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Home My WebLink About187-064From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:RE: 3M-19 (187-064) P&A - Supporting Documentation for Requested Variance Date:Wednesday, September 24, 2025 1:14:48 PM From: Lau, Jack J (OGC) Sent: Wednesday, September 24, 2025 1:01 PM To: Roth, Joey <Joey.Roth@conocophillips.com> Subject: RE: [EXTERNAL]RE: 3M-19 P &A - Supporting Documentation for Requested Variance Good afternoon Joey, As discussed, if CPAI attempts a coil FCU / Venturi run and it fails, we will approve the alternate plug variance as written in your sundry request. Jack From: Roth, Joey <Joey.Roth@conocophillips.com> Sent: Wednesday, September 24, 2025 10:23 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]RE: 3M-19 P &A - Supporting Documentation for Requested Variance Jack, At your earliest convenience please give me a call to discuss the abandonment of the well. The RWO and subsequent slick line ops spent a significant amount of time trying to clean out the debris and sand unsuccessfully. Please call my cell: 713.203.7428 Thank you, Joey Roth From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, September 23, 2025 12:02 PM To: Roth, Joey <Joey.Roth@conocophillips.com> Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL]RE: 3M-19 P &A - Supporting Documentation for Requested Variance 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. 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. Thanks Joey, very well detailed. A few comments: The rig successfully cleaned out to the previously established top of fill/shavings. Subsequent slickline operations were unsuccessful in bailing down to the plug. Given the rig’s prior success with fill cleanout (FCO), our preference is to perform a comprehensive coiled tubing unit FCO attempt before evaluating this well for a plugging variance. If needed, a venturi cleanout with coiled tubing could also be considered to reach the top of the plug. If successful, the plug could then be retrieved and the FCO extended through the C sands. This approach would allow the well to be plugged in compliance with regulatory requirements and ensure proper isolation between the A and C sands. The AOGCC’s objective of isolating the A and C sands during plugging operations is supported by the findings presented in SPE-212949-MS, Kuparuk Field Reservoir Management After 40 Years. Jack From: Roth, Joey <Joey.Roth@conocophillips.com> Sent: Sunday, September 14, 2025 1:43 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: 3M-19 P &A - Supporting Documentation for Requested Variance Hello Jack, Please find attached further information regarding our previous correspondence and the Variance Request. I look forward to hearing from you. Please let me know if you have any questions. Regards, Joey Roth 713.203.7428 ConocoPhillips Staff P&A Engineer 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: Change Status to OBS 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): 8965' 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 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 2-7/8" Packer: Baker FH Retrvbl Packer Packer: Camco HRP-1-SP Packer SSSV: None Perforation Depth MD (ft): L-80, J-55 4443' 8445-8471', 8476-8495', 8500- 8544' 8889' 6177-6196', 6200-6213', 6249' 7" Perforation Depth TVD (ft): 115' 4480' 6524'8923' 16" 9-5/8" 77' 8346' MD MD 115' 3463' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool- Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025523 187-064 P.O. Box 100360, Anchorage, AK 99510 50-029-21737-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6819' MD and 5048' TVD 8316' MD and 6084' TVD 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: Contact Name: Joey Roth Contact Email: Joey.Roth@conocophillips.com Contact Phone:(713) 203-7428 Staff P&A Engineer KRU 3M-19 6554' 8333' 6097' 8333' 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 10/10/2025 By Grace Christianson at 7:36 am, Sep 11, 2025 325-552 A.Dewhurst 22OCT25 DSR-9/11/25 10-407 X J.Lau 10/22/25 Reservoir plug - AOGCC witness tag TOC and MITT to 2500 psi. Intermediate plug - AOGCC witness tag TOC and CMIT-TxIA to 2500 psi. AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut X 10/22/25 Objective: Well History: Well Status: Variance Request: *Variance approved after failed fill cleanout attempt on 10/21/25: CPAI attempt to clean out sand/debris failed. - JJL Reservoir Information: o o o o o Current Tubular Detail: String (OD)Top (ft) Bottom (MD / TVD) Size / Weight / Grade / Conn ID BBL / FT FT / BBL Volume BBL String Top (ftKB) Bottom (ftKB) Size, Wt., Grade & Top Thread ID BBL/FT FT/BBL Volume BBL Program: Slickline Coiled Tubing Reservoir Plug Notes: Cement Detail: Total cement to pump w/ 10% excess 60 bbl. Cement Type / Weight Class G 15.8 ppg batch mixed Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs. Thickening Time Minimum 5 hours Slick Line & Pump: Tag, Test Reservoir Plug & Perforate Tubing. Coiled Tubing Intermediate Plug Total cement to pump (on the fly)204 bbl. Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Requires latex additive for gas block. Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs. Thickening Time Minimum 5 hours Pumping/Cementing Surface Plug Notes: o Total cement to pump on the fly 96 bbl., have 150 bbl. pumpable cement available Cement Type / Weight Permafrost Cement mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs. Thickening Time Minimum 4 hours Cement thickening time: Mix on the Fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Safety 1 Minimum required thickening time:4 Cement Ramp for Blend Time Volume Pumped (bbl.) Temperature (°F) Pressure (psi) 0:00 0 32 0 0:30 0 32 0 1:00 0 32 1800 2:00 60 32 1800 3:00 88 32 1800 Contingency Cement Top Job Post Casing Cut Procedure: Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,477.0 3M-19 4/12/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull SOV, Set DV, Pull B&R and RHC Plug Body 3M-19 4/26/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Lost ~ 2.25" piece of JD Dog below 5873'. DID NOT RECOVER 3/20/2011 lmosbor NOTE: STRIPPED F/N OFF LATCH ON GLV@ 6364' 3/20/2011 lehallf NOTE: CTU FOUND CORKSCREWED TUBING FROM 7800' to 8333' 8/12/2006 WV5.3 Conversio n NOTE: WAIVERED WELL: IA x OA COMMUNICATION 12/22/2002 WV5.3 Conversio n NOTE: FISHNECK ON GLV LATCH @ 6364' IS STRIPPED 7/20/2002 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 38.0 115.0 115.0 62.50 H-40 SURFACE 9 5/8 8.83 37.0 4,479.7 3,463.1 36.00 J-55 BTC PRODUCTION 7 6.28 34.0 8,923.3 6,524.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.0 Set Depth 8,271.5 String Max No 2 7/8 Set Depth 6,052.2 Tubing Description Tubing Production Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-M ID (in) 2.44 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) 34.0 34.0 0.07 Hanger 7.000 FMC Gen IV Tubing Hanger, 2 7/8" FMC Gen 4 2.340 3,270.9 2,650.6 47.12 Mandrel GAS LIFT 5.424 2-7/8" x 1-1/2" MMG SN 25343-02 DV SN 25343-04 SLB MMG 2.366 6,737.2 4,992.7 47.15 Mandrel GAS LIFT 5.424 2-7/8" x 1-1/2" MMG SN 25343-01 SOV 2000psi SN 25343-05 SLB MMG 2.366 6,795.3 5,032.0 47.58 PBR 5.860 2-7/8" Baker PBR 80-32 Baker 80-32 2.380 6,818.8 5,047.9 47.66 Packer 5.960 2-7/8" x 7" Baker FH Retrievable Packer (~6815' above leak in CSG) Baker FH 2.420 8,248.6 6,035.8 44.13 Nipple - X 3.699 2-7/8" X Nipple 2.313" Halliburt on 2.313" X 2.313 8,265.9 6,048.2 44.13 Overshot 5.740 2 7/8" TBG Patch (swallow 3.53') Baker Sealing 2.441 Top (ftKB) 8,268.0 Set Depth 8,346.1 String Max No 2 7/8 Set Depth 6,105.8 Tubing Description Tubing Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection 8rd AB MOD ID (in) 2.44 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) 8,298.2 6,071.4 44.13 PBR 5.000 2 7/8" CAMCO 'OEJ' Camco OEJ 2.313 8,315.7 6,084.0 44.05 PACKER 6.151 2 7/8" x 7" CAMCO HRP-1-SP Pkr Camco HRP-1- SP 2.347 8,333.6 6,096.8 43.96 NIPPLE 3.668 2 7/8" CAMCO 'D' Nipple ID 2.25" Camco D 2.250 8,345.5 6,105.4 43.90 SOS 3.750 2 7/8" CAMCO SOS Pinned 3500 PSI - TTL ELMD @ 8352' SWS 7/17/1997 Camco PE-500 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,895.0 5,099.1 47.84 LEAK - CASING CSG LEAK IDENTIFIED BY ACOUSTIC LDL (0.6 BPM, 3000 PSI) 5/25/2021 6.280 8,327.9 6,092.7 43.99 CATCHER Set 2.25" Junk catcher on top of plug (OAL = 67") 12/8/2024 0.000 8,333.4 6,096.7 43.96 TUBING PLUG 2.25" CA-2 Plug (2.29" NO- GO, OAL = 25") 12/8/2024 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) 3,270.9 2,650.6 47.12 2 GAS LIFT DV RK 2 7/8 4/7/2025 SLB FO-2 MMG 0.000 6,737.2 4,992.7 47.15 1 GAS LIFT DV RK 2 7/8 4/26/2025 SLB FO-2 MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,445.0 8,471.0 6,177.3 6,196.1 C-4, 3M-19 5/24/1991 6.0 APERF 2 1/8" EnerJet; 0 deg. ph 8,476.0 8,494.0 6,199.7 6,212.7 A-2, 3M-19 5/24/1991 6.0 RPERF 2 1/8" EnerJet;; 0 deg. ph 8,486.0 8,487.0 6,206.9 6,207.6 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,490.0 8,491.0 6,209.8 6,210.5 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,494.0 8,495.0 6,212.7 6,213.4 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,500.0 8,544.0 6,217.0 6,248.8 A-1, 3M-19 9/3/1987 4.0 IPERF 4" Csg Gun; 120 deg. ph 3M-19, 9/9/2025 10:18:28 AM M D (ft KB ) -15,407.8 -15,302.8 -7.9 -7.5 -5.2 -4.9 -4.6 -2.3 -0.7 0.0 34.1 34.4 37.1 38.1 41.0 65.0 69.2 73.8 115.2 2,000.0 3,262.8 3,271.0 3,279.9 3,288.1 4,397.3 4,399.3 4,477.7 4,479.7 4,480.0 6,727.0 6,737.2 6,746.1 6,756.2 6,787.1 6,795.3 6,818.9 6,825.8 6,829.7 6,895.0 6,896.0 6,980.0 8,126.0 8,238.5 8,248.7 8,249.7 8,259.8 8,266.1 8,268.0 8,271.7 8,292.0 8,298.2 8,298.9 8,315.0 8,315.6 8,323.5 8,327.8 8,333.3 8,333.7 8,335.3 8,345.5 8,346.1 8,367.1 8,407.5 8,411.1 8,442.9 8,444.9 8,456.0 8,471.1 8,474.1 8,476.0 8,477.0 8,480.0 8,485.9 8,486.9 8,490.2 8,491.1 8,494.1 8,495.1 8,499.0 8,500.0 8,515.1 8,536.1 8,544.0 8,569.9 8,831.4 8,833.3 8,921.6 8,922.9 8,923.2 8,971.1 Vertical schematic (actual) BASE HKALUBIUPPER K-1 MALOWER KUPARUNIT D UNIT C C-4 INTC-4B S C-4A S C-3 INTC-2 INTC-1 INTC-1B SC-1A SUNIT B B-8 INTB-7 INTB-6 INTB-5 INTB-4 INTB-3 INTB-2 INTB-1 INTUNIT A (A-6 INTA-5 INTA-4 INTA-3 INTA-2 INTA2-2 SU A2-1 SU A-1 INTA1-2 SU A1-1 SU MILUVE FLOAT SHOE; 8,921.5-8,923.3; 1.83; 3-7; 7.656; 6.276 Casing; 8,833.2-8,921.5; 88.31; 3-6; 7.000; 6.276 FLOAT COLLAR; 8,831.5-8,833.2; 1.69; 3-5; 7.656; 6.276 Casing; 8,407.6-8,831.5; 423.88; 3-4; 7.000; 6.276 IPERF; 8,500.0-8,544.0; 9/3/1987 IPERF; 8,494.0-8,495.0; 9/3/1987 IPERF; 8,490.0-8,491.0; 9/3/1987 IPERF; 8,486.0-8,487.0; 9/3/1987 RPERF; 8,476.0-8,494.0; 5/24/1991 APERF; 8,445.0-8,471.0; 5/24/1991 Casing; 8,367.1-8,407.6; 40.47; 3-3; 7.000; 6.276 SOS; 8,345.5-8,346.1; 0.63; 2-8; 3.750; 2.441 TUBING PUP; 8,335.4-8,345.5; 10.11; 2-7; 2.875; 2.441 NIPPLE; 8,333.6-8,335.4; 1.80; 2-6; 3.668; 2.250 TUBING PUP; 8,323.5-8,333.6; 10.07; 2-5; 2.875; 2.441 PACKER; 8,315.7-8,323.5; 7.77; 2-4; 6.151; 2.347 PBR; 8,298.2-8,315.7; 17.53; 2-3; 5.000; 2.313 TUBING PUP; 8,292.1-8,298.2; 6.05; 2-2; 2.875; 2.441 Tubing; 8,268.0-8,292.1; 24.16; 2-1; 2.875; 2.441 Overshot; 8,265.9-8,271.5; 5.56; 3- 23; 5.740; 2.441 Tubing - Pup Joint; 8,259.8-8,265.9; 6.19; 3-22; 2.875; 2.410 Tubing - Pup Joint; 8,249.6-8,259.8; 10.18; 3-21; 2.875; 2.441 Nipple - X; 8,248.6-8,249.6; 0.96; 3-20; 3.699; 2.313 Tubing - Pup Joint; 8,238.5-8,248.6; 10.13; 3-19; 2.875; 2.441 Tubing; 6,829.8-8,238.5; 1,408.72; 3 -18; 2.875; 2.441 Tubing - Pup Joint; 6,825.7-6,829.8; 4.06; 3-17; 2.875; 2.420 Packer; 6,818.8-6,825.7; 6.86; 3-16; 5.960; 2.420 PBR; 6,795.3-6,818.8; 23.55; 3-15; 5.860; 2.380 Tubing - Pup Joint; 6,787.1-6,795.3; 8.23; 3-14; 2.875; 2.440 Tubing; 6,756.2-6,787.1; 30.82; 3- 13; 2.875; 2.441 Tubing - Pup Joint; 6,746.1-6,756.2; 10.13; 3-12; 2.875; 2.441 Mandrel GAS LIFT; 6,737.2-6,746.1; 8.87; 3-11; 5.424; 2.366 Tubing - Pup Joint; 6,727.1-6,737.2; 10.16; 3-10; 2.875; 2.441 Tubing; 3,288.1-6,727.1; 3,439.03; 3-9; 2.875; 2.441 FLOAT SHOE; 4,477.8-4,479.7; 1.83; 2-5; 10.625; 8.921 Casing; 4,399.1-4,477.8; 78.70; 2-4; 9.625; 8.835 FLOAT COLLAR; 4,397.4-4,399.1; 1.76; 2-3; 10.625; 8.921 Casing; 65.0-8,367.1; 8,302.13; 3-2; 7.000; 6.276 Tubing - Pup Joint; 3,279.8-3,288.1; 8.26; 3-8; 2.875; 2.441 Mandrel GAS LIFT; 3,270.9- 3,279.8; 8.88; 3-7; 5.424; 2.366 Tubing - Pup Joint; 3,262.7-3,270.9; 8.23; 3-6; 2.875; 2.441 Casing; 41.0-4,397.4; 4,356.34; 2-2; 9.625; 8.835 Tubing; 73.7-3,262.7; 3,188.98; 3-5; 2.875; 2.441 CONDUCTOR; 38.0-115.0; 77.00; 1-1; 16.000; 15.062 Tubing - Space Out; 69.1-73.7; 4.60; 3-4; 2.875; 2.441 Tubing; 38.1-69.1; 30.96; 3-3; 2.875; 2.441 Casing; 34.0-65.0; 31.00; 3-1; 7.000; 6.276 HANGER; 37.0-41.0; 4.03; 2-1; 11.000; 8.835 Tubing - Pup Joint; 34.5-38.1; 3.67; 3-2; 2.875; 2.441 Hanger; 34.0-34.5; 0.50; 3-1; 7.000; 2.340 KUP PROD KB-Grd (ft) 37.00 RR Date 7/19/1987 Other Elev 3M-19 ... TD Act Btm (ftKB) 8,971.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292173700 Wellbore Status PROD Max Angle & MD Incl (°) 48.52 MD (ftKB) 4,000.00 WELLNAME WELLBORE3M-19 Annotation Last WO: End Date 4/7/2025 H2S (ppm) 200 Date 11/3/2013 Comment SSSV: TRDP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 37.0 4,480.0 37.0 3,463.3 Primary Full Bore Lead 512 bbl 12.3 ppg Cold Set III + Tail 103 bbl 15.8 ppg Class G... Run 9-5/8" csg - R/U BJ cmt head - Circ 1X csg volume -PT lines. Pump 80 bbl H2O. Mix & pump CS III Lead, drop plug, pump Class G Tail. Drop top plug & displ w/H2O. Bump plug w/2000 psi - Held press 15 min - Floats held. CIP @ 23:45 7/13/87. No indication on Daily Drilling Report of cmt returns to surface or top job. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 6,980.0 8,923.0 5,156.3 6,524.0 Primary Full Bore Lead 36.5 bbl 12.5 ppg Class G + Tail 46 bbl 15.9 ppg Class G... Run 7" csg - R/U BJ cmet head - Circ 2X csg volume - PT lines to 3800 psi. Pump 40 bbl H2O Spacer, drop btm plug. Mix & pump Class G Lead @ 12.5 ppg, drop middle plug, pump Class G Tail @ 15.9 ppg. Drop top plug & displ w/338 bbl brine @ 10.0 ppg. Bump plug w/3500 psi - Held press 15 min - Floats held. CIP @ 22:00 7/18/87. ^^Csg OD=7 3M-19, 9/9/2025 10:18:28 AM M D (ft KB ) -15,407.8 -15,302.8 -7.9 -7.5 -5.2 -4.9 -4.6 -2.3 -0.7 0.0 34.1 34.4 37.1 38.1 41.0 65.0 69.2 73.8 115.2 2,000.0 3,262.8 3,271.0 3,279.9 3,288.1 4,397.3 4,399.3 4,477.7 4,479.7 4,480.0 6,727.0 6,737.2 6,746.1 6,756.2 6,787.1 6,795.3 6,818.9 6,825.8 6,829.7 6,895.0 6,896.0 6,980.0 8,126.0 8,238.5 8,248.7 8,249.7 8,259.8 8,266.1 8,268.0 8,271.7 8,292.0 8,298.2 8,298.9 8,315.0 8,315.6 8,323.5 8,327.8 8,333.3 8,333.7 8,335.3 8,345.5 8,346.1 8,367.1 8,407.5 8,411.1 8,442.9 8,444.9 8,456.0 8,471.1 8,474.1 8,476.0 8,477.0 8,480.0 8,485.9 8,486.9 8,490.2 8,491.1 8,494.1 8,495.1 8,499.0 8,500.0 8,515.1 8,536.1 8,544.0 8,569.9 8,831.4 8,833.3 8,921.6 8,922.9 8,923.2 8,971.1 Vertical schematic (actual) BASE HKALUBIUPPER K-1 MALOWER KUPARUNIT D UNIT C C-4 INTC-4B S C-4A S C-3 INTC-2 INTC-1 INTC-1B SC-1A SUNIT B B-8 INTB-7 INTB-6 INTB-5 INTB-4 INTB-3 INTB-2 INTB-1 INTUNIT A (A-6 INTA-5 INTA-4 INTA-3 INTA-2 INTA2-2 SU A2-1 SU A-1 INTA1-2 SU A1-1 SU MILUVE FLOAT SHOE; 8,921.5-8,923.3; 1.83; 3-7; 7.656; 6.276 Casing; 8,833.2-8,921.5; 88.31; 3-6; 7.000; 6.276 FLOAT COLLAR; 8,831.5-8,833.2; 1.69; 3-5; 7.656; 6.276 Casing; 8,407.6-8,831.5; 423.88; 3-4; 7.000; 6.276 IPERF; 8,500.0-8,544.0; 9/3/1987 IPERF; 8,494.0-8,495.0; 9/3/1987 IPERF; 8,490.0-8,491.0; 9/3/1987 IPERF; 8,486.0-8,487.0; 9/3/1987 RPERF; 8,476.0-8,494.0; 5/24/1991 APERF; 8,445.0-8,471.0; 5/24/1991 Casing; 8,367.1-8,407.6; 40.47; 3-3; 7.000; 6.276 SOS; 8,345.5-8,346.1; 0.63; 2-8; 3.750; 2.441 TUBING PUP; 8,335.4-8,345.5; 10.11; 2-7; 2.875; 2.441 NIPPLE; 8,333.6-8,335.4; 1.80; 2-6; 3.668; 2.250 TUBING PUP; 8,323.5-8,333.6; 10.07; 2-5; 2.875; 2.441 PACKER; 8,315.7-8,323.5; 7.77; 2-4; 6.151; 2.347 PBR; 8,298.2-8,315.7; 17.53; 2-3; 5.000; 2.313 TUBING PUP; 8,292.1-8,298.2; 6.05; 2-2; 2.875; 2.441 Tubing; 8,268.0-8,292.1; 24.16; 2-1; 2.875; 2.441 Overshot; 8,265.9-8,271.5; 5.56; 3- 23; 5.740; 2.441 Tubing - Pup Joint; 8,259.8-8,265.9; 6.19; 3-22; 2.875; 2.410 Tubing - Pup Joint; 8,249.6-8,259.8; 10.18; 3-21; 2.875; 2.441 Nipple - X; 8,248.6-8,249.6; 0.96; 3-20; 3.699; 2.313 Tubing - Pup Joint; 8,238.5-8,248.6; 10.13; 3-19; 2.875; 2.441 Tubing; 6,829.8-8,238.5; 1,408.72; 3 -18; 2.875; 2.441 Tubing - Pup Joint; 6,825.7-6,829.8; 4.06; 3-17; 2.875; 2.420 Packer; 6,818.8-6,825.7; 6.86; 3-16; 5.960; 2.420 PBR; 6,795.3-6,818.8; 23.55; 3-15; 5.860; 2.380 Tubing - Pup Joint; 6,787.1-6,795.3; 8.23; 3-14; 2.875; 2.440 Tubing; 6,756.2-6,787.1; 30.82; 3- 13; 2.875; 2.441 Tubing - Pup Joint; 6,746.1-6,756.2; 10.13; 3-12; 2.875; 2.441 Mandrel GAS LIFT; 6,737.2-6,746.1; 8.87; 3-11; 5.424; 2.366 Tubing - Pup Joint; 6,727.1-6,737.2; 10.16; 3-10; 2.875; 2.441 Tubing; 3,288.1-6,727.1; 3,439.03; 3-9; 2.875; 2.441 FLOAT SHOE; 4,477.8-4,479.7; 1.83; 2-5; 10.625; 8.921 Casing; 4,399.1-4,477.8; 78.70; 2-4; 9.625; 8.835 FLOAT COLLAR; 4,397.4-4,399.1; 1.76; 2-3; 10.625; 8.921 Casing; 65.0-8,367.1; 8,302.13; 3-2; 7.000; 6.276 Tubing - Pup Joint; 3,279.8-3,288.1; 8.26; 3-8; 2.875; 2.441 Mandrel GAS LIFT; 3,270.9- 3,279.8; 8.88; 3-7; 5.424; 2.366 Tubing - Pup Joint; 3,262.7-3,270.9; 8.23; 3-6; 2.875; 2.441 Casing; 41.0-4,397.4; 4,356.34; 2-2; 9.625; 8.835 Tubing; 73.7-3,262.7; 3,188.98; 3-5; 2.875; 2.441 CONDUCTOR; 38.0-115.0; 77.00; 1-1; 16.000; 15.062 Tubing - Space Out; 69.1-73.7; 4.60; 3-4; 2.875; 2.441 Tubing; 38.1-69.1; 30.96; 3-3; 2.875; 2.441 Casing; 34.0-65.0; 31.00; 3-1; 7.000; 6.276 HANGER; 37.0-41.0; 4.03; 2-1; 11.000; 8.835 Tubing - Pup Joint; 34.5-38.1; 3.67; 3-2; 2.875; 2.441 Hanger; 34.0-34.5; 0.50; 3-1; 7.000; 2.340 KUP PROD 3M-19 ... WELLNAME WELLBORE3M-19 ANNCOMM-ZX30 Scale Removal Pre- RWO Recompletion Repair Well 3M-19 P&A Supporting Documentation for Requested variance Joey Roth (713.203.7428) September 14, 2025 Re: Submitted Sundry Request on 9/10/2025 for the Permanent Abandonment of 3M-19 Sundry #325-221 (operational shut down) & Sundry # 324-667 (PTD) Requested Variance: We are mechanically unable to plug the perforated A & C sand intervals below the primary packer @ 8316 MD, per 20 AAC 25.112 Well Plugging requirements. Prior work on the well indicates the A sand perforations are plugged with sand and debris from a coil tubing clean out attempt that left a amount of sand in the tubing in 2021 (see the well work summary outline below). A CA-2 plug is set in the D nipple @ 8350 MD isolating the perforations. Slick line was unable to go passed 8276 MD in the most recent clean out (post rig) attempt. We are asking for a Variance request to perform a hesitation squeeze cement sequence if we can establish a workable injection rate: 2-3 bpm <2500 psi. If we cannot establish a workable injection rate, we would ask to lay a continuous cement plug through tubing and into the IA (7 x 2 7/8): plugging the tubing and the annular space between the two packers currently in the well. This interval between the packers is from 8316 MD / 6084 TVD 6819MD / 5048 TVD. Supporting Information for the Request (taken from Daily Ops Reports): Background Non-Rig Work April 6th 12th, 2021: Coil Tubing o CTU Clean-out: Bead blasted the tubing down to 8363 MD (EOT). The blaster plugged while Pulled plugged coil, cut 100 plugged coil, RIH and tag hard at 8515 RKB 37 RKB = 8478 MD (4 below A sand top perf). The A sand top perf @ 8474 MD. Supporting Evidence: sand and debris from the tubing clean out. RD coil / RU slick line: SL tagged TD @ 8744 MD. Brush & Flush & Set a Ca-2 plug in D nipple @ 8350 MD, attempted MITT & CMIT (both failed). 3M-19 was recommended for RWO: Tbg pull and replace. December 2nd 8th, 2024: Slick line Drifted tubing (2.25 OD) pulled CA-2 plug in the D nipple at 8350 MD, Ran dual Spartech gauges to 8445 MD: POOH w/ gauges (SBHP 3932 @ 6113 TVD) RIH w/ 2.2 gauge and Tubing Brush: brushed tubing and D nipple @ 8350 MD: the tubing Set a No-Go Catcher in D nipple Pulled Gas Lift valves and replaced with dummy valves (days, valves did not pull easy) Set 2.25 CA-2 plug in D nipple at 8350 MD. With Junk catcher on top of plug. Ran tbg drift to 8340 MD, no issues getting down. Negative pressure test: Bled tbg & IA from 1600 psi to 500 psi and monitored 15 min. Good Test (12/8/2024). December 22nd, 2024: e- line C trouble releasing anchor and had to jar torch. March 25th April 8th 2025: RWO Nabors 7ES Unable to pull pre-cut RWO at 8290 MD. Second Tbg cut made @ 8254 MD (successfully pulled tbg) Attempted to Fish Stub (36) o recovered 3 yards of sand and debris. Continued to wash from 8188 8246MD. o Trouble getting over stub and attempted to burn over: Circulated sweep, POOH, Fishing BHA: OD from 6 1/8 OD. o RIH w/ overshot & control, milling BHA. (several attempts (3 days) of milling and trying to -line cutter & unable to get past 8245 MD. o Slick line bailer (1.5 days) bailer from 8247 MD - 8273 MD (recovered 16.75 gal of sand) o E- o RIH w/ Overshot: TOF and mill to 8279 MD. POOH & recovered 20# metal from barrel & boot Good test from 6850 MD (after multiple failed csg test: f/ 8205 8170 MD.) o POOH w/ test packer. Note: lots of metal on test packer and element gouged in places. o Grow and stretch casing: 18.75 o TIH w/ clean out BHA to 8268 MD & Circulated (sand and debris in returns) o POOH o RIH w/ AS1X test packer and found production casing leaks below 6850 MD. o Set and isolation straddle packer at 6818 MD, unable to get a tubing test due leaking overshot & mis aligned @ 8316 MD. o Good T, Tx IA test above isolation packer at 6818 MD. April 29th 2025: Slick line o Slick line: unable to pass 8276 MD (<2 OD): recovered metal shavings and scale. From:Lau, Jack J (OGC) To:Coldiron, Samantha J (OGC) Cc:Chmielowski, Jessie L C (OGC) Subject:FW: CPAI RWO Straddle Packer Casing Patch Strategy Date:Tuesday, August 26, 2025 2:18:08 PM Thank you Jack From: Lau, Jack J (OGC) Sent: Wednesday, July 16, 2025 11:22 AM To: Dodson, Kate <Kate.Dodson@conocophillips.com> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Zwarich, Nola R <Nola.R.Zwarich@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: CPAI RWO Straddle Packer Casing Patch Strategy Kate – We have reviewed the submitted data and reconsidered PC leak straddle repair requirements for KRU. Please review the following updated requirements below and let us know if you have any questions or concerns. We have removed the biennial testing and pore pressure frac gradient requirements. We landed on 90 days to set a plug with an option for a 30-day extension. Jack PC Leak Straddle Repair Requirements (7/16/25) Requirement to secure well when shut in - plug shall be set and tested within 90 days of well being shut-in to prevent any waste due potential fluid migration Plug depth - plug set below lowest straddle packer Testing requirement - when secured straddle shall be tested with plug set below lowest straddle packer (lower packer tested) Both straddle packers and straddle pipe require testing If previous test was performed within 2 years an updated test is 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. recommended but not required. If plug cannot be set within 90 days, a 30 day extension may be approved by AOGCC with justification and other means of verification such as logging. The biennial testing requirement can be removed given: The above plugging requirement is met The above testing requirement is met The corrosion and chemistry data presented illustrated long life of L-80 tubing in KRU Sundry applications must include: 1. PC cementing detail including TOC and method of determination 2. Proposed plug depth for pressure testing and securing well 3. Identification of any permeable or hydrocarbon zones behind the straddle From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Wednesday, July 2, 2025 11:53 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Dodson, Kate <Kate.Dodson@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Zwarich, Nola R <Nola.R.Zwarich@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: CPAI RWO Straddle Packer Casing Patch Strategy Jack, I am going on vacation from July 7 through the 31st and was reaching out on the status of the response to the data that ConocoPhillips Alaska Inc. (CPAI) provided for the 3M-19 RFI (OTH-25-016), and the proposed 120 day timing to set a tested plug in the tubing tail below the straddle assembly for long term shut in producers with that repair. As discussed in our final meeting this mitigation could allow relief on previously requested (via attached e-mail) pore pressure frac gradient plots for rig workover candidates repaired with this technique, and the tested plug would remove the need for mechanical integrity testing at a regular interval. CPAI also provided data for the Kuparuk field that reflected a 19-year tubing life prior to any failure of the completion. Produced fluid chemistry was also provided that supported this life for the majority L-80 completion stock in the field. I appreciate the review of the matter by the AOGCC and a response that ties up the correspondence that has been exchanged between the AOGCC and CPAI. Thank-you, Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 Cell: 907-231-0515 May 5, 2025 Jessie Chmielowski Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 Gregory Wilson Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 VIA E-MAIL (samantha.coldiron@alaska.gov) Re: Docket No. OTH-25-016 Request for Information Sundry 324-667 for Kuparuk River Unit (KRU) Well 3M-19 Request for Reconsideration Commissioners Chmielowski and Wilson: On March 25, 2025, CPAI filed a Request for Reconsideration of the two-year testing requirement in Sundry 324-667. On April 2, 2025, AOGCC issued a request for information (RFI) to support CPAI’s request. This letter responds to that RFI. 1. 3M-19 Well Log Analysis (Uncemented Zones) The well log analysis, cross sectional log, and other information responsive to this AOGCC request are provided in the attached slide deck. See slide 1. Regarding the AOGCC’s specific questions: a. There are no identified uncemented hydrocarbon-bearing zones behind 3M-19 casing. b. There are no identified abnormally pressured zones with flow potential behind 3M-19 casing. c. There are no uncemented disposal zones behind 3M-19 casing. The Kuparuk River Unit (KRU) disposal zone is shallow (approximately 3000’ TVD, in the Ugnu formation), and Scott Kolstad Intervention & Integrity RWO CTD Manager 700 G Street, ATO 520 Anchorage, AK 99501 (907) 265-6347 (office) Scott.Kolstad@conocophillips.com By Samantha Coldiron at 8:20 am, May 06, 2025 2 the two KRU disposal wells are located on the 1B pad, approximately 11 miles from 3M-19. d. Regarding “flow units behind cemented and uncemented casing,” the Ugnu and West Sak formations are isolated by surface casing cement. The Moraine formation is isolated by production casing cement. CPAI identified one low quality, wet silty sandstone at the base of the Schrader Bluff in the uncemented section of the overburden, approximately 700’ TVD above the straddle packer. The straddle packer (and isolated production casing (PC) leak) is separated from the wet sandstone stratum by Torok and Seabee clay/siltstone intervals. See slide 2. 2. Risk Assessment (New Potential PC Leak) CPAI’s risk assessment, including mitigations, and a flow schematic, are provided in the attached slide deck. See slides 4-5. Regarding the AOGCC’s specific question, although the existing PC leak in 3M-19 has been fully isolated by the straddle packer, if another leak occurred in this well across this repair, the “worst- case scenario” would be potential migration of production fluids into the wet, silty sandstone layer identified above, elevating pressure in that zone and creating a future potential drilling hazard. CPAI has determined this scenario is very unlikely, for the following reasons: a. Like other producers, when 3M-19 is on production, internal well pressure (~1220 psi) is much less than hydrostatic pressure in the outer annulus (OA) (~2240 psi), and fluids, including lift gas, will follow the path of least resistance up the wellbore, bypassing any (hypothetical) non-isolated PC leak. b. 3M-19 was kept on production, with few shut-ins of short duration, until deemed inoperable, and the plan (pending additional post-rig remedial work) is to keep the well on production consistently. See slide 5. c. As discussed below and in the attached slide deck, the corrosion mechanism that most likely caused the PC leak is uninhibited fluids (wellbore fluids and/or degraded corrosion inhibitor) at or below the deepest lift point in the inner annulus (IA), particularly in higher incline sections where depositions may form on the low side of the PC. This mechanism is generally understood to occur slowly. 3M-19 has no identified PC leaks above the isolated (straddle-packed) PC leak and was drilled in 1987. CPAI installed gas lift points above the straddle packer, where production casing (and tubing) was not previously exposed to liquids while on production, with corrosion inhibiting fluids pumped into the IA. d. CPAI has not encountered elevated pressure zones in the overburden during PC leak remediation work. Analysis of the twelve rig workover BOPE closures over the last five 3 years determined there were no closures during casing leak isolation operations, and no evidence of formation(s) being charged from lift gas or produced fluids because of the leaks. e. The overburden includes a single low quality, wet, silty sandstone, which is separated from the straddled section by the Torok and Seabee intervals. Initial “formation as a barrier” testing performed at 3S suggests that the Seabee interval collapses and/or swells to likely impede fluid flow behind the PC. f. Additionally, where CPAI has pulled casing in the past, we have observed significant formation collapse around the casing, further impeding any potential fluid flow behind the PC. 3. Pore Pressure and Fracture Gradient Data (Zones with Flow Potential) There are no identified over-pressured zones with flow potential. See slide 6. 4. Root Cause Analysis (3M-19 PC Leak) The corrosion mechanism that most likely caused the PC leak is uninhibited fluids (wellbore fluids and/or degraded corrosion inhibitor) at or below the deepest lift point in the IA, particularly in higher incline sections where depositions may form on the low side of the PC. See below, capturing information from slides 4 and 7. These graphics show the isolated PC leak (6895’) within the planned repair technique, correlated with the measured casing degradation in a 50-degree incline section at or near the same depth (6800’ to 7700’) as the deepest gas lift (orifice) valves throughout the well history (6856’ to 8267’). 4 See also Section 6 below and slide 9. 5 5. List of Affected Wells Below is a list of all wells with identified PC leaks at 3M, 3I, 3N, and 3Q pads. Of 81 total wells on these four pads, most of which were drilled more than 30 years ago, ten (~12%) have identified PC leaks. All ten of these wells are (or were) gas-lifted producers. See slide 8. 6. Root Cause Analysis and Historical Data (PC Leaks) As stated above, the corrosion mechanism that most likely caused existing PC leaks is uninhibited fluids (wellbore fluids and/or degraded corrosion inhibitor) at or below the deepest lift point in the IA, particularly in higher incline sections where depositions may form on the low side of the PC. See slide 7, 9, 11. The data supporting this determination are: a. Correlation of PC leaks and observed corrosion at or near the deepest lifting locations. See slide 7, 11, 12, and the table in Section 5 above. b. Casing caliper data shows internal corrosion. See slide 7. 6 c. When pulled in workover operations, tubing corrosion is observed at gas lift valve locations when internal casing corrosion is suspected. d. All observed PC leaks in this area are in gas lifted producers (or wells that were gas lifted producers). See slide 8. 7. Mitigation Measures (PC Leaks) When PC leaks are detected in workover operations, a. the leak is isolated from lift gas and produced fluids by a straddle packer or other isolation mechanism; b. where a straddle packer is used, the deepest gas lift valve is relocated above the packer, relocating any gas-liquid interface to a section of casing not previously exposed to the interface; and c. corrosion inhibiting fluids are placed in the IA. These mitigation measures have been shown effective over many decades of well operations. 8. Casing Integrity (External Corrosion) The fluid / gas lift point corrosion mechanism is the most likely cause of the PC leaks observed in 12% of the wells on the 3M, 3I, 3N, and 3Q pads. Casing caliper data shows internal corrosion. See slides 7, 11, and 12. We have no evidence that external corrosion is a significant contributing factor. As noted above, where disposal fluids have been identified as a potential external corrosion cause at the Prudhoe Bay Unit, the KRU disposal zone is shallow (approximately 3000’ TVD, in the Ugnu formation), and the two KRU disposal wells are located on the 1B pad, approximately 11 miles from 3M-19. Accordingly, it is extremely unlikely that disposal fluids are interacting with any 3M wells. 9. Systemic Corrosion Concerns Only 12% of the wells on the 3M, 3I, 3N, and 3Q pads have observed PC leaks. Most are near or below the lowest gas lift valve location, supporting our determination that the most likely cause of PC leaks in these wells is uninhibited fluids (wellbore fluids and/or degraded corrosion inhibitor) at or below the deepest lift point. The data also show that this corrosion mechanism usually occurs slowly and that raising the deepest gas lifting point over time (and the other steps described in Section 7 above) are effective mitigations. 7 Respectfully, these data do not reflect a “systemic issue” with PC corrosion. We look forward to meeting with the AOGCC to further discuss this issue and the information above and attached to this response. Sincerely, Scott Kolstad Intervention & Integrity RWO CTD Manager ConocoPhillips Alaska, Inc. Attachment – PowerPoint Deck Digitally signed by Scott Kolstad DN: OU=Intervention & Integrity RWO CTD Manager, O=ConocoPhillips, CN=Scott Kolstad, E=Scott.Kolstad@ConocoPhillips.comReason: I have reviewed this documentLocation: Anchorage, AK Date: 2025.05.05 16:20:24-08'00' Foxit PDF Editor Version: 13.1.6 Scott Kolstad 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:Lau, Jack J (OGC) To:Coldiron, Samantha J (OGC) Subject:RE: Docket No. OTH-25-016 CPAI RFI Response 3M-19 Date:Tuesday, May 6, 2025 9:55:21 AM Unfortunately, I do not. I verbally extended it during our monthly meeting with CPAI on Thursday May 1, 2025. Jack From: Coldiron, Samantha J (OGC) <samantha.coldiron@alaska.gov> Sent: Tuesday, May 6, 2025 8:41 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: Docket No. OTH-25-016 CPAI RFI Response 3M-19 Do you have an email or anything extending the deadline for the file? Samantha Coldiron AOGCC Special Assistant (907) 793-1223 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, May 5, 2025 4:31 PM To: Coldiron, Samantha J (OGC) <samantha.coldiron@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: Docket No. OTH-25-016 CPAI RFI Response 3M-19 Good afternoon, Attached please find the response of ConocoPhillips Alaska Inc. to the subject request for information. As agreed last Thursday, it is being submitted on the 5th of May versus the 4th when the original timing of the request would have put it. Thank-you, Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 Cell: 907-231-0515 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov April 2, 2025 via email: scott.kolstad@conocophillips.com Scott Kolstad Intervention and Integrity RWO CTD Manager ConocoPhillips Alaska, Inc. 700 G Street, ATO 520 Anchorage, AK 99501 Re: Docket Number: OTH-25-016 Request for Information CPAI Request for Reconsideration Sundry 324-667 (KRU 3M-19) Dear Mr. Kolstad: On December 18, 2024, the Alaska Oil and Gas Conservation Commission (AOGCC) issued Sundry 324-667 for a rig workover on KRU well 3M-19. The Sundry included two other conditions ofapproval. The second of these was "Biannual charted or recorded 1) MITT and MITIA or 2) CMITto verify integrity of the straddle over PC leak" (Testing Requirement). After the Sundry applicationwas submitted, CPAI deferred work on 3M-19 until March 2025, at which point CPAI noted the Testing Requirement. On March 25, 2025, CPAI filed a Request for Reconsideration of the two-year testing requirement in the conditions of approval. Specifically, CPAI requested that the Sundry Testing Condition (pressure test or caliper) for Well 3M-19 be modified to occur every8 years. Pursuant to AS 31.05.080, CPAI’s Request for Reconsideration is granted in order to allow the AOGCC to consider the merits of CPAI’s underlying reconsideration request tomodify the testing requirement. Upon reviewing CPAI’s Request for Reconsideration, however, the AOGCC determined that the submission lacked sufficient justification and supporting documentation to reach a decision. Given the broader implications of this matter, the AOGCC formally requestsunder 20 AAC 25.300 the following additional information to facilitate a thorough evaluation. Docket Number: OTH-25-016 Request for Information April 2, 2025 Page 2 of 3 Request for Additional Information Specific to Well KRU 3M-19 The AOGCC requests further information regarding 3M-19: 1.Well Log Analysis o A cross-sectional log identifying uncemented hydrocarbon-bearing and abnormally pressured zones behind the casing. o Any potential sources of overpressure, such as uncemented disposal zones, that could be contributing to casing failures. o Any potential flow units behind cemented and uncemented casing 2.Risk Assessment o An evaluation of the worst-case scenario if this well were to develop another production casing leak unknowingly with 12.7 ppge formation pressure. 3.Pore Pressure and Fracture Gradient Data o A pore pressure and fracture gradient (PPFG) curve for this area to assess fracture and potential casing integrity risks. 4.Root Cause Analysis o An evaluation of potential and most likely cause of production casing degradation in 3M-19. Request for Additional Information regarding Production Casing Leaks in Kuparuk The AOGCC is seeking further information regarding production casing leaks in this section of the Kuparuk River Unit (KRU). Specifically, the AOGCC requests the following: 5.List of Affected Wells o A comprehensive list of wells in this area of Kuparuk that have experienced production casing leaks including leak depths. 6.Root Cause Analysis and Historical Data o Reports detailing the likely causes of these leaks, including any historical data or past studies on similar occurrences in KRU. 7.Mitigation Measures o Information on CPAI’s strategies to prevent the recurrence of similar casing leaks. 8.Casing Integrity o Clarification on external vs. internal casing conditions contributing to the observed failures. Docket Number: OTH-25-016 Request for Information April 2, 2025 Page 3 of 3 9. Systemic Corrosion Concerns o Based on sundry requests and prior communication with CPAI, there appears to be a potential systemic issue with production casing corrosion at similar depths across KRU. o AOGCC would like to formally request further investigation and additional data to better understand the cause of this corrosion. Please submit this information to the AOGCC by close of business on May 4, 2025. Specify how/to whom info should be submitted. Should you have any questions about the information request, please contact Senior Petroleum Engineer Jack Lau at (907) 793-1244 or jack.lau@alaska.gov. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: J. Lau AOGCC Inspectors Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.02 13:31:50 -08'00' Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.04.02 14:01:39 -08'00' Originated: Delivered to:7-May-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1E-04 50-103-21852-00 910026680 Kuparuk River Leak Detect Log Field- Final 4-May-25 0 12 1E-11 50-029-20787-00 910026795 Kuparuk River Leak Detect Log Field- Final 3-May-25 0 13 1E-11 50-029-20787-00 910026795 Kuparuk River Plug Setting Record Field- Final 3-May-25 0 14 1E-36 50-029-22927-00 910026794 Kuparuk River Multi Finger Caliper Field & Processed 29-Apr-25 0 15 2F-12 50-029-21097-00 909990397 Kuparuk River Radial Bond Record Field- Final 16-Apr-25 0 16 3M-19 50-029-21737-00 909953646 Kuparuk River Leak Detect Log Field- Final 27-Apr-25 0 178910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40363T40364T40364T40365T40366T40367180-057182-051198-213184-043187-0645/8/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.05.08 10:12:05 -08'00'63M-1950-029-21737-00 909953646Kuparuk RiverLeakDetect LogField- Final27-Apr-2501187-064 ORIGINATED TRANSMITTAL DATE: 4/21/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5374 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 5374 3M-19 50029217370000 Tubing Cut Record 30-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Lorna.C.Collins@conocophillips.com 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 187-064 T40323 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:17:32 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 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: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8971'None Casing Collapse Conductor Surface Production 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: 907-263-4742 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 8333'3411'6109'6559' Packer: Baker FH Retrievable Packer: CAMCO HRP-1-SP SSSV: None Perforation Depth MD (ft): 8351' 6524'7" 6177-6196'TVD 6200-6213'TVD 6207-6208'TVD 6210-6211'TVD 6213-6213'TVD 6217-6249'TVD 8445-8471'MD 8476-8494'MD 8486-8487'MD 8490-8491'MD 8494-8495'MD 8500-8544'MD 9691'8923' 16" 9-5/8" 78'115' 4480'4341' 8272'MD/6052'TVD 8346'MD/6106'TVD MD 115' 2-7/8" 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025523 187-064 P.O. Box 100360, Anchorage, AK 99510 50-029-21737-00-00 KRU 3M-19 Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 4/7/2025 Current Pools: MPSP (psi):Plugs (MD): Kuparuk River Field ConocoPhillips Alaska, Inc Proposed Pools: PRESENT WELL CONDITION SUMMARY Length Size Elliott Tuttle elliott.tuttle@conocophillips.com TVD 6819'MD/5048'TVD 8316'MD/6084'TVD Perforation Depth TVD (ft): 3463' Burst CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 J-55 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: m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-221 By Gavin Gluyas at 1:35 pm, Apr 11, 2025 Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.04.11 13:27:07-08'00' Elliott Tuttle DSR-4/11/25A.Dewhurst 11APR25JJL 4/14/25 10-404 Jack Lau 4/7/25 Per 20 AAC 25.072, temporary shutdown of operations is granted for one year, provided that the well is either repaired or brought into compliance with suspension regulations within that period. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.14 16:43:29 -08'00'04/14/25 RBDMS JSB 041525 Well: 3M-19, Producer Operation Shutdown, Sundry 324-667 4/8/2025 1 P.O Box 100360 Anchorage, Alaska 99510-0360 April 11th, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 To whom it may concern, The original completion approved in sundry 324-667 was unable to be executed due to production casing condition and not being able to get a test packer to set near the planned depth of the lower production packer near 8240’ RKB. We moved to the alternate completion approved by email, 4/4/2025, utilizing an external casing patch latched onto the original tubing stub. Once the completion was landed, we were unable to test the integrity of the straddle, suggesting that either the external casing patch wasn’t fully landed or the tubing stub does not have integrity. With a lack of on rig options to remedy, we followed through with the steps to set the packer and test the rest of the completion. This request is to 8le an operation shutdown for Nabors 7ES due to casing integrity where we planned to straddle the known PC leaks. We are currently working through what the post rig repair will be and the repair will be 8led on a separate 10-403. Operations details are attached but a summary is below: Friday, 4/4/25 • RU E-line, run 40 arm caliper, tag bottom at 8,270’ • Log caliper F/8,270’ T/surface, RD E-line, (send data in for processing). • PU/Set RBP @ 1,045’ COE, test 1,000 psi • ND BOPE, grow and stretch casing 13.25”, set it in slips w/100k (total stretch 18.75”) installed new pack-oC, cut casing, installed new casing spool. NU BOP Saturday, 4/5/25 • Continued NU, tested void (good test) • MU Cleanout BHA, TIH on stands to 6815’, installed a closed TIW valve, TIH T/8,210’ 8lling DP, PT DP 2,500 psi for 5 mins. (good test) – veried that the DP was not a problem. • TOOH, laid out the TIW valve, TBIH, performed cleanout to stub, washed down T/8,276’, circulated high vis sweep, TOOH on stands. • MU AS1X test packer, TIH F/surface T/1,045’ COE, test 2,500 psi (good test), release packer. • Had failed tests around 6840’ then: Well: 3M-19, Producer Operation Shutdown, Sundry 324-667 4/8/2025 2 • PUH T/6,349’, obtain passing test for 5 min @ 2,500 psi – above packer. • TIH T/ 6849’ got a good test @ 2500psi for 5 minutes – above packer. Sunday, 4/6/25 • TIH, attempt to get passing test COE 8,190’, 8,240’, 8,250’ below packer. (all test failed to backside of DP) • Perform leak oC test @ 8240’, 1.0 bpm Hat line 2,000 psi. 1.5 bpm climbing above 2,500 psi, shut down pump. • TOOH sideways LD/DP, slip and cut drill line, LD test packer • Run 2-7/8” completion as per con8rmed tally w/Baker FH packer - Alternative completion • Park oC stub. circulate 8.6 ppg CI, RIH stack out on stub, PU to con8rm, PT 250 psi/5 min – failed @ 6spm Condition of well: The well is secured with a plug set at 8350’ RKB and has been veri8ed by a drawdown test. The entire RWO was performed on 8.6ppg Seawater without any inHux throughout the job. We have evaluated our options to repair the leaking External Casing Patch post rig, (or holes in the old tubing below the external casing patch) but more work is required to properly outline that work. Again, 10-403 will follow, requesting permission to repair. Elliott Tuttle Rig Workover Engineer Elliott.tuttle@conocophillips.com, 907-252-3347 CoP Drilling and Wells Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.04.11 13:27:41 -08'00' Elliott Tuttle Page 1/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/24/2025 16:00 3/24/2025 17:30 1.50 MIRU, MOVE MOB P MIRU on 3M-19. Pulled off 3M-22 at 1600 0.0 0.0 3/24/2025 17:30 3/24/2025 20:00 2.50 MIRU, MOVE MOB P Spot sub over 3M-19. Set mats. 0.0 0.0 3/24/2025 20:00 3/24/2025 20:30 0.50 MIRU, MOVE MOB P Spot in pits to sub. 0.0 0.0 3/24/2025 20:30 3/25/2025 00:00 3.50 MIRU, MOVE RURD P R/U berming, and shim pits and sub. Work on completing rig acceptance check list. 0.0 0.0 3/25/2025 00:00 3/25/2025 04:30 4.50 MIRU, MOVE RURD P Load pits with sea water, R/U lines in the cellar. Build deep clean swep. Rig acceptad @ 00:00 0.0 0.0 3/25/2025 04:30 3/25/2025 07:00 2.50 MIRU, MOVE CIRC P PJSM. Flood and pressure test lines. line up on tubing, and bleed pressure. Line up on IA and bleed pressure. Circulate 40 BBL deepclean pill followed by 357 BBL's 8.6# Seawater at 3BPM 600 PSI Blow down lines and secure tanks. Allow U-tube to relax. 0.0 0.0 3/25/2025 07:00 3/25/2025 07:30 0.50 MIRU, MOVE OWFF P OWFF for 30 minutes after U-tube stopped 0.0 0.0 3/25/2025 07:30 3/25/2025 08:30 1.00 MIRU, MOVE OTHR P Set BPV and test under BPV to 1000 PSI for 30 minutes. 0.0 0.0 3/25/2025 08:30 3/25/2025 09:30 1.00 MIRU, MOVE NUND P ND tree and adapter, FT LDS, function X-O in TBG HGR threads, install blanking plug over hanger neck 0.0 0.0 3/25/2025 09:30 3/25/2025 12:30 3.00 MIRU, MOVE NUND P NU BOP's torque up kill line, secure stack and install riser. Mark test joints at the floor. Flood lines and function test rams and annular shell test BOP's 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 2/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2025 12:30 3/25/2025 18:30 6.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular to 3500PSI on 2-7/8" and 3-1/2" test joint, UVBR's, LVBR's w/2-7/8" and 3-1/2" test joint. Test #1.) Blind Rams, CMV 1-2-3-16, RIg Floor Kill, Outer Test Spool Valve, IBOP, Test #2.) Blind Rams, CMV 4-5-6, HCR Kill, Inner Test Spool Valve, Manual IBOP (Open CMV 2, Inner Test Spool Valve, Rig Floor Kill, Upper IBOP), B/D TD Move test hose T/Cellar Test Spool Valve cia T manifold, Pickup 3.5" Donut Test Joint W/HT-38 TIW, Test #3.) LPR, HT-38 TIW, Test #4.) Annular (3,500 psi), CMV 7-8-9, Manual Kill, HT-38 Dart, (Open CMV 4-5 -6, HCR Kill, Outer Test Spool Valve), Test #5.) Hydraulic Super Choke and Manual Adjustable Choke (1,500 PSI Test), (Open CMV 7-9), Test #6.) UPR, CMV, 10-11, (8), Manual Kill, (Open Super and Manual Adjustable Choke) PU 2-7/8" Donut Test Joint w/3.5" EUE FOSV, Move Test Manifold T/Kill Line, Test #7.) LRP, 3.5" FOSV, Test #8.) Annular (3.500 psi), CMV 12-13-15 (8) , (Open CMV 10,11) ,Test #9.) UPR, CMV 14, (Open CMV 15), Test #10.) UPR, HCR Choke, (Open CMV 14), Test #11.) Manual Choke, (Open HCR Choke). Hydraulic Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =20 sec, Full recovery attained = 153 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sean Sullivan. 0.0 0.0 3/25/2025 18:30 3/25/2025 19:30 1.00 COMPZN, RPCOMP RURD P LD Test Tools, RD test joints, B/D test pump, choke and kill, pump out stack 0.0 0.0 3/25/2025 19:30 3/25/2025 20:00 0.50 COMPZN, RPCOMP MPSP P Pull blanking plug and BPV RU Haliburton Spooling Unit RU Rig power tongs 0.0 0.0 3/25/2025 20:00 3/25/2025 21:00 1.00 COMPZN, RPCOMP PULL P MU Landing joint to hanger ,set down 10k, BOLDS Pull hanger free 50k, continue to 100k no movement Work pipe x 7 50k to 100k, no movement 0.0 0.0 3/25/2025 21:00 3/25/2025 21:30 0.50 COMPZN, RPCOMP WAIT T Call out SL, RD SL off of 3T-pad and headed this way. Space out on rig floor w/90k in slips MU 3-1/2" EUE 8rd TIW valve ontop of landing joint. Confirm with rig crew, working height from rig floor. 0.0 0.0 3/25/2025 21:30 3/25/2025 22:00 0.50 COMPZN, RPCOMP SVRG P Rig Service 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 3/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2025 22:00 3/26/2025 00:00 2.00 COMPZN, RPCOMP RURD T HES SL on location, spot in unit, send hand to retrieve tools from wireline shop Load SL equipment onto beaver-later and bring to rig floor. 0.0 0.0 3/26/2025 00:00 3/26/2025 01:30 1.50 COMPZN, RPCOMP SLKL T Standby for tools, RU pumping sub and install 1502 cap MU/secure sheave into elevators Bring/MU HES tool string 39.3' w/hold open sleeve ID 1.79" 0.0 0.0 3/26/2025 01:30 3/26/2025 03:30 2.00 COMPZN, RPCOMP SLKL T Stab into tubing, zero at RF RIH w/HES SL T/1,759' set holding sleeve. TOOH, MU 1.75" drift, RIH F/surface, set down @ 8,295', work past continue IH T/8,320' set down, POOH LD/RD HES SL 0.0 0.0 3/26/2025 03:30 3/26/2025 04:30 1.00 COMPZN, RPCOMP SLKL T RD Slick Line and clear floor. 0.0 0.0 3/26/2025 04:30 3/26/2025 06:00 1.50 COMPZN, RPCOMP WAIT T Called out E-Line 0.0 0.0 3/26/2025 06:00 3/26/2025 08:00 2.00 COMPZN, RPCOMP HOSO T Land hanger in bowl RILDS LD landing joint PU pup joints and space out collar a the floor. BOLDS Pull 100K and slack off to 90K in slips, Remove 8' pup joint 0.0 0.0 3/26/2025 08:00 3/26/2025 08:30 0.50 COMPZN, RPCOMP ELNE T Spot in E-Line 0.0 0.0 3/26/2025 08:30 3/26/2025 09:00 0.50 COMPZN, RPCOMP SFTY T PJSM W/YJ E-Line Nabors and CPAI. Walk down job identify hazards and mitigations. 0.0 0.0 3/26/2025 09:00 3/26/2025 09:30 0.50 COMPZN, RPCOMP SVRG T Service draw works and rough neck. Dress power tongs F/2-7/8" 0.0 0.0 3/26/2025 09:30 3/26/2025 13:00 3.50 COMPZN, RPCOMP ELNE T Rebuild E-Line oil jars and build out string shot. 0.0 0.0 3/26/2025 13:00 3/26/2025 19:30 6.50 COMPZN, RPCOMP ELNE T RU E-Line RIH with String shot log main pass and repeat pass shift depth to correct to ORKB Saw slag from previous shot below original cut at 8286' POOH with E-Line C/O T.S. MU RCT 0.0 0.0 3/26/2025 19:30 3/26/2025 20:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 3/26/2025 20:00 3/27/2025 00:00 4.00 COMPZN, RPCOMP ELNE T Rebuild E-line oil jars again, replace pin connectors and insulators. Meg test tools all good, MU on rig floor, tools failed test. Confer with town team, decision was made to RIH without jars. RIH, adjust depth after correlation pass from previous log. Set down 8,303.5', work wire, confer with town team, decision POOH MU 7' spacer weight bar to space out anchors above previous pre-rig cut. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 4/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2025 00:00 3/27/2025 02:30 2.50 COMPZN, RPCOMP ELNE T RIH w/E=-line, w/o jars, w/7' spacer weight bar F/surface T/8,301' Detained unable to move, work wire F/455 lbs T/3,300 lbs, pull out of weak point, continue POOH :RD E-line Call out HES SL 0136 am. *** Note: TOF @ 8,280' Rope socket 1-7/16" (1.44"), with a 1" JIC fishing neck. 0.0 0.0 3/27/2025 02:30 3/27/2025 05:00 2.50 COMPZN, RPCOMP WAIT T Stand by for SL Service Rig Equipment Monthly Inspection of shakers 0.0 0.0 3/27/2025 05:00 3/27/2025 06:30 1.50 COMPZN, RPCOMP SLKL T RU HES slick line MU T.S. to fish E-Line T.S. 0.0 0.0 3/27/2025 06:30 3/27/2025 10:00 3.50 COMPZN, RPCOMP SLKL T POOH with E-Line T.S. 53' OAL. RIH W/GR confirm Iso sleeve still across SSSV. POOH and R/D slick line 0.0 0.0 3/27/2025 10:00 3/27/2025 10:30 0.50 COMPZN, RPCOMP SVRG T Service draw works rough neck and handling equipment 0.0 0.0 3/27/2025 10:30 3/27/2025 16:30 6.00 COMPZN, RPCOMP ELNE T Spot in and RU E-Line, mob equipment to floor, MU CCL and String shot. T.S.=1.69' x 28' RIH to SSSV at 1759' set down POOH centralized string shot RIH correlated main pass back to ORKB Made repeat pass. Fire String shot from 8247'-8257' POOH with T.S. LD tools MU RCT T.S. RIH 0.0 0.0 3/27/2025 16:30 3/27/2025 18:00 1.50 COMPZN, RPCOMP ELNE T Correlate main pass back to ORKB, make repeat pass confirm depth control. Attempt to set anchors, moving up hole, grab off depth, attempt to reset anchors, unsuccessful, POOH to inspect BHA, 0.0 0.0 3/27/2025 18:00 3/27/2025 19:00 1.00 COMPZN, RPCOMP ELNE T At surface, LD tools, anchors partilally open and inadvertently pulled SSSV hole open sleeve to surface. Break down tools remove hold open sleeve. Call out slick line tools to reset hold open sleeve on E-line. *** Note: Line up, circulate SXS to warm things up, 6 bpm/1,430 psi. Send out 30 bbls of dirty fluid to cuttings tank. 0.0 0.0 3/27/2025 19:00 3/28/2025 00:00 5.00 COMPZN, RPCOMP ELNE T Slickline tools on location, PJSM with E- line/SL crews MU GS, 2x 60 lb E-line weight bars, spangs, and hole open sleeve RIH w/SL tools on E-line wire. Set TOS @ 1,749' POOH, MU RCT cutter BHA, zero at rig floor RIH 0.0 0.0 3/28/2025 00:00 3/28/2025 01:45 1.75 COMPZN, RPCOMP ELNE T Continue RIH w/E-line 1-11/16" RCT Cutter, correlate for depth control Work to get anchors set, cut tubing @ 8,254', good indication at RF and E-line unit. work to get tool string free, POOH, LD and inspect tools, (good), Rack back E-line 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 5/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/28/2025 01:45 3/28/2025 02:30 0.75 COMPZN, RPCOMP PULL P Screw into landing joint, pull tubing free 80k RD E-line Unit RU RF for laying down tubing 0.0 0.0 3/28/2025 02:30 3/28/2025 12:45 10.25 COMPZN, RPCOMP PULL P Lay down 2-7/8" tubing F/8,254' ELMD T/surface Cut joint measured 18.97' clean cut *** Note: 251 jts of 2-7/8" laid down plus cut joint. 8,254.0 0.0 3/28/2025 12:45 3/28/2025 13:15 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 3/28/2025 13:15 3/28/2025 15:00 1.75 COMPZN, RPCOMP RURD P RU floor to Pick up DP. Set wear ring in tubing spool 0.0 0.0 3/28/2025 15:00 3/28/2025 16:30 1.50 COMPZN, RPCOMP BHAH P PU wash over dress off BHA. 0.0 245.7 3/28/2025 16:30 3/29/2025 00:00 7.50 COMPZN, RPCOMP PULD P RIH with DP to 7650'' 245.7 7,650.0 3/29/2025 00:00 3/29/2025 00:45 0.75 COMPZN, RPCOMP TRIP P RIH with DP to 7,650'' wash over stump to 8,191', PUW=165k, SOW=91k Rot.=15 RPM, 7,000 ft/lbs torque TIH slowly F/8,188' T/8,200' PUW=130k, SOW=100k PUH F/8,200' T/8,188' Bring pump online, slightly plugged off, 2,000 psi, broke back to 950 psi. *** Note: Total sand recovered on cirulation (3 yards of sand/debris) 7,650.0 8,191.0 3/29/2025 00:45 3/29/2025 02:00 1.25 COMPZN, RPCOMP WASH P Stop Rotating Circulate BU 5 BPM, 950 psi Continue to wash F/8,188' T/8,246' 7ES RKB 8,191.0 8,200.0 3/29/2025 02:00 3/29/2025 04:00 2.00 COMPZN, RPCOMP WASH P Unable to get over stub Rot=20,40, and 60 RPM, Free TQ=6,300-7,000 ft/lbs TIH to top of stub, Attempt to burn over stub Rot=60 RPM, TQ=7,000 ft/lbs 8,200.0 8,200.0 3/29/2025 04:00 3/29/2025 05:30 1.50 COMPZN, RPCOMP CIRC P Circ hi vis sweep SxS 6 BPM at 1200 PSI Blow down top drive and surface lines. 8,200.0 8,200.0 3/29/2025 05:30 3/29/2025 08:30 3.00 COMPZN, RPCOMP TRIP P TOOH F/8200' T/245.7 8,200.0 245.7 3/29/2025 08:30 3/29/2025 09:30 1.00 COMPZN, RPCOMP BHAH P LD BHA inpspect shoe. Shoe vertically cracked in water course approx 4" face chunked out 2 sections. Shoe flaired out to 6-3/16 from 6-1/8" 245.7 0.0 3/29/2025 09:30 3/29/2025 13:00 3.50 COMPZN, RPCOMP BHAH P MU overshot with control mill BHA 0.0 220.6 3/29/2025 13:00 3/29/2025 15:00 2.00 COMPZN, RPCOMP TRIP P TIH W/ BHA F/220.56' to top of fish at 8232.34'. PU off, space out W/5' pup. PUW=163K SOW=100K 0... 220.6 8,232.3 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 6/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/29/2025 15:00 3/29/2025 18:00 3.00 COMPZN, RPCOMP FISH P Engage top of fish at 8232.34 swallow fish to 8234.3' set down 10K Pull up to 180K, 20K over. Slack off Bleed off jars.at 165K worked up to 180K jars opened Straight pulled to 185K tubing stated moving. RIH tagged at 8231' PUW fluctuating 165K-168K 2-5K over pull. 8,323.3 8,231.0 3/29/2025 18:00 3/29/2025 18:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 15 minutes. Lay down Pup 8,231.0 8,227.0 3/29/2025 18:30 3/29/2025 22:30 4.00 COMPZN, RPCOMP TRIP P TOOH W/BHA. and fish F8227' PUW=165K-168K 8,227.0 221.0 3/29/2025 22:30 3/29/2025 23:00 0.50 COMPZN, RPCOMP BHAH P LD BHA, Stand back collars Shoe at surface NO FISH 221.0 0.0 3/29/2025 23:00 3/29/2025 23:30 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 3/29/2025 23:30 3/30/2025 00:00 0.50 COMPZN, RPCOMP BHAH P MU fishing BHA #3 XO - HT38 x 3-1/2" IF, 4-3/4" Accelerator, 4-3/4" drill collars x 6, 4- 3/4" Jar, 4-3/4" LBS, 5-3/4" overshot (Bowen). *** Note: 2-7/8" Nom. Catch Grapple, 2- 7/8" Mill Control 0.0 223.0 3/30/2025 00:00 3/30/2025 00:30 0.50 COMPZN, RPCOMP BHAH P Continue to MU fishing BHA #3 XO - HT38 x 3-1/2" IF, 4-3/4" Accelerator, 4-3/4" drill collars x 6, 4- 3/4" Jar, 4-3/4" LBS, 5-3/4" overshot (Bowen). *** Note: 2-7/8" Nom. Catch Grapple, 2- 7/8" Mill Control 223.0 223.0 3/30/2025 00:30 3/30/2025 04:30 4.00 COMPZN, RPCOMP TRIP P TIH on stands F/surface T/8,167' 223.0 8,167.0 3/30/2025 04:30 3/30/2025 06:30 2.00 COMPZN, RPCOMP FISH P Obtain paramerters PUW=160, SOW=100, ROTW=125k Rot=20 RPM, 6.6k Torque Begin to wash down F/8,167' T/8,131' Engage fish T/8,133.75' fully swallowed (4.5' swallow) PU bleed jars straight pull to 30K over, no movement. Space out set 16K in slips. 8,167.0 8,233.8 3/30/2025 06:30 3/30/2025 12:00 5.50 COMPZN, RPCOMP ELNE P RU Eline RIH W/ string shot. set down at 8254' ELMD. (Top of cut) Unable to pass. POOH Add centralizer to T.S. RIH W/String shot to 8254' ELMD Uanble to pass. POOH W/E-Line RD E-Line 8,233.8 8,233.8 3/30/2025 12:00 3/30/2025 14:30 2.50 COMPZN, RPCOMP TRIP P Release overshot and TOOH F/8133' T/223' 8,233.8 223.0 3/30/2025 14:30 3/30/2025 16:00 1.50 COMPZN, RPCOMP BHAH P LD BHA #3, Inspected cut lip shoe. Slight gouge in shoe at leading edge of cut lip guide. MU BHA #4. 223.0 216.0 3/30/2025 16:00 3/30/2025 16:30 0.50 COMPZN, RPCOMP SVRG P Service hydraulic system in cellar. replaced hose for bridge crane. 216.0 216.0 3/30/2025 16:30 3/30/2025 19:30 3.00 COMPZN, RPCOMP TRIP P TIH W/dressoff BHA F/215.95 T/ stump at 8232' PUW=160K SOW=103K 216.0 8,232.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 7/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/30/2025 19:30 3/30/2025 20:30 1.00 COMPZN, RPCOMP MILL P Establish milling parmeters 60 RPM ROT WTt=125K 3 BPM 500 PSI On Free tq=7200 Ft/Lbs engage top of fish at 8230' Torque at 7700 WOB=1.5K-2K 8,232.0 8,236.0 3/30/2025 20:30 3/30/2025 22:00 1.50 COMPZN, RPCOMP CIRC P Circulate sweep with SW 8,236.0 8,236.0 3/30/2025 22:00 3/31/2025 00:00 2.00 COMPZN, RPCOMP TRIP P Observe well for flow TOOH, F/8,236' T/6,149' 8,236.0 6,149.0 3/31/2025 00:00 3/31/2025 02:00 2.00 COMPZN, RPCOMP TRIP P Continue TOOH F/6,149', T/BHA 6,149.0 215.0 3/31/2025 02:00 3/31/2025 03:30 1.50 COMPZN, RPCOMP BHAH P Stand back collars, LD dress off BHA #4, MU fishing BHA #5 215.0 0.0 3/31/2025 03:30 3/31/2025 07:00 3.50 COMPZN, RPCOMP TRIP P TIH w/fishing BHA #5 F/surface T/7,950'. 0.0 7,950.0 3/31/2025 07:00 3/31/2025 08:30 1.50 COMPZN, RPCOMP SVRG P Slip and cut drill line. (105') 7,950.0 7,950.0 3/31/2025 08:30 3/31/2025 10:00 1.50 COMPZN, RPCOMP TRIP P Engage fish. Place DP in tension with 25k in slips. 7,950.0 8,231.0 3/31/2025 10:00 3/31/2025 12:00 2.00 COMPZN, RPCOMP ELNE P RU E-line PU and load into cellar MU and test 8,231.0 8,231.0 3/31/2025 12:00 3/31/2025 14:30 2.50 COMPZN, RPCOMP ELNE P RIH w/1.69" RCT cutter // Unable to pass 8036' WLM w/ cutter, pull out of hole to loosen bow spring tension // 8,231.0 8,231.0 3/31/2025 14:30 3/31/2025 16:30 2.00 COMPZN, RPCOMP ELNE P Re-configure bow springs, RIH w/1.69" RCT cutter // Unable to pass top of fish w/ cutter, attempt multiple times 8,231.0 8,231.0 3/31/2025 16:30 3/31/2025 18:30 2.00 COMPZN, RPCOMP ELNE P EIH w/ 1-11/16" drift to attempt get past top of fish, unable to pass 8245' multiple attempts 8,231.0 8,231.0 3/31/2025 18:30 3/31/2025 20:30 2.00 COMPZN, RPCOMP ELNE P Pull out of hole with e-line, rig down e- line 8,231.0 8,231.0 3/31/2025 20:30 3/31/2025 22:00 1.50 COMPZN, RPCOMP SLKL P Spot in and rig up slick line truck 8,231.0 8,231.0 3/31/2025 22:00 4/1/2025 00:00 2.00 COMPZN, RPCOMP SLKL P RIH w/ 2" bailer, make it to 8247' start out of hole 8,231.0 8,231.0 4/1/2025 00:00 4/1/2025 01:45 1.75 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' x 2" PUMP BAILER (msfb), SD @ 8,248' SLM, WORK BAILER FOR 20 MIN, POOH, OOH W/ ~1/4 GAL FINE SAND, SMALL METAL CHUNCKS, ROPE SOCKET PIG TAILED, RE-TIE ROPE SOCKET 8,231.0 8,231.0 4/1/2025 01:45 4/1/2025 04:15 2.50 COMPZN, RPCOMP SLKL P Re-configure to 2" pump bailer w/flapper, run in hole 0.25 gal of debris recovered 8,231.0 8,231.0 4/1/2025 04:15 4/1/2025 05:45 1.50 COMPZN, RPCOMP SLKL P RIH W/ 10' x 1.75" PUMP BAILER (msfb), CHANGE OUT w/ COLLINS AND CREW, SD @ 8252' SLM, WORK BAILER SEVERAL TIMES, UNABLE TO SEE BAILER 8,231.0 8,231.0 4/1/2025 05:45 4/1/2025 07:15 1.50 COMPZN, RPCOMP SLKL P RIH w/ QC, 10' X 2" PUMP BAILER, MSFB, TOOLS FALL FREELY, S/D @ 8252' SLM, WORK BAILER DOWN TO 8255' SLM, POOH, OOH w/ ~ .75 GAL OF SAND, SPANGS LOCKED UP. 8,231.0 8,231.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 8/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2025 07:15 4/1/2025 08:45 1.50 COMPZN, RPCOMP SLKL P RIH w/ QC, 10' X 1.75" PUMP BAILER, MSFB, TOOLS FALL FREELY, S/D @ 8255' SLM, WORK BAILER DONW TO 8257' SLM, POOH, OOH w/ ~ .75 GAL OF SAND 8,231.0 8,231.0 4/1/2025 08:45 4/1/2025 10:30 1.75 COMPZN, RPCOMP SLKL P RIH w/ QC, 10' X 2" PUMP BAILER, MSFB, S/D @ 8256' SLM, WORK BAILER DOWN TO 8258' SLM, POOH, OOH w/ ~ .75 GAL OF SAND, ROPE SOCKET PIG TAILED, RE-TIE ROPE SOCKET, 8,231.0 8,231.0 4/1/2025 10:30 4/1/2025 12:30 2.00 COMPZN, RPCOMP SLKL P RIH w/ QC, 10' X 2" PUMP BAILER, MSFB, S/D @ 8258' SLM, WORK BAILER TO 8260' SLM, POOH, OOH w/ ~ 1.5 GAL OF SAND 8,231.0 8,231.0 4/1/2025 12:30 4/1/2025 13:30 1.00 COMPZN, RPCOMP SLKL P CHANGE OUT CREW RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8259' SLM, WORK BAILER TO 8262' SLM, POOH (RECOVER 1.5 GAL SAND) 8,231.0 8,231.0 4/1/2025 13:30 4/1/2025 14:30 1.00 COMPZN, RPCOMP SLKL P RIH W/ QC, 3' X 1.5'' STEM, 2.30'' G- RING (OAL= 48'') S/D ON NIPPLE @ 8019' SLM / 8019' RKB, POOH 8,231.0 8,231.0 4/1/2025 14:30 4/1/2025 16:00 1.50 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8262' SLM, WORK BAILER TO 8264' SLM, POOH (RECOVER 1.5 GAL SAND) 8,231.0 8,231.0 4/1/2025 16:00 4/1/2025 19:00 3.00 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8264' SLM, WORK BAILER TO 8266' SLM, POOH (RECOVER 1.0 GAL SAND) 8,231.0 8,231.0 4/1/2025 19:00 4/1/2025 21:00 2.00 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8264' SLM, Tagged 2' high. WORK BAILER TO 8266' SLM, POOH (RECOVER 1.0 GAL SAND) 8,231.0 8,231.0 4/1/2025 21:00 4/1/2025 22:45 1.75 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8264' SLM, Tagged 2' high. WORK BAILER TO 8266' SLM, POOH (RECOVER 1.0 GAL SAND) 8,231.0 8,231.0 4/1/2025 22:45 4/2/2025 00:00 1.25 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8266' SLM, WORK BAILER TO 8268' SLM, POOH (RECOVER 1.0 GAL SAND) 8,231.0 8,231.0 4/2/2025 00:00 4/2/2025 01:00 1.00 COMPZN, RPCOMP SLKL P Continue with RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8266' SLM, WORK BAILER TO 8268' SLM, POOH (RECOVER 1.0 GAL SAND) 8,231.0 8,231.0 4/2/2025 01:00 4/2/2025 02:30 1.50 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8265' SLM, WORK BAILER TO 8270' SLM, POOH (RECOVER 1.0 GAL SAND) 8,231.0 8,231.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 9/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/2/2025 02:30 4/2/2025 04:30 2.00 COMPZN, RPCOMP SLKL P RIH W/ QC, 10' X 2.0'' PUMP BAILER, MSFB S/D @ 8269' SLM, WORK BAILER TO 8273' SLM, POOH (RECOVER 1.0 GAL SAND) *** Note: 0.35 bbls of sand recoveded during SL operations. RD SL to RU E-line 8,231.0 8,231.0 4/2/2025 04:30 4/2/2025 06:00 1.50 COMPZN, RPCOMP ELNE P E-line on location Spot in and RU 8,231.0 8,231.0 4/2/2025 06:00 4/2/2025 08:30 2.50 COMPZN, RPCOMP ELNE P E-line, RIH w/CCL-Drift BHA Set down @ 8,267' Correlate logs 8,231.0 8,231.0 4/2/2025 08:30 4/2/2025 10:30 2.00 COMPZN, RPCOMP ELNE P MU RCT cutter RIH, corratate depth BTM GLM 8,253' RCT Cut @ 8,266' POOH, LD Tools 8,231.0 8,231.0 4/2/2025 10:30 4/2/2025 11:30 1.00 COMPZN, RPCOMP TRIP P RU to pull on fish, PUW=160k, SOW=102 Fish moving up hole. Park @ 8,224' 8,231.0 8,224.0 4/2/2025 11:30 4/2/2025 13:00 1.50 COMPZN, RPCOMP CIRC P Circulate BU, 5 bpm/700 psi 8,224.0 8,224.0 4/2/2025 13:00 4/2/2025 16:00 3.00 COMPZN, RPCOMP TRIP P TOOH, racking back 3.5" DP stands F/8,224' T/BHA 8,224.0 216.0 4/2/2025 16:00 4/2/2025 16:30 0.50 COMPZN, RPCOMP BHAH P LD BHA and fish OAL=30.66' // 8.40' joint below GLM 216.0 0.0 4/2/2025 16:30 4/2/2025 17:00 0.50 COMPZN, WELLPR SVRG P Changeout Saber Sub and PT to 250/4000 psi for 5 min and charted. 0.0 0.0 4/2/2025 17:00 4/2/2025 17:30 0.50 COMPZN, WELLPR BOPE P Weekly function test BOPE. 0.0 0.0 4/2/2025 17:30 4/2/2025 19:00 1.50 COMPZN, WELLPR BHAH P MU CO/Dress off BHA #6 0.0 248.4 4/2/2025 19:00 4/2/2025 22:30 3.50 COMPZN, WELLPR TRIP P TIH on DP stands F/248' T/8255' 248.4 8,255.0 4/2/2025 22:30 4/2/2025 23:00 0.50 COMPZN, WELLPR DISP P Circulate well to 45 Vis for hole cleaning. 8,255.0 8,255.0 4/2/2025 23:00 4/2/2025 23:30 0.50 COMPZN, WELLPR PRTS P Attempt to PT CSG to 2500 psi. Pumping 1BPM it broke over at 2425 psi. Pumped 5 bbls total. 8,255.0 8,255.0 4/2/2025 23:30 4/3/2025 00:00 0.50 COMPZN, WELLPR REAM P Dress off tubing stub. PUW 175K/SOW 95K/RWT 125K 70 RPM, 9K TQ off bottom, 2.5 BPM at 350 psi Ream down T/8261' and observe 200 psi increase. Continue reaming down to 8270.5' and tag TOF with mill 2K. 8,255.0 8,270.5 4/3/2025 00:00 4/3/2025 03:00 3.00 COMPZN, WELLPR MILL P Mill off 7.5' tubing stub to get past pre- rig cut. PUW 175K/SOW 95K/RWT 125K 70 RPM, 9K TQ off bottom, 2.5 BPM at 350 psi Mill down F/8,270.5 T/8,276'. 8,270.5 8,276.0 4/3/2025 03:00 4/3/2025 04:30 1.50 COMPZN, WELLPR CIRC P Pump a 40 bbl high vis sweep 8,276.0 8,276.0 4/3/2025 04:30 4/3/2025 06:30 2.00 COMPZN, WELLPR MILL P Mill F/8,276' T/8,279' w/5k down weight 8,276.0 8,279.0 4/3/2025 06:30 4/3/2025 07:00 0.50 COMPZN, WELLPR TRIP P Dry drift clean, confirm depth 8,279' PUW=150k, SOW=120k 8,279.0 8,279.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 10/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/3/2025 07:00 4/3/2025 10:30 3.50 COMPZN, WELLPR TRIP P TOOH, dress packer setting area F/6,964' T/6775 8,279.0 248.4 4/3/2025 10:30 4/3/2025 11:30 1.00 COMPZN, WELLPR BHAH P LD dress off BHA, 20+ lbs of metal recovered from barrel and boot backets. Good wear on packer mill. indication good dress off. 248.4 0.0 4/3/2025 11:30 4/3/2025 12:00 0.50 COMPZN, WELLPR BHAH P MU Packer BHA #7 3-1/2" IF Pup Jt, 3-1/2" IF x 2-7/8" EUE 7" AS1X Test Packer *** Note: COE 5' from bottom. 0.0 13.4 4/3/2025 12:00 4/3/2025 15:30 3.50 COMPZN, WELLPR TRIP P TIH w/Test Packer UWT 163K/SOW 95K 13.4 8,200.0 4/3/2025 15:30 4/3/2025 20:30 5.00 COMPZN, WELLPR MPSP P Set AS1X packer as per rep COE @ 8205' MU Head pin fluid pack surface lines. Test Production Casing below test packer. Failed test. Set AS1X packer as per rep COE @ 8195'. Test Production Casing below test packer. Failed test. Set AS1X packer as per rep COE @ 8170'. Test Production Casing below test packer. Failed test. 8,200.0 8,170.0 4/3/2025 20:30 4/3/2025 22:00 1.50 COMPZN, WELLPR CIRC P Pump 35 BBL HI VIS sweep SxS at 3 BPM/500PSI. 8,170.0 8,170.0 4/3/2025 22:00 4/3/2025 23:00 1.00 COMPZN, WELLPR TRIP P POOH F/8170' T/6815' PUW 160K @8170' PUW 142K @ 6815' 8,170.0 6,815.0 4/3/2025 23:00 4/4/2025 00:00 1.00 COMPZN, WELLPR MPSP P Set AS1X packer as per rep COE @ 6815'. Test Production Casing from surface to test packer. Good test. 6,815.0 6,815.0 4/4/2025 00:00 4/4/2025 01:00 1.00 COMPZN, WELLPR MPSP P Set AS1X packer as per rep COE @ 6850'. Test Production Casing from surface to test packer. Good test. 6,815.0 6,815.0 4/4/2025 01:00 4/4/2025 03:00 2.00 COMPZN, WELLPR TRIP P TIH F/6815' T/8257'. 6,815.0 8,257.0 4/4/2025 03:00 4/4/2025 04:00 1.00 COMPZN, WELLPR MPSP P Set AS1X packer as per Yellow Jacket fishing rep COE @ 8262'. Test Production Casing below test packer. Failed Test 8,257.0 8,257.0 4/4/2025 04:00 4/4/2025 07:15 3.25 COMPZN, WELLPR TRIP P TOOH 8,257.0 13.4 4/4/2025 07:15 4/4/2025 07:45 0.50 COMPZN, WELLPR BHAH P LD and inspect BHA Lot of metal on Packer Gouge and marks on elements 13.4 0.0 4/4/2025 07:45 4/4/2025 09:15 1.50 COMPZN, WELLPR ELNE P AK E-line Services on location Spot in and RU MU Reed Cased Hole 40 arm caliper and test function. (good) 0.0 0.0 4/4/2025 09:15 4/4/2025 14:00 4.75 COMPZN, WELLPR ELNE P RIH with E-line 40 arm caliper Tag top of stub @ 8,270' 7ES RKB Log w/caliper OOH, process data RD E-line. 0.0 0.0 4/4/2025 14:00 4/4/2025 14:30 0.50 COMPZN, WELLPR TRIP P MU RBP on DP TIH set RBP @ 1045' COE 0.0 1,045.0 4/4/2025 14:30 4/4/2025 15:00 0.50 COMPZN, WELLPR TRIP P TOOH, racking back DP, LD Setting tools 1,045.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 11/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/4/2025 15:00 4/4/2025 15:30 0.50 COMPZN, WELLPR BHAH P PT RBP against blind rams to 1000 psi for 5 min. Good test. 0.0 0.0 4/4/2025 15:30 4/5/2025 00:00 8.50 COMPZN, WELLPR NUND P ND BOP, RU Cameron equipment and grow CSG, remove tubing spool, spear casing, stretch with 100K and set in slips. Release spear, total grow and stretch 18.75", install new packoff and cut casing with WACHS cutter. Install new tubing spool. 0.0 0.0 4/5/2025 00:00 4/5/2025 04:00 4.00 COMPZN, WELLPR NUND P Install wellhead and PT void, install test plug. NU BOP and install riser. 0.0 0.0 4/5/2025 04:00 4/5/2025 06:30 2.50 COMPZN, WELLPR BHAH P MU Cleanout BHA #10 XO HT38-3-1/2" IF, 4-3/4" Accelerator, 4 -3/4" DC x 6, 4-3/4" fishing jars, 4-3/4" bumper sub, 3-1/2" x 31/2" Red Bit sub, 5" boot basket x 2, 3-1/2" x Reg x 3-1/2" x 3-1/2" IF PXP, 6.125" SOD String Mills x 2, 3-1/2" x 5-3/4" KHT CFB, 5-3/4"x2- 7/8" dress off shoe. 0.0 247.7 4/5/2025 06:30 4/5/2025 10:30 4.00 COMPZN, WELLPR TRIP P TIH, with cleanout BHA Stand #72 install closed TIW valve Continue TIH, filling every 3 stands in hole 247.7 8,210.0 4/5/2025 10:30 4/5/2025 11:00 0.50 COMPZN, WELLPR PRTS P RU Head pin to top of string PT DP 2,500 psi for 5 mins charted (good test) Bleed pressure off. 8,210.0 8,268.0 4/5/2025 11:00 4/5/2025 11:30 0.50 COMPZN, WELLPR TRIP P TOOH F/8,100' racking back stands. Pull out TIW 8,210.0 7,058.0 4/5/2025 11:30 4/5/2025 12:00 0.50 COMPZN, WELLPR TRIP P TBIH F/7,058' T/8,269' PUW=163k, SOW=95k 7,058.0 8,269.0 4/5/2025 12:00 4/5/2025 12:30 0.50 COMPZN, WELLPR TRIP P Obtain parameters 60 RPM, 7.4k TQ, RWT=125k, 3 bpm, 360 psi, tag stump at 8,268', ream down T/8,276' at 20 fpm, WOB 1.3k TQ 7.8k, wash away fill, sand returned at surface. PUW=163k, SOW=95k 8,269.0 8,276.0 4/5/2025 12:30 4/5/2025 14:00 1.50 COMPZN, WELLPR CIRC P Circulate high vis sweep 5 bpm/2,700 psi 8,276.0 8,276.0 4/5/2025 14:00 4/5/2025 16:30 2.50 COMPZN, WELLPR TRIP P TOOH, racking back DP 8,276.0 247.8 4/5/2025 16:30 4/5/2025 17:30 1.00 COMPZN, WELLPR BHAH P LD cleanout BHA 10 247.8 0.0 4/5/2025 17:30 4/5/2025 18:00 0.50 COMPZN, WELLPR BHAH P MU Test packer BHA #11 XO HT38 x 3-1/2" IF, 3-1/2" IF pup joint, 3-1/2" x 2-7/8" EUE, 7" AS1X Test Packer 0.0 14.4 4/5/2025 18:00 4/5/2025 18:30 0.50 COMPZN, WELLPR MPSP P TIH w/AS1X Test packer PT IA to 2500 psi for 5 minutes from test packer COE at 1040' up to BOP rams. Good test. 14.4 1,045.0 4/5/2025 18:30 4/5/2025 20:30 2.00 COMPZN, WELLPR MPSP P TIH to 6850' PT to 2500 psi for 5 minutes from test packer COE at 6850', 6845' and 6840' up to BOP rams. Failed tests. 1,045.0 6,850.0 4/5/2025 20:30 4/5/2025 23:00 2.50 COMPZN, WELLPR MPSP P POOH to 6349'. PT IA to 2500 psi for 5 minutes from test packer COE at 6349' up to BOP rams. Good test. 6,850.0 6,349.0 4/5/2025 23:00 4/6/2025 00:00 1.00 COMPZN, WELLPR MPSP P RIH to 6849'. PT IA to 2500 psi for 5 minutes from test packer COE at 6849' up to BOP rams. Good test. 6,349.0 6,849.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 12/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2025 00:00 4/6/2025 03:00 3.00 COMPZN, WELLPR MPSP P RIH to 8250'. PT IA to 2500 psi for 5 minutes from test packer COE at 8190', 8240' and 8250' down to packer. Failed everytime. 6,849.0 8,250.0 4/6/2025 03:00 4/6/2025 04:30 1.50 COMPZN, WELLPR MPSP P Leak off rate on bottom. Pumping 0.5 BPM pressure flatlines at 1850 psi. Pumping 1.0 BPM pressure flatlines at 2000 psi. Pumping 1.5 BPM pressures climbing above 2500 psi so stopped test. 8,250.0 8,250.0 4/6/2025 04:30 4/6/2025 12:00 7.50 COMPZN, WELLPR PULD P POOH LD DP sideways. Slip and cut 68' DL 8,250.0 13.4 4/6/2025 12:00 4/6/2025 13:00 1.00 COMPZN, WELLPR BHAH P LD Test Packer BHA Load out of pipe shed 13.4 0.0 4/6/2025 13:00 4/6/2025 14:00 1.00 COMPZN, WELLPR BHAH P Load all completion equipment, & verify running order. Count pipe RU RF for tubing operations 0.0 0.0 4/6/2025 14:00 4/6/2025 14:30 0.50 COMPZN, WELLPR SFTY P PJSM w/crew 0.0 0.0 4/6/2025 14:30 4/7/2025 00:00 9.50 COMPZN, RPCOMP PUTB P Run 2-7/8" L-80 6.5# EUEM 8rd completion as per confirmed tally to 8069' Apply Jet Lube Run-N-Seal and TQ to 2250 FT/LBS. PUW 75K/ SOW 55K 0.0 8,069.0 4/7/2025 00:00 4/7/2025 01:00 1.00 COMPZN, RPCOMP PUTB P Run 2-7/8" L-80 6.5# EUEM 8rd completion as per confirmed tally F/ 8069' T/8256' Apply Jet Lube Run-N-Seal and TQ to 2250 FT/LBS. 75K PUW/ 55K SOW 8,069.0 8,256.0 4/7/2025 01:00 4/7/2025 03:00 2.00 COMPZN, RPCOMP CIRC P Pump 290 BBLS CI seawater down tubing at 3 BPM/400 PSI. 8,256.0 8,256.0 4/7/2025 03:00 4/7/2025 04:30 1.50 COMPZN, RPCOMP PUTB P TIH, start swallow 8,265' set down 25k T/8,269', Confirm latch, pull in tention 22k, Unable to catch pressure Work grapple 22kup 25k down, throw some torque into it. continue to work pipe, unable to get a test, confer with town team 8,256.0 8,269.0 4/7/2025 04:30 4/7/2025 07:30 3.00 COMPZN, RPCOMP WAIT T Standby for plan forward 8,269.0 8,269.0 4/7/2025 07:30 4/7/2025 10:00 2.50 COMPZN, RPCOMP PUTB P Continue moving forward, Drop ball and rod, pressure up to set 2- 7/8" x 7" FH packer, 1,000 psi 5 min, brought pressure up to 2,600 psi 5 mins, PUW=80k 5k over pickup shear out PBR, fully locate Mark pipe 5' in on joint # 259, Space out (6.17" pup), 1.91' off fully located. MU landing joint, and land hanger, RILDS 8,269.0 8,269.0 4/7/2025 10:00 4/7/2025 11:00 1.00 COMPZN, RPCOMP PRTS P Pressure test tubing 3,000 psi/30 mins, charted (good test) Bleed pressure to 1,500 psi and hold pressure, test IA to 2,500 psi/30 mins, charted (good test), Dump tubing to shear SOV, circulate 3.0 bpm down the IA, good shear. 0.0 0.0 4/7/2025 11:00 4/7/2025 11:30 0.50 COMPZN, RPCOMP MPSP P Set BPV w/T-bar, test from below 1,000 psi for 10 mins (good test) 0.0 0.0 4/7/2025 11:30 4/7/2025 12:00 0.50 COMPZN, RPCOMP WASH P Jet BOPE 10 bpm, suck out stack 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Page 13/13 3M-19 Report Printed: 4/11/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/7/2025 12:00 4/7/2025 13:00 1.00 COMPZN, RPCOMP WAIT T Standby for confirmation of plan forward. 0.0 0.0 4/7/2025 13:00 4/7/2025 14:00 1.00 COMPZN, RPCOMP NUND P ND BOP, well head, pull riser, break bolts, rack back stack on pedestal secure, remove DSA 0.0 0.0 4/7/2025 14:00 4/7/2025 16:30 2.50 COMPZN, RPCOMP NUND P NU new 2-9/16" tree. Spot LRS. Test adapter to 5000 psi. Pull BPV. 0.0 0.0 4/7/2025 16:30 4/7/2025 22:30 6.00 DEMOB, MOVE NUND P Move office and pits to 3A pad. 0.0 0.0 4/7/2025 22:30 4/8/2025 00:00 1.50 DEMOB, MOVE FRZP P Freeze protect tubing and IA to 2000' with 80 bbls diesel 2BPM @ 375psi and let U-tube. Final pressures T/IA/OA 0/0/0 Rig release at midnight. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/8/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,477.0 3M-19 4/12/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut 3M-19 12/22/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Lost ~ 2.25" piece of JD Dog below 5873'. DID NOT RECOVER 3/20/2011 lmosbor NOTE: STRIPPED F/N OFF LATCH ON GLV@ 6364' 3/20/2011 lehallf NOTE: CTU FOUND CORKSCREWED TUBING FROM 7800' to 8333' 8/12/2006 WV5.3 Conversio n NOTE: WAIVERED WELL: IA x OA COMMUNICATION 12/22/2002 WV5.3 Conversio n NOTE: FISHNECK ON GLV LATCH @ 6364' IS STRIPPED 7/20/2002 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 38.0 115.0 115.0 62.50 H-40 SURFACE 9 5/8 8.83 37.0 4,479.7 3,463.1 36.00 J-55 BTC PRODUCTION 7 6.28 34.0 8,923.3 6,524.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.0 Set Depth … 8,271.5 String Max No… 2 7/8 Set Depth … 6,052.2 Tubing Description Tubing – Production Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-M ID (in) 2.44 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) 34.0 34.0 0.07 Hanger 7.000 FMC Gen IV Tubing Hanger, 2 7/8" FMC Gen 4 2.340 3,270.9 2,650.6 47.12 Mandrel – GAS LIFT 5.424 2-7/8" x 1-1/2" MMG SN 25343-02 DV SN 25343-04 SLB MMG 2.366 6,737.2 4,992.7 47.15 Mandrel – GAS LIFT 5.424 2-7/8" x 1-1/2" MMG SN 25343-01 SOV 2000psi SN 25343-05 SLB MMG 2.366 6,795.3 5,032.0 47.58 PBR 5.860 2-7/8" Baker PBR 80-32 Baker 80-32 2.380 6,818.8 5,047.9 47.66 Packer 5.960 2-7/8" x 7" Baker FH Retrievable Packer (~6815' above leak in CSG) Baker FH 2.420 8,248.6 6,035.8 44.13 Nipple - X 3.699 2-7/8" X Nipple 2.313" w/RHC SN APF23G0264-66 Halliburt on 2.313" X 2.313 8,265.9 6,048.2 44.13 Overshot 5.740 2 7/8" TBG Patch (swallow 3.53') Baker Sealing 2.441 Top (ftKB) 8,268.0 Set Depth … 8,346.1 String Max No… 2 7/8 Set Depth … 6,105.8 Tubing Description Tubing – Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection 8rd AB MOD ID (in) 2.44 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) 8,298.2 6,071.4 44.13 PBR 5.000 2 7/8" CAMCO 'OEJ' Camco OEJ 2.313 8,315.7 6,084.0 44.05 PACKER 6.151 2 7/8" x 7" CAMCO HRP-1-SP Pkr Camco HRP-1- SP 2.347 8,333.6 6,096.8 43.96 NIPPLE 3.668 2 7/8" CAMCO 'D' Nipple ID 2.25" Camco D 2.250 8,345.5 6,105.4 43.90 SOS 3.750 2 7/8" CAMCO SOS Pinned 3500 PSI - TTL ELMD @ 8352' SWS 7/17/1997 Camco PE-500 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,895.0 5,099.1 47.84 LEAK - CASING CSG LEAK IDENTIFIED BY ACOUSTIC LDL (0.6 BPM, 3000 PSI) 5/25/2021 6.280 8,327.9 6,092.7 43.99 CATCHER Set 2.25" Junk catcher on top of plug (OAL = 67") 12/8/2024 0.000 8,333.4 6,096.7 43.96 TUBING PLUG 2.25" CA-2 Plug (2.29" NO- GO, OAL = 25") 12/8/2024 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) 3,270.9 2,650.6 47.12 2 GAS LIFT DV RK 2 7/8 4/7/2025 SLB FO-2 MMG 1.500 6,737.2 4,992.7 47.15 1 GAS LIFT SOV RKP 2 7/8 4/7/2025 SLB FO-2 MMG 1.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,445.0 8,471.0 6,177.3 6,196.1 C-4, 3M-19 5/24/1991 6.0 APERF 2 1/8" EnerJet; 0 deg. ph 8,476.0 8,494.0 6,199.7 6,212.7 A-2, 3M-19 5/24/1991 6.0 RPERF 2 1/8" EnerJet;; 0 deg. ph 8,486.0 8,487.0 6,206.9 6,207.6 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,490.0 8,491.0 6,209.8 6,210.5 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,494.0 8,495.0 6,212.7 6,213.4 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,500.0 8,544.0 6,217.0 6,248.8 A-1, 3M-19 9/3/1987 4.0 IPERF 4" Csg Gun; 120 deg. ph 3M-19, 4/10/2025 9:48:41 AM Vertical schematic (actual) PRODUCTION; 34.0-8,923.3 IPERF; 8,500.0-8,544.0 IPERF; 8,494.0-8,495.0 IPERF; 8,490.0-8,491.0 IPERF; 8,486.0-8,487.0 RPERF; 8,476.0-8,494.0 APERF; 8,445.0-8,471.0 TUBING PLUG; 8,333.4 CATCHER; 8,327.9 PACKER; 8,315.7 Nipple - X; 8,248.6 LEAK - CASING; 6,895.0 Packer; 6,818.8 Mandrel – GAS LIFT; 6,737.2 SURFACE; 37.0-4,479.7 Mandrel – GAS LIFT; 3,270.9 CONDUCTOR; 38.0-115.0 Hanger; 34.0 KUP PROD KB-Grd (ft) 37.00 RR Date 7/19/1987 Other Elev… 3M-19 ... TD Act Btm (ftKB) 8,971.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292173700 Wellbore Status PROD Max Angle & MD Incl (°) 48.52 MD (ftKB) 4,000.00 WELLNAME WELLBORE3M-19 Annotation Last WO: End DateH2S (ppm) 200 Date 11/3/2013 Comment SSSV: TRDP 3M-19 Final RWO Completion Updated 4/8/2024 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 115'115'16"15.06"62.5#H-40 Welded Surface 4479.7'3463.1'9 5/8"8.921"36#J-55 BTC Production/ Intermediate 8923.3' 6524.3' 7" 6.276" 26# J-55 BTC Tubing 8292'6067'2 7/8"2.441"6.5#L-80 8rd MOD NEW COMPLETION - Depths are Nabors 7ES RKB FMC Gen 4 Wellhead/ 2 7/8" EUE-M Tubing Hanger 2 7/8" 6.5# L-80 EUE 8rd Mod Tubing to surface SLB MMG gas lift mandrels @ 3271' RKB, 6737' RKB 80-32 PBR Assy 20' - Pinned to shear at 33,150 lbs. 3 1/2" x 7" Baker FH Pkr @ ~6818' RKB 2 7/8" 6.5# L-80 EUE 8rd Mod Tubing 2 Ǭ" X Nipple at 8249' RKB (2.313" min ID) 2 Ǭ" External Casing Patch - Sealing Overshot - 5.51' Lng -Leaking REMAINING COMPLETION LEFT IN HOLE Tubing cut @ 8290' RKB, dressed to 8293' ORKB 2 Ǭ" Camco OEJ @ 8315.4' ' ORKB (2.313" ID) 2 Ǭ" Camco HRP-1SP Pkr @ 8332.9' ORKB (2.347" ID) 2 Ǭ" Camco D Nipple @ 8350' ORKB (2.25" ID) - 2.25" CA-2 plug installed 2 Ǭ" Camco SOS @ 8362.6' ORKB, 8352' ELMD Surface Casing @ 4479.7' RKB Production Casing @ 8923.3' RKB Conductor @ 115' RKB A-sand perfs 8474' - 8544' RKB C-sand perfs 8445' - 8471' RKB Tubing Cut @ 8290' RKB PC Leak found Pre-Rig @ 6895' MD Potential PC Leaks found w/ MFC 6876', 7311', 7365', 7467', 7684' MD Estimated TOC: 7050' RKB CBL Dated: 8/10/87 Arctic Packed, no volume recorded Sand likely from tubing cut to CA-2 Plug From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]Re: 3M-19 (PTD 187-064) Sundry 324-667 Date:Tuesday, April 8, 2025 10:13:48 AM From: Lau, Jack J (OGC) Sent: Monday, April 7, 2025 1:50 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3M-19 (PTD 187-064) Sundry 324-667 Good afternoon Elliott, As discussed, you are verbally approved to move off well 3M-19 with the plug isolating the reservoir and tubing ran in hole. You will need to submit a Change of Approved program sundry for an operational shutdown to close the loop before the new sundry application for a non-repair is submitted. This should be done within 3 days. Thanks, Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Monday, April 7, 2025 12:25 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3M-19 (PTD 187-064) Sundry 324-667 Jack, We moved to the alternate completion after performing another cleanout and a second test packer run. We are requesting the approval to RDMO from the well without integrity across the straddle and fix it post rig. Past operations below: Friday RU E-line, run 40 arm caliper, tag bottom at 8,270’ Log caliper F/8,270’ T/surface, RD E-line, (send data in for processing). PU/Set RBP @ 1,045’ COE, test 1,000 psi ND BOPE, grow and stretch casing 13.25”, set it in slips w/100k (total stretch 18.75”) installed new pack-off, cut casing, installed new casing spool. NU BOP Saturday Continued NU, tested void (good test) MU Cleanout BHA, TIH on stands to 6815’, installed a closed TIW valve, TIH T/8,210’ filling DP, PT DP 2,500 psi for 5 mins. (good test) – verified that the DP was not a problem. TOOH, laid out the TIW valve, TBIH, performed cleanout to stub, washed down T/8,276’, circulated high vis sweep, TOOH on stands. MU AS1X test packer, TIH F/surface T/1,045’ COE, test 2,500 psi (good test), release packer. Had failed tests around 6840’ then: PUH T/6,349’, obtain passing test for 5 min @ 2,500 psi – above packer. TIH T/ 6849’ got a good test @ 2500psi for 5 minutes – above packer. Sunday TIH, attempt to get passing test COE 8,190’, 8,240’, 8,250’ below packer. (all test failed to backside of DP) Perform leak off test @ 8240’, 1.0 bpm flat line 2,000 psi. 1.5 bpm climbing above 2,500 psi, shut down pump. TOOH sideways LD/DP, slip and cut drill line, LD test packer Run 2-7/8” completion as per confirmed tally w/Baker FH packer - Alternative completion as worked last week with you. Park off stub. circulate 8.6 ppg CI, RIH stack out on stub, PU to confirm, PT 250 psi/5 min – failed @ 6spm We did not get a passing test on the external casing patch prior to setting the packer. With a lack of options ahead of us, we followed through with setting the Packer at 6818’ RKB against a ball and rod rather than the CA-2 plug at 8350’. We have evaluated our options to repair the leaking External casing patch post rig (or holes in the old tubing below the external casing patch), and there is no current WL run patches, that allow a plug run below it, available for 2 7/8” tubing. However, we are working with Welltec currently to develop an almost fullbore patch for 2 7/8” tubing that we have successfully deployed in 3 ½” tubing that could be a remedy to the plan below if it fails. We are still isolated from the reservoir and this repair does not require pulling the CA-2 plug until we get a passing test – assuming no future mechanical options are required due to cement plug not holding. An overburden study has been performed and there is no HC bearing zones identified behind the straddle so we do not believe we are compromising the final P&A of this well with this fix. Post rig remediation plan: RU SL: 1. Fish Ball and Rod and RHC Plug 2. Pull SOV from station 2 at ~6737’ RKB 3. Set DV in Station 2 at ~6737’ RKB RU pumping services and Eline: 1. Establish a leak off rate through the patch/ old tubing and pull an LDL. 2. Based on rate/ depths of leaks, shoot tubing punch above OEJ at 8315’ RKB 3. Set Comp BP at 8334’ RKB (inside HRP-1SP packer 4. Set Comp Cement Retainer at 8280’ RKB or above External casing patch RU CT: 1. Sting into comp CR at 8280’ RKB, pump cement into annulus bullheading into casing leaks (most significant PC leak found pre rig at 6895’ RKB) a. Total volume of annuli: 45.8Bbls b. Wait in adequate time for cement to set up 2. Mill up Comp BP/ CR and sand down to the catch on top of the CA-2 plug at 8350’ 3. Perform MIT-T/ down to the CA-2 plug @ 8350’ to 3000psi. 4. Cleanout down to CA-2 plug catcher, fish catcher and plug RU SL: 5. Install GL Design Return well to operations or seek full bore patch currently in development if cement squeeze fails. Regards, Elliott Tuttle C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, April 4, 2025 6:03 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: [EXTERNAL]Re: 3M-19 (PTD 187-064) Sundry 324-667 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. Elliott, 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. If necessary, you are approved for the alternate plan below with testing of the tubing, new packer, and overshot external patch with plug set in the Camco D Nipple at 8350' RKB. Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Friday, April 4, 2025 5:53 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: RE: 3M-19 (PTD 187-064) Sundry 324-667 Jack, As discussed, see the detailed testing sequence below in red. I have received the caliper data now and it does not show the corrosion we had thought was down there, although still waiting for the LAS file to confirm. We will continue to pursue the original completion outlined on the approved sundry, but we would appreciate an approval to complete the well as outlined below. Thank you, Elliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Friday, April 4, 2025 4:44 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: 3M-19 (PTD 187-064) Sundry 324-667 Jack, Last night we were able to get a successful test from 6850’ RKB up but was unable to get a test from 8025’, 8195’, 8170’ RKB to the packer and plug on bottom due to flow being seen on the backside, essentially around the test packer suggesting that the casing corrosion was similar to 3M-22 or we were having issues with the test packer. We just got done pulling a caliper across the PC and I am awaiting the results. Different than 3M- 22, the packer currently in the hole has integrity and could be a bottom to the straddle isolating the PC leak. We have found a 2 7/8” External casing patch and are suggesting the fix depicted in the attached proposed schematic. Does this completion require a CAP be submitted? Are we approved to proceed? Operational Change: TIH with 2 7/8” Upper completion. Once on depth, shear OS and space out as needed. Land tubing hanger, RILDs and test PO’s. Circulate corrosion inhibited fluid. Land Casing Patch and pull into tension to confirm. Pressure up to set 2-7/8” x 7” Packer – testing Casing Patch integrity. · The packer is pinned to set at 2,500 psi. Pick up to shear out the new PBR while holding 2,000 psi on the tubing. After shear is observed, bleed off tubing pressure. Once the PBR has sheared, Space out Hanger and MU Land the tubing hanger and RILDS. Pressure test tubing to 3,000 psi for 30 minutes and chart down to a CA-2 plug set in the D Nipple at 8350’ RKB (incorrectly stated in the schematic originally. Corrected in the attached). Pressure test IA to 2,500 psi for 30 minutes and chart down to the upper packer at ~8030’ RKB. Back on plan. Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 564 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-04-04_16026_KRU_3M-19_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16026 KRU 3M-19 50-029-21737-00 Caliper Survey w/ Log Data 04-Apr-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 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:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 3M-19 (PTD 187-064) Sundry 324-667 Date:Monday, April 7, 2025 10:21:19 AM From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, April 4, 2025 6:03 PM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: Re: 3M-19 (PTD 187-064) Sundry 324-667 Elliott, If necessary, you are approved for the alternate plan below with testing of the tubing, new packer, and overshot external patch with plug set in the Camco D Nipple at 8350' RKB. Jack From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Friday, April 4, 2025 5:53 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: RE: 3M-19 (PTD 187-064) Sundry 324-667 Jack, As discussed, see the detailed testing sequence below in red. I have received the caliper data now and it does not show the corrosion we had thought was down there, although still waiting for the LAS file to confirm. We will continue to pursue the original completion outlined on the approved sundry, but we would appreciate an approval to complete the well as outlined below. Thank you, Elliott Tuttle C: 907.252.3347 From: Tuttle, Elliott Sent: Friday, April 4, 2025 4:44 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: 3M-19 (PTD 187-064) Sundry 324-667 Jack, Last night we were able to get a successful test from 6850’ RKB up but was unable to get a test from 8025’, 8195’, 8170’ RKB to the packer and plug on bottom due to flow being seen on the backside, essentially around the test packer suggesting that the casing corrosion was similar to 3M-22 or we were having issues with the test packer. We just got done pulling a caliper across the PC and I am awaiting the results. Different than 3M- 22, the packer currently in the hole has integrity and could be a bottom to the straddle isolating the PC leak. We have found a 2 7/8” External casing patch and are suggesting the fix depicted in the attached proposed schematic. Does this completion require a CAP be submitted? Are we approved to proceed? Operational Change: TIH with 2 7/8” Upper completion. Once on depth, shear OS and space out as needed. Land tubing hanger, RILDs and test PO’s. Circulate corrosion inhibited fluid. Land Casing Patch and pull into tension to confirm. Pressure up to set 2-7/8” x 7” Packer – testing Casing Patch integrity. · The packer is pinned to set at 2,500 psi. Pick up to shear out the new PBR while holding 2,000 psi on the tubing. After shear is observed, bleed off tubing pressure. Once the PBR has sheared, Space out Hanger and MU Land the tubing hanger and RILDS. Pressure test tubing to 3,000 psi for 30 minutes and chart down to a CA-2 plug set in the D Nipple at 8350’ RKB (incorrectly stated in the schematic originally. Corrected in the attached). Pressure test IA to 2,500 psi for 30 minutes and chart down to the upper packer at ~8030’ RKB. Back on plan. Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 564 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Sundry 324-667 KRU 3M-19 (PTD 187-064) Date:Wednesday, March 19, 2025 10:35:56 AM From: Lau, Jack J (OGC) Sent: Tuesday, March 18, 2025 3:50 PM To: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: Sundry 324-667 KRU 3M-19 (PTD 187-064) Good Afternoon Erica, The AOGCC staff convened today to review Sundry 324-667 for KRU 3M-19 (PTD 187- 064). Following the review, the staff recommends upholding the approved sundry in its current form, including the prescribed Conditions of Approval, which require biennial integrity verification. ConocoPhillips has the following options to proceed with this work: 1. Execute the work as outlined in the approved Sundry 324-667. 2. Submit a new sundry with an alternative design. 3. File for reconsideration pursuant to AS 31.05.080. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5213 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 5213 3M-19 50029217370000 Tubing Cut Record 22-Dec-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 187-064 T39932 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:06:16 -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 187-064 T39862 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.17 08:09:30 -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: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8971'None Casing Collapse Conductor Surface Production 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: 907-263-4742 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 8351'3411'6109'6559' Packer: HRP-1-SP SSSV: Camco TRDP-1A-SSA Perforation Depth MD (ft): 8351' 6524'7" 6177-6196'TVD 6200-6213'TVD 6207-6208'TVD 6210-6211'TVD 6213-6213'TVD 6217-6249'TVD 115' 4480' 8923' 2-7/8" 16" 9-5/8" 78' 8445-8471'MD 8476-8494'MD 8486-8487'MD 8490-8491'MD 8494-8495'MD 8500-8544'MD 9691' Burst 4341' 8363'MD/6118'TVD MD 115' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025523 187-064 P.O. Box 100360, Anchorage, AK 99510 50-029-21737-00-00 KRU 3M-19 AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 12/15/2024 Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): Kuparuk River Field ConocoPhillips Alaska, Inc Proposed Pools: PRESENT WELL CONDITION SUMMARY Length Size Elliott Tuttle elliott.tuttle@conocophillips.com TVD 8333'MD/6096'TVD 1759'MD/1607'TVD Perforation Depth TVD (ft): 3463' CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 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: m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:57 pm, Nov 22, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.11.22 15:21:04-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 324-667 JJL 11/26/24 DSR-12/17/24A.Dewhurst 26NOV24 Witnessed BOP to 4000 psi and Annular Test 3500 psi. Biannual charted or recorded 1) MITT and MITIA or 2) CMIT to verify integrity of the straddle over PC leak. 10-404 XX *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.18 10:31:17 -09'00'12/18/24 RBDMS JSB 121924 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 21st, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3M-19 (PTD# 187-064). Well 3M-19 was drilled in July of 1987 by Doyon 9 and completed in September of 1987 by Nordic 1 as a Kuparuk A sand producer. The well was Fractured 3 different times, in ‘87, ’92 and ’97 which is why we believe the corkscrewed tubing occurred low or above the packer. The well has multiple tubing holes and a PC leak was found on 4/18/2021. An acoustic LDL was run and located the leak at 6895’ RKB. The intermediate casing packoffs are leaking during a positive pressure test. A seal-tite job was performed on 4/20/01 and the packoffs will be remedied during this RWO. To bring the well back online, we request approval to proceed with a rig workover to pull and replace the tubing and grow and stretch the casing to address the Intermediate casing packoffs. The 2-7/8” tubing down to a pre rig cut will be pulled, then a cleanout run will be completed followed by a test packer run to confirm casing leak depth and integrity above, and a new 2-7/8” gas lift completion will be installed with two packers, straddling the PC leak found on the LDL. If you have any questions or require any further information, please contact me at 907-252-3347. Elliott Tuttle Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN =Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.11.22 15:21:34-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 3M-19 Kuparuk Producer Pull and Replace Tubing RWO PTD: 187-064 Page 1 of 2 CCompleted Pre-Rig Work 1. Log acoustic LDL, located PC leak at 6895’ RKB – 4/25/21 2. T-POT/PPPOT (passed) and IC-POT (passed)/PPPOT (failed) – 11/16/24 3. MIT-OA to 1800psi (passed) – 11/16/24 Pre-Rig Work Remaining 4. Dummy off GLM Station 1-5. Pull DV from station 8 @ 8268’ RKB – if unable, perform tubing punch near planned tubing cut. 5. Fish CA-2 plug from nipple @ 8350.7’ RKB – set in 2021 6. Take SBHP survey at 8445’ RKB (6177’ TVD) 7. Set plug in tubing tail/ CA-2 plug in nipple at 8350.7’ RKB 8. CDDT TxIA 9. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3M-19. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier as needed, ND tree, NU BOPE and test to 250/4,000 psi. Test annular 250/3,500 psi. Retrieve 2-7/8” Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” completion from a pre rig cut @ ~8290’ RKB a. If completion will not pull free from pre-rig cut, make an E-Line cut on-rig as deep as possible, then jar tubing free with fishing BHA on DP, if needed. 6. Close VBR on 2 7/8” tubing circulate bottoms up. 7. On the way out with tubing, TIH with storm packer and set near surface, confirm as barrier. a. (Alter casing) ND BOPE, ND tubing head, grow and stretch casing. Set in slips and new IC-PO’s. NU tubing head and BOPE/ Stack. b. TIH and retrieve Storm packer, continue to lay down tubing. Cleanout Run and Test Packer Run 8. PU DP and RIH with casing scraper to cleanout down to tubing stub. a. MU test packer BHA to confirm casing integrity above known PC leak at 6895’ RKB and packer below as barrier. 9. POOH laying down DP. Install 2-7/8” Gas Lift Completion 10. MU new 2-7/8” completion with PBOS, nipple profile, two packers, and GLMs. RIH to tubing stub. 11. Once on depth, shear OS and space out as needed. Land tubing hanger, RILDs and test PO’s. 3M-19 Kuparuk Producer Pull and Replace Tubing RWO PTD: 187-064 Page 2 of 2 12. Circulate corrosion inhibited fluid. 13. Drop Ball and Rod, pressure up and set packers (no Mandrel movement). 14. Pressure test tubing to 3,000 PSI. 15. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 16. Shear out SOV with pressure differential. 17. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 18. Pull BPV and freeze protect well. 19. RDMO. PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 12/15/2024 Current Operations: Shut-In Well Type: Producer Wellhead Type: FMC Gen IV. 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 4,030 psi / 6187.4’ TVD measured on 4/12/2021 MPSP: 3,411 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 2-7/8” completion froma pre rig cut, perform cleanout run and test packer run to confirm PC leak depth, install a new 2-7/8” gas lifted completion with straddle packers. Personnel: Workover Engineer: Elliott Tuttle (907-252-3347) / Elliott.Tuttle@conocophillips.com) Reservoir Surveillance Engineer: Kaylie Plunkett Production Engineer: Sydney Autry Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,477.0 4/12/2021 3M-19 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: E-line ID'd additional tbg leak at 6860' 4/25/2021 3M-19 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 37.0 Set Depth (ftKB) 4,479.7 Set Depth (TVD) … 3,463.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.0 Set Depth (ftKB) 8,923.3 Set Depth (TVD) … 6,524.3 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 34.0 Set Depth (ft… 8,363.3 Set Depth (TVD) (… 6,118.2 Wt (lb/ft) 6.50 Grade J-55 Top Connection 8rd AB MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 34.0 34.0 0.07 HANGER FMC 2 7/8" x 7" Tbg Hgr & Pup Jt (L-80) 2.441 1,759.0 1,607.1 42.45 SAFETY VLV CAMCO TRDP-1A-SSA SSSV and Pup Jt 2 7/8" 2.312 8,315.4 6,083.7 44.05 PBR 2 7/8" CAMCO 'OEJ' 2.313 8,332.9 6,096.3 43.96 PACKER 2 7/8" x 7" CAMCO HRP-1-SP Pkr 2.347 8,350.7 6,109.2 43.87 NIPPLE 2 7/8" CAMCO 'D' Nipple ID 2.25" 2.250 8,362.6 6,117.8 43.81 SOS 2 7/8" CAMCO SOS Pinned 3500 PSI - TTL ELMD @ 8352' SWS 7/17/1997 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,828.0 3,699.2 47.45 LEAK GLM TBG LEAK IN GLM @ 4828' RKB 7/15/2014 6,860.0 5,075.6 47.76 TUBING LEAK TUBING LEAK IDENTIFIED BY E-LINE LDL AT 6860' 4/25/2021 2.440 7,703.0 5,651.8 46.02 TUBING LEAK TUBING LEAK IDENTIFIED WITH SLB LDL AND WITH HES RELAY ON 5/24/19 1/20/2019 2.440 8,350.7 6,109.2 43.87 2.25" CA-2 Plug 2.25" CA-2 Plug (27" OAL) 4/12/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,445.0 8,471.0 6,177.3 6,196.1 C-4, 3M-19 5/24/1991 6.0 APERF 2 1/8" EnerJet; 0 deg. ph 8,476.0 8,494.0 6,199.7 6,212.7 A-2, 3M-19 5/24/1991 6.0 RPERF 2 1/8" EnerJet;; 0 deg. ph 8,486.0 8,487.0 6,206.9 6,207.6 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,490.0 8,491.0 6,209.8 6,210.5 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,494.0 8,495.0 6,212.7 6,213.4 A-2, 3M-19 9/3/1987 1.0 IPERF 4" Csg Gun; 120 deg. ph 8,500.0 8,544.0 6,217.0 6,248.8 A-1, 3M-19 9/3/1987 4.0 IPERF 4" Csg Gun; 120 deg. ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,781.0 2,316.1 46.43 McMurry FMHO 1 GAS LIFT GLV BK-1 0.156 1,292.0 3/21/2011 2 4,827.7 3,699.0 47.45 McMurry FMHO 1 GAS LIFT GLV BK 0.156 1,287.0 7/16/2014 3 5,873.2 4,401.6 47.48 McMurry FMHO 1 GAS LIFT GLV BK-2 0.188 1,314.0 7/16/2014 4 6,364.2 4,736.5 46.72 McMurry FMHO 1 GAS LIFT GLV BK-2 0.188 1,394.0 9/19/1997 5 6,856.4 5,073.2 47.75 McMurry FMHO 1 GAS LIFT OV BK-2 0.188 0.0 1/9/2019 6 7,317.4 5,386.7 46.08 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/17/2011 7 7,810.2 5,726.2 46.02 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/19/2002 8 8,267.8 6,049.6 44.13 Otis LB 1 1/2 GAS LIFT DMY RM 0.000 0.0 7/20/2002 Notes: General & Safety End Date Annotation 3/20/2011 NOTE: Lost ~ 2.25" piece of JD Dog below 5873'. DID NOT RECOVER 3/20/2011 NOTE: STRIPPED F/N OFF LATCH ON GLV@ 6364' 8/12/2006 NOTE: CTU FOUND CORKSCREWED TUBING FROM 7800' to 8333' 12/22/2002 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7/20/2002 NOTE: FISHNECK ON GLV LATCH @ 6364' IS STRIPPED 3M-19, 4/26/2021 10:35:04 AM Vertical schematic (actual) PRODUCTION; 34.0-8,923.3 IPERF; 8,500.0-8,544.0 IPERF; 8,494.0-8,495.0 IPERF; 8,490.0-8,491.0 IPERF; 8,486.0-8,487.0 RPERF; 8,476.0-8,494.0 APERF; 8,445.0-8,471.0 SOS; 8,362.6 2.25" CA-2 Plug; 8,350.7 NIPPLE; 8,350.7 PACKER; 8,332.9 PBR; 8,315.4 GAS LIFT; 8,267.8 GAS LIFT; 7,810.2 TUBING LEAK; 7,703.0 GAS LIFT; 7,317.4 TUBING LEAK; 6,860.0 GAS LIFT; 6,856.4 GAS LIFT; 6,364.2 GAS LIFT; 5,873.2 GAS LIFT; 4,827.7 SURFACE; 37.0-4,479.7 GAS LIFT; 2,781.0 SAFETY VLV; 1,759.0 CONDUCTOR; 38.0-115.0 HANGER; 34.0 KUP PROD KB-Grd (ft) 37.00 Rig Release Date 7/19/1987 3M-19 ... TD Act Btm (ftKB) 8,971.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292173700 Wellbore Status PROD Max Angle & MD Incl (°) 48.52 MD (ftKB) 4,000.00 WELLNAME WELLBORE3M-19 Annotation Last WO: End DateH2S (ppm) 200 Date 11/3/2013 Comment SSSV: TRDP 3M-19 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115' 115' 16" 15.06" 62.5# H-40 Welded Surface 4479.7' 3463.1' 9 5/8" 8.921" 37# L-80 BTC BTC Production/ Intermediate 8923.3' 6524.3' 7" 6.276" 26# J-55 BTC BTC Tubing 8363.3' 6118.2'2 7/8"2.441" 6.5#L-80*8rd MOD 8rd MOD PROPOSED COMPLETION 2 7/8" 6.5# L-80 EUE 8rd Mod Tubing to surface SLB MMG gas lift mandrels @ 3280' RKB, 6770' RKB Crossover, 2 7/8" EUE-M to 3 1/2" EUE-M 3 1/2" x 7" Pkr @ xxxx' RKB (XXXX" ID) 3 1/2" 9.3# L-80 EUE 8rd Mod Tubing 3 1/2" x 7" Pkr @ xxxx' RKB (XXXX" ID) Crossover, 3 1/2" EUE-M to 2 7/8" EUE-M 2 >" X Nipple at xxxx' RKB (2.313" min ID) 2 >" Non-sealing Overshot - 6' Lng REMAINING COMPLETION LEFT IN HOLE 2 >" Camco OEJ @ 8315.4' ' RKB (2.313" ID) 2 >" Camco HRP-1SP Pkr @ 8332.9' RKB (2.347" ID) 2 >" Camco D Nipple @ 7332' RKB (2.25" ID) 2 >" Camco SOS @ 8362.6' RKB, 8352' ELMD Surface Casing @ 4479.7' RKB Production Casing @ 8923.3' RKB Conductor @ 115' RKB A-sand perfs 8474' - 8544' RKB C-sand perfs 8445' - 8471' RKB Tubing Cut @ 8290' RKB PC Leak @ 6895' RKB TOC: 7050' RKB CBL Dated: 8/10/87 Arctic Pack, no volume recorded WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.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 SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϳϬϲϰϬͲ^Ğƚ͗ϯϲϮϰϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 C:\Users\aebell\Desktop\May 2021 Data Drop\CPA Data Drop 06022021\2021-05-25_15782_KRU 3M-19_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15782 KRU 3M-19 25-May-21 LeakPoint Survey 25-May-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name 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 PTD: 1870640 E-Set: 35195 Abby Bell Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n .� AOGCC w AT N. Natural Resources Technician 11 )- Alaska Oil & Gas Conservation Commision �M 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 f i i MIMIJIVOM TRANSMITTALDATE TRANSMITTALS �.• v v v V Ntaimje al RecepX A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Xpackage have been verified to match the media noted above. The Sign'Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Sc lu berger and CPAI. point. Alaska PTSPrintCenter slb.com Tom.Osterkam hilli om Conoco SLB Auditor- T� Schlumberger -Private SCANNED AUG0 7 2019 ORDERSERVICE FIELD NAME DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATELOGGED Prints CD's 1H-114 1H-111 1H-105 1H-113 1H-116 50-029-23584-00 50-029-23581-00 50.029-20727-01 50-029-23588-00 50-029-23594-00 EOSH-00071 EAI8.00022 E118.00075 E118-00076 E118.00077 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL IPROF (PROF-WFL IPROF-WFL ]PROF-WFL IPROF-WFL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19 -Jul -19 20 -Jul -19 21 -Jul -19 1 1 1 1 1 3M-19 50.029-21737-00 E118-00078 KUPARUK RIVER WL Caliper FINAL FIELD 22 -Jul -19 1 3G -07A 50-103.20127-01 E118.00079 KUPARUK RIVER WL PPROF FINAL FIELD 23 -Jul -19 1 3G-11 50.103-20133-00 E118-00081 KUPARUK RIVER WL IPROF FINAL FIELD 25 -Jul -19 1 3M-13 50-029.21720-00 E118.00084 KUPARUK RIVER WL Caliper FINAL FIELD 28 -Jul -19 1 18.16AL1 50.029-22457.60 EDEA -00009 KUPARUK RIVER Memory PPROF FINAL FIELD 28 -Jul -19 1 IA -17 50.029-22102-00 E118-00085 KUPARUK RIVER WL LDL FINAL FIELD 29 -Jul -19 1 1C-121 3N -14A 3G-08 50.029-23015.00 50-029.21589-01 50.103-20128-00 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL IPROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 2N-317 50-103-20266-00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 v v v V Ntaimje al RecepX A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Xpackage have been verified to match the media noted above. The Sign'Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Sc lu berger and CPAI. point. Alaska PTSPrintCenter slb.com Tom.Osterkam hilli om Conoco SLB Auditor- T� Schlumberger -Private SCANNED AUG0 7 2019 WELL LOG TRANSMITTAL #905442157 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Setting Records: 3M-19 Run Date: 05/22/2019, 05/24/2019, and 05/25/2019 10 7064 3 105 5 June 26, 2019 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 3M-19 Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-029-21737-00 AUG 0 5 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: I Signed: WELL LOG TRANSMITTAL #905442157 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: String Shot Record: 3M-19 Run Date: 1/26/2019 10106! 30310 February 13, 2019 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 3M-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21737-00 RECEIVED FEB 19 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: � b l m Signed: Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: }� AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision ` 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 16 7060 TRANSMITTAL DATE r -' TRANSMITTAL# WELL NAME 16-102 ,. # 50-029-23167-00 ORDERSERVICE # EOSH-00015 FIELD NAME DESCRIPTION KUPARUK RIVER WL DELIVERABLE DESCRIPTIONColor Caliper Vert DATA FINAL FIELD DATELOGGED Prints 1 -Jan -19 CD's11 1 1J-10 1H-119 3H -31A 50-029-23010.00 50-029.23591-00 50.103.20205.01 EOSH-00017 EOSH-00018 EOSH-00019 KUPARUK RIVERIPROF KUPARUK RIVER!M: KUPARUK RIVER Caliper LDL FINAL FIELD FINAL FIELD FINAL FIELD 17 -Jan -19 18 -Jan -191 19 -Jan -19 1 1 3M-19 1H-116 1C-117 50-029-21737-00 50-029.23594.00 50.029-23027.00 EOSH-00020 EOSH-00021 EOSH-00022 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL1 LDL (PROF RST-WFL FINAL FIELD FINAL FIELD FINAL FIELD 20 -Jan -19 21 -Jan -19 22 -Jan -19 1 1 7 Signature courier or sign/scan and email a copy 0 Date and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA AL,"-'.-., ,A OIL AND GAS CONSERVATION COMMIS .... N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Plugging Perforate Repair well Other 6. Datum elevation (DF or KB) 5. Type of Well: Development X Exploratory _ Stratigraphic _ 7. Service 4. Location of well at surface 8. 835' FNL, 1549' FEL, Sec. 25, T13N, RSE, UM At top of productive interval 1675' FNL, 1647' FEL, Sec. 26, T13N, RSE, UM At effective depth 1753' FNL, 1904' FEL, Sec. 26, T13N, RSE, UM At total depth 1780' FNL~ 1992' FEL~ Sec. 26~ T13N~ RSE~ UM 12. Present well condition summary Total Depth: measured 8965 feet true vertical 6554 feet RKB 64 Unit or Property name Kuparuk River Unit Well number 3M-19 9. Permit number/approval number 87-64 10. APl number $0-029-21737-00 11. Field/Pool Kuparuk River Field/Oil Pool feet . Plugs (measured) None Effective depth: measured 8 8 31 true vertical 6 4 5 6 Casing Length Size Structural Conductor 8 0' 1 6" Surface 4443' 9-5/8" Intermediate Production 8889' 7" Liner feet feet Junk (measured) None Cemented Measured depth True vertical depth Not available 1 1 5' 1 1 5' 1500 Sx CS III & 4480' 3463' 500 Sx Class G 325 Sx Class G 89 2 3' 6 52 4' Perforation depth: measured 8445'-8471 ',8476'-8494',8486'-8487',8490'-8491 ',8494'-8495',8500'-8544' true vertical 61 77'-61 96',6201 '-621 3',6207'-6208',621 0'-6211',6213',6217'-6289' Tubing (size, grade, and measured depth) 0~ 2.875", 6.5#/ft., J-55 @ 8363' Packers and SSSV (type and measured depth) Packer: Camco HRP-1-SP @ 8333'; SSSV: Camco TRDP-1A-SSA @ 1759' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 9/13/97. Intervals treated (measured) 8476'-8494', 8486'-8487' ,8490'-8491',8494'-8495',8500"8544' Treatment description including volumes used and final pressure Pumped 250.7 Mlbs of 20/40 and 12/18 ceramic proppant into formation~ fp was 6000 psi. 14. Representative Daily Average Produ(~tion or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run 413 358 112 1070 808 1034 228 1085 -- 116. Status of well classification as: Daily Report of Well Operations X Oil X Gas Suspended 17. I her~rtify that the foregoing is true and correct to the best of my knowledge. Si~ned ~7~'~.~/'~ ~J.-,~~ TitleWells Superintendent,.~ .. , Form~~(~v'06/~' ~" :~'?:~ ~::~ Tubing Pressure 183 177 Service SUBMI~IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ , K1(3M-19(W4-6)) WELL JOB SCOPE JOB NUMBER' 3M-19 FRAC, FRAC SUPPORT 0901 972258.3 DATE DAILY WORK UNIT NUMBER 09/13/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes O No (~ Yes C) No DS-GALLEGOS JOHNS FIELD AFC~ CC.,~ DAILY COST ACCUM COST Signe~ /' I /',/ ESTIMATE KD151 1 230DS36ML $1 57,700 $200,632 Initial Tb.cl Press Final Tb_cl Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann ~ Final OL~t~ Ann 500 PSI 1 500 PSI 500 PSI 1 000 PSII 1200 PSI 300 PSI DAILY SUMMARY PUMPED "A" SANDS REFRAC, WITH 250, 773# OF UP TO 13 PPA 12/18 TO PERFS, LEFT 694# IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LI'I-FLE RED PUMP AND APC VACUUM TRUCK. 09:05 HELD JOB SITE SAFETY MEETING. 09:30 INITIAL WHP 350 PSI, SET TREE SAVER 09:37 PRESSURE TEST SURFACE LINE TO 9400 PSI. 09:42 10:20 11:10 12:12 12:25 13:07 13:28 PUMP BREAKDOW!r~ .~:ic~'~[ !c, ~i~r' FLUSH STAGES 25 TO 15 BPM FROM 8400 PSI TO '"'"" '~,'.t 7~.','C..~.~P0/40 PUMPED IN 1 AND .'? ;:~'~, ~.:OC)U~ .~ ;~i~I'AGE. SHUT DOWN FOR ISIP AND PULSE TEST. PUMP DATA FRAC AND FLUSH ,'5 TO 15 BPM AND 163 BBLS FLUIDS. SHUT DOWN FOR CLOSURE CALCULTION. PUMP 430 BBLS PAD AT 5 TO 15 BPM , 5397 PSI. PUMP 2 PPA FLAT STAGE OF 15,439# 20/40 PROPPANT AT 15 BPM AND 5255 PSI. PUMP RAMP UP STAGE FROM 2 TO 10 PPA , 12/18 PROPPANT, 15 BPM AND 5534 PSI. PUMP FLAT 10 PPA STAGE OF 93,280# 12/18 PROPPANT. 15 BPM AND 5534 PSI. PUMP RAMP UP FROM 10 TO 13 PPA 12/18 PROPPANT , 15 TO 10 BPM. MAX TREATING PRESSURE 6000 PSI. SHUT DOWN WITH TUBING FLUSHED TO PERFS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $684.00 APC $7,500.00 $18,250.00 ARCO $400.00 $400.00 _DIESEL $0.00 $2,861.00 _DIESEL GEL $0.00 $0.00 _DOWELL $148,000.00 $165,917.00 _ HALLI BURTON $ 0.00 $4,481.00 _LITTLE RED $1,800.00 $5,760.00 _NITROGEN $0.00 $2,280.00 TOTAL FIELD ESTIMATE $1 57,700.00 $200,633.00 STATE OFALASKA ~ ~'~ ! ~ ~ ~j~ ~ ~ ~ OIL AND GAS CONSERVATION COMM~,,~,ON FIEPOFIT OF SUNDRY WEll OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well . Other 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 835' FNL, 1549' FEL, Sec. 25, T13N, RSE, UM At top of productive interval 1675' FNL, 1647' FEL, Sec. 26, T13N, R8E, UM At effective depth 1753 FNL, 1904' FEL, Sec. 26, T13N, R8E, UM At total depth 1780' FNL, 1992' FEL~ Sec. 26, T13N~ R8E, UM 12. Present well condition summary Total Depth: measured 8965' feet true vertical 6554' feet 5. Type of Well: Development X. Exploratory _ Stratigraphic .- Service Plugs (measured) 6. Datum elevation (DF or KB) 64' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-19 9. Permit number/approval number 87-64 10. APl number 50-029-21737 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 8 831 ' feet true vertical 6456' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4443' 9 5/8" 8889' 7" measured 8445'-8471 ', 8500'-8544' true vertical- 6177'-6196', 6217'-6289' Cemented Report Not Available 1500 Sx CS III & 500 Sx Class G 325 Sx Class G 8476'-8494', 6201'-6213', 8486'-8487', 6207'-6208', Measured depth 115' 4480' True vertical depth 115' 3463' 8923' 6524' 8490'-8491', 8494'-8495' Tubing (size, grade, and measured depth) 2 7/8" 6.5#, J-55, ABMOD, 8363' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA~ 1759'~ Packer: Camco HRP-1-SP~ 8333' 13. Stimulation or cement squeeze summary A-Sand Seawater Gel Fracture Treatment Intervals treated (measured) 8445'-8471', 8476'-8494', 8486'-8487', 8490'-8491', 8494'-8495', 8500'-8544' Treatment description including volumes used and final pressure Pumped 135MIbs in perfs-16/20 Carbolite followed by 12/18 Carbolite (see Well Service Report) 14. Reoresentative Daily Average Productioq or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 850 425 - 0 - 1 100 140 15. Subsequent to operation Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 900 500 20 1200 150 16. Status of well classification as: Water Injector__ Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned C-.-(,~. ~ Title Kuparuk Petroleum Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLIGATE ~ARCO Alaska, Inc~-~ Subsidiary of Atlantic Richfield Compan WELL CONTRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME Co ~ ~,~.r= 1-~= WELL SERVICE REPORT IDAY~ IDATE q-/9-~ I 1,5-g 5' /GO I I/~ ~o P,,,.,,,~, C.g o r3g / ! · '~ o ,, o o o -1:1:. I ~Si o o o //;/3 II ~ ~ 661r ~,ala', /, &x ['-] CH~CK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. Chill Factor Visibility Wind Vel. Report I °F °F miles I 'Signed knots 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIQN REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate X Repair well O t h e r ,, 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address 5. Type of Well: Development X Exploratory _ Stratigraphic _ 64' RKB 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Location of well at surface 835' FNL, 1550' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1675' FNL, 1647' FEL, Sec. 26, T13N At effective depth 1753' FNL, 1904' FEL, Sec. 26, T13N At total depth 1780' FNL, 1992' FEL, Sec. 26, T13N , R8E, UM , R8E, UM 12. Present well condition summary Total Depth: , R8E, UM Kuparuk River Unit 8. Well number 3M-1~ 9. Permit number/approval number 87-64 10. APl number $0-029-21737 measured 8 9 65' true vertical 6554' feet 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 8 831 ' true vertical6456' feet Junk (measured) None feet Casing Length Size Structural 8 0' 1 6" Conductor 444 3' 9 - 5 / 8" Surface Intermediate Production 8889' 7" Liner Perforation depth: measured 8445'-8471 ', true vertical 6177'-6196', Cemented Measured depth Conductor report 1 1 5' not available 1500 sx CS III & 4480' 500 sx Class G True vertical depth 115' 3463' 325 sx Class G 8923' 6524' 85OO'-8544' 6217'-6249' 8476'-8495', 6200'-6213', Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w tail @ 8363' Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 8333' & TRDP-1A-SSA SSSV @ 1759' 13. Stimulation or cement squeeze summary See attached well report 14. RE( IV i) J L/L '? ~ ~;~i ~"~"~'~*~ Oil & Gas Cons. Con.r~,~,:,o,~ ..,~,~ ,~,~ ~ . Intervals treated (measured) See attached well report ^r~ch0ra§e Treatment description including volumes used and final pressure See attached well report Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 903 453 -0- 1250 150 1073'/'''~ 483 -0- 1250 156 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector Daily Report of Well Operations X. Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 09/12/90 Title Senior Operations Engineer Date ?'-~ '- ~/ SUBMIT IN DUPLICATE V~ELL ~.~u ~lasKa, Inc. Subsidiary of Atlantic Richfield Comr~-~' CONTRACTOR REMARKS / FIELD. DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPOR JD^~S 0~oo - IlO0 - I'-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ]Signed ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7375 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please-acknowledge receipt and return one signed copy of this transmittal. ~ 3 H- 1 4 Kuparuk Fluid Level Report I 2-1 0 - 8 8 Casing ~ 3 H- 1 5 Kuparuk Fluid Level Report 1 2- 0 9 - 8 8 Tubing · 3 H - 1 7 Kuparuk Fluid Level Report I 2- 0 9 - 8 8 Casing · 3 M - 1 9 Kuparuk Fluid Level Report 1 2 - 0 9 - 8 8 Casing · 3 H- 0 6 Kuparuk Fluid Level Report I 2- 0 8 - 8 8 Tubing · 3 H - 0 9 Kuparuk Fluid Level Report I 2- 1 3 - 8 8 Casing · 3 H - 21 Kuparuk Fluid Level Report I 2- 1 3 - 8 8 Casing · 3 K - 0 6 Kupaurk Fluid Level Report I 2- 1 2 - 8 8 Casing ~ 3 H - 21 Kuparuk Fluid Level Report I 2-1 2 - 8 8 Casing · 1 Y- 0 6 Kuparuk Fluid Level Report 1 2- 1 2 - 8 8 Casing ' 30-07 BHP Report 1 1-27-88 Receipt Acknowledged: Alaska ........................... Date: ............ DISTRIBUTION: State of Alaska D&M Unocal SAPC Chevron Mobil ? STATE OF ALASKA ~"~ ~ ALASKA OIL AND GAS CONSERVATION L, OMMISSION ~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .__ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-64 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21737 4. Location of well at surface 9. Unit or Lease Name 835' FNL, 1550' FEL, Sec.25, T13N, RSE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1675' FNL, 1647' FEL, Sec.26, T13N, R8E, UM 3M-19 At Total Depth 11. Field and Pool 1780' FNL, 1992' FEL, 5ec.26, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 64' I ADL 25523 ALK 2559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/11/87 07/17/87 11/01/87* J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) : 19. Directional Survey 20. Depth Where SSSV set I 21. Thickness of Permafrost 8965'MD, 6554'TVD 8831 'MD, 6456'TVD YEs [~ NO [] 1759' feet MD I 1600' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL, Cal, CBL/VDL/GR/CCL, Gyro 23. 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# H-40 Surf 115' 24" Conductor report not available 9-5/8" 36.0# J-55 Surf 4480' 12-1/4" 1500 sx CS Ill & 500 ;x Class G 7" 26.0# J-55 Surf 8923' 8-1/2" 325 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/1 spf, 120° phasing 2-7/8" 8363' 8333' 8486 'MD 6206 'TVD 8490 'MD 6209'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8494 'MD 6212 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Perforated w/4 spf, 120° phasing See attached Adder dum~ dated 12/29/87, 8500'-8544'HD 6216'-6248'TVD for fracture 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours TeSted PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE I'GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,,k OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Drilled RR 7/19/87. Perforated well & ran tubing 9/4/87. Fractured well 11/1/87. Form 10-407 WC4/22 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. (' .... 30. ( · GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8440' 6173' N/A Base Kuparuk C 8474' 6198' Top Kuparuk A 8474' 6198' Base Kuparuk A 8574' 6270' 31. LIST OF ATTACHMENTS Addendum (dated 12/29/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~/'~/~_.~_/)l~_~t_/ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL' 8/10/87 11/1/87 3M-19 RU Gearhart & RIH to 8800' w/6.03" GR/JB, POOH. No junk recovered. PU CBL/VDL/GR/CCL and logged f/8800'-6500'. TOC @ 6980', good bonding. POOH. Ran Gyro f/8750' to surface. POOH. RD Gearhart. Frac Kuparuk "A" sand perfs 8486', 8490', 8494' and 8500' -8544' in 9 stages per procedure dated 10/20/87 as follows' Stage 1' 100 bbls gelled diesel @ 10-20 BPM, 5797-5070 psi Stage 2- 450 bbls gelled diesel @ 20 BPM, 5050-4778 psi Stage 3' 40 bbls gelled diesel 2# 20/40 @ 20 PBM, 4775-4808 psi Stage 4- 50 bbls gelled diesel 4# 20/40 @ 20 BPM, 4850-5300 psi Stage 5' 50 bbls gelled diesel 6# 20/40 @ 20 BPM, 5101-5100 ps~ Stage 6- 60 bbls gelled diesel 7# 20/40 @ 20 BPM, 5200-5400 ps~ Stage 7' 60 bbls gelled diesel 8# 20/40 @ 20 BPM, 5530-5800 ps~ _ Stage 8' 40 bbls gelled diesel 9# 20/40 @ 20 BPM, 5850-6200 psi Stage 9' 81 bbls gelled diesel flush 10# 20/40 @ 18 BPM, 5600-5420 psi Fluid to recover: 859 bbls diesel Sand in casing' 427# 20/40 Sand in zone' 67,478# 20/40 Avg pressure' 5450 psi '- Dr~ Supervis~ August 13, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 FILE OP¥ A! ASKA, INC. Re: Our Boss Gyroscopic Survey Job No. AK-BO-70056 Well: 3M-19 Field: Kuparuk Survey Date: August 10, 1987 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-Sun/NL Industries, Inc. P.O. Box.190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARCO ALASKA, KLIF'ARUK ACASKA VERT I CAL t TF'TH · '-]i;PERRY-.'_--;LIN WELL ~E;LIRVEY I NG F:OMF'ANY ~ ~ ~ F'~tGE 1 · ~.,~. .:~4:;~::~:i~:::';::. ............ " .... ' ' ' ...... ": :'~'' ~ .......... ~'::~ ......... -., ......... ~ .............. ~.:~:~..:¥. ~...:~?<~.-.~:. ~-<::::..-;?~.~ ............. ~:::-.:~.'~s~.:~ .:~¥~:~..:~:.;.. < ;,:e-~:~ ;'~ ~':~ '<:' :" ................................................................................................. .~.~:~.~[s2~.......!.Ku.....!.~.~Z ............................................ ,J.~_~ LJM B E R_ ~K :~: 7.0058 KELLY BLoHINb ELEV = ' v::'-.: :: .-':¢~ .:: .:~ ~:~:'.. SE C T I ON CAL Ci~~EONG CLO~URE~ '":?:: "' :' ¥";'?:'~:"' ': ...... ::::::::::::::::::::::: .............. .:::`:?.i:;::.~;~:?~?i~?::??i~:~i~??~:~:?~:~i~t;~?:~i~:~l~~;~:~??~i~~~ ..... .:...,:::: ,..: ......... .:.:,:..: ::,,.:::~:::~ ,¥::., :...:~.: .~.:.::.:~.~;~ ........... ~::???:~::::::::::::::::::::::::.~.~:::~?::~,:,:~ ............... .~.::.:~..:... ,,::.:¥,: ....................... ======================= ~" ;:' ?:: :;: ;'::: ':.. ::C'::~.~':::::?:~t~:~.:. ;7;.:~ ~::::::.~:';1~:~:~:~;~;~;~ :~:;?(/7:.~:;~~? '~/ :. ':.<.:: · LS: ::::· ""~ ~ ~:::~.!:::~:/~::':."t.:::'~:~;'::':- :'L:' .:;' Z:: ?~::::~:.~??~:'?~¢:~j~:: :¢:::::::::::::::::::::::::::: .-.- .: . .: :. ,;.~.;-~;:;.:.::x~...-x... ;: .;.; ~ :~!~'~.~. '~.:~'~ TRLtE E;UB-~EA c:n~ IRSE COURSE DOG'LEG::'. "::':::'~:'::' ':':~:"::~:?:: """ '"~:~'?~'~::'~:~:'~'~'::~':~:~'~':: ..... ':~' ':':'~' ~:'~?~ . _ _ . ...................... . .... :..:.....:..:. ~~:::::.~::: .... :::.:.:; ::. ~::~i~ I"~E: F']"H DE:PTH DEG M I N DEGREE::; DEA/100 NiqRTH/F;AI ITH EAF;T / WEtgT ::;EF'T I FiN 20,:_') ............ 300 ..... 0,60 N O. 12 :.. '"'-'=; ':"':' 5> I 1, ?3 ,:.:I ,: .) .=, ,::,~;, ._-,; W 1 · ,:,7 oo, 66 ;:, 1 ,..,o, / ._, W 161.6.,- , -- ~ .. . u . ~, ~'--t-~ ~.:::.:~?¥.: .::;~s; .: :t. :! 54. ,:}~ 1070. ()6 29 19 S 81. 19 W 1.50 4:::. 49 S 248. ~8 W :::' ~:12' ,, ;'::~ 1-;;~, .............. ~,,:",. J~'z 11 v ?, ,, 7..]( ......................... ~'.~ ............. L'.~'.J ............ ......................... 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ARCO ALASKA~ INC. 3 M- 19 ............................ rr'l KUF'ARi_tI<i A L A E; K A : ..... VF__'RT}E']AL- ]:::~ECT I ON CA[~:UE~TED::::~ONE~ F:LO::;URE · ?7 ' ~ ~-.,>4 T RUE SU B~.~EA COUR SE ..... '~ L]~E?~i::..] D ' Vf.TF:T I C:AI_ VERT I C:AL INCI._ I NAT I ON ( F']"H I:LE F"H-,i ' DEP"Tiq .......... DEG M I Iq SF'IERRY-SUN WELL_ Sl_IRVEYING COMF'ANY F'AGE 2 ...... COMPUTAT I ON. DAT~-'. ::::.,: ..... ...:. ALJ}UST 11, 1987 JOB NUMBER AK-BO-70056 KEL. LY BUSHING ELEV. = 64.o('~ FT OF'ERATOR-MCGU I RE COURSE DOG-LEG T D Z RECT ~ ON SEVER Z TY RECTANGULAR C:00RD ~ N~TES VER T ~ CAL ...................................................................................................................................................................................................................................... DEGREES DEG/1 O0 NORTH/SOLITH EAST/NEST SECT Z ON 2100 :220C~ :2:30(} ................... :24 0 250 C, t :34 .'.!- ,, ::2 i 1 '7 80, 21 47 14 S 78 ''~' ' . .~ ~, 154. ~7 ¢. 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COMF'ANY .............. Z N~~)~D VfiLUES FOR 'EVEN 1000 FEET. :'OF ".~;~¢??)::)'~:~:: "-.':,::..5 ::. .... ::?:?::¢;~F~:~:::~:?~:..:::?~::. :~:;:;::':::- ....... 'T'RU~ SLIB~SEA TOTAL ;[:'~Z F:'-I"H DEPTFI NCIRTH / SOIJ-FH EAST/WEST D I FF'ERENC:E CORRECT I ON ~,:: ...:.: ......... O. O0 -64. O0 O. O0 O. O0 O. O0 ...... ,::,-z,=: o.:: 911 93 .............. · :, 3 66 S · oo. 75 N 24.':07 2~.','07 1. 7' 7/-. 4 ,'_!:~ 1 '7 l '2 46 1 ':: 9. '77 :_--: .... '.=, ....... ........... 7..: .... !5 (] W :2.-.: 2 :':: .~ 4 1 '9 o. 47 .2.:1.-5 ,:'-. ,, !56 :2402.5e 2:B9.06 S 1451.7.'_--: W 5:B:B. 44 :BO9.90 'B :t 42 26 :'5.:0., ~ '"'., :7.:22.11 S 21:34 O0 W ,:,,..,7. '74- :2:24.5:0 !~:::-5' 14],'-!q~:] ............. :=:i'¢~?i'?~" ':5~ ....... :-=::~";5_ .~. .' ',=-o._, .... ::,-; ,~.:, o'=,.:,.. ,:=._,. 31 .W1 it '="=',.-,,_,. 67' "" ~'",_.,~ ,. ~':'...:-, 448'7. 18 442:F.: . 18 47"4.70 ._,e .~6..,.=~ 70 W 1 o!~, 8,.~. ": /_ c? ~:i · .. I - -. 5?44.6..5 S 5722.49 W 2411.27 269.5'2 THE .... ' .... .~N THE. U,:,E · UF .. TH:R:E~:. ,::DI N:~N~.:I:UN:~,E~:,:.R:ADIU=, ';.::::E~'F:~;' :GUR~ATURE METHUD. ARCO ALASKA 3M-19 K'L.~F'ARLIK ALASKA SF'ERRY-SLIN WELL 'SLIRVEYINA C:OMPANY F'AGE 6 ....................... : "!~' i~:'i ~~ ~'~:~:':~? ~:~.~'~'.': ~ ~ ' i · ,.' ::. ..... ~:": :c:.:~:~.~:::~-'.. ~ :::' .:... '..~ :~:~",~'" :.,.: .~:::~ .:~?~'~:.~.~,' ,-~.~ .4:, ] :'," : . ........ ALIGLIST 11, 1987 ,JOB NUMBER AK-BO-70056 OF'ERA TOR-MC:GL! I RE , · .:::.~:¢:?t ~ ..... :.:?: ~;::: ....... IN~OLA~ED... ..... .... VALLIES FOR EVEN 100 FEET' OF SUB'SEA DEP~TH -..~...::~.?::: .?: :..¥: :,.... ~:.~..;~%~::~:~.::::::::.:.: ..... "t-~LID SLID-SEA TOTAL ;, E F"t"~.! ................................ DEP TH Nr:iR ........ TH'/S n L'~ T H E ~f~'~;:i~ 7' N'E~; :i 64 6,4. O0 O. 00 .t. 6 4 I ,:.'-, q :.. 00 :t. ,:)(}~ 00 2 <.'-., -'1 2 ,'.':':, .--"~. ,, 00 200.00 .364 32, 4 .. 00 3 C, C, ~ 00 464 .1.64L Oi:ii ........ 4()0.. O0 0. O0 0.00 0. 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W ..,_~::'-~,. 64 10.73 44.34 '.-3 254. 10 W 47.40 13.77 ......., ..~i-:, ..~.? 7 ::; 312.8, ;': W 6:3.66 16.26 ij;~!i~i!:.~i~ijiij~i~::hl .:. .::. ..... -.,: ~::!? :: .' ; .'.::. :::!;i 'i:.¢::':::!;::.~?i::.::~,i:~: ..::~~~!~!~·:::::~:::: '::' : ::::::::::::::::::::::::::::::::::::::::::::::?:!!?::!!'~':::::::::.:- ::::::::::::::::::::::::::::::::::::::::::: _~ ~~b~,~ ..... ........ ,: .:: ,:. :.:.... :.::..:.,--:.,. ...... · - SPERRY-F.;L~N WELL SURVEYING CriMPANY 7 ARCO AI_ASKA~ INE:. ' OF'ER~TOR-MC6U "1" R LIE S I_l B -S E A T O T A L. A'.SUF:~:~-~'./F~:~:-F :~(:.m.._ '"'~E~T'ii~'~L ............ REc:'T?~'N's<i'L~F: .... ~J~ooe~i'iNr~'~'E'.~ ....................... '~"~'s¥'0~ ........................................... 0'~'~'7'~]~'~' ................................................................................................... DEPTH ;('~iS:F:'TH DEPTH NORTH/SOUTH E~ST/NEST D ~ FF'EF~ENC:E CORRECT ~ ON ..................................................... 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AI..!GLIST 1 I, 1987 ,JOB NLIMBER AK-BO-70056 i;!:EEE'V'-"~i'iji~iFi'~t-iqS'-~i]E'(/.--:--;;_:,~'] DO-F'Y'~ ................. CIF'E RAT ClR- MC: GIJ ] RE .......... : ::.~ :,.~ ;:?:~;~ .: VaLL ED EVEN I NTER~ UKASE[ FOR FEET O~ SUB'SEA DEPTH ::::::" ....:.~?~,~:.:~:~ .~:::~ ..: · :...: :.... -:-:::;: . . 'TRLtE SLIB-'.E~EA TOTAL CAL. "VE~R'?"i'iZ:F~L ' F:ECT[f~NGi. J[:AR ..... ~:3':] 3RD [ NATES .............. ND2TO'Ei .................................. V'E'R'~"['i~:~'E ................................................................................ .................... P"!"H DE:F'TFI NCiF~T H/'.~;(:)L.I"I"FI EAST / WE:S'I" [) Z FF:'ERENCE C(:)RREC:T Z ON :::.=,4 '-'" '?,.q/-,'7 76 W I 160. '-'":' oO :3 .... 48, 20 _ _ . :364.70._,° z ~;'7o. o4 W 1210.._'~ 1 4 F,~ , 40 :3'7'7. :32:3 :30:38.60 W 1:25 9.71 49.4 () '::.j:".i':.'.L'-,':: 'F".:.:' S :2:1 '.-? 7 : '3'.' 7 W 1:308 : :::i: 4 2i.';I~':' 'i')} .............. . . '-t (" 4. 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S 4 .S~ :::_ A. . 1 ::3 W 1921 . .='_,,-,'-'.. 4.5 . ~....:,':' ":" 7 !5 '7 6 5 54:: 4. ~ 00 7:_::6,5 5764, :iii: 14':'-: ...."-' 64- ,.-, ..) ,]) (:, -- ,::: ............... 4:,':..:' 64-, ,'.".7:427 6,1 ,/_-,4. ,:,.Joo /::., 2 G 4, 870:3 6364, 8'? ": ~:: .... ,' ....... : (b .""~..J :[".':. SF'ERRY-F;UN WELL SURVEYING COMPANY F'AAF '-? ARCO ALASKA, I NC:. - . ......... -:::":-::~:.::?~:~::~:'~;:~:~ ....... ~::~::~:::?::~:~z~:~::t:~t~:~:::~:~:~:~::~:~:~?~4~:t~~~~~" . ....... ..... ~.:~:U.F'.A~UK ............................................................................................................................... h.l=~J.3JJs~ ........ {_~.~ ...... ~JP:~3Z ..................................... ,JOB ~LIMBER A~.A?:~.~. .................................................................................................................................................................................................................. KELL :':;..:::L :: ':: . ::::::::::::::::::::: , ~, , ,, . . ............. ; .:,:..:~ ~<.., -t"NIjE SI_ID-SEA TCITAL. v~::;~::T: ~:::;F-N~ .... ...Y.(.~.B.J~:f).h ................ F:..e(,?.Ta.~4.?!?.I::.A.~ ............. '?.~{P !..bF~.?.F.':~ ....................... .~.g~.:.T.?.F=~. ....................................... ?.g. EL~,2n_L ............................................................................................. i'}EP'TH DEPTH NC RTH/'.F 0 JTH EAS;T/HEST KII FFERENCE C:ORREC:T ION :: :::::::::::::::::::::::::::::':"::::.:: '"?~:,-:... ::::::....:: :.. .::::~::~:: O0 Pl6cx'~ O0 701. :36 ~ ~ ..... o ~o~,,:,. ~o W 2:0~7.53 O0 :~c'"' O0 726.=~_, o ........ . ~. ~ .,u. '-'~ ''~ 49.8~. 56 W 2101 . ;:, ::~ c:,('~ 5800 AO .... ,..:..:3'7 S PSOA7 61 W 2144. 18 42.65 0() 5900.00 780.93 S 5183.61 W 21:35.52 41.34 ...... ,4' -';:~-"~ ...... ;:: ....... L{- ::;4 '; .... ;::; ............................. >; .:;:::; ........... ,~'~: 00 600 (). 00 c, 0 :: .... 1 .:, ._, ~ / c,. 4,::, H .,: z. ~ 4. :: ..:, O0 6., 100, O0 00 62-.': 00, 00 00 6300.00 O0 &, 4C, 0. O0 / .:, <':. 4 :.:.'!: (i>~ '73 ARCO AI.A.':]KA, 3M- 19 t.::i U F' A R U K INC. · · ;:_:;F'ERRY-SLIN WELL SLIRVEYING COMF'ANY F'AGE 10 ............ ~": .'"~ :':' '~'~":T:~""'"',~:, '~'~: ........ ~ ~i:"E-~'~i~-~.~ ................... '%;4 '~: ~'::~~,~ '::'-.. · , ':, r - · .: :.-~ v .4~ ~,~. :': '?~.::~:. ~ .- · ' : ' ..... ::~:--.' .' ~ .... . ::;.:::.:~...~+~.;~:~.:l;..~:C~:~:`::.~:~`~:~.:~T:~{~` :: .- '.. ' ~.,':':. :.:--. ..... ::.{'-? ~:?'~q)~;~:~' ~.:¥~:Ps~F:=:.~:~. '::~:'~::C:~;~.~-:~:~b~, ~ r~ ~ ...b:'?:~'..." ' '...~" ~: ~ ~:~:.L~:~. :J ~ : .:' ~ · :.::~'~ ALIGLIST 11, 1987 ,JOB NUMBER AK-BO-70056 KELLY BUSHING ELEV. = 64.c~c~ FT. OF'ERATOR-MCGLII RE SLIB-SEA TOTAL V E R T I C ~i L R E C: 'l' A N G I_1L A R C: Cl iii R D I N A T E S " ............... :::. ,:,.:~ ..~o 5376.61 W TOP KUP.ARUK'..::C '.~: 6 ]. 3:3. ~'._,L~ o46':' .... 46 ~; ~,~.:,o,,,:, ~. 1 ,:,o W BA~,E~' KLtPARI IK_. ALAS;KA '.~ A S U R Ii.:.-. L] ....... :; F:' T H TRLIE V E R"I" i C A L. [liE!i,~':' 6172.96 61 '.:.~ 7.50 8 44. 0 84 7 4 ...... ]~i474 846.46:3 5:3'79. 1 :!ii: W T F;P KI._IF'ARUK A 9 01. :2 :!. ::J; .5 5:-F.: 1. :2:7 W ::_:.;I._IR V E Y D E F' ~r'H T~ TAL DEF: TH E.R iLLER -( i DERIVED USING D IL DEF'THS AND SPERRY SUN SURVEY DATA MARKER- TOP KL1F'Ai-&'IJK A E}~A:~};E t-:::i.._tF:'ARt_IK A F:'L. U (}'i J::3 A (.'.:J'::] T [I ]'-r3 TA L.. I:;i Eil F' -i" I--.t .b R .1; L. [... 1:7; R ::: 474 ,':-, 1 '.-? 7.5,:3,61:3 :'::. 50 o 4 ,",. 46 S ..... 5 :~:'-::" '~. ,.1. 8 W :'3474 61 t:~7. ~A_. 6133.50 :::::::::':" ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.: .".:::8~':~:4:6~ ........ 5:3.-~'~? . 18W :::~74 62,5~ 70 6205.70 ':'::'~ ........ ~ ~ .... · :::::::::::::::::::::::::::::::<:,::'[~::: 546._,. :.:,.~W ':":":? 1 6456 '"- "= '":' 7W . ."*W 63.'P. 2.3'P ~::.":' ;':::.. .: ..... ~:I':7~:.~8 .. 4 · _,6...'., 4 '""'-'" ':" /-.'=;,Fq":-, -/'.2:/-,4:=:'::-' 7:3 ?44.65:_:; 5722. c:, .-.. ,::,..., ...................................................................... ~._.~.;;;..;.:..::~. ,~ .................... -: ........ -:.:. .............................................................................................................................................................................................................................................................. ................................. ................................... :' : ~.¢.~ ............................................... · ...................... ',"2" C:OHPUT_. A T I'ON ::::;::D~::~. ...... .......... KUPARUK 31'1-19 SPERRY -SUN ;?- 5CRLE :- 1 INCH TO lO00. OO / lOOO. O ~!;: RBCQ RLRSKR, INC. AUOUST .-!O, ~987 RK-80-?Q056 TRUE NORTH O. O0 1500.00 3000.00 4500.00 7500.00 5PEF~BT 5CRLE :- 1 INCH TO 1500.00 / 1 KUPRRUK 3M-19 RK -00 -"70056 6553. 13 -- VERTICAL ice 'RLRSKR. INC. 8965 ~s~o. oo~o~o. oo,5~o. oo ~o'oo. oo PROJECTION ARCO Alaska, Irll Pos! Office I:;ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 22, 1987 Transmittal #: 6062 RETURN TO: ARCO Alaska, inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-1 3I-1 1R-4 1R-6 3C-14 3I-5 3M-16 3M-18 3M-19 .PBU Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey Static BHP Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey 'A' Sand PBU Bottomhole Pressure Survey. Kuparuk Well Pressure Report(Otis) 8-20-87 8-15-87 8-27-87 8-20-87 8-21-87 8-16-87 Kuparuk Well Pressure Report(Otis) Static 'C' Sand Kuparuk Well Pressure Report (Otis) Static Kuparuk Well PreSsure Report (Otis) 50-029-21413 50-029-21407 50-029-21331 50-029-21425 9-7-87 9-14-87 9-14-87 Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Ala$1~a, Inc. is a Subsidiary of AllanllcRichfleldCompany ARCO Alaska, Ii~ Post Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the folloWing items. Please acknowledge receipt and return one s~gned copy of this transmittal. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement'Bond Log 8-21-87 7689-8410 3M-14 Cement Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement Bond'Log 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt'Acknowledged: DISTRIBUTION: NSK Dri State of Alaska 1~ault(film) ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ¢~'" STATE OF ALASKA AL~v...,~A OIL AND GAS CONSERVATION CO, ,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate .~ Plugging [] Perforate [~ Pull tubing Alter Casing [] Other ~ CONPLETE 2. Name of Operator ARCO Alaska, inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 835' FNL, 1550' FEL, Sec.25, T13N, RSE, UM At top of productive interval 1675' FNL, 1647' FEL, Sec.26, T13N, RSE, UM At effective depth 1753' FNL, 1904' FEL, Sec.26, T13N, RSE, UM At total depth 1780' FNL~ 1992' FEL~ Sec.26~ T13N~ RSE~ UM 11. Present well condition summary Total depth: measured 8965'MD true vertical 6554 ' TVD 5. Datum elevation (DF or KB) RKB 64 ' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-19 8. Approval number 7-503 9. APl number 50-- 029-21737 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 8831 'MD feet Junk (measured) None true vertical 6456'TVD feet Casing Length Size Cemented Measured depth Conductor 80 ' 16" Conductor Report 115 'MD not available Surface 4443' 9-5/8" 1500 sx CS iil & 4480'MD 500 sx Class G Production 8889' 7" 325 sx Class G 8923 'MD ~ue Vertical depth 115'TVD 3463'TVD 6524'TVD Perforation depth: measured 8486'MD, 8490'MD, 8494'MD, 8500'-8544'MD true vertical 6206'TVD, 6209'TVD, 6212'TVD, 6216'-6248'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 8363' Packers and SSSV (type and measured depth) HRP-1-SP pkr (~ 8333' & TRDP-1A-SSA SSSV ~ 1759' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description inclUding volumes used and final pressure 12. 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl etlon Wel 1 Hi st~[y) Daily Report of Well Operations Copies of Logs and Surveys Run ~] Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW02/81 Date - 57 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ]County or Parish Alaska Ii North Slope Borough F~e~d Kuparuk River tease or Unit ADL 25523 Auth. or W.O. no. ITitle AFE J Comp let ion Nordic #1 API 50-029-21737 tAccounting cost center code Stat~ Alaska We~, ~-19 Operator ]A.R.Co.W~6.24% ARCO Alaska, Inc. Spudded or W.O. be~n IDate Complete I 9/3/87 Date and depth as of 8:00 a.m. Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W,O. 0015 hrs. I 9/03/87 9/04/87 9/05/87 7" @ 8923' 8831' PBTD, Perf'g 10.0 ppg NaC1/NaBr Accept ri~ @ 0015 hrs, 9/3/87. ND tree. Gearhart, RIH & pert f/8544'-8524'. NU & tst BOPE. RU 7" @ 8923' 8831' PBTD, Displ well w/diesel 7.0 ppg Diesel Fin perf'g f/8544'-8524' @ 4 SPF, 8524'-8504' @ 4 SPF, 8504'-8500' @ 4 SPF & 8494', 8490' & 8986' @ 1 SPF. RD Gearhart. Rn 253 its, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1759', HRP-i-SP Pkr @ 8333', TT @ 8363'. Set pkr. Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree. Displ well to diesel. 7" @ 8923' 8831' PBTD, RR 7.0 ppg Diesel Fin displ'g well w/diesel. Old TD ] New TD PB Oepth 8831 ' PBTD Released rigI Date ]Kind of r g 0715 hrs, 9/04/87 J Rotar7 Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil I Single Producing method ] Official reservoir name(s) Flowing I Kuparuk Sands I Potential test data Well no. Date ! Reservoir Producing Interval Oil or gasTest tim~ Production Oil"on test Gas per day Pump size, SPM X length Choke size T.P.' C.P. Water % GOR Grav{ty Allowable Effective date corrected The above is correct For~for~m ~OC~ ~,~ ~::) ,~/~/ ,,~ Drilling Superintendent see Procedures Man"0"al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well, J ]. Dl¥1~ton o! AtlantlcRIchfleldCompan¥ ARCO Alaska,~lnc.~ Pos! Of/I ~ox 100360 Anchora~,,I 41aska 99510-0360 Telephone 907 276 1215 Date: August 6, 1987 Transmittal # ~014 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-21 OH Lis Tapes 7-24-87 #72411 3M-19 OH Lis Tapes 7-17-87 #72409 3M-20 OH Lis Tapes 7~9-87 #72408 . ka 0il & Gas Cons. C0mmissio~ - ~ch0rag.~ ,. Receipt Acknowledged: DISTRIBUTION: M. Stanford Date: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other 2. N ~En,,e,,o f.Q pe r.ato r ~r~,u ~/asKas Inc 3. Address P. O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 835' FNL, 1549' FEL, Sec.25, T13N, RSE, UM At top of productive interval 1636' FNL, 1805' FEL, Sec.26, T13N, RSE, UM (approx) At effective depth 1666' FNL, 1924' FEL, Sec.26, T13N, RSE, UM (approx) At total depth 1692' FNL, 2014' FEL, Sec.26, T13N, RSE~ UM (approx) 11. Present well condition summary Total depth: measured 8965 ' MD feet Plugs (measured) true vertical 6549 ' TVD feet Effective depth: measured 8831 ' MD feet Junk (measured) true vertical 6452 'TVD feet Casing Length Size Cemented Conductor 80' 16" Conductor Report not available Surface 4443' 9-5/8" 1500 sx CS Ill & 500 sx Class G Production 8889' 7" 325 sx Class G 5. Datum elevation (DF or KB) R KB 64 ' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-19 8. Permit number 9. APl number 50-- o29-21 757 10. Pool Kuparuk River Oil Pool None None Measured depth 115'MD 4480'MD 8923 'MD True Vertical depth 115'TVD 3460'TVD 651 9 ' TVD Perforation depth: measured None true vertical No ne ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 7( / Commission Use Only (han~ Conditions of approval Notify commission so representative may witness' I ~,pprov~l No. [] Plug integrity [] BOP Test [] Location clearanceI Date Approved by BY LINNIE ~. Sllllli urne~ Commissioner by order of .,~ , ~ I the commission Date ~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior tO spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, parish or borough North Slope Borough ILease or Unit ADL 25523 JTitle Drill IState Alaska Kuparuk River IWell no. 3M-19 Auth. or W.O. no. AFE AK2661 Doyon #9 API 50-029-21737 Operator ARCO Alaska, Inc. Spudded or W.O. begun rate J,our Spudded 7 / 11/87 Date and depth aa of 8:00 a.m. 7/13/87 7/14/87 7/15/87 7/16/87 7/17/87 Complete record for each day reported 1330 hrs. 16" @ 115' 4490', (4375'), CBU Wt. 9.0, PV 11, YP 16, PH 8.5, WL 9.6, Sol 5 Accept rig @ 1030 hrs, 7/11/87. NU diverter sys. 1330 hfs, 7/11/87. Drl 12~' hole to 4490'. 220', .3°, N 7.5E, 583', 11.4°, S75.2W, 1129', 27.8°, S82.9W, 1878', 45.3°, S79.1W, 2251', 47.1°, SS0.SW, 2875', 46.8°, S85.5W, 3816', 48.1°, S85.1W, JARC W.I. Prior Status Spud well @ 56.24% if a W,O, 220.00 TVD, -.16 VS, N 0.57, E .08 580.95 TVD, 28.82 VS, S .27, W 29.08 1091.16 TVD, 217.07 VS, S 31.55, W 214.76 1689.96 TVD, 661.60 VS, S 99.45, W 654.10 1948.12 TVD, 930.66 VS, S146.42, W 919.16 2378.63 TVD, 1381.95 VS, S195.76, W1368.01 3015.49 TVD, 2074.10 VS, S269.30, W2d56.74 R[CEIVED 9-5/8" @ 4480' 4490', (0'), MU BHA Wt. 9.1, PV 11, YP 9, PH 9.0, WL 9.8, Sol 6 A; , sT¢~,~,..-~ ~. n 138 Short trip, circ, POOH. RU & rn 112 its 9-5/8", 36#, J-55 ..... csg w/FC @ 4397', FS @ 4480'. Cmt w/1500 sx CS III & 500 sx C1 "G" w/2% A-7 & 2 GHS D-6L. Displ using rig pmp, bump pl~SkaN~l & GaS diverter. NU &tst BOPE. MU BHA. Anchorage 4390'', 47.7°, S88.6W, 3400.00 TVD, 2498.26 VS, 292.70S, 2481.92W 9-5/8" @ 4480" 4490', (0'), POOH Wt. 8.9, PV 5, YP 2, PH 9.5, WL 10.8, Sol 4 TIH, tst csg to 2000 psi. DO flt equip & cmt + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl to 5745', POOH. 5015', 48.2°, S87.0W, 3818.92 TVD, 2959.79 VS, 310.52, 2945.68 5499', 47.8°, S81.5W, 4142.78 TVD, 3319.14 VS, 346.56, 3303.55 9-5/8" @ 4480' 7430', (1685'), Drl 8½" hole Wt. 9.2, PV 5, YP 4, PH 9.0, WL 11.2, Sol 6 Drl 8½" hole to 7430'. 5954', 47.1°, SS0.9W, 4450.47 TVD, 3654.32 rS, 397.84S, 3634.80W 7153', 46.8°, S78.7W, 5272.38 TVD, 4527.11VS, 538.13S, 4496.37W 9-5/8" @ 4480' 8860', (1430'), Drl 8½" hole Wt. 9.9, PV 11, YP 7, PH 9.0, WL 4.8, Sol 10 Drl 8½" hole to 8860'. Drl to 8860'. 7500', 47.2°, S78.0W, 5509'03TVD, 4780.44 VS, 589.38S, 4744.92W 8536', 43.8°, S74.6W, 6238.79TVD, 5511.06 VS, 774.94S, 5456.30W The above is correct Signature/'). j,~,~ . /~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ] Title J Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I i Accounting cost center code I Alaska i North Slope Borough Alaska Field Lease or Unit Well Kuparuk River ADL 25523 -19 Auth. or W.O. no. Title AFE AK2661 Drill Doyon #9 API 50-029-21737 Operator./~mco Alaska, Inc. IA'R'C°' w'1'56 · 24% .laband°nmentlC°strr°tal number °f wells (active °r inactive) °n thisIcenter priOrof thist° pluggingwell and Spudded or W.O. begun IDate IHour I Prior status If a W.O. Spudded 7/11/87 ! 1330 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 7/18/87 thru 7/19/87 7" @ 8923' 8965' TD, 8831' PBTD, (105'), RR 10.0 ppg NaC1 Drl to 8965', short trip, C&C, POOH. RU Schl, rn DIL/SP/SFL/CAL/GR f/8966'-4482'; cont w/GR to 1000'. Rn FDC/CNL f/8966'-8200' & 5850'-5580'. RD Schl. Make wiper trip, POOH, LD DP. RU & rn 205 its + marker jt, 7", 26#, J-55 BTC csg; csg stopped @ 8923'. (FS @ 8923', FC @ 8831') Cml w/100 sx lead slurry w/2% A-2, 1% R-7 & 2 GHS FP-6L & 225 sx C1 "G" tail slurry w/l% FL-19, .5% CD-31, .3% A-2 & 1GHS FP-6L. ND BOPE. Instl packoff, tbg head, adapter & master vlv; tst to 3000 psi. Freeze protect annulus. RR @ 0400 hrs, 7/19/87. 8965', 43.6°, S73.1W, 6548.87 TVD, 5804.62 VS, 857.38N, 5744.99E Old TD Released rig 0400 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD I PB Depth 8965' TD 8831' PBTD Date ~Kind of rig 7/19/87 I Rotary IType completion (single, dual, etc.) S'ingle Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct S ' g n~z.,~ J~.~.~' For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle Drilling Supervisor ARCO Alaska, Inc. Post Of,T"~-ox 100360 Anchora~ ,laska 99510-0360 Telephone 907 276 1215 Date: July 29, 1987 Transmittal f~009 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~'3M-19 Cyberlook 7-17-87 ,,3M-19 2" Porosity FDC 7-17-87 4482-8939 ,. 3M-19 5" Porosity FDC 7-17-87 4482-8939 -,3M~9 2" Raw Data FDC 7~17-87 4482-8939 ~ ~3M-19 5" Raw Data FDC 7-17-87 4482-8939 ' ~3M-19 2" Dual Induction 7-17-87 4482-8965 ' ,3M-~9 5" Dual Induction 7-17-87 4482-8965 I'3M 9~M~9 5" Dual Induction 4-24-87 115-3480 2" Porosity FDC 4-24-87 114-3494 ~'3M-9 5" Porosity FDC 4-24-87 114-3494 ''3M-9 2" Raw Data FDC 4-24-87 114-3494 ~,3M-9 5" Raw Data FDC 4-24-87 114-3494 -~3M-9 2" Dual Induction 4-24-87 115-3480 · .3M-21 5" Dual Induction 7~24-87 1000-10761 . ~3M-21 2" Dual Induction 7-24-87 1000-10761 · '3M-21 5" Porosity FDC 7-24-87 5400-10735 ~ .3M-21 2" Porosity FDC 7-24-87 5400-10735 · '3M-21 Cyberlook 7-24-87 10150-10680 . ~3M-21 2" Raw Data FDC 7-24-87 5400-10735 '-3M-21 5" Raw (+1.2") FDC 7-24-87 5400-10735 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Rathmell D & M L. Johnston (vendor.Package~received Yault(f~lm) 3~-9 a~ready ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany State of Alaska (+sepia) ARCO Alaska, InC.~ '%: Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. ¥. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, ' Gruber Associate Engineer JG/pk GRU1/31 Enclosure · .~ ., ~.:;. Alask~ 0il & Gas Cons. C0mm[ss[0r~ Anchorarj3 ARCO AI;'~sl,:a, Inc. is a Subsidiary of AllanticRichl!ieldCompany ,UR~ -"~Vi(;iNiTY MAP $~ALE I" NOTES: I. ALL COORDINATES ARE A.$J~. , ZONE 4. 2.ALL DISTANCES SHOWN ARE TRUE. ALL WELLS LOCATED IN SEC. 25, TI:~N, R8E, UMIAT MERIDIAN. · EblILE$ SIIdPSON LAGOON I HEREBY CERTIFY THAT I AM PROPERLY REGISIERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 3/8/87 D.S. 3 M ~-&'.-' --_~". ~ "t ~/4gth~ .~:.~ WELL CONDUCTOR AS-BUILT ~ · .~;.--.~':'~ ,.- ARCO ,202.17 6,016,225.10 506,156.45 6pl6,246.21 506,145.9 6,016,271.24 506,155.5 7 6,016 ,294. 28 506,165.0 20.685 6,016,$17.42 506,174.6 20.915 ,' ,6'58.$16 ,016,$ 40.48 S06,164.1: ; 58 ,016,$65.49 506,19:3.5 - 6,016,$86.92 506,Z05.1a 1042 6,016,456.13 506,252.0: I0 19 6 ,016 ,479.22 506,241 996 506,251.07 975 506,260.75 950 548.62 506,270.~0 '7'25,186 ', ~27' 571.45 506,1:79.77 :7 25.410 59 4.T$ 50~t289.40 7'2:3.659 904 016,617.99 506,t99.05 7'25.866 881' 6t016,641.02 506,$08.76 70eZ7'24'094 49056'$4'647 858' OIb, ,/7~,~g 5Ob, /17..;~ 70'Z7'/~/. 71~2 49°~ ASPs 'X' LATITUDE ;ITUDE Dis t.F.E.L. 1741' 25.1' 26.6' ,?~,,: ~.~' ~.~' ,~, ~3.s; ~.~: 1694 E3.3 ~6.T 1684' 23.2* 26.6* 1675' ~3. l* ~6.6' uss~', ~3.o', ~s.~' ,~. ~ ,. ~. ,~o7 ~,.~ ~.~ ,598', ~, 1' 26.4; t~os, ~.¢, ~.4, 1578, ~0.9, ~6.S, 15G9 ~0.9 ~6.5 1559' ~0.8' ~6.6' /~' ~.~' ~7~/' Z~.~' ZG.Z ' /7~' z~.O' ze.~ ' Alaska Inc. Dist. EN.L. 1296' 127:3' 1250', 1227' 1204', ll8l 1158~ 11:35 1112' $.ELEVATIONS ARE B.RM.S.L. 4.RER FIELD BOOK L87-$, POt. 7-I~ L87-1, R 7; L 87-$,P 51 * 55; 5.0.G.ELEVATIONS FROM Ir.l..ELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON ~M C~. ~,~:! [~,r ~:!. ~} MONUMENTS PER LHD ~ ASSOCIATES. July 2, 1987 Mr. J. B. Kewin Regional Drilling Engineer A~RCO Alaska, Inc. P. O. Box 100360 AnChorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3M- 19 ~RCO Alaska, Inc. Permit No. 87-64 Sur. Loc. 835'FNL, 1549'FEL, Sec. 25, T13N, R8E, UM. Btmhole Loc. 1685'F~T~, 2140'FEL, Sec. 26, T13N, R8E, UM. Dear Mr. Kewin: Enclosed is the ~approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. .To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~r~tr~y~yo~ ~, M ~ l ?'' './"/; C. V. Chatterto~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION COI,.MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill Redrill lb. Type of well. Exploratory [] Stratigraphic Test [-~x ,,Development Oil Re-Entry Deepen Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' , PAD 27' feet Kuparuk River Field Kuparuk River Oil Pool 3. Address 6. Property Designation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25523 ALK 2559 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 835'FNL, 1549'FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1636'FNL, 1805'FEL, Sec.26, T13N, R8E, UM 3M-19 #8088-26-27 At total depth 9. Approximate spud date Amount 1685'FNL, 2140'FEL, Sec.26, T13N, RSE, UM 07/06/87 $500,000 / 12. Distance to nearest 13.~,.,--.o~'i's~r~ce to nearest well 14. Number of acres in property 15"'0P~r~°l~'°'Aed~ o~-,-,u depth(MD and TVD) P8roperty line 35'~ Surface feet 16' ~ 560'TVD feet 2560 (6538'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 48 0 I~laximumsurface 2044 psig At total depth (TVP) 3202 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 4442' 35' 35' 4477' 3453' 1500 sx AS III & HF-E W 500 sx Class G blend ~-1/2" 7" 26.0# J-55 BTC 9029' 34' 34' 9063' 6538' 200 sx Class G(minimum HI--b W TOC 5,)0' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ¢ ~¢. ,...~ Surface Intermediate Production Liner Alaska 0ii & '-',,- --, Perforation depth: measured true vertical 20. Attachments Fi~n,g fee~,. Property plat [] BOP Sketch',~. Diverter Sketch~ Drilling program/~ Drilling fluid program ,,~.Tim~ v~ depth plot [] Refraction analysis [] Seabed repo'rt [] 20 AAC 25.050 requirements 21. I hereby c, eft~ that the forego~g is true and correct to the best of my knowledge · .-.. ' · Regional Drilling Engineer Signed//~_~.X~/'~~~~~ Title Date ,.~'~ /~/~ //~'--~"' ' ~" Commission Use Only (JLQ) PD2/~,0 Permit Nu~nber._ ~. ' I APl number I Appr,,o.v, aJ,,d~t~,., _, I See cover letter ,~-~.- [~ L/-- J 50-- (/-~ %~-- ~"! ? ~3;' ? I u//uz./~ /J for other requirements Conditions of approval Samples required [] Yes ~.,No Mud Icg required ~ Yes '~f, No Hydrogen sulfide measures [] Yes [] No Directibnal survey required ,'~..Yes. [] No O ther:Requiredw°rking'J;zr'essure~, E~3M;~~~ [] 5M; [] 10M; [] 15M by or der of Approved b Commissioner the commission Date Form 10-401 R'~-1-8~ Submit ir' cate KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC J L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD FMC DIVERTER ASSEHBLY WITH TWO 2-1 / 1§" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/lO" OUTLETS 5. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTC)rlATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., .REQUESTS APPROVAL OF THIS DIVERTER SYSTEH AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 i i . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 I 7 6 II I DIAGRAM ~1 13-5/8" 50(X3 PSI RSRRA BOP STA(;~< I. 16" - 2000 PSI TAN<CO STARTING HEAD 2. II" - 3030 PSI CASING HEAD 3. II" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOCL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/CHOKE ~ KILL LII~:.S G. 13-5/8"" - 5000 PSI ~ RAM W/PIPE RAMS ON TCP, 7. 13-5/8' - 5000 PSI ~ ACQ. IVIJLATOR CP~ACITY TEST I. CHE(]( AN:) FILL A~TOR RESERVOIR TO PROPER LEVEl. WITH HYDRAULIC FLUID. 2. ~ THAT A~TOR PRESSJRE IS 3000 PSI WITH 1500 PSI D(]t~TREAM C~ THE REGULATCE. 3. ~ TINE, 3]-EN CLOSE ALL UNITS SINIJLTAI~OIJS_Y ALL UNITS ARE CLOSED WITH ~ING Primp OFF. 4. RECORD CN NADC REP(:RT, THE ACCEFrT~ LCIt~ LIMIT IS 45 SE~ CLOSING TIhE AN3 1200 PSI RE34AINING L 5 2 13-5/8" BOP STACK TEST I. FILL BCP STAO( AhD CH(]~ MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LCX]( ~ SCRL=3~S IN ~ELLHEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN ~ WITH RUNNING JT A~D RUN IN LCX]<DOV~ LI~E VALVES ADJACENT TO BOP STAQ(, ALL OTHER VALVES AN) CHOKES SHOM_D BE OPEN. 4. PRE~ UP TO 250 PSI A~D HClD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI ~ HOLD FOR I0 MIN. BLEED PRES,gJRE TO 0 PSI. LI~E VALVES. CLOSE TOP PIPE RN, iS ~ HCR VALVES ON KILL ~ CHCI<E LI~.S. 6. TEST TO 250 PSI ~ 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LI~_S, AND WITH A 250 PSI LO// ~ 3000 PSI HIGH. TEST AS IN STEP 4. BO NOT PRESSURE TEST ANY O-~KE THAT NOT A FULL CLOSING POSITIVE SEAL CH(]<E. ~ION TEST (]-t(](E$ THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS ~ CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI ~ 3000 PSI. 9. OPEN BOTTCM PIPE RAMS, BACK OUT RUN'lING JT i0. CLOSE BLIND RAIV~ ~ TEST TO 250 PSI AhD 3000 PSI. II. OPEN BLIND RAMS A~D RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AND LI~ES ARE FULL OF NCN-FREE~ING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAI~]PIPE VALVES, KELLY, KELLY COQ<S, DRILL PIPE SAFETY VALVE, A~D INSIDE BOP TO 250 PSI AAD 3000 PSI. 13. RECCRD TEST I~FCI~MATION ON BLO/~OUT PREVENTER TEST FORM, SIGN, A~D ~ TO DRILLING SUPERVISOR. 14. PERFORM CCIVPLETE BOPE TEST AFTER NIPPLING UP Ai~ ., ' _WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 5100~4001 REV. 2 MAY 15,. 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. Lw~5 / ±h In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubimg, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. DE6A,SSER ! SHALE _ ,SHAKER,5 .~. STIR .,~..~, STIR _.~. STIR CENTRIFUOE TYPICAL PIUD SYSTEM SCHEMATIC LWK4/ih 'reserve Pit wing valve IIn~~ swab valve master valve pad center lPlan- View actuator valve g. I. valve I line psi gauge w. I. adaptor _~ Swab valve wing valve---,. flow'cross actuator valve Kuparuk Well-head Orientation ARCO ALASKA, INC. master valve VR plug-~ well line valve View from Pad Center (2) Loc (3) ...... 6-7 -z? 9. (9'thru 13) 10. 13) . 12. 13. (14 thru 22) (..5) BOPE (23 ~ 28) (6) ~ (29~tj~u,,~3,1) (6) Add: Geolo~y: rev: 01/28/87 6.011 Company 1. Is the permit fee atzached .......................................... ~ . YES NC) R.B"fARKS 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper d~.~rance from other wells . .' ................. pool ' 5. Is sufficient undedicated acreage available in this ............ 6. IS well to be deviated and is wellbore plat included ................ 7. Is operator the only affected parry ................................. 8. Can pezmit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. Does operator have a bond in force .................................. IS a conservation order needed ...................................... IS ad~dnistrative approval-needed ................................... IS the lease r~her appropriate ' Does the well have a unique name and m~her .......................... ,, Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will c~t tie in surface and intermed~ ~te or production strings ... Will cm~at cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension and burst.. 20 Is this well to be kicked off from an existing we!lbore ............ ; 21. Is old wellbore abandonmemt procedure included on 10-403 ............ 22. IS adequate wellbore separation proposed ............................ 23. Is a diverter system recp~ved ......................... .. ............. ..~ 24. Is the dz411~ng fluid program schematic and list of equipment adequate 4~¢ 25. Are necessary diagr~ and descriptions of diverter and BOPE attached. ,Cfc 26. Does BOPE have sufficient pressure rating - Test to $ ooo psig .. ,¢~ 27. Does the choke m~nifold comply w/API RP-53 ¢~ay 84) .................. 28. Is the presence of ~S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic am~]ysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32 Additional r~ts - · eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee IRii'AAL ~0. UNiT ON/OFF POOL CLASS $TATIYS AREA NO. 5/~ORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~V9 010,H02 VERIFICATION bI$~ING PA~, I HAEADER ~* ~72409 i*. TAPE HEADER ~* ~INUATION # REV!OU$ TAPE .OMHENT$ ~6 ~APE, ARCO ALASKA, INC:.::~ 3Mm.19, API $0u0:29'21737. · , NAME ;.EDIT:' .001 ~CE NA~E·· 1 ION It i N!~ b~NGTH I 1024 1~$ iNFORMATXON RECORDS ! ! ARCO ALASKA , ~PARUK ~ANGt RE$1 , iNC.. UNIT TYPE CATE SIZE CODE mu,gm, ummm: minim, mul! m'iuu ooo 000 O0 000 000 000 0 000 000 §gE ooo 000 UNIT T~PE CATE. aXlE CODE 000 000 OOt 065 VP: 0!0,HO2, VERI]LrlCATION LISTING~ PAGE 2 $CHbUNBERGgR ........ ~AN¥ m ARCO ALASKAw m. KUPARUK iUGH s NORTH SLOPE': m AbA&KA C'EB~CA?ION · SE~ 25 UM · 50 029-21737 ANAbYSTI DOUG.:'; :AAXNG., ~.,9.$25" P: 4479' 'YPE:FLUXD IiNB!Ty ~, 10.0 bB/G I&COSlT¥ =. 40.0 '~ m 9,5 'LUciD bOSS = 4,8 C3 IAXIMUM RECORDED TEMPERATURE = ~48 Dr 'ATR~X SANDSTONE ,~, 3N RANGE 81C 835". tnb & ~549" rgb .,. BlT'SIZE =: 8,5" TO 8971' fa Rid, AT BHT ,Vt;* OtO'H02 VERIFICATION: LISTING? PAGEi 3 DATA HAS' NOT .BEEN DEPTH SHIFTED -.: OVERLAYS' FlgbD PRINTS (SEE F.XLE EDXT,OO2':FOR'I,2 DUA.bINDUCTION SPHERICALLY FO~US£D DATA AVAXLABLEI COMP,ENSATED NEUTRON LOG (FDN) DATA AVAXLABLEI 8924*TO 8 8 DATA AVRXLABLEI 5910' T'O GA.M~ RAY VAXCA LEI .' TO 968 DATA FORMAT RECORD VP 0t0,H02 VERIFICATION bISTING PAGE~ 4 4 $ i ! 66 65 ~6 iATUM ~PECZFICA. TZON BLOCK5 iN:EM SERVXCE'iSERVXCE UNIT AP! APZ: APX FiLE CLASS OiL OHMM ~ DIL DX~ GAPE O0 FDN FDN FDN O0 42O FDN O0 000 ,. oo... 'ton LB O0 C.L: GAP! O0 CHh .LB O0 6:35 44 Ol O~ 01 O0 O0 0:1 O0 O1 0 0 0 0 0 0 0 ~ o 0 0 0 0 O, ~, o 0 0 0 0 0 0 0 0 0 0 0 0 0 ~DATA ~. ~EPT 8091~.0000 SFt, U 3'.0~07 ~H:OB DRHO OPXX iPHX 5:t,0254 NRAT 3,8928 RNRA .~CNL 430.2500 TENS 3284,0000 GR rCNb $2~,0000 TENS GR ENTRY 0 0:! ,l N i 68 00000000001,000 68 O000000OO0(~O00 68 000000:0000(~000 o, oooooooooo ,ooo ,, oooooooooo ,ooo i I 6 0 0 0000 I0.0 oooooooooooooo 60 oooooooooooooo '80 0 :0000 0 : 0 , . ~, ~o~o~oo~o~o , ,8oooooooooooooo , o0oooooooooooooo , Deoooooooooooooo I I "oooooooooooooo 60 oooooooooooooo ::,,o, .ON, ~ l LD SP e35.5000 GR 92.1250 92,12S0 RHOB 2,4277 ORHO 0,036t OPXI 't3,4706 CAGI 9,0000 NPHX 4~,6992 NRAT 3.4590 RNRA 4'0313 NCNb 195400000 rCNb 484.5000 TENS 5348.0000 GR 0999.2500 TENS e99902500 DEPT 9700,0000 SFLU 3,3474 Z~D 3,264t Xb~ 3,,3060 ~VP OIO.H02 VERIFICATION bISTING PAgE 5 !EPT ~EPT 'C/IL tHOB i~HZ ~CXb ~CNL triOS tBHZ ~CNb )EPT 649,5000 860000000 O~ 85~,~1'0000~500'~S!'64980 v .oo.oo 94000000 0195 8300,0000 4~ ~6582 0~,5000 820000000 397,250~ 8100,~000 e29,2500 -99~,2S00 - 9 O0 8000~0000 ~00,0000 .~.~oo~°° ~800,0000 GR ORHO RA~ I~:NS NRA? TIgN8 §RH0 NRAT TENS i~.o NRAT TENS SFbU srbu NRAT TENS SFLU NRAT TENS SFLU NRAT 2 "..9863 5280.0000 88'68'75 ~& 0 5:J8 ;0 0 ?~:.~it~ '0 oelB6 3'~0898 510880000 RNRA GR IbO: TEN8 GR' LD ~ENS DPHZ NRA R ~ 0,0220 LD 3,4158 ~'ENS . ,.,,o~ LD 6°1712 IENS RNRA m99g,lfSOO GR ': PPXl o999.2500 GR ' 4.0474 .,,.9976 487t'0000 3,6466 488&;00~0 18~081 $,~274 $ 0100000 .9~:~o 3,9864 : : 405445 /ICNb. TENS NCN~ CAb! , NCNb NCNb TENS VP 010,H02 VERIFICATION LIB~ING, PAGE 6 HOB ikOe ~:kOe )EPT ~N~ , CNL )EFT O0 O0 O0 770o,0000 · :, ~, !,~'. 0 , OP 7600*0000 :03215000 o::., ,, O0 0 ?300,0000 134'5000 - 9 .," · O0 999,2500 ?~00,0000 41,.tloo ~99~$00 GR DRHO NRAT TENS NRAT TENS NRAT TEN S , NRAT NRAT TENS ~RHO TENS 8FbU NRAT TENS :~0.00o0 4,7500 99,9.2500 6900°0000 SFLU ~:, -*99:~500 . "999, -999, -999 4,0889 0999*2$00 3,4078 RNRA GR" ZLD DPNZ RNR~ GR' LD ~ENS DPH! RNRA GR RNR~ OR RNNA iLO ENS DPUX RNRA GR LD DPHX RNRA OR PXX NRA GR RNRA GR XbO 4,~26 4.4 *~0 3,e978 . . ~:i' : . 4..~520 4: : :* 0 0 -:9~9'=$100 -9~'eSO0 4.401~ -999,~$00 3,6198 NCNb .... Tt~N8 '999 ~00 3,5270 ~VP rOlOeH021 VERIF!C~TiON blSTI~G PAGE 7 'CN~ 0999,.2500 TENS !EPT 6800,0000 ?'._ "~:' ~H:I -~ 00TENS ~,844 [p:az -:, oo 6600,0000 ~! !, O0 iF' 6soo.oooo ~ L ';l NRAT iE PT 6400.0000 SFbU ,:~0B ,t0,4844 ~RHO °990,2500 IPHI -990,2500 NRAT ~CNL -099,2500 TENS )EPT 6~!~.0000.7500 srbu I~o, .9 ,.~,oo ~.,o tPH! 0999,2~00 NRA~ )EFT 6200,~000 srbu jp. · I & ' ~ O)& ~HOB . ~PH! NR:A~ rCNb g09,iS 0 TENS I EPT 6100.0000 ,.o. .11~:~,oo rCNb -999,2500 TENS ~EPT' 6000.0000 SFLU .1;8. ,,,.~,oo · TEN8 09 :~ 0 TENS 3,3874 bM ::71. $ . !i:,.{l.i '999'"~ TENS 2.4747 lbN - tO o,99! 0 ',, 90 ..J , 0 3,2998 -090 .,,,:t18°o . kOs ~CNL. 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CENTER :OMPANY a ARCOgALAS, KA, XNC,- I, OROUGH = NORTH SLOPE ~"~FACEU~ LOCATZON = ALASKA ~ : 50'SEC' 25. T~P lSN RANGE: SE: 835' tnb. & 1549' FEb 029 2[ 737 ,OG ANALYST I DOUG SMITH iAI~INGFLUID' ma ~N9 6~5" P 44?9' - BIT SIZE )ENS~TY = lO,O LB/G RM [~8EOSITY = 40.0 $ RNr TO 897~' · or VP 01:0,H02 VERIFICATION LISTING: PAGE': AXZMUM RECORDED. TEMPERATURIC :=:~ !48 Dr .A~RZX SANDSTONE: RM AT BHT: TH:rSDATA HAS NOT:BEENDEP. H ************************************************************************************* ********************************************** SCHLUHBERGER LOGS:XNCLUD~D W~TH THIS FXLE~ (EDXT:.O02)i FORMATION DENSITy'CoMPENSATED bOG: (FDH) 1,2 iNCH DATA AVAZLABLEI' 893g* TO COMPENSATED NEUTRON:LOG::. (FDH) ~,,2 INCH DATA DATA fORMAT RECORD ** TYPE SiZE 4 1 REPR CODE ENTRY' 66 0 66 73 1~ ,VP 0~0,H02 VERi:F'ICATION blST]:NG PAGE !6 9 t6 0 I'A~UM 6PEC~F'iCAT~ON B~OCK$ NE~ SI~RVICE' SERVZCE UNI? AP! 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