.58 5864317.68 n70 2 24.03 w150 25 37.96 7500.00 68.90 160.17 4458.48 4748.89S 2651. 87E 446625.78 5864197.76 n70 2 22.85 w150 25 36.72 8000.00 68.90 160.17 4638.48 5187.71S 2810.09E 446780.64 5863757.79 n70 2 18.54 w150 25 32.17 8500.00 68.90 160.17 4818.47 5626.54S 2968.31E 446935.50 5863317.81 n70 2 14.22 w150 25 27.62 9000.00 68.90 160.17 4998.47 6065.36S 3126.53E 447090.35 5862877 . 83 n70 2 09.90 w150 25 23.08 9500.00 68.90 160.17 5178.46 6504.19S 3284.76E 447245.21 5862437.86 n70 2 05.59 w150 25 18.53 9857.07 68.90 160.17 5307.00 6817.57S 3397.75E 447355.80 5862123.65 n70 2 02.50 w150 25 15.29 10000.00 68.90 160.17 5358.45 6943.02S 3442.98E 447400.07 5861997.88 n70 2 01. 27 w150 25 13 .99 10057.07 68.90 160.17 5379.00 6993.11S 3461. 04E 447417.75 5861947.66 n70 2 00.78 w150 25 13 .47 10154.30 68.90 160.17 5414.00 7078.44S 3491. 80E 447447.86 5861862.10 n70 1 59.94 w150 25 12.58 10500.00 68.90 160.17 5538.45 7381. 84S 3601. 20E 447554.93 5861557.90 n70 1 56.95 w150 25 09.44 10648.76 68.90 160.17 5592.00 7512.40S 3648.27E 447601. 00 5861427.00 n70 1 55.67 w150 25 08.09 11000.00 68.90 160.17 5718.44 7820.67S 3759.42E 447709.78 5861117.93 n70 1 52.63 w150 25 04.90 11134.89 68.90 160.17 5767.00 7939.05S 3802.10E 447751.56 5860999.23 n70 1 51. 47 w150 25 03.67 11348.78 68.90 160.17 5844.00 8126.78S 3869.79E 447817.81 5860811.01 n70 1 49.62 w150 25 01.73 11500.00 68.90 160.17 5898.44 8259.49S 3917.64E 447864.64 5860677.95 n70 1 48.32 w150 25 00.36 11538.78 68.90 160.17 5912.40, 8293.53S 3929.91E 447876.65 5860643.82 n70 1 47.98 w150 25 00.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #424 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 9177.52 on azimuth 154.65 degrees from wellhead. Total Dogleg for wellpath is 15.31 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 149.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL e e ConocoPhillips Alaska, Inc. Drill Site 2P,424 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-424A ST Vertl.A Last revised: 8-Jan-2004 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Cormnent - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - --- - - - - - - -- - -- - - - - - - -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 6870.00 4194.28 4230.55S 2415.81E KOP - Tie In 6920.00 4218.46 4267.92S 2438.58E End 4/100 Drop 7014.58 4264.22 4339.81S 2479.60E End Initial 3/100 B1d/Trn 7363.73 4409.43 4629.28S 2608.75E Eoe 9857.07 5307.00 6817.57S 3397.75E 5 1/2 x 3 1/2 XO 10057.07 5379.00 6993.11S 3461. 04E T4. 2 I Top Cairn) 10154.30 5414.00 7078.44S 3491. 80E T4.1 10648.76 5592.00 7512.40S 3648.27E 2P-424A ST TGT 07 Jan 04 11134.89 5767.00 7939.05S 3802.10E owe 11348.78 5844.00 8126.78S 3869.79E T2 (Base Bermuda) 11538.78 5912.40 8293.53S 3929.91E TD ~ Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- n/a 4194.28 4230.55S 2415.81E n/a 4194.28 4230.55S 2415.81E 9 5/8" Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 2P-424A ST TGT 07 Ja 447601.000,5861427.000,999.00 5592.00 7512.40S 3648.27E 8-Jan-2004 ORIGI~~f\ e e ConocoPhillips Alaska, Inc. Drill Site 2P 424 slot #424 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-424A ST Ver#l.A prop5600 Date printed Date created Last revised 8-Jan-2004 8-Jan-2004 8-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 9.571,w150 26 53.022 Slot Grid coordinates are N 5868966.260, E 444010.429 Slot local coordinates are 909.67 S 2053.38 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,424 Your ref 2P-424A ST Ver#l.A Meltwater,North Slope, Alaska Last revised 8-Jan-2004 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I NA T E S Deg/100ft Sect 6870.00 62.02 148.26 4194.28 4230.55 S 2415.81 E 0.00 4871.66 ST KOP 6900.00 60.89 148.73 4208.62 4253.02 S 2429.58 E 4.00 4898.01 6920.00 60.14 149.05 4218.46 4267.92 S 2438.58 E 4.00 4915.41 End 4/100 Drop 7000.00 61.71 151.13 4257.34 4328.53 S 2473.43 E 3.00 4985.32 7014.58 62.00 151. 50 4264.22 4339.81 S 2479.60 E 3.00 4998.18 End Initial 31100 Bld/Trn 7100.00 63.64 153.71 4303.24 4407.27 S 2514.55 E 3.00 5074.07 7200.00 65.60 156.22 4346.10 4489.13 S 2552.75 E 3.00 5164.07 7300.00 67.61 158.66 4385.81 4573.88 S 2587.94 E 3.00 5255.06 7363.73 68.90 160.17 4409.43 4629.28 S 2608.75 E 3.00 5313.44 EOC 7500.00 68.90 160.17 4458.48 4748.89 S 2651. 87 E 0.00 5438.58 8000.00 68.90 160.17 4638.48 5187.71 S 2810.09 E 0.00 5897.71 8500.00 68.90 160.17 4818.47 5626.54 S 2968.31 E 0.00 6356.84 9000.00 68.90 160.17 4998.47 6065.36 S 3126.53 E 0.00 6815.97 9500.00 68.90 160.17 5178.46 6504.19 S 3284.76 E 0.00 7275.10 9857.07 68.90 160.17 5307.00 6817.57 S 3397.75 E 0.00 7602.98 5 1/2 x 3 1/2 XO 10000.00 68.90 160.17 5358.45 6943.02 S 3442.98 E 0.00 7734.23 10057.07 68.90 160.17 5379.00 6993.11 S 3461. 04 E 0.00 7786.64 T4.2(Top Cairn) 10154.30 68.90 160.17 5414.00 7078.44 S 3491.80 E 0.00 7875.92 T4.1 10500.00 68.90 160.17 5538.45 7381. 84 S 3601. 20 E 0.00 8193.36 10648.76 68.90 160.17 5592.00 7512.40 S 3648.27 E 0.00 8329.96 2P-424A ST TGT 07 Jan 04 11000.00 68.90 160.17 5718.44 7820.67 S 3759.42 E 0.00 8652.49 11134.89 68.90 160.17 5767.00 7939.05 S 3802.10 E 0.00 8776.35 OWC 11348.78 68.90 160.17 5844.00 8126.78 S 3869.79 E 0.00 8972 . 77 T2(Base Bermuda) 11500.00 68.90 160.17 5898.44 8259.49 S 3917.64 E 0.00 9111. 62 11538.78 68.90 160.17 5912.40 8293.53 S 3929.91 E 0.00 9147.23 TD All data is in feet unless otherwise stated. Coordinates from slot #424 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 9177.52 on azimuth 154.65 degrees from wellhead. Total Dogleg for wellpath is 15.31 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 149.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL e It ConocoPhillips Alaska, Inc. Drill Site 2P,424 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-424A ST Ver#l.A Last revised: 8-Jan-2004 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 6870.00 4194.28 4230.55 S 2415.81 E ST KOP 6920.00 4218.46 4267.92 S 2438.58 E End 4/100 Drop 7014.58 4264.22 4339.81 S 2479.60 E End Initial 3/100 Bld/Trn 7363.73 4409.43 4629.28 S 2608.75 E EOC 9857.07 5307.00 6817.57 S 3397.75 E 5 1/2 x 3 1/2 XO 10057.07 5379.00 6993.11 S 3461. 04 E T4.2(Top Cairn) 10154.30 5414.00 7078.44 S 3491. 80 E T4.1 10648.76 5592.00 7512.40 S 3648.27 E 2P-424A ST TGT 07 Jan 04 11134.89 5767.00 7939.05 S 3802.10 E OWC :.1348.78 5844.00 8126.78 S 3869.79 E T2(Bas", Bermuda) 11538.78 5912.40 8293.53 S 3929.91 E TD .V Casing positions in string 'A' ------------------------------ ------------------------------ TOp MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- n/a 4194.28 4230.55S 2415.81E n/a 4194.28 4230.55S 2415.81E 9 5/8" Targets associated with this wel1path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2P-424A ST TGT 07 Ja 447601.000,5861427.000,999.00 5592.00 7512.40S 3648.27E 8-Jan-2004 ORIGINAL e e MEL TW A TER - DRILLING HAZARDS SUMMARY 8 Iii' Open Hole & 5 Vi' x 3 Vi' Production Casing Interval Event Drill through a shallow pressured interval: C-80 to C-37 Insufficient or undetermined LOT High ECD / Tight hole on trips/ Swabbing Differential sticking Barite sa Lost circulation Risk Level Low .I Moderate Moderate Moderate Moderate High Miti ation Strate / Cantin 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 arties familiar with LOT rocedure. 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 ORIGINAL Meltwater Drilling Hazards Summary Prepared by Philip Hayden 1/812004 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/8/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 26S.{¡20S Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 95/8",40.0#, L-80 grade BTC, AB Modified at 3,005 ft. MD < 51/2",15.5#, L-80 grade BTC, AB Modified in 8 1/2" OH < Top of Tail at 9,557 ft. MD < X-over at 9,857 ft. MD < TopofCairnFm. at 10,057 ft. MD < 31/2",9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH TD at 11,539 ft. MD (5,912 ft. TVD) Mark of Schlumberger .. 2P-424A CemCADEw Preliminary Job Design 5 1/2" x 3 1/2" Production SchllmblPgrr 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 187 min.) GasBLOK wI Class G + 053, D600G, D065, B155, 0047 per lab testing @ 15.8 ppg, 1.17 ft3/sk 0.2291 ft3/ft x 300' x 1.75 (75% excess) = 0.3272 ft3/ft x (11539' - 9857') x 1.75 (75% excess) = 0.0488 ft3/ft x 120' (Shoe Joint) = 120.3 ft3 + 963.1 ft3 + 5.9 ft3 = 1089.3ft3/1.17 ft3/sk = Round up to 931 sks 120.3 ft3 963.1 ft3 5.9 ft3 1089.3 ft3 931 sks BHST = 146°F, Estimated BHCT = 124°F. (BHST calculated using a gradient of 2SF/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Rate Stage Volume Cumulative Stage Time Time (min) (bpm) (bb!) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 50 10.0 22.0 MudPUSH II 5 30 6.0 28.0 GasBLOK Slurry 5 194 38.8 66.8 Drop 5-Y2 x 3-Y2 Plug 5.0 71.8 Displacement 5 228 45.6 117.4 Bump Plug 2 20 10.0 127.4 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, as thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, Pv: 16-20, Ty: 30-34 Centralizers: Recommend 1-Y2 per joint on 5-W' casing and 1 per joint on the 3-W' casing in the cemented interval. ORIGJ.~rAL Meltwater 2P-424A ~ducer Proposed Completion Schematic 3-1/2" Completion String ~illips 3 Y2" FMC Gen 5 Tubing Hanger, 3 Y2" L-80 EUE8RD Mod pin down 3 Y2" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 Y2" 9.3# L-80 EUE8RD Mod Tubing to Surface Depths are based on Doyon 141 RKB 3 Y2" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 Y2" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 30" x 16" 62.6# @ +1- 108' MD (Insulated) 3 Y2" 9.3# L-80 EUE8RD Mod tubing to landing nipple 4 x 3 Y2" x 1" Camco 'KBG-2-9' mandrels 3 Y2" x 6' L-80 handling pups installed above and below, EUE8RD Mod Surface csg. 95/8" 40.0# L-80 BTC +1- 3005' MD I 2386' TVD 3 Y2" x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 Y2" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 Y2" Baker 'eMU' sliding sleeve wI 2.813" Cameo DS profile, EUE8RD Mod box x pin. 3 Y2" x 6' L-80 EUE8RD Mod handling pup installed above 3 W' Camco 'D' nipple wI 2.75" No-Go profile. 3 Y2" x 12' L-80 EUE8RD Mod spacaeout pup installed above, 3 W' x 6' handling pup installed below 5 Y2" 15.5# L-80 BTCM x 3 Y2" 9.3# L-80 EUE8RD Mod crossover at +1- 9857' MD I 5307' TVD 3 Y2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 Y2" L-80 EUE8RD Mod box up, 3 Y2" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 Y2" BTCM x 3 Y2" EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) Future Perforations Production csg 5 Y2" 15.5# L-80 BTCM x 3 W' 9.3# L-80 EUE8RD Mod +1- 11539' MD I 5912' TVD ~' ORIGINAL 01/08/2004 "Verbal" Approval to drill2P-424A (204-009--50-103-... e e Subjeët: "\l.erbal" Approval to dri1l2P-424A:j(204;0ÖØ9-~50-l03-20475-01)' From: Thomas Maunder <tom _maunder@adlnirï.sf~~e.ak.us> . ,.. .. . . ,.. ~ Date: 'Fri<09 Jan 2004 17:09: 17'-0900 ,>"',i';' . ~....,. . .:~:lì~~Ha:~:; :~l~Jt ~::~~:.::~ Philip, We have received your application to sidetrack 2P-424. No Commissioner is available to formally sign the permit. I did inform Commissioner Seamount of your application and I am able to give you a "verbal" approval to commence drilling the sidetrack. Regulation 20 AAC 25.005 (a) allows a verbal approval to be given in situations such as this. Please forward a copy of this message to the rig. receive a copy of the actual signed permit, a copy should be posted in the doghouse with the approved 2P-424. Please call with any questions, good luck with the operations. Tom Maunder, PE AOGCC Until they of this message permit for I of I 1/9/2004 5: 13 PM J ~3: ¡ i 'li 'J. , :t. !' ~~- ,0- f j:. :1 ~f· iii --. ~ ~ ~~ f ~-..~-: UNIVERSAL e ':0:1 ~ ~OO ~a.a. MEMO e 2P-ff, o CHASE ,. . tð co ~~ ~nil!~~"" Do>¡II'IS On Ba~k. f,: f ~ ~ WEL!L PERMIT CHECKLIST Field & Pool KUPARUK RIVER, MELTWATER OIL - 490140 \, 'olio ~': , + '" PTD#: 2040090 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType Administration 1 P.ßrmitfee attacheø Yßs 2 Leas.ß .numberappropriate Yes 3 .Unique welln.am.ß.and oumb.er Yßs _ 4 WelllQcat.ßd in a d.efinedpool. Yes 5 WelUQcated proper .distance from driJling unit boundary. Yßs 6 WelUQcated proper distance. from otber wells Y.es 7S.ufficient acreag.e.available indJilliog. unjt Yes 8 Jtd.ßviated, js weJlbQre platil]cJu.ded .Yßs 9 .O'perator only aff.ected party. Yßs 10 .O'perator bas.apprppriate-'~o!ld inJQrce . Yßs 11 Pßrmit c.an be issued witbQut co.nservation Qrder Yßs 12 Pßrmit can be issued wjtbQut admil]istratille.approyaJ Yes 1/9/2004 13 Can permit be approved before 15-day wait Yes 14 WelUQcatßd within area and.strataauthQrized by-'ojectiol] Ord.er # (puUO# in.commeotsJ-(FQr NA 15 .AJlweIJs.wit!1inJI4JTJile.area.ofreviewidßot[fied(Forservjc.eweUOnlYL .NA .. _ 16 Pre-produ.ced injector; øuratio.n.of pre-.proøuçtionIßss. than 3 montbs (FQr.service well onJy) NA 17 .AÇMPF.inding9fCon.slstencyhas Þee.nis.sued.for.tbis pr.olect .. NA 18 .C9nductor string.PJQvided No 19 .S.urfaœcas.ingpJotecJs. allk!lown USDWs NA 20 .CMTvoladequate.to circ.ulateo.n.conductor.& surfCSg Yes 21 .CMT v91 adequ.ate.to tie-inJQng .string to surf cs.g. No. 22 .CMTwil! cover.aJl knownpro.ductive bQri;!:Qn.s. Yes 23 .C.asiog designs ad.equa.te for CJ, B& permafrost Yes 24 .AøequateJan.kage.oJ re.serve pit. Yes Rig js.equippe.d.with steelpits. No. resel"lle.pjt.planoed, Wa.steJQ apprQved annulus ordjspos.a! welt 25 Jta.re-drilL bas.a. 10-403 fQr abandQnme.nt been apPJQved Yes. ';bandQnmentoJ orjginal wellþQre apPJQved,304-0Q4. 26 Aøequatewe!lbore s.eparatio.n.pro'poseø. . Yßs prOJ5imity analysis pertorme.d, Ne¡;¡rest well i.$ .abanøoned weUb.ore~ _ _ 27 Jf.diver:ter Jequired, dQes it meet reguJatiol]s. NA 28DJiUiog fluid program schematic&. ec¡.uip Jistadequ¡:¡te. Yes 29 .BOPEs, do .they meet reguJation Yes 30 .BOPE.press ratiog ¡;¡p.propriate; .test to .(pu.t psig in .commel]ts). Yßs 31 .CMkemanifold cQmpJies. w/API R~-53 (May 64). Yes 32 WQrk will occur withoutoperatjonsbutdQwn Yßs 33 Js. pres.ençe Qf H2S gas. prQb.aþle .No 34 Mecba.nicalcPodjlion of wells withil] ';QR veriJied (for.s.ervjce welJ onJy.). NA Appr SFD Date Engineering Appr Date TEM 1/9/2004 f$\v\ Geology Appr SFD Date 1/9/2004 35 Permit cao be lssued w/Q hydrogen sulfide meas.ures 36 .D.ata.PJeseoted on poteJltial overpres.surezol]e.$. 37 .Sei.$mic.a!lalysjs Qf sbaJlow gas.zooes. 38 .Seabedconditipo survey.(if off.-sh9re) 39 . CQnta.ct l]amelp!1oneJor.weekly progress.reports [exploratoryonlYl Well Name: KUPARUK RIV U MELT 2P-424A DEV I PEND GeoArea 890 Unit o o Program DEV On/Off Shore On Well bore seg Annular Disposal 11160 - . - - - - - e Sidetrack oLexisling welJ.. . . . .. Set in Qriginalwellb.ore. . M quifers exempteø, ~O CFR '147..102 (b)(3). . Casing cemented to surface on originaLweJlboJe. . . ';nn.ular disP9sal m.ay be proposed. . Expected BI:I~ in .BßmJuda 5..1- ß.1EMW.. PI¡:¡l]n.ed MW 1 Q.2.. NQ shalJow highpJessures. seeo 01] original weJlbQr CalcuJaJed MASP. 1788 psi.. 3500 psi.appropriate, .CPAl usually.tests.to 5QO.0.psi, e . .. Yßs YßS .NA NA NA.. Reservoir ex.pected to be 5.1tQ 8.1 PPGEMW.. Will be drilled with 10..2 ppgmud, Geologic Commissioner: ff$ Date: //I¿/1-- Engineering Commissioner: J:~ate ~~. '=' \~ Date Public Commissioner e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. c2{) cf-o vC¡ !2-fos;¿ .. e e RECEIVED **** REEL HEADER **** LDWG 04/03/29 2 'Î 2004 J~OJl & Gas Cons. Commission PJlchorage AWS 01 **** **** TAPE HEADER LDWG 04/03/29 01 *** LIS COMMENT RECORD *** !! !!!!! !!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER MELTWATER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2P-424A 501032047501 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 29-MAR-04 MWD RUN 3 3 G. SUTING F. HERBERT MWD RUN MWD RUN 2 2 D. LABREQUE F. HERBERT MWD RUN MWD RUN 1 1 C. WONG D. GLADDEN MWD RUN 4 4 S. TUFTON F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 17 8N 7E 252.00 224.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 108.0 16.000 e e # REMARKS: 3RD STRING 12.250 PRODUCTION STRING 8.500 3005.0 11539.0 Tape Subfile: 1 9.625 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 03' 9.571" LONG: W150 DEG 26' 53.022" LOG MEASURED FROM D.F. AT 252.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a Multiple Propagation Resistivity (MPR) and Gamma Ray with Near Bit Inclination services from 108 - 3010 feet MD (108 - 2389 TVD). (2) Baker Hughes INTEQ runs 2, 3, & 4 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 3010 - 11539 feet MD (2389 - 5873 TVD). (3) 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: 3005 feet MD (2386 TVD) Depth of 9 5/8" Casing Shoe - Driller: 3005 feet MD (2386 TVD) (2) The interval from 2962 to 3010 feet MD (2366 - 2389 TVD) was not logged due to the presence of the 9 5/8" casing. (3) No density data is presented in the interval 5323 - 5476 feet MD (3461 - 3533 TVD) due to a failure of the ORD (Optimized Rotational Density) tool on MWD run 2. (4) The interval from 5522 to 5662 feet MD (3556 - 3624 TVD) was logged up to 19.4 hours after being drilled due to a trip out to change the MWD/LWD tools. (5) This well, 2P-424A, was sidetracked from 2P-424 at 6870 feet MD (4194 TVD). (6) The interval from 11498 to 11539 feet MD (5859 - 5873 TVD) was not logged due to sensor-bit offset at TD. $ 90 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 *** LIS COMMENT RECORD *** e e !!!!!!! ! ! ! !!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 108.0 STOP DEPTH 11539.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 108.0 2962.0 5593.0 6870.0 MERGE BASE 2962.0 5593.0 6870.0 11539.0 # 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-424a_5.xtf 150 ConocoPhillips Alaska 2P-424A Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 e e Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1204 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 108.000000 11539.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 1254 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! !! ! ! ! !! !!!! ! ! !!!!!!!! FILE HEADER FILE NUMBER: RAW MWD LDWG File Version 1.000 Extract File: FILEOll.HED 2 e e header data for each bit run in separate files. 1 .2500 Curves and log BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 90.0 STOP DEPTH 2962.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 27-DEC-03 MSB 18655 8.25 MPR MEMORY 3010.0 90.0 2962.0 o .0 62.4 TOOL NUMBER DHA 7113 MPR 8028 SRIG 58017 12.250 108.0 Spud 9.60 .0 .0 200 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (MWD Run 1) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE REMARKS: e e FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-424a.xtf 150 ConocoPhillips Alaska 2P-424A Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CRAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 e 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 605 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 90.000000 2962.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 704 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!! ! ! !!! LDWG File Version 1.000 !!! !!!!!!!!!!! ! !!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 e log header data for each bit run in separate files. 2 .2500 START DEPTH 2962.0 STOP DEPTH 5593.0 # 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: # 02-JAN-04 MSB 18655 6.75 TC MEMORY 5662.0 2962.0 5593.0 o 61. 2 63.7 fa TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ # BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RES IS. GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # tit TOOL NUMBER DHA 99030 CCN 71631 ORD 46894 MPR 6245 SRIG 92230 8.500 3005.0 LSND 10.50 .0 .0 300 .0 .000 .000 .000 .000 120.0 .0 .0 .0 Sandstone .00 .000 .0 o BIT RUN 2 (MWD Run 2). GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU WDFN 2p-424a.xtf ------------------------------ e e LCC CN WN FN COUN STAT 150 ConocoPhillips Alaska 2P-424A Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 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 16 TCDM MWD 68 1 DEGF 4 4 e e ------- 64 Total Data Records: 752 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2962.000000 5593.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 862 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! !! !!!!!!!!!!! ! ! !! Extract File: FILEOI3.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 5593.0 STOP DEPTH 6870.0 # 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: 06-JAN-04 MSB 18655 6.75 TC MEMORY 6870.0 5593.0 6870.0 o 60.3 62.3 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY TOOL NUMBER DHA 75787 CCN 71630 ORD 12103 MPR 97378 SRIG 5306 e e # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3005.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.35 .0 .0 300 .0 .000 .000 .000 .000 139.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Sandstone .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 2RR1 (MWD Run 3) . GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER 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) This well, 2P-424A, was sidetracked from 2P-424 at 6870 feet MD (4194 TVD). $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-424a.xtf 150 ConocoPhillips Alaska 2P-424A Meltwater Unit North Slope Alaska e e *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 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 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 365 e e Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5593.000000 6870.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 477 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** ! ! ! ! !!!!! !! ! ! ! ! ! !!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 log header data for each bit run in separate files. 4 .2500 START DEPTH 6870.0 STOP DEPTH 11539.0 # 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: 15-JAN-04 MSB 18655 6.75 TC MEMORY 11539.0 6870.0 11539.0 o 56.8 70.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY TOOL NUMBER DHA 75787 CCN 71630 ORD 51687 MPR 97378 SRIG 5306 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3005.0 # BOREHOLE CONDITIONS e e MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.20 .0 .0 300 .0 .000 .000 .000 .000 150.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Sandstone .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 4). GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) This well, 2P-424A, was sidetracked from 2P-424 at 6870 feet MD (4194 TVD). $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-424a.xtf 150 ConocoPhillips Alaska 2P-424A Meltwater Unit North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP · e e GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 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 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 1335 Tape File Start Depth 6870.000000 Tape File End Depth 11539.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet **** FILE TRAILER **** Tape Subtile: 6 Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 04/03/29 01 **** REEL TRAILER **** LDWG 04/03/29 AWS 01 Tape Subtile: 7 Minimum record length: Maximum record length: e e 1447 records... 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes