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182-196
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. WSW-09 KUPARUK RIV UNIT WSW-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 WSW-09 50-029-20868-00-00 182-196-0 S SPT 2627 1821960 1500 250 260 260 260 100 210 210 210 OTHER P Adam Earl 6/3/2025 MIT-IA class 2 slurry inj. Well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT WSW-09 Inspection Date: Tubing OA Packer Depth 50 1800 1670 1650IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250604091036 BBL Pumped:0.7 BBL Returned:0.7 Wednesday, July 23, 2025 Page 1 of 1 Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed: Other: Replace TubingCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment Service 6. API Number:Stratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth 3835'feet 3394'feet true vertical 3457'feet None feet measuredEffective Depth 3476'feet 2926', 3124', 3292', 3550' feet true vertical 3119'feet 2626', 2798', 2949', 3188' feet Measured depthPerforation depth True Vertical depth Tubing (size, grade, measured and true vertical depth) L-80 L-80 J-55 3111' 3379' 3554' 2787' 3029' 3191' Packers and SSSV (type, measured and true vertical depth)2926' 3124' 3292' 3550' 2626' 2798' 2949' 3188'' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: Kuparuk Oil Pool13b. Pools active after work: 15. Well Class after work: StratigraphicServiceDevelopmentExploratoryDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Contact Name:Digital Signature with Date: Contact Email: Contact Phone:Authorized Title: 324-649 Sr Res Eng:Sr Pet Geo:Sr Pet Eng: WAGWINJ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB MRP-MP-SPR Packer: SLB BluePack Packer: SLB BluePack Packer: Baker Otis Sump SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 RWO/CTD Engineer 3060-3080', 3140-3182', 3191-3213', 3220-3229', 3244-3248', 3263-3297', 3321-3461' 2742-2759', 2812-2850', 2858-2878', 2884-2832, 2906-2909', 2923-2954', 2976-3105' measured true vertical Packer Representative Daily Average Production or Injection Data Tubing PressureCasing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 80' Well Shut-In measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 182-196 50-029-20868-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025648 Kuparuk River Field/ Tertiary Undefined Waste Disposal Pool KRU WSW-09 Plugs measuredJunk Length 3775' Casing 3431'3807' 2442' 80'Conductor Surface Production 16" 10-3/4" 44' 2255'2477' CollapseBurst ServiceDevelopment SPLUGSUSPGINJ Gas WINJ WAG Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 3-1/2" 3-1/2" 4.14" By Gavin Gluyas at 9:38 am, Feb 18, 2025 RBDMS JSB 021925 JJL 2/27/25 DSR-2/18/25 Page 1/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/5/2025 00:00 1/5/2025 03:45 3.75 MIRU, MOVE DMOB P RDMO off 3K-27 Move pit module office and shop complex to 1B Pad. On location at 345 AM. 0.0 0.0 1/5/2025 03:45 1/5/2025 08:00 4.25 MIRU, MOVE WAIT T Standby with sub base at 3K waiting for willow trasport assist to clear location. 0.0 0.0 1/5/2025 08:00 1/5/2025 15:00 7.00 MIRU, MOVE DMOB P Move Sub base to WSW-09. Set down rig on location. 0.0 0.0 1/5/2025 15:00 1/6/2025 00:00 9.00 MIRU, MOVE DMOB T Perform BOP Double Gate swap Rigs Double Gate Repaired, swap out rentals. 0.0 0.0 1/6/2025 00:00 1/6/2025 06:00 6.00 MIRU, MOVE DMOB T Continue Swapping Double gates. 0.0 0.0 1/6/2025 06:00 1/6/2025 08:30 2.50 MIRU, MOVE MOB P Hange tree in cellar, lay down pit liner in cellar and stage wellhead and DSA's. Set plywood on pit liner. MIRU on well spot sub over well. 0.0 0.0 1/6/2025 08:30 1/6/2025 10:00 1.50 MIRU, MOVE MOB P Spot pits set mats under stompers on pits. Work post move checklist, safe out stairs and landings, build handi-berm. 0.0 0.0 1/6/2025 10:00 1/6/2025 11:00 1.00 MIRU, MOVE MOB P Raise derrick install pins in derrick. 0.0 0.0 1/6/2025 11:00 1/6/2025 12:00 1.00 MIRU, MOVE MOB P Spool tuggers raise cattle chute start to bridle down blocks. Install containment around rig. 0.0 0.0 1/6/2025 12:00 1/6/2025 14:00 2.00 MIRU, MOVE MOB P Hang bridle lines in Derrick, Attempt to hook up inter connect steam line broken and leaking blew down lines and replaced fittings. 0.0 0.0 1/6/2025 14:00 1/6/2025 15:00 1.00 MIRU, MOVE MOB P Set kill tank and RU hardline. 0.0 0.0 1/6/2025 15:00 1/6/2025 20:00 5.00 MIRU, MOVE MOB P Load 11.3 ppg fluid into pits Load rig water into rig Condition 11.3 ppg to 9.1 ppg fluids *** Note: Inital pressure T/220, IA/230, OA/0 0.0 0.0 1/6/2025 20:00 1/6/2025 21:30 1.50 MIRU, WELCTL KLWL P Air test, fluid pack, test surface lines and rig up in cellar to 2,500 psi. 0.0 1/6/2025 21:30 1/6/2025 23:00 1.50 MIRU, WELCTL KLWL P Bring pump online 4 bpm/600 psi Shut down pump, bleed pressure. 0.0 0.0 1/6/2025 23:00 1/6/2025 23:30 0.50 MIRU, WELCTL OWFF P Check well for flow. No Flow 0.0 0.0 1/6/2025 23:30 1/7/2025 00:00 0.50 MIRU, WELCTL MPSP P Pickup T-bar MU and set IS-A BPV 0.0 0.0 1/7/2025 00:00 1/7/2025 00:30 0.50 MIRU, WELCTL MPSP P Perform rolling test from below BPV, 500 psi @ 1.5 bpm 0.0 0.0 1/7/2025 00:30 1/7/2025 01:00 0.50 MIRU, WELCTL RURD P Bleed pressure off, blow down and RD lines in cellar Bleed pressure between packoff and hanger 0.0 0.0 1/7/2025 01:00 1/7/2025 02:00 1.00 MIRU, WHDBOP NUND P ND & pull tree and adaptor, inspect hanger threads 0.0 0.0 1/7/2025 02:00 1/7/2025 06:00 4.00 MIRU, WHDBOP NUND P Set crossover spool onto tubing spool. 7 -1/16" 5k x 7-1/16" 3k NU BOPE, Install choke and kill hoses onto mud cross. Torque flanges. Hook up Koomey hoses to BOP. 0.0 0.0 1/7/2025 06:00 1/7/2025 08:00 2.00 MIRU, WHDBOP NUND P Install rams into double gate. 0.0 0.0 1/7/2025 08:00 1/7/2025 09:00 1.00 MIRU, WHDBOP NUND P PU test tools and make up XO #38 HT- 38 x 3-1/2" IBT 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 2/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/7/2025 09:00 1/7/2025 11:00 2.00 MIRU, WHDBOP BOPE P Shell Test BOPE 0.0 0.0 1/7/2025 11:00 1/7/2025 18:00 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular to 250/2500 on 3-1/2" test joint, UVBR's on 3-1/2" test joint, and LVBR's on 3-1/2" test joint. Test blinds rams. Test #1) CMV 1,2,3,16, rig floor Kill, Outer Test Spool Valve, Annular, 3.5", EUE, FOSV, Test #2) CMV 4,5,6. HCR Kill Inner Test Spool Valve, UPR. (Failed Inner Test Spool Valve), moved test hoses T/blanking Sub and cellar test spool valves. Test #3) LPR, HT-38 Dart, Test #4) UPR, CMV 7,8,9, Manual Kill, HT-38, TIW (open CMV 4,5,6, HCR Kill, Outer Test Spool Valve) Test #5) Hydraulic Super Choke & Manual Adjustable Choke (Open CMV 7 -9, 1,500 psi test), Test #6) UPR, CMV, 10,11, Manual Kill (open super and manual adjustable choke), Koomey Draw Down Test, remove test joint, Test #7) Blinds, CMV, 12,13,15, I-bop (open CMV 10,11), Test #8) Blinds, CMV 14, lower manual I -bop, (open CMV 8, 12,13), Test #9) HCR Choke, Blinds (open CMV 14), Test #10) Manual Choke, Blinds (openm HCR Choke), Test #11) Retest Outer test spool valve after replacement, Test #12) Inner Test spool valve after replacement. Perform accumulator test. Initial pressure= 3000 PSI, after closure= 1600 PSI, 200 PSI attained = 18 sec, full recovery attained =118 sec. UVBR's= 5 sec, Annular= 21 sec. Simulated blinds= 6 sec. LVBR’s= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2108 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Adam Earl. 0.0 0.0 1/7/2025 18:00 1/7/2025 19:30 1.50 MIRU, WHDBOP RURD P LD test tools and x-overs. Purge circ lines w/9.1 ppg brine. 0.0 0.0 1/7/2025 19:30 1/7/2025 20:00 0.50 COMPZN, RPCOMP BHAH P MU Baker ITCO spear, 4.4' no-go 0.0 34.6 1/7/2025 20:00 1/7/2025 20:30 0.50 COMPZN, RPCOMP FISH P Kelly up, engage hanger, pull 54 k free from pre-rig cut 2,907' 34.6 2,907.0 1/7/2025 20:30 1/7/2025 21:30 1.00 COMPZN, RPCOMP CIRC P Bring pump online 10 bbl away catch fluid, continue pumping diesel to surface, continue pumping conditioning hole. Diesel in returns, take overboard to cuttings tank. 315 bbl total pumped, 80 bbls to cuttings tank, 2,907.0 2,907.0 1/7/2025 21:30 1/7/2025 22:00 0.50 COMPZN, RPCOMP OWFF P Flow check well. Well on slight vacuum. 2,907.0 2,907.0 1/7/2025 22:00 1/7/2025 22:30 0.50 COMPZN, RPCOMP SVRG P Service rig, top drive tongs. 2,907.0 2,907.0 1/7/2025 22:30 1/8/2025 00:00 1.50 COMPZN, RPCOMP PULL P Pull 3.5" tubing to surface. laying down to pipe shed. 2,907.0 1,970.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 3/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/8/2025 00:00 1/8/2025 04:00 4.00 COMPZN, RPCOMP PULL P Continue pulling 3.5" tubing F/1,970' T/cut joint LD 93 joints, pup joint, and cut joint length = 13.88' Jts 63 and 64 are bent. 1,970.0 0.0 1/8/2025 04:00 1/8/2025 04:30 0.50 COMPZN, WELLPR SVRG P Service Rig 0.0 0.0 1/8/2025 04:30 1/8/2025 05:00 0.50 COMPZN, WELLPR CLEN P Clean RF and organize Unload pipeshed 0.0 0.0 1/8/2025 05:00 1/8/2025 06:30 1.50 COMPZN, WELLPR BHAH P MU fishing BHA w/overshot. UWT 40K 0.0 221.0 1/8/2025 06:30 1/8/2025 07:30 1.00 COMPZN, WELLPR PULD P PU DP single F/221' T/1354' 221.0 1,354.0 1/8/2025 07:30 1/8/2025 09:30 2.00 COMPZN, WELLPR MPSP P MU storm packer assembly, RIH & set at 97.3' per Baker rep. COE at 110.3'. PT T/1500 psi for 10 minutes. Good test. 1,464.0 1,464.0 1/8/2025 09:30 1/8/2025 10:30 1.00 COMPZN, WELLPR NUND P Rack back BOP on pedestal and secure. 1,464.0 1,464.0 1/8/2025 10:30 1/8/2025 15:30 5.00 COMPZN, WELLPR NUND T Remove DSA and spacer spool. Break bolts on wellhead. Nuts will not break free, going to use a nut splitter. 1,464.0 1,464.0 1/8/2025 15:30 1/8/2025 18:30 3.00 COMPZN, WELLPR NUND P ND Old Tubing Head, after torching off nuts, NU new Tubing Head with reducer bushing Install new 2-9/16" 5K IA/OA valves and dress with flanges. PT Packoff 250 psi/3,000 psi 1,464.0 1,464.0 1/8/2025 18:30 1/8/2025 21:00 2.50 COMPZN, WELLPR NUND P NU BOP Install test plug 1,464.0 1,464.0 1/8/2025 21:00 1/8/2025 21:30 0.50 COMPZN, WELLPR BOPE P Test BOP breaks to 5,000 psi on chart (good test) RD, blow down testing equipment. 1,464.0 1,464.0 1/8/2025 21:30 1/8/2025 22:00 0.50 COMPZN, WELLPR BHAH P Pull test plug 1,464.0 1,464.0 1/8/2025 22:00 1/8/2025 23:00 1.00 COMPZN, WELLPR CLEN P Prep and clean RF 1,464.0 1,464.0 1/8/2025 23:00 1/8/2025 23:30 0.50 COMPZN, WELLPR TRIP P Release storm packer fluid falling Pull packer free 1,464.0 1,464.0 1/8/2025 23:30 1/9/2025 00:00 0.50 COMPZN, WELLPR CIRC P Circulate down the DP to confirm hole is full and no gas. Air from empty DP to surface, clean returns 9.1 ppg in and out, shut down pump 1,464.0 1,464.0 1/9/2025 00:00 1/9/2025 02:00 2.00 COMPZN, WELLPR TRIP P Single IH w/BHA #5 overshot 1,464.0 2,904.0 1/9/2025 02:00 1/9/2025 02:30 0.50 COMPZN, WELLPR FISH P Circulate BU PUW=75k, SOW=70k Engage fish, PUH, PUW=95k observe seals pulling out of PBR and gravel pack extension 2,904.0 2,864.0 1/9/2025 02:30 1/9/2025 04:30 2.00 COMPZN, WELLPR CIRC P Circulate SxS, gas in returns at surface continue to circulate 2 SxS. Returns cleaned up. Montinor well 9.1 ppg in and out. 2,864.0 2,864.0 1/9/2025 04:30 1/9/2025 06:00 1.50 COMPZN, WELLPR TRIP P TOOH, racking back DP UWT 75K 2,864.0 220.0 1/9/2025 06:00 1/9/2025 07:00 1.00 COMPZN, WELLPR BHAH P LD BHA #5. LD overshot assembly and break grapple off cut joint. Seals and cut joint = 28.96' 220.0 0.0 1/9/2025 07:00 1/9/2025 07:30 0.50 COMPZN, WELLPR BHAH P PU BHA #6. Packer retreival tool. 0.0 224.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 4/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/9/2025 07:30 1/9/2025 08:30 1.00 COMPZN, WELLPR TRIP P TIH to 2923 then set down 30 K to engage collet. UWT 77K /SOW 70K 224.0 2,923.0 1/9/2025 08:30 1/9/2025 12:00 3.50 COMPZN, WELLPR JAR P Started jarring @100K & straight pull 175K and worked up to Jar at 175K and straight pull 300K. Circulating @ 1.5 bpm at 100 psi. Total jar licks 61 when weight fell off at 175K. Possible fish free. Perform post jarring inspection. 2,923.0 2,923.0 1/9/2025 12:00 1/9/2025 13:30 1.50 COMPZN, WELLPR TRIP P Trip out of hole F/2923' UWT 77K/ SOW 70K 2,923.0 224.0 1/9/2025 13:30 1/9/2025 14:30 1.00 COMPZN, WELLPR BHAH P LD BHA #6. LD packer retrieval tool with 6 missing slip dies and 1 missing collet. 224.0 0.0 1/9/2025 14:30 1/9/2025 15:00 0.50 COMPZN, WELLPR SVRG P Service top drive, blocks, black jak and draw works. 0.0 0.0 1/9/2025 15:00 1/9/2025 18:00 3.00 COMPZN, WELLPR WAIT T Waiting on Baker fishing tools from Baker shop in Deadhorse. 0.0 0.0 1/9/2025 18:00 1/9/2025 19:30 1.50 COMPZN, WELLPR BHAH P Fishing tools on location Load and MU fishing BHA #7 w/ITCO spear/grapple 0.0 128.3 1/9/2025 19:30 1/9/2025 20:30 1.00 COMPZN, WELLPR TRIP P TIH on stands F/129' T/2,803' 128.3 2,803.0 1/9/2025 20:30 1/9/2025 21:00 0.50 COMPZN, WELLPR CIRC P Circulate BU 2.0 bpm/163 pis Take dirty returns over board 33 bbls, bring back inside Mud Weight 9.1 ppg in and out. 2,803.0 2,920.0 1/9/2025 21:00 1/9/2025 23:00 2.00 COMPZN, WELLPR FISH P PUW=75k, SOW=70k Engage fish @ 2,920', pull 175k no movement Begin warming up and jarring on fish @ 150-175k, straight pull to 300k x 2,920.0 2,920.0 1/9/2025 23:00 1/10/2025 00:00 1.00 COMPZN, WELLPR SVRG P Perform derrick inspection and organize RF 2,920.0 2,920.0 1/10/2025 00:00 1/10/2025 00:30 0.50 COMPZN, WELLPR FISH P Work to get off fish, dragging 85k up hole, 2,920.0 2,898.0 1/10/2025 00:30 1/10/2025 01:00 0.50 COMPZN, WELLPR CIRC P Circulate BU, clean 9.1 ppg in and out 2,898.0 2,898.0 1/10/2025 01:00 1/10/2025 02:00 1.00 COMPZN, WELLPR TRIP P TOOH, F/2,898' T/2911' 2,898.0 2,411.0 1/10/2025 02:00 1/10/2025 03:30 1.50 COMPZN, WELLPR FISH P Overpull 150k, "Temporily Detained" Work pipe, jarring @ 175k, straight pull 300k 2,411.0 2,411.0 1/10/2025 03:30 1/10/2025 03:45 0.25 COMPZN, WELLPR FISH P Rotate to the right release from fish @ 2,402' 2,411.0 2,308.0 1/10/2025 03:45 1/10/2025 05:00 1.25 COMPZN, WELLPR TRIP P TOOH, F/2,402' T/128 UWT 65K 2,308.0 128.0 1/10/2025 05:00 1/10/2025 05:30 0.50 COMPZN, WELLPR BHAH P LD spear assembly BHA #7, inspect spear all BHA at surface. No indication/marks. 128.0 0.0 1/10/2025 05:30 1/10/2025 07:00 1.50 COMPZN, WELLPR TRIP P PU BHA #8 gutted overshot for wireline run. UWT 64K/ SOW 60K 0.0 2,366.0 1/10/2025 07:00 1/10/2025 12:30 5.50 COMPZN, WELLPR ELNE P RU AK wireline and perform a drift/CCL run. Locate top of packer at 2411' and noted nothing below the safety jt. Must have parted at the safety joint when jarring. Second E-line run was a string shot accross the packer. 2,366.0 2,366.0 1/10/2025 12:30 1/10/2025 13:00 0.50 COMPZN, WELLPR BHAH P POOH with BHA #8. 2,366.0 0.0 1/10/2025 13:00 1/10/2025 13:30 0.50 COMPZN, WELLPR BHAH P MU BHA #9 spear assembly OD 4.01" to fish packer. 0.0 2,414.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 5/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/10/2025 13:30 1/10/2025 16:00 2.50 COMPZN, WELLPR TRIP P TIH w/ITCO spear F/BHA T/2,411', engage fish 2,414', jaring @ 175k, straight pulling to 300k, working up to 400k, 100 licks w/no movement, release off fish w/1,200 ft/lbs torque. 2,414.0 2,414.0 1/10/2025 16:00 1/10/2025 16:30 0.50 COMPZN, WELLPR OWFF P OWFF, TOF=2,414' 2,414.0 2,414.0 1/10/2025 16:30 1/10/2025 17:30 1.00 COMPZN, WELLPR TRIP P TOOH on stands F/2,414' T/BHA 2,414.0 128.9 1/10/2025 17:30 1/10/2025 18:00 0.50 COMPZN, WELLPR BHAH P LD BHA #9 and inspect, nothing to report. 128.9 0.0 1/10/2025 18:00 1/10/2025 18:30 0.50 COMPZN, WELLPR CLEN P Clean and organize RF Lower E-line tools to ground and palletize 0.0 0.0 1/10/2025 18:30 1/10/2025 19:00 0.50 COMPZN, WELLPR SVRG P Service rig 0.0 0.0 1/10/2025 19:00 1/10/2025 21:30 2.50 COMPZN, WELLPR BHAH P MU BHA #10 w/joint 5.375"wash pipe 30.68', metal muncher crown shoe Swap out Jars and Intensifier 0.0 277.1 1/10/2025 21:30 1/10/2025 23:00 1.50 COMPZN, WELLPR TRIP P TIH w/BHA #10 277.1 2,410.6 1/10/2025 23:00 1/11/2025 00:00 1.00 COMPZN, WELLPR MILL P Tag fish @ 2,411' PUW=75k, SOW=70k Obtain pump parameters 4 bpm/320 psi RPM=65, TQ=1,075 ft/lbs Wash F/2,410.6' T/2411.3' 2,410.6 2,411.3 1/11/2025 00:00 1/11/2025 02:00 2.00 COMPZN, WELLPR MILL P PUW=75k, SOW=70k Pump parameters 4 bpm/320 psi RPM=65, TQ=1,075 ft/lbs, milling 800- 1000 ft/lbs Wash F/2,410.6' T/2411.3' Launch 20 bbl. sweep 300k vis, rubber returning to surface. 2,411.3 2,412.6 1/11/2025 02:00 1/11/2025 06:30 4.50 COMPZN, WELLPR MILL P Continue washing/milling over SC-1 packer as per baker fishing rep. PUW=75k, SOW=70k Pump parameters 2 bpm/100 psi RPM=50, TQ=1,075 ft/lbs., milling 1300- 1500 ft/lbs of torque Wash F/2,410.6 T/2,913..9' Launch 20 bbl. sweep 300k vis, rubber returning to surface. At 42" milled over packer it started moving down hole. 2,412.6 2,416.0 1/11/2025 06:30 1/11/2025 08:00 1.50 COMPZN, WELLPR MILL P Reaming and washing F/2413.9' T/2919'. 2,416.0 2,919.0 1/11/2025 08:00 1/11/2025 09:00 1.00 COMPZN, WELLPR CIRC P Pump 50 bbl 200 vis sweep SxS at 5.5 BPM/400 psi until clean fluids to surface. 2,919.0 2,919.0 1/11/2025 09:00 1/11/2025 09:30 0.50 COMPZN, WELLPR OWFF P Flow check well 2,919.0 2,919.0 1/11/2025 09:30 1/11/2025 10:30 1.00 COMPZN, WELLPR TRIP P TOOH F/2919' T 277' UWT 80K / SOW65K 2,919.0 277.0 1/11/2025 10:30 1/11/2025 11:00 0.50 COMPZN, WELLPR BHAH P LD wash over BHA #11 277.0 0.0 1/11/2025 11:00 1/11/2025 11:30 0.50 COMPZN, WELLPR BHAH P MU spear BHA #12 0.0 221.0 1/11/2025 11:30 1/11/2025 13:00 1.50 COMPZN, WELLPR TRIP P TIH F/221' T/2919' UWT 67K / SOW 62K Spear fish with 40K set down and 1.5K added up WT, notice some bobbles TOOH 221.0 2,919.0 1/11/2025 13:00 1/11/2025 14:00 1.00 COMPZN, WELLPR TRIP P TOOH 40-60 fpm with Fish F/2919' T/221' 2,919.0 221.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 6/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2025 14:00 1/11/2025 15:00 1.00 COMPZN, WELLPR BHAH P LD spear BHA #11 and fish OAL=20.34' 221.0 0.0 1/11/2025 15:00 1/11/2025 15:30 0.50 COMPZN, WELLPR BHAH P MU Spear, with DC x 6, and 4.01" spear. 0.0 221.0 1/11/2025 15:30 1/11/2025 16:30 1.00 COMPZN, WELLPR TRIP P TIH w/ITCO Spear BHA#12 PUW=80k, SOW=67k 221.0 2,872.0 1/11/2025 16:30 1/11/2025 17:30 1.00 COMPZN, WELLPR FISH P Wash down 2.0 bpm/340 psi engage fish T/2,940' PU and rotate string x 4 and set down 20 each time. 2,872.0 2,940.0 1/11/2025 17:30 1/11/2025 19:00 1.50 COMPZN, WELLPR TRIP P TOOH to see what we have F/2,940' T/BHA 2,940.0 221.0 1/11/2025 19:00 1/11/2025 22:30 3.50 COMPZN, WELLPR BHAH P Stand back collars in derrick, Brake out and LD fish to shed OAL=116.94' 221.0 0.0 1/11/2025 22:30 1/12/2025 00:00 1.50 COMPZN, WELLPR BHAH P MU Washover BHA#13 w/Wavy bottom burn shoe, 4 joints of 5.375" wash pipe, boot backets x 2, string magnet, bumper sub, jars, DC x 6, intensifier and crossover to HT-38. OAL=360.6' 0.0 360.6 1/12/2025 00:00 1/12/2025 00:30 0.50 COMPZN, WELLPR SVRG P Service Rig, Top Drive, floor tong dies and heads, etc. 125.5 125.5 1/12/2025 00:30 1/12/2025 01:30 1.00 COMPZN, WELLPR BHAH P Continue MU BHA #13, 125.5 360.6 1/12/2025 01:30 1/12/2025 04:00 2.50 COMPZN, WELLPR TRIP P TIH F/360 T/3036' PUW 85K/ SOW 70K 360.0 3,036.0 1/12/2025 04:00 1/12/2025 06:30 2.50 COMPZN, WELLPR MILL P Washing over screens F/3040 T/3171' Rotating 50 RPM, Torque 2.1-2.3K off bottom/ 2.5-3.5K on bottom Pumping 5 BPM, 400 psi Back reaming each stand. 3,036.0 3,171.0 1/12/2025 06:30 1/12/2025 07:00 0.50 COMPZN, WELLPR CIRC P Pump 25 BBL 200 vis sweep all the way around until clean. Observed minimal debre/sand at shakers. 3,171.0 3,171.0 1/12/2025 07:00 1/12/2025 08:00 1.00 COMPZN, WELLPR TRIP P TOOH F/3171' T/360' UWT 85K / SOW 70K 3,171.0 360.0 1/12/2025 08:00 1/12/2025 09:00 1.00 COMPZN, WELLPR BHAH P LD BHA #13, clean magnets/boot baskets. Rack back collars/washpipe. 360.0 0.0 1/12/2025 09:00 1/12/2025 09:30 0.50 COMPZN, WELLPR BHAH P MU Overshot BHA #14 0.0 5.0 1/12/2025 09:30 1/12/2025 11:00 1.50 COMPZN, WELLPR TRIP P TIH F/5' T/3054' UWT 77K / SOW 65K Set string weight down to ingage overshot PU and set slips in 7K tension. MU FOSV. 5.0 3,054.0 1/12/2025 11:00 1/12/2025 14:00 3.00 COMPZN, WELLPR ELNE P RU AK wireline 2.40" drift and CCL. RIH. Log CCL to verify cut and pull depths. 3,054.0 3,054.0 1/12/2025 14:00 1/12/2025 14:30 0.50 COMPZN, WELLPR SVRG P Service rig. grease crown, topdrive, blocks and blakjak. 3,054.0 3,054.0 1/12/2025 14:30 1/12/2025 19:30 5.00 COMPZN, WELLPR ELNE P RU Welltec to make cut at 3172'. One foot max below collar at 3171'. Log CCL, on depth, make WelTec cut @ 3,172', no indication at E-line unit, Driller felt bump on RF with hand on DP. TOOH w/E-line and LD tools Rig to the side E-line sheaves, shackles, wire rope socket, etc. 3,054.0 3,054.0 1/12/2025 19:30 1/12/2025 20:00 0.50 COMPZN, WELLPR TRIP P Prep RF for tripping operations 3,054.0 3,054.0 1/12/2025 20:00 1/12/2025 21:30 1.50 COMPZN, WELLPR TRIP P TOOH, w/Overshot BHA #14 TOF=3,172' 3,054.0 360.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 7/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/12/2025 21:30 1/12/2025 22:30 1.00 COMPZN, WELLPR BHAH P LD BHA #14 and fish Baker 0.006 gauge, centrilized screens. 360.0 0.0 1/12/2025 22:30 1/13/2025 00:00 1.50 COMPZN, WELLPR MU BHA #15 w/4 jts of 5.375" wash pipe, and new wavy bottom burn shoe 0.0 360.2 1/13/2025 00:00 1/13/2025 02:00 2.00 COMPZN, WELLPR TRIP P TIH w/Wavy Bottom Burn Shoe, BHA #15 360.2 3,172.0 1/13/2025 02:00 1/13/2025 05:00 3.00 COMPZN, WELLPR MILL P Washing over screens F/3171' T/3,289' Rotating 50 RPM, Torque 2.0-2.2K off bottom/ 2.5-3.2K on bottom Pumping 4 BPM, 252 psi Back reaming each stand. Circulate sweeps every stand, and after reaching TD. 3,172.0 3,289.0 1/13/2025 05:00 1/13/2025 05:30 0.50 COMPZN, WELLPR OWFF P OWFF 3,289.0 3,289.0 1/13/2025 05:30 1/13/2025 07:00 1.50 COMPZN, WELLPR TRIP P TOOH on stands F/3,289' T/surface 3,289.0 360.2 1/13/2025 07:00 1/13/2025 08:00 1.00 COMPZN, WELLPR BHAH P LD BHA #15 Wash over assembly 360.2 0.0 1/13/2025 08:00 1/13/2025 08:30 0.50 COMPZN, WELLPR BHAH P PU BHA #16 overshot assmbly 0.0 5.0 1/13/2025 08:30 1/13/2025 10:00 1.50 COMPZN, WELLPR TRIP P TIH on stands T/3170' 5.0 3,170.0 1/13/2025 10:00 1/13/2025 11:30 1.50 COMPZN, WELLPR TRIP P TOOH on stands F/3171' UWT 82K 3,170.0 5.0 1/13/2025 11:30 1/13/2025 13:00 1.50 COMPZN, WELLPR BHAH P Remove overshot BHA #16 from top of fish then LD 199' of screens. New top of fish at 3371.34' 5.0 0.0 1/13/2025 13:00 1/13/2025 14:30 1.50 COMPZN, WELLPR BHAH P MU 117' wash over BHA #17 0.0 361.3 1/13/2025 14:30 1/13/2025 16:00 1.50 COMPZN, WELLPR TRIP P TIH to top of fish at 3371' then wash over 117' of screens. 361.3 3,371.0 1/13/2025 16:00 1/13/2025 20:30 4.50 COMPZN, WELLPR MILL P PUW=82k, SOW=70k Bring pump online 4 bpm/284 psi Rot=65 rpm, Rot TQ=2.1k, off bottom, on bottom 3-4k RW=78k F/3,371' T/3,486' 3,371.0 3,486.0 1/13/2025 20:30 1/13/2025 21:00 0.50 COMPZN, WELLPR CIRC P Circulate 25 bbl sweep 3,486.0 3,486.0 1/13/2025 21:00 1/13/2025 21:30 0.50 COMPZN, WELLPR OWFF P Check well for flow 3,486.0 3,486.0 1/13/2025 21:30 1/13/2025 23:00 1.50 COMPZN, WELLPR TRIP P TOOH on stands F/3,486' T/BHA 3,486.0 360.1 1/13/2025 23:00 1/14/2025 00:00 1.00 COMPZN, WELLPR BHAH P LD BHA #17, 4 joints 5.375" wash pipe, etc. Clean magnets and boot baskets. 360.1 143.0 1/14/2025 00:00 1/14/2025 00:30 0.50 COMPZN, WELLPR BHAH P Continue LD BHA, brake off burn shoe. 143.0 0.0 1/14/2025 00:30 1/14/2025 01:00 0.50 COMPZN, WELLPR BHAH P MU gutted overshot BHA #18, 0.0 2.8 1/14/2025 01:00 1/14/2025 02:45 1.75 COMPZN, WELLPR TRIP P TIH, w/BHA #18 F/BHA T/3,371' 2.8 3,371.0 1/14/2025 02:45 1/14/2025 03:00 0.25 COMPZN, WELLPR TRIP P Pull DP into tension 7k 3,371.0 3,371.0 1/14/2025 03:00 1/14/2025 05:00 2.00 COMPZN, WELLPR ELNE P RU E-line, RIH, unable to get past top of fish, clean pickup, TOOH, RD ELine to the side, 3,371.0 3,371.0 1/14/2025 05:00 1/14/2025 06:00 1.00 COMPZN, WELLPR TRIP P Attempt to rotate over TOF. 3,371.0 3,372.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 8/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/14/2025 06:00 1/14/2025 09:00 3.00 COMPZN, WELLPR ELNE P RU E-line, RIH, unable to get past top of fish, clean pickup, TOOH, RD ELine to the side, Discuss plan forward with town. 3,372.0 3,372.0 1/14/2025 09:00 1/14/2025 10:00 1.00 COMPZN, WELLPR TRIP P TOOH from 3371' to surface. UWT 85K / SOW 67K 3,372.0 3.0 1/14/2025 10:00 1/14/2025 10:30 0.50 COMPZN, WELLPR BHAH P LD Overshot BHA #18 3.0 0.0 1/14/2025 10:30 1/14/2025 12:00 1.50 COMPZN, WELLPR BHAH P MU Dress off BHA #19 SOW 40K 0.0 247.0 1/14/2025 12:00 1/14/2025 13:00 1.00 COMPZN, WELLPR TRIP P TIH to 3306' UWT 80K / SOW 70K On highline power at 12:40. 247.0 3,306.0 1/14/2025 13:00 1/14/2025 14:30 1.50 COMPZN, WELLPR MILL P Dress off top 1.5' of tubing stub to 3373' at 3BPM Off Bottom 200 psi / TQ 3.1K On Bottom 400 psi / TQ 4K ROTWT 80K WOB 15K 3,306.0 3,373.0 1/14/2025 14:30 1/14/2025 15:00 0.50 COMPZN, WELLPR CIRC P Circulate and condition hole pump 30 bbl 200 vis sweep SxS until clean at 4BPM, 675 PSI, no flow test 3,373.0 3,373.0 1/14/2025 15:00 1/14/2025 16:00 1.00 COMPZN, WELLPR TRIP P TOOH F/3373' T/247' UWT 85K / SOW 67K 3,373.0 247.0 1/14/2025 16:00 1/14/2025 16:45 0.75 COMPZN, WELLPR BHAH P L/D BHA. F/ 247' to surface. Wear on pilot mill, good indications of dressing tubing stump on flat bottom mill. Debris found inside of pilot mill. 247.0 0.0 1/14/2025 16:45 1/14/2025 17:00 0.25 COMPZN, WELLPR BHAH P P/U Overshot W/O Grapple. 0.0 0.0 1/14/2025 17:00 1/14/2025 18:30 1.50 COMPZN, WELLPR TRIP P RIH w/ Gutted over shot from surface to 3342'. 0.0 3,342.0 1/14/2025 18:30 1/14/2025 19:00 0.50 COMPZN, WELLPR FISH P Engage top of stump w/ overshot @ 3373'. Set down 8K to confirm. P/U to original down weight set slips, and install E-line safety valve. 3,342.0 3,376.0 1/14/2025 19:00 1/14/2025 19:30 0.50 COMPZN, WELLPR ELNE P R/U AK E-line to make drift run. 3,376.0 3,346.0 1/14/2025 19:30 1/14/2025 20:30 1.00 COMPZN, WELLPR ELNE P AK E-line RIH w/ 2.4" Drift F/ Surface to 3423'. Observe ~50LB "bobble" passing through top of tubing. No over pull observed pullng through top of tubing. Drift back through top of stump 3x w/ similar results. POOH W/ AK E-line 3,376.0 3,346.0 1/14/2025 20:30 1/14/2025 21:00 0.50 COMPZN, WELLPR ELNE P R/D AK E-line. 3,376.0 3,376.0 1/14/2025 21:00 1/14/2025 22:30 1.50 COMPZN, WELLPR TRIP P POOH F/ 3373' to surface. 3,376.0 0.0 1/14/2025 22:30 1/14/2025 23:00 0.50 COMPZN, WELLPR CLEN P Clean and clear floor. Mobilize BHA compontents to the rig floor. 0.0 0.0 1/14/2025 23:00 1/15/2025 00:00 1.00 COMPZN, WELLPR BHAH P P/U BHA #21. Clean out BHA w/ string mills. 0.0 82.0 1/15/2025 00:00 1/15/2025 01:00 1.00 COMPZN, WELLPR BHAH P Cont. RIH w/ BHA F/ 82' to 172'. 82.0 172.0 1/15/2025 01:00 1/15/2025 02:00 1.00 COMPZN, WELLPR TRIP P RIH F/ 172' to 2900' 172.0 2,900.0 1/15/2025 02:00 1/15/2025 04:45 2.75 COMPZN, WELLPR REAM P Ream F/ 2874' to 3360' to clean packer setting depths. 60 RPM @ 2.2 K TQ 210 GPM @ 500 PSI. 2,900.0 3,360.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 9/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2025 04:45 1/15/2025 05:00 0.25 COMPZN, WELLPR WASH P Cut rotary and wash over stump and tag @ 3373'. Set down 10 K to confirm. Observe 80 psi pressure increase after swallowing stump. 210 GPM @ 500 PSI. 3,360.0 3,373.0 1/15/2025 05:00 1/15/2025 06:00 1.00 COMPZN, WELLPR CIRC P Pump 20 BBL High vis sweep, and circulate hole clean. 5.5 BPM @ 550 PSI Flow check well good. 3,373.0 3,373.0 1/15/2025 06:00 1/15/2025 07:00 1.00 COMPZN, WELLPR TRIP P TOH F/3373' T/172 UWT 85K / SOW 70K 3,373.0 172.0 1/15/2025 07:00 1/15/2025 07:30 0.50 COMPZN, WELLPR BHAH P LD BHA #21, clean magnets and boot basket. Minimal amount of metal recovered. 172.0 0.0 1/15/2025 07:30 1/15/2025 09:00 1.50 COMPZN, WELLPR ELNE P RU AK wireline and calibrate 24 arm caliper. 0.0 0.0 1/15/2025 09:00 1/15/2025 13:00 4.00 COMPZN, WELLPR ELNE P E-line log Caliper and GR/CCL. 0.0 0.0 1/15/2025 13:00 1/15/2025 16:30 3.50 COMPZN, WELLPR ELNE P E-line log CBL and GR/CCL. RIH to 3373', log up to surface. 0.0 0.0 1/15/2025 16:30 1/15/2025 17:00 0.50 COMPZN, WELLPR ELNE P L/D E-line tools. Clen and clear rig floor. 0.0 0.0 1/15/2025 17:00 1/15/2025 18:15 1.25 COMPZN, WELLPR ELNE P Mobilize guns to rig. PJSM w/ crew for handling perf guns. P/U tools and hot check firing head. 0.0 0.0 1/15/2025 18:15 1/15/2025 20:00 1.75 COMPZN, WELLPR ELNE P RIH and correlate off of previous logs to 3300'. Space out and fire guns placing perfs between 3060' and 3080'. E-line POOH w/ tools. 0.0 0.0 1/15/2025 20:00 1/15/2025 20:30 0.50 COMPZN, WELLPR ELNE P L/D guns, and R/D AK E-line equipment on the rig floor. 0.0 0.0 1/15/2025 20:30 1/15/2025 21:00 0.50 COMPZN, WELLPR SVRG P Service rig floor equipment. 0.0 0.0 1/15/2025 21:00 1/15/2025 21:15 0.25 COMPZN, WELLPR OTHR P Unannounced kick while out of the hole drill, and AAR held with crew. 0.0 0.0 1/15/2025 21:15 1/15/2025 21:30 0.25 COMPZN, WELLPR OTHR P Mobilize BHA compontents to the rig floor. 0.0 0.0 1/15/2025 21:30 1/15/2025 22:00 0.50 COMPZN, WELLPR BHAH P P/U BHA # 21 (clean out run for perfs) F/ Surface to 171' 0.0 171.0 1/15/2025 22:00 1/15/2025 23:00 1.00 COMPZN, WELLPR TRIP P RIH F/ 171' to 3000' PUWT: 84 K SOWT: 75 K 171.0 1/15/2025 23:00 1/15/2025 23:30 0.50 COMPZN, WELLPR REAM P Ream F/ 3000' to 3126'. 210 GPM @ 500 PSI 65 RPM @ 2.5 K TQ 3,000.0 3,126.0 1/15/2025 23:30 1/16/2025 00:00 0.50 COMPZN, WELLPR CIRC P Pump 20 BBL high vis sweep, circulate hole clean. 210 GPM @ 500 PSI 3,126.0 3,126.0 1/16/2025 00:00 1/16/2025 00:30 0.50 COMPZN, WELLPR CIRC P Circulate hole clean. 210 GPM @ 500 PSI 3,126.0 3,126.0 1/16/2025 00:30 1/16/2025 02:00 1.50 COMPZN, WELLPR TRIP P POOH F/ 3126' to 171' 3,126.0 171.0 1/16/2025 02:00 1/16/2025 03:00 1.00 COMPZN, WELLPR BHAH P L/D BHA F/ 171' to surface. 171.0 0.0 1/16/2025 03:00 1/16/2025 03:30 0.50 COMPZN, WELLPR CLEN P Clean and clear rig floor. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 10/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/16/2025 03:30 1/16/2025 04:00 0.50 COMPZN, WELLPR BHAH P P/U BHA # 23 (test packer). 0.0 15.1 1/16/2025 04:00 1/16/2025 06:30 2.50 COMPZN, WELLPR TRIP P RIH F/ 15' to 3100'. UWT 77K SOW 65K 15.1 3,100.0 1/16/2025 06:30 1/16/2025 07:00 0.50 COMPZN, WELLPR CIRC P Circ bottoms up @ 4BPM 200 psi 3,100.0 3,100.0 1/16/2025 07:00 1/16/2025 08:30 1.50 COMPZN, WELLPR MPSP P Set test packer at COE 3101' Close UPR, Test backside to 100 for 15 minutes, Test backside to 150 psi watching drillpipe for fluid movement. It apprears we are loosing fluid to lower perfs with no indication fluid is moving up hole. Pressure bleed to zero psi rapidly for both tests to new perfs. Doiscuss with town and relaese test packer and POOH. 3,100.0 3,100.0 1/16/2025 08:30 1/16/2025 10:00 1.50 COMPZN, WELLPR TRIP P TOOH with test packer F/3100' UWT 77K/ SOW 65K 3,100.0 0.0 1/16/2025 10:00 1/16/2025 12:00 2.00 COMPZN, WELLPR PUTB P RU to run 3.5" 9.3# L-80 EUE 8RD Lower Straddle Packer completion. MU as per tally, TQ connections to 3030 ft/lbs. Apply run-n-seal to pin/box. 0.0 302.0 1/16/2025 12:00 1/16/2025 14:30 2.50 COMPZN, WELLPR TRIP P RIH F/ 302' to 3373'. UWT 80K SOW 65K At 3377' seat down 7K and sheared screws. Continue down to fully located at 3380'. PU to neutral wt plus 1'. 302.0 3,373.0 1/16/2025 14:30 1/16/2025 15:30 1.00 COMPZN, WELLPR ELNE P RU FOSV and AK wireline. MU CCL/GR, RIH to 3330' and log up. 3,373.0 3,373.0 1/16/2025 15:30 1/16/2025 16:00 0.50 COMPZN, WELLPR ELNE P Send to logs to town, and verify setting depths. 3,373.0 3,373.0 1/16/2025 16:00 1/16/2025 17:30 1.50 COMPZN, WELLPR CIRC P R/U and Circulate in CI brine. Spot between packers, and around PBR. 3,373.0 3,373.0 1/16/2025 17:30 1/16/2025 18:30 1.00 COMPZN, WELLPR PACK P Remove circulating equipment, drop ball and rod. 3,373.0 3,373.0 1/16/2025 18:30 1/16/2025 19:30 1.00 COMPZN, WELLPR OTHR P R/U equipment for setting packer. 3,373.0 3,373.0 1/16/2025 19:30 1/16/2025 20:30 1.00 COMPZN, WELLPR PACK P Stage up pumps to 1000, and 2000 PSI holding pressure for 3-5 min. Continue to ramp up to 3000 PSI, at 3000 PSI observe seal assy shear out from PBR. Continue to increase to 3500 PSI, and hold for 30 min to fully set SLB packers per SLB procedure. 3,373.0 3,373.0 1/16/2025 20:30 1/16/2025 21:00 0.50 COMPZN, WELLPR OTHR P R/D test equipment, L/D 2 joints of DP. 3,373.0 3,089.0 1/16/2025 21:00 1/16/2025 22:00 1.00 COMPZN, WELLPR CIRC P CBU @ 210 GPM @ 200 PSI 3,089.0 3,089.0 1/16/2025 22:00 1/16/2025 23:00 1.00 COMPZN, WELLPR TRIP P POOH F/ 3089' to surface. 3,089.0 0.0 1/16/2025 23:00 1/16/2025 23:30 0.50 COMPZN, WELLPR BHAH P Inspect seal assy. Wrap seal areas, and L/D. 0.0 0.0 1/16/2025 23:30 1/17/2025 00:00 0.50 COMPZN, WELLPR SVRG P Service rig, grease top drive, crown, and rig floor equipment. 0.0 0.0 1/17/2025 00:00 1/17/2025 00:30 0.50 COMPZN, WELLPR BHAH P P/U and inspect test packer. 0.0 0.0 1/17/2025 00:30 1/17/2025 02:00 1.50 COMPZN, WELLPR TRIP P RIH w/ Test packer from surface to 3040' SOWT: 60K PUWT: 89K 0.0 3,040.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 11/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/17/2025 02:00 1/17/2025 02:30 0.50 COMPZN, WELLPR MPSP P Slack off and tag top of PBR @ 3089.39' set down 10K. Calculate element placement. P/U 1' 3,040.0 3,089.0 1/17/2025 02:30 1/17/2025 03:00 0.50 COMPZN, WELLPR CIRC P CBU 168 GPM @ 200 PSI 3,089.0 3,089.0 1/17/2025 03:00 1/17/2025 03:30 0.50 COMPZN, WELLPR RURD P Rack back stand of drill pipe. P/U pup joints for space out. 3,089.0 3,089.0 1/17/2025 03:30 1/17/2025 04:00 0.50 COMPZN, WELLPR MPSP P Tag top of PBR w/ 5K. P/U .5' mark pipe, and set test packer. 3,089.0 3,088.0 1/17/2025 04:00 1/17/2025 04:15 0.25 COMPZN, WELLPR OTHR P R/U test equipment 3,088.0 3,088.0 1/17/2025 04:15 1/17/2025 05:30 1.25 COMPZN, WELLPR PRTS P Pressure test upper straddle packer below test packer to 1800 PSI for 30 min: 3,088.0 3,088.0 1/17/2025 05:30 1/17/2025 08:00 2.50 COMPZN, WELLPR PULD P LD DP from 3032' to surface. UWT 75K / DWT 65K LD test packer 3,088.0 0.0 1/17/2025 08:00 1/17/2025 08:30 0.50 COMPZN, WELLPR SVRG P Service power tongs and draw works. 0.0 0.0 1/17/2025 08:30 1/17/2025 09:00 0.50 COMPZN, WELLPR WWWH P Pull wear ring. Wash BOP stack at 7 bpm 400 psi. 0.0 0.0 1/17/2025 09:00 1/17/2025 10:00 1.00 COMPZN, RPCOMP PUTB P RU to run 3.5" 9.3# L-80 EUE 8RD completion. RU power tongs, Halliburton spooler & sheave. 0.0 0.0 1/17/2025 10:00 1/17/2025 15:00 5.00 COMPZN, RPCOMP PUTB P Terminate gauge mandrel and feed through packer per Halliburton rep. 0.0 185.0 1/17/2025 15:00 1/17/2025 21:00 6.00 COMPZN, RPCOMP PUTB P MU Upper completion. installing one tec wire clamp on each collar. 185.0 3,060.0 1/17/2025 21:00 1/17/2025 21:30 0.50 COMPZN, RPCOMP PUTB P Continue to RIH and fully locate @ 3113.05' observed 3K seal drag. Set down 5K to confirm. L/D JTS. 100, 99, 98, and 97. 3,060.0 3,113.1 1/17/2025 21:30 1/17/2025 23:00 1.50 COMPZN, RPCOMP PUTB P Calculate space out and P/U 8.2,8.1,5.12,4.21' pup joints. P/U JT. 97 P/U tubing hanger, and landing joint. 3,313.1 3,080.0 1/17/2025 23:00 1/18/2025 00:00 1.00 COMPZN, RPCOMP CIRC P Circulate in CI fluids. HAL and FMC terminate Tec wire at the hanger. 3,080.0 3,080.0 1/18/2025 00:00 1/18/2025 00:45 0.75 COMPZN, RPCOMP CIRC P Continue to Circ in CI fluids @ 3.5 BBL/Min @ 120 PSI. 3,080.0 3,080.0 1/18/2025 00:45 1/18/2025 01:15 0.50 COMPZN, RPCOMP THGR P Suck out stack and land tubing hanger. Final depth of uppercompletion 3111.05'. RILDS. 3,080.0 3,111.1 1/18/2025 01:15 1/18/2025 02:00 0.75 COMPZN, RPCOMP OTHR P R/U test equipment. 0.0 0.0 1/18/2025 02:00 1/18/2025 02:30 0.50 COMPZN, RPCOMP PACK P Line up on tubing pressure up to 500 psi and hold for 5 min. Stage up to 1000 PSI, and hold for 5 min. Stage up to 2000 PSI and hold for 5 min. Pressure up to 3500 PSI for 10 min. 0.0 0.0 1/18/2025 02:30 1/18/2025 04:30 2.00 COMPZN, RPCOMP PRTS P Hold pressure for 5 more minutes, pressure dropping. Bleed off pressure, purge test lines, and pressure up to 3500 PSI and hold for 30 min: Good test. Bleed tubing down to 1500 PSI, and hold pressure. Line up on IA, and attempt to pressure test IA. Unable to get over 800 PSI. Shut down pumps. IA on a vac. 0.0 0.0 1/18/2025 04:30 1/18/2025 05:30 1.00 COMPZN, RPCOMP PACK T Line up on tubing, and pressure up to 4000 PSI, and hold to verify packer has fully set: GOOD TEST. Bleed tubing to 1500 PSI, and hold. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 12/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/18/2025 05:30 1/18/2025 12:00 6.50 COMPZN, RPCOMP PULL T Fill IA, and rig up to IA attempt to test IA again. IA bleeds down right away. Discuss with town and decide to hook up Halliburton Opsis gauge and presuure up on IA and see an instant increase on IA below packer. Packer is bad. Packer should pull at 180K total hook load. We pulled to 195K and it did not budge. Pressure up tubing to 2000psi and started to pull in 5K increments until packer released at 155K. 0.0 0.0 1/18/2025 12:00 1/18/2025 16:00 4.00 COMPZN, RPCOMP TRIP T POOH with upper completion. Changing out EUE ring seals on all stand tops. LD jewerly to pipe shed. UWT 55K 3,111.0 0.0 1/18/2025 16:00 1/18/2025 16:30 0.50 COMPZN, RPCOMP OTHR T Set wear busing, and RILDs. 0.0 0.0 1/18/2025 16:30 1/18/2025 19:30 3.00 COMPZN, RPCOMP PULD T RIH F/ Surface to 3050' w/ test packer. 0.0 3,050.0 1/18/2025 19:30 1/18/2025 20:00 0.50 COMPZN, RPCOMP MPSP T Set test packer, purge lines, and line up to test CSG. 3,050.0 3,050.0 1/18/2025 20:00 1/18/2025 20:30 0.50 COMPZN, RPCOMP PRTS T Pressure test CSG to 1800 PSI for 30 MIn: GOOD TEST. 3,050.0 3,050.0 1/18/2025 20:30 1/18/2025 23:30 3.00 COMPZN, RPCOMP PULD T POOH L/D DP F/ 3050' to surface. L/D test packer. 3,050.0 0.0 1/18/2025 23:30 1/19/2025 00:00 0.50 COMPZN, RPCOMP WAIT T Wait on replacement packer from SLB. Rig crew service equipment, and work on housekeeping through out the rig. 0.0 0.0 1/19/2025 00:00 1/19/2025 03:00 3.00 COMPZN, RPCOMP WAIT T Wait on replacement packer from SLB. Rig crew perform maintenance on rig equipment. Work on housekeeping through out the rig. R/U HAL spooler, and Pipe handling equipment. 0.0 0.0 1/19/2025 03:00 1/19/2025 04:30 1.50 COMPZN, RPCOMP PUTB T PJSM P/U tubing F/ Surface to 188' 0.0 188.0 1/19/2025 04:30 1/19/2025 07:00 2.50 COMPZN, RPCOMP PUTB T Run TEC wire through packer to Opsis gauge mandrel. Pressure test gauge connection. Hnag sheave in derrick. 188.0 188.0 1/19/2025 07:00 1/19/2025 12:00 5.00 COMPZN, RPCOMP PUTB T MU and RIH with upper completion. Run and Seal pipe dope. Torque to 3030 Ft- lbs. Test Tec wire every 1000'. Install clamp every connection. Installed 100 clamps total. UWT 55K / SOW 49K. Space out. 188.0 3,091.0 1/19/2025 12:00 1/19/2025 14:00 2.00 COMPZN, RPCOMP DISP T Pump 82 bbls 9.1 CI NaCl while FMC and Halliburton terminate wire through hanger. 3,091.0 3,091.0 1/19/2025 14:00 1/19/2025 16:30 2.50 COMPZN, RPCOMP PACK T Line up on tubing and pressure up to 3600 psi for a 30 minute 3500 psi test. Pressure went down then up with the heaters turning on and off so we bumped it up to 3700 psi after the heat on the rig floor stabilized. We topped off the IA and the pressue guge under the packer went up, so we believe the packer element is not expanded. Called town and increased pressure to 4000psi on tubing side in an effort to shear the screws and set the packer element. 3,091.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Page 13/13 WSW-09 Report Printed: 2/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/19/2025 16:30 1/19/2025 17:30 1.00 COMPZN, RPCOMP PRTS P Line up on OA, and pressure test IA/Packer to 1800 PSI for 30 min: GOOD TEST. Monitored OA pressure guage (no pressure transfer to OA), and Opsis guage for pressure transfer below the packer (no pressure transfer) during the test. Bleed tubing and sheared SOV in GLM, observed pressure drop in IA through GLM. 0.0 0.0 1/19/2025 17:30 1/19/2025 18:00 0.50 COMPZN, RPCOMP OWFF P Monitor tubing and IA for flow. Blow down lines, R/D test, and HAL equipment on the rig floor. 0.0 0.0 1/19/2025 18:00 1/19/2025 18:30 0.50 COMPZN, RPCOMP MPSP P Pull landing jt. Set BPV in hanger. Line up and test from below to 1000 PSI for 10 min: Good test 0.0 0.0 1/19/2025 18:30 1/19/2025 23:00 4.50 COMPZN, WHDBOP NUND P Rig crew prep, and perform between wells maintenance of the BOP. 0.0 0.0 1/19/2025 23:00 1/20/2025 00:00 1.00 COMPZN, WHDBOP NUND P N/D BOP, 0.0 0.0 1/20/2025 00:00 1/20/2025 01:30 1.50 COMPZN, WHDBOP NUND P N/D BOP, and rack back. 0.0 0.0 1/20/2025 01:30 1/20/2025 02:30 1.00 COMPZN, WHDBOP NUND P HAL, Terminate line at well head. 0.0 0.0 1/20/2025 02:30 1/20/2025 06:30 4.00 COMPZN, WHDBOP NUND P N/U Tree and adaptor flange. FMC test hanger neck void to 5000 PSI for 10 min. Test Tree to 5000 PSI for 10 min. Pull BPV. 0.0 0.0 1/20/2025 06:30 1/20/2025 09:00 2.50 DEMOB, MOVE FRZP P R/U Circulating lines, and LRS in the cellar. LRS pressure test lines 5000 psi for 10 minutes. Pump 65 BBLS fo diesel freeze protect at 2BPM/ 1000psi. Hook up jumper and u-tube well. Final pressures on well OA/IA/TBG= 10psi/50psi/50psi. Release rig at 09:00. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 1/20/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 3,476.0 WSW-09 10/14/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update RWO WSW-09 2/10/2025 pottej Notes: General & Safety Annotation End Date Last Mod By NOTE: WSR Review 9/11/2023 pproven 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 36.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 35.1 2,476.8 2,254.6 45.50 K-55 BTC PRODUCTION 7 6.28 32.3 3,807.3 3,431.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 3,111.4 String Max No… 3 1/2 Set Depth … 2,787.0 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.0 30.0 0.13 Hanger 7.000 FMC Tubing hanger w/feedthrough port for tec wire FMC GEN 4 2.992 2,871.9 2,579.8 31.73 Mandrel – GAS LIFT 5.960 3.5"x1.5" MMG S/N 24758-08 w/SOV 1300psi IA>TBG SLB MMG 2.920 2,925.9 2,625.9 30.96 Packer 5.996 3.5" x 7" SLB MRP-MP-SP"R feedthrough packer S/N C16P-0096 SLB MRP- MP-SPR 2.942 2,982.2 2,674.3 30.48 Sensor - Discharge Gauge 4.851 3.5" Dual /sensing Gauge Mandrel HT#D2217311 w/Opsis Gauge Installed HAL OPSIS 2.933 3,038.1 2,722.8 29.50 Nipple - X 4.500 2.813" X Nipple S#0004993357-0 HAL X-nipple 2.813 3,059.5 2,741.4 29.03 Mandrel – GAS LIFT 5.960 3.5"x1.5" MMG S/N 24758-07 w/DV SLB MMG 2.920 3,088.7 2,767.0 28.40 Seal Assembly 4.000 Baker Seal Assembly (2' above fully seated) Baker 80/40 2.992 Top (ftKB) 3,089.1 Set Depth … 3,379.3 String Max No… 3 1/2 Set Depth … 3,029.1 Tubing Description Tubing - Waste Injection Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,089.1 2,767.4 28.39 PBR 5.880 Baker PBR - pinned to 55K Baker 80/40 2.992 3,123.8 2,798.0 27.67 Packer 5.992 3.5" x 7" SLB BluePack packer (target 3120') S/N C24P-0239 SLB BluPak 2.885 3,201.9 2,867.6 26.12 Mandrel – GAS LIFT 5.960 3.5"x1.5" MMG S/N# 24758-06 w/DV SLB MMG 2.920 3,292.1 2,949.2 24.45 Packer 5.992 3.5" x 7" SLB BluePack packer (target 3292') S/N C24P-0198 SLB BluPak 2.885 3,349.5 3,001.7 23.32 Nipple - X 4.500 2.813" X Nipple S#0005011991-8 w/RHC profile installed HAL X-nipple 2.813 3,370.8 3,021.2 22.90 Overshot 5.000 3.5" Poorboy Overshot (1' above fully seated= 6.25' swallow) NS PBOS 4.276 Top (ftKB) 3,373.3 Set Depth … 3,553.7 String Max No… 4.14 Set Depth … 3,191.4 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.20 Grade J-55 Top Connection NUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,373.3 3,023.6 22.85 SCREEN 4.140 BAKERWELD .006 GAUGE SCREEN 2.992 3,538.1 3,176.7 20.47 O-RING 4.250 BAKER O-RING SEAL SUB 1.250 3,538.6 3,177.3 20.46 SCREEN 4.140 BAKERWELD .006 GAUGE LOWER TELL-TALE SCREEN 2.992 3,549.6 3,187.5 20.28 LOCATOR 5.000 OTIS LOCATOR 3.500 3,550.0 3,187.9 20.27 SUMP PACKER 5.875 OTIS SUMP PACKER, MODEL 'WD' 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,394.3 3,042.9 22.43 BALL & ROD B&R in RHC plug body (both run on-rig) 1/16/2025 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,871.9 2,579.8 31.73 1 GAS LIFT SOV RKP 1 1/2 1/18/2025 SOV SOV 3,059.5 2,741.4 29.03 2 GAS LIFT Dumm y RK 1 1/2 1/18/2025 Dummy valve DV 3,201.9 2,867.6 26.12 3 GAS LIFT Dumm y RK 1 1/2 1/16/2025 Dummy Valve DV Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,060.0 3,080.0 2,741.8 2,759.3 1/15/2024 IPERF 3,140.0 3,182.0 2,812.3 2,849.8 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,191.0 3,213.0 2,857.9 2,877.6 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns WSW-09, 2/17/2025 2:19:56 PM Vertical schematic (actual) PRODUCTION; 32.3-3,807.3 SUMP PACKER; 3,550.0 SCREEN; 3,538.6 SCREEN; 3,373.3 IPERF; 3,321.0-3,461.0 Nipple - X; 3,349.5 Packer; 3,292.1 IPERF; 3,263.0-3,297.0 IPERF; 3,244.0-3,248.0 IPERF; 3,220.0-3,229.0 Mandrel – GAS LIFT; 3,201.9 IPERF; 3,191.0-3,213.0 IPERF; 3,140.0-3,182.0 Packer; 3,123.8 Seal Assembly; 3,088.7 IPERF; 3,060.0-3,080.0 Mandrel – GAS LIFT; 3,059.5 Nipple - X; 3,038.1 Packer; 2,925.9 Mandrel – GAS LIFT; 2,871.9 SURFACE; 35.1-2,476.8 CONDUCTOR; 36.0-80.0 Hanger; 30.0 KUP DISP KB-Grd (ft) 41.01 RR Date 12/20/198 2 Other Elev… WSW-09 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292086800 Wellbore Status DISP Max Angle & MD Incl (°) 36.02 MD (ftKB) 2,600.00 WELLNAME WELLBOREWSW-09 Annotation Last WO: End Date 1/19/2025 H2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,220.0 3,229.0 2,883.9 2,892.0 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,244.0 3,248.0 2,905.6 2,909.2 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,263.0 3,297.0 2,922.8 2,953.6 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,321.0 3,461.0 2,975.6 3,104.8 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns WSW-09, 2/17/2025 2:19:56 PM Vertical schematic (actual) PRODUCTION; 32.3-3,807.3 SUMP PACKER; 3,550.0 SCREEN; 3,538.6 SCREEN; 3,373.3 IPERF; 3,321.0-3,461.0 Nipple - X; 3,349.5 Packer; 3,292.1 IPERF; 3,263.0-3,297.0 IPERF; 3,244.0-3,248.0 IPERF; 3,220.0-3,229.0 Mandrel – GAS LIFT; 3,201.9 IPERF; 3,191.0-3,213.0 IPERF; 3,140.0-3,182.0 Packer; 3,123.8 Seal Assembly; 3,088.7 IPERF; 3,060.0-3,080.0 Mandrel – GAS LIFT; 3,059.5 Nipple - X; 3,038.1 Packer; 2,925.9 Mandrel – GAS LIFT; 2,871.9 SURFACE; 35.1-2,476.8 CONDUCTOR; 36.0-80.0 Hanger; 30.0 KUP DISP WSW-09 ... WELLNAME WELLBOREWSW-09 ORIGINATED TRANSMITTAL DATE: 1/28/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5211 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 5211 WSW-09 50029208680000 Tubing Cut Record 21-Dec-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 182-196 T40024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 13:39:44 -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 ORIGINATED TRANSMITTAL DATE: 1/27/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5241 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 5241 WSW-09 50029208680000 Correlation 9-Jan-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 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 182-196 T40018 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 09:48:32 -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 ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5211 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 5211 WSW-09 50029208680000 Tubing Cut Record 21-Dec-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 182-196 T39933 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:08:05 -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 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: Ugnu Oil Pool UgnuOil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 3835'3457' 3476' 3119'908 None 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: 907-265-6049 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 KRU WSW-09 3140-3182' 3191-3213' 3220-3229' 3244-3248' 3263-3297' 3321-3461' 2812-2850' 2858-2878' 2884-2892' 2906-2909' 2923-2954' 2976-3105' 12/15/2024 3-1/2" Baker Model SC-1L Baker Otis Sump Packer SSSV: None 7"3775' 2442' Perforation Depth MD (ft): 3807'3431' 80' 2477' 16" 10-3/4" 44' Burst 3554' MD 80' 2255' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25648 182-196 P.O. Box 100360, Anchorage, AK 99510 50-029-20868-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing MD (ft): 2923'MD/2623'TVD 3550' MD/ 3188' TVD Perforation Depth TVD (ft): 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: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: TVD 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 Tubing Grade: J-55 1RY By Grace Christianson at 7:53 am, Nov 15, 2024 324-649 A.Dewhurst 04DEC24 sameTertiary Undefined Waste Disposal Pool -A.Dewhurst 21NOV24 DSR-11/21/24 CDW 12/03/2024 Disposal Operations to be in compliance with AIO 2C. 10-404 XX X JJL 12/02/24 Witnessed BOP and Annular Test to 2500 psi. Post-injection witnessed MITIA to 1800 psi. Notify AOGCC if communication becomes present via monitored overburden. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.04 15:22:32 -09'00'12/04/24 RBDMS JSB 121324 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 14, 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 Class II Disposal Injector WSW-09 (PTD# 182-196). Well WSW-09 was drilled and completed in December of 1982 by Parker 191 as an Ugnu water source well. The well was converted to a Class II disposal well in 1988 by removing the jet pump and isolating the jet pump profile with an Iso Sleeve. WSW-09 has been shut-in since July of 1994. The Iso Sleeve across the jet pump profile has leaked and been replaced multiple times in the past. A passing MIT-IA was achieved with a new Iso Sleeve installed on 10/15/2024. We request approval to proceed with a rig workover to install a more robust completion for disposal injection. The workover plan is to pull the tubing from a pre-rig cut above the upper packer, fish the upper packer and a portion of the gravel pack screens, replace the tubing head, perforate a monitoring interval in the overburden above the confining layer, then install a new 3-1/2” completion with straddle packers to isolate the upper section of Ugnu C perforations, and straddle packers with a downhole gauge between them to monitor the overburden layer. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells KRU WSW-09 P&R Tubing, Install Overburden Monitoring PTD: 182-196 Page 1 of 3 PPre-Rig Work 1. Pull and replace Iso Sleeve at 2,884’ RKB (10/15/2024) 2. MIT-IA to 1,700 psi passed (10/15/2024) 3. Set gauges at 2,881’ RKB to obtain updated SBHP (10/15/2024) 4. Pull gauges from 2,881’ RKB. 5. T-POT/PPPOT 6. IC-POT/PPPOT 7. Function test LDS 8. MIT-OA to 1,700 psi 9. Perform tubing cuts at ~2,907’, ~3,059, and ~3,380’ RKB. 10. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on WSW-09. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. Replace Tubing Head 6. RIH with plug or storm packer. Set and test to confirm set. 7. ND BOPs. ND tubing head. NU new tubing head. PT Packoffs. NU BOPS. Test breaks to 250/2500 psi. 8. RIH and retrieve plug and storm packer. Retrieve Packer and Gravel Pack Screens 9. PU DP and RIH with fishing BHA and jar tubing stub free. 10. RIH with packer retrieval tool and remove section from packer to middle pre-rig cut. 11. RIH with fishing BHA and remove section from middle cut to lower cut. a. Wash over screens and remove in sections as necessary. b. If screen sections are removed easily, attempt to pull lower section of screens free from sump packer. 12. Perform cleanout run to tubing stub and confirm overshot can wash over stub. Run E-line Log and Perforate 13. RU E-Line, RIH with caliper and CCL and confirm existing perforation depths. 14. RIH and perforate the overburden monitoring interval. RD E-line. KRU WSW-09 P&R Tubing, Install Overburden Monitoring PTD: 182-196 Page 2 of 3 Perform Cleanout Run 15. RU casing scraper and RIH to tubing stub. 16. RIH with dress off BHA, wash over tubing stub and dress off as needed. Install Lower Straddle Packers 17. MU non-sealing overshot, nipple profile, lowest packer, GLM, middle packer, and PBR. RIH on DP, correlate depths. 18. Once on depth, circulate corrosion inhibited fluid and drop ball and rod. Set packers in tandem. Shear out of PBR and TOOH. 19. MU test packer, RIH and set below new monitoring perforations and test below to test middle packer if depths allow. Install Upper Packer 20. MU seal assembly, GLM, gauge, nipple profile, upper packer, PBR, GLM and new 3-1/2” tubing string. RIH and tag middle packer. 21. Circulate corrosion inhibited fluid, land seal assembly in PBR on middle packer and space out. 22. Drop ball and rod, set packer. 23. Shear out of PBR, space out, land tubing hanger and RILDS. 24. Pressure test tubing to 1,800 PSI. 25. Pressure test IA to 1,800 PSI. ND BOP, NU Tree 26. Shear out SOV with pressure differential. 27. Install BPV and test. ND BOPE. NU tree. 28. Pull BPV and freeze protect well. 29. RDMO. PPost-Rig Work 1. Pull SOV and replace with DV. 2. Pull ball/rods and RHC profiles used for setting packers. General Well Information: Estimated Start Date: 12/15/2024 Current Operations: Shut-In Well Type: Class II Disposal Injector Wellhead Type: FMC. 11” 3M casing head top flange. 7-1/16” 3M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 1,167 psi / 2,589’ TVD measured on 9/18/2018 MPSP: 908 psi using 0.1 psi/ft gradient KRU WSW-09 P&R Tubing, Install Overburden Monitoring PTD: 182-196 Page 3 of 3 Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above upper packer, swap tubing head, fish packer and gravel pack screens, perforate overburden monitoring interval, install lower straddle packers, install gauge and upper packer with a new 3-1/2” tubing string. PPersonnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Reservoir Surveillance Engineer: Cody Keith Production Engineer: Banabas Dogah Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 3,476.0 WSW-09 10/14/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled slipstop & IsoSleeve. Set gauges, slipstop, & Isosleeve. Update Tag depth WSW-09 10/15/2024rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WSR Review 9/11/2023 pproven Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 36.080.080.065.00 H-40 WELDED SURFACE 10 3/49.9535.12,476.8 2,254.6 45.50 K-55 BTC PRODUCTION 7 6.28 32.3 3,807.3 3,431.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.0 Set Depth … 3,553.7 Set Depth … 3,191.4 String Max No… 3 1/2 Tubing Description TUBING-GRAVEL PACK Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.030.00.12 HANGER 8.000 TUBING HANGER FMC3.500 2,883.92,590.031.49 NIPPLE 4.500 JET PUMP PROFILE NIPPLE BHA w/XOs. EXACT ID UNKNOWN. BELIEVED TO BE 2.47"-2.55" National 2.500 2,922.0 2,622.6 31.00 SEAL ASSY 5.000 MODEL G-22 LOCATOR/SEAL ASSEMBLY (SEALS STUN IN 13' OF 13.15') Baker 2.985 2,922.5 2,623.0 30.99 PACKER 5.968 MODEL SC-1L PACKER Baker 4.000 2,926.7 2,626.7 30.96 EXTENSION 5.000 PERFORATED EXTENSION MODEL S Baker4.400 2,932.5 2,631.6 30.91 SBR 5.560 80-40 SEAL BORE RECEPTACLE Baker 4.000 2,934.02,632.930.89 EXTENSION5.000 LOWER EXTENSION4.400 2,942.4 2,640.130.82 SAFETY JT 3.500 SHEAR OUT SAFETY JOINT 2.992 3,075.62,755.5 28.68 SCREEN 4.140 BAKERWELD .006 GAUGE SCREEN 2.992 3,538.13,176.7 20.47 O-RING 4.250 BAKER O-RING SEAL SUB 1.250 3,538.7 3,177.3 20.46 SCREEN 4.140 BAKERWELD .006 GAUGE LOWER TELL-TALE SCREEN 2.992 3,549.6 3,187.5 20.28 LOCATOR 5.000 OTIS LOCATOR 3.500 3,550.0 3,187.9 20.27 SUMP PACKER 5.875 OTIS SUMP PACKER, MODEL 'WD' 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,880.02,586.7 31.57 GAUGES NO GO gauge hanger w/ gauges set on top of slipstop (2.313" external F/N) (OAL = 57") 10/15/2024 0.000 2,881.0 2,587.5 31.55 SLIP STOP Slip stop set on top of IsoSleeve (2.313" G F/N) (OAL= 19") 10/15/2024 1.750 2,883.9 2,590.0 31.49 ISO-SLEEVE National Jet Pump IsoSleeve w/AVA seals (OAL = 19") 10/15/2024 2.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 3,140.03,182.02,812.32,849.812/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,191.0 3,213.0 2,857.9 2,877.6 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,220.0 3,229.0 2,883.9 2,892.0 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,244.0 3,248.0 2,905.6 2,909.2 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,263.0 3,297.0 2,922.8 2,953.6 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,321.0 3,461.0 2,975.6 3,104.8 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns WSW-09, 10/18/2024 9:43:39 AM Vertical schematic (actual) PRODUCTION; 32.3-3,807.3 FLOAT SHOE; 3,805.5-3,807.3 FLOAT COLLAR; 3,761.1- 3,762.7 SUMP PACKER; 3,550.0 LOCATOR; 3,549.6 SCREEN; 3,538.7 IPERF; 3,321.0-3,461.0 SCREEN; 3,075.6 IPERF; 3,263.0-3,297.0 IPERF; 3,244.0-3,248.0 IPERF; 3,220.0-3,229.0 IPERF; 3,191.0-3,213.0 IPERF; 3,140.0-3,182.0 SAFETY JT; 2,942.4 EXTENSION; 2,934.0 SBR; 2,932.5 EXTENSION; 2,926.7 PACKER; 2,922.5 SEAL ASSY; 2,922.0 NIPPLE; 2,883.9 ISO-SLEEVE; 2,883.9 SLIP STOP; 2,881.0 GAUGES; 2,880.0 SURFACE; 35.1-2,476.8 FLOAT SHOE; 2,474.9-2,476.8 FLOAT COLLAR; 2,397.8- 2,399.4 COLLAR; 2,377.6-2,382.3 CONDUCTOR; 36.0-80.0 HANGER; 35.1-37.6 HANGER; 32.3-37.9 HANGER; 30.0 KUP DISP KB-Grd (ft) 41.01 RR Date 12/20/198 2 Other Elev… WSW-09 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292086800 Wellbore Status DISP Max Angle & MD Incl (°) 36.02 MD (ftKB) 2,600.00 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE WSW-09 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 80 80 16 15.06 65 H-40 WELDED Surface 2477 2255 10.75 9.95 45.5 K-55 BTC Production 3807 3431 7 6.28 26 K-55 BTC Tubing (Existing)3554 3191 3.5 2.99 9.2 J-55 BTC Tubing (Proposed)~3320 ~2975 3.5 2.99 9.2 L-80 EUE 8rd Surface Casing Shoe - 2477' RKB Conductor -80' RKB Monitoring Perfs @ ~3065' - 3085' RKB PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUEM 8rd Tubing to Surface 3-1/2" x 1-1/2" Gas Lift Mandrel PBR 3-1/2" x 7" Feed Through Packer @ ~2945' RKB 2.813" X Nipple 3-1/2" Dual Sensing Gauge and Mandrel 3-1/2" x 1-1/2" Gas Lift Mandrel Locator Seal Assembly PBR 3-1/2" x 7" Packer @ ~3115' RKB 3-1/2" x 1-1/2" Gas Lift Mandrel 3-1/2" x 7" Packer @ ~3292' RKB 2.813" X Nipple 3-1/2" Non-sealing overshot EXISTING COMPLETION LEFT IN HOLE 3-1/2" x 0.006" BakerWeld Screens O-Ring Seal Sub @ 3538.1' RKB Baker Tell-Tale Screen @ 3538.7' RKB OTIS Locator Assembly @ 3549.6' RKB Ugnu C Perfs 3306' - 3525' RKB Production Casing Shoe - 3807' RKB K-15 Marker Perfs/ Upper Ugnu C Perfs 3135' - 3278' RKB 7" PC TOC: 2522' RKB from 12/14/1982 CBL • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, April 16, 2017 6:46 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of failed MITIAs for WSW-07(PTD 182-188) and WSW-09 (PTD 182-196)4-16-17 Chris, Water source wells WSW-07 (PTD 182-188)and WSW-09 (182-196) both effectively failed MITIAs on Friday April 14th. WSW-09's MIT was aborted when there was clear communication to the tubing observed. The test was aborted when the IA had reached 750psi (with tubing at 720psi). WSW-07's MIT was aborted after 50 bbls of diesel were pumped without catching pressure. Fill up volume should have been-8 bbls based on the latest fluid level shot obtained in January. Both wells have been shut in for decades and will remain so. Proper paperwork will be submitted once a path forward is determined. Kelly Lyons/Brent Rogers Well Integrity Supervisor swee r or at ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone(907)943-0170 1 Pi Ferguson, Victoria L (DOA) • ..0 v From: Hunter, Lindsey L <Lindsey.Hunter@conocophillipNs.co Wednesday, June 19, 2013 3:57 PM To: Ferguson, Victoria L(DOA) Cc: Wallace, Chris D (DOA); NSK Fld Drlg Supv; Jolley, Liz C Subject: RE: ConocoPhillips Water Source Step rate test SCAN NEp ._.�. Victoria, Please see the information you requested below. I wanted to verify diesel was our preferred fluid for step rate tests with our field drilling supervisor before I responded,which is why you received the email today. From now on you can consider me the single point of contact for this project, I apologize for the confusion. WSW-02—PTD 182-137 1. MITIA's in 1989, 1993 and 1997 passed. Well was used to dispose of pigging fluid in 1991 and was not in use after 1991. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1710 psi on 5/9/13. 2. Plan forward for this well is to complete further investigation to see if it will be an adequate slurry injection well, this is the only well we are considering for slurry injection at this time,the rest of the WSWs will remain class 2 fluid disposal wells. Once the sundry is approved we plan to use this well to inject class two fluids while monitoring other well pressures on 1B pad to confirm that they are not in communication with this well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We are currently verifying cement bond logs of surrounding 1B wells and confirming upper shale zone confining pressures from previous modeling results. We are currently working on a plan to monitor surrounding wells while using WSW-02 as a class 2 fluid disposal well to confirm that it will be an adequate slurry injector. We plan to submit all of our results when our studies are complete and the sundry requesting slurry service is submitted. WSW-03—PTD 182-142 1. MITIAs in 1988, 1993 and 1997 passed. Well was used for pit dewatering from 1997-2001 and was not in use after 2001. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1700 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-05—PTD 182-164 1. MITIAs in 1988, 1992, 1996, 2000, 2004, 2006, 2009 passed. Well was used for pit dewatering from 1996- 2001, has not been used since 2001 but was kept current on its MITIA schedule. Well passed MITIA to 1715 psi on 3/29/12 and passed a state witnessed MITIA to 1700 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. i 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-06—PTD 182-177 1. MITIAs in 1988, 1993 and 1997 passed. Well was never used for injection. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1690 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-07—PTD 182-188 1. MITIAs in 1993 and 1997 passed. Well was used for pit dewatering from 1997-2001 and was not in use after 2001. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1735 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-09—PTD 182-196 1. MITIAs in 1992, 1996, 2000, 2004, 2006, 2009 passed. Well was not used for injection but was kept current on its MITIA schedule. Well passed MITIA to 1715 psi on 3/29/12 and passed a state witnessed MITIA to 1700 psi on 5/9/13. A step rate test was performed on this well on 6/8/13 using diesel. 2. Plan forward is to use this well as a class 2 fluids disposal well. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter@conocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Wednesday,June 19, 2013 2:16 PM To: Hunter, Lindsey L Cc: Wallace, Chris D (DOA); NSK Fld DrIg Supv Subject: [EXTERNAL]FW: ConocoPhillips Water Source Step rate test Lindsey, 2 We sent you an email on 6/6/2013 outlining the following information request for the Sundries on the WSWs: We received Sundrys for the subject wells and are requesting the following information: 1. Brief history of each well including results of previous MITs 2. Plan forward including planned MITs and step rate tests 3. Plans for hydraulic modeling prior to slurry injection We have not received this information but instead the request to Jim Regg from the NSK Drilling Supervisors was received as outlined below. Please provide the information requested to process these sundries and we would appreciate a single point of contact for review and approval of this work. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(a)alaska.gov From: Wallace, Chris D (DOA) Sent: Wednesday, June 19, 2013 1:19 PM To: Ferguson, Victoria L(DOA) Subject: FW: ConocoPhillips Water Source Step rate test Victoria, Did you get a response from the CPAI town engineer on the Sundries? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace()alaska.gov From: Regg,James B(DOA) Sent: Wednesday,June 19, 2013 10:37 AM To: Wallace, Chris D (DOA) Subject: FW: ConocoPhillips Water Source Step rate test Jim Regg 3 AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK Fid DrIg Supv [mailto:n1335@conocophillips.com] Sent: Wednesday, June 19, 2013 10:34 AM To: Regg, James B (DOA) Subject: ConocoPhillips Water Source Step rate test Good morning Jim, I am emailing you in regards for permission to perform a step rate injection test utilizing diesel in our class two injection wells on 1B pad in Kuparuk, Alaska -specifically WSW-02,05,09.. We choose diesel in the event a well locks up during injection for permafrost concerns. WSW-02 =API 500292081200 WSW-05=API 500292083800 WSW-09=API 500292086800 We have intentions of installing a G&I unit on 1B pad in Kuparuk and would like to perform this preliminary feasibility test. We would assume a max bottom hole pressure of 2500 PSI based of our TVD of 2,850'-3,181' along with a current proved MIT on each wellbore. We would like to inject less than or equal to 1 1/2 time our tubing volumes to perform this test. Currently these wells are freeze protected with diesel and we do not see an issue with pushing this into the formation but do wish your guidance. Best regards, Rock Bobby Morrison/Rock Rauchenstein NSK Field Drilling Supervisors 907-659-7726 Pager 907-659-7000, 243 n 1335(a�conocophillips.com 4 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Thursday, June 06, 2013 10:20 AM To: 'lindsey.hunter @cop.com' Cc: Wallace, Chris D (DOA) Subject: WSW-02, WSW_03, WSW-05, WSW-06, WSW-07, WSW-09 Attachments: 1821640 WSWeII 05 Class II Permit Lindsey, We received Sundrys for the subject wells and are requesting the following information: 1. Brief history of each well including results of previous MITs 2. Plan forward including planned MIT5 and step rate tests 3. Plans for hydraulic modeling prior to slurry injection Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson(a)alaska.gov From: Wallace, Chris D (DOA) Sent:Thursday, June 06, 2013 9:59 AM To: Ferguson, Victoria L(DOA) Subject: FIN: WSW Path Forward From: Wallace, Chris D (DOA) Sent: Monday, May 06, 2013 12:27 PM To: 'NSK Problem Well Supv'; Regg,James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Hunter, Lindsey L; NSK DHD Field Supervisor Subject: RE: WSW Path Forward Brent, As in the attached email, if the well status and intent of use is being changed then a 10-403 should be prepared with all relevant information. If these wells are to be used for slurry injection,then the appropriate hydraulic modeling should be performed to establish the injection pressure and rate limitations to avoid fracturing the well into the confining layers. This would then be included into the MIT test pressure consideration. The MIT you speak of should be performed to the maximum anticipated surface pressure, 1500 psi, or 0.25 psi/ft x packer depth TVD ft whichever is greater. As per Guidance Bulletin 10-002 MIT,Shut in Wells "The Commission's preference is to witness an MIT while a well is actively injecting and wellbore conditions(rate and temperature)are stable. If the well is in a short-term shut-in status when the MIT is due,the Commission should be notified and provided an alternate date for testing based on when injection will be recommenced. Injection wells that are shut in long-term (undetermined when injection will restart)need not be tested until they are ready to recommence injection. In lieu of an MIT for the long term shut-in well, the operator must provide to the Commission a quarterly graph of tubing, inner annulus and outer annulus pressures." Please schedule MITs with the inspectors at your earliest convenience,to the maximum that you feel is adequate for your path forward. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617(aconocophillips.com] Sent: Friday, May 03, 2013 11:12 AM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay; Hunter, Lindsey L; NSK DHD Field Supervisor Subject: FW: WSW Path Forward Chris, As described below and with Lindsey previously,there are 6 wells that CPAI would like to perform witnessed MIT's on while the well is shut in. Currently there is no injection piping connected to these wells in order to test while injecting. The tests are to bring them current in their compliance testing and then to apply for the appropriate approvals as needed. Would this be an acceptable plan? Please advise. Please let me know if you have any questions. Thank you. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 From: Hunter, Lindsey L Sent: Friday, May 03, 2013 10:37 AM To: NSK Problem Well Supv Subject: WSW Path Forward Brent, The plan I discussed with Chris Wallace is to use the Ugnu water source wells on 1B pad(converted to class 2 injectors in 1988) to replace the ailing 1R-18 class 2 injection well. We plan to start by injecting class 2 drilling fluids while monitoring the reservoir 2 performance,in the near future we'll be requesting permission from the state to use 2-3 of the wells for slurry injection of drilling cuttings. Please let me know if you need any other information from me. Thanks, Lindsey Lindsey Hunter Senior Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter(u conocophillips.corn 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 15,2013 TO: Jim Regg 'K� i '117(L3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC WSW-09 FROM: Lou Grimaldi KUPARUK RIV UNIT WSW-09 Petroleum Inspector Src: Inspector Reviewed By: ,�� P.I.Supry ` 1-" NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW-09 API Well Number 50-029-20868-00-00 Inspector Name: Lou Grimaldi Permit Number: 182-196-0 Inspection Date: 5/9/2013 Insp Num: mitLG130509103913 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WSW-09 Type Inj N TVD 2623 IA 200 1710 1645 1630 PTD O T yP e Test SPT I Test psi 1500 , - 125 • zzo 205 , 190 [ Interval !OTHER P/F P Tubin g 1175 1175 1175 1175 Notes: Test for possible restart..3 bbl's pumped.Good test. scO FEB 6 20\ Wednesday,May 15,2013 Page 1 of 1 • • �.- RECEIVED ConocoPh . SEP 19 2012 Alaska AOGCC P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 17, 2012 Commissioner Dan Seamount ¢ 1 / 1� Alaska Oil and Gas Commission U 333 West 7 Avenue, Suite 100 VV 5 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped September 11, 2011. The corrosion inhibitor /sealant was pumped August 15, 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lov land ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 09/17/2012 1B PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1B WSW -5 50029208380000 1821640 SF NA 39" NA 7.65 8/15/2012 1B WSW -8 50029208640000 1821920 72" 1.5 bbls 14" 9/11/2011 14.5 8/15/2012 1B WSW -9 50029208680000 1821960 SF NA 19" NA 2 8/15/2012 1B-WSW-10 50029208760000 1822050 SF NA 20" NA 3.4 8/15/2012 MEMORANDUM ~ 'ro: Jim Regg ' C l~ 2(Z3f ~ C~ P.I. Supervisor ~ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 23, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC WSW-09 KUPARUK RIV iJNIT WSW-09 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RN iJNIT WSW-09 API Well Number: 50-029-20868-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090630093142 Permit Number: 182-196-0 .. Inspection Date 6/27l2009 Rel Insp Num: MITOPO0oo02705 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'S~'-O~Type Inj. N 'I'~ Z6z~ IA 180 1650 ,i 1630 1630 ~ P.T.D 182196o TypeTest SPT Test psi isoo pA izo iao iso ~60 Interval Four Yeaz Cycle . p~ Pass ~ Tubing lo0 100 100 100 Notes: s ? v~`~~.~~. E,i,i` `~ ~' ,}~~: Thursday, July 23, 2009 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg VA vJ g(1Jt1o+ P.I. Supervisor'r r DATE: Thursday, August 19, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPlllLLIPS ALASKA INC WSW-O9 KUPARUK RIV UNIT WSW-O9 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: 3 2A 104 P.I. Suprv -.:J&-- Comm NON-CONFIDENTIAL Well Name: KUPARUKRIV UNIT WSW-09 API Well Number: 50-029-20868-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ040818093957 Permit Number: 182-196-0 Inspection Date: 8/15/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WSW-O9 Type Inj. N TVD 3457 IA 240 1620 1550 1530 P.T. 1821960 TypeTest SPT Test psi 1500 OA 240 225 170 150 Interval 4YRTST P/F P Tubing 110 110 110 110 Notes: .8 BBLS diesel pumped Thursday, August 19,2004 Page 1 of I ..---.- .... . ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate m Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Ala~;ka, In~. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 321' FNL, 1180' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 924' FSL, 1377' FEL, Sec. 4, T11N, R10E, UM At effective depth 1100' FSL, 1400' FEL, Sec. 4, T11 N, R10E, UM At total depth 1285' FSL, 1434' FEL, Sec. 4, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 3899' 3424' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number WSW ~ 9. Permit number/approval number ~-196/9-304 10. APl number 5o-029-20868 11. Field/Pool Upper Ugnu Effective depth: measured 3 60 0' true vertical 3350' feet Junk (measured) feet Casing Length Size Structural 80' I 6" Conductor 236 9' 10 Surface Intermediate Production 3 8 6 4' 7" Liner 3/4" Cemented 200 Sx Permafrost 1400 Sx AS III & 250 Sx AS I 250 Sx Class G Measured depth 116' 2405' True vertical depth 116' 2200' 3899' 3424' Perforation depth: measured 3135'-3526' true vertical 2950'-3200' Tubing (size, grade, and measured depth) 3 1/2" J-55, 3076' Packers and SSSV (type and measured depth) GP pkr @ 2927' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 'j U L 2 !989 Alaska 0il & Gas Cons. Commission Anchorage 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 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. Date SUBMIT IN DUPLICATE X TIME 24 HOUR REPORT DRILL SITE ! - .ES WATER SOURCE WELL STATUS REPORT PAGE / OF WELL SOURCE WELL PRODUCTION SOURCE WELL POWER FLUID NET PROD REMARK 7-'/~ TEMP CHOKE 10.3,4 METER GROSS TUBING TEMP CHOKE METER POWER WELL NUM PSI oF BEAN PSI TOTAL BBLS PSI OF' BEAN TOTAL BBLS SI/HR BBLS 2. qO0 ITG .~&o i qoo 45s~,e_,~ 4o~-/ , , 'q ~)o '9_30 ~E,O .... ~/w,??,.o 3~;:~p_, ............... · -7 9'60 ~' . ~o ~&os~ .~3G4 / ~ ,, , fi' 980 ...... W .... ~o e~,,~, ~: :~ ~.~9 ....... ~ .................. I .~o~ ~ ?o c/ ..?,.q,O ~Z~ 75 .... '" .. . ' ,1 . _ ...... · .... , ..... , , !, .,,, .... , . , . . ! ,., ..... ~ .... ............... __ ,~........... .... , ..... ..... , __ .... GROSS. TOTAL TOTAL POWER FLUID 14.80 8 NET OPERATOR~3/~-~ c~ ~~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 1.2, 1989 John Boyle- State of Alaska AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501 bear Mr. Boyle- Please find enclosed the copies of the CBL Logs on WSW ~9, which you r equ e s t ed. contact me at 263-4618. Danielle Martin Engineering Aide MAY 1 8 89' (j - glaska.0il & Gas C0ns~, ' ~ ~chorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ARCO Alaska, Inc; Post Oilice Bo J0360 Anchorage, Ala~<a 99510-0360 Telephone 907 276 1215 : . . April 17, 1989 Mr. C. V. Chatterlon, Chairman 3001 Porcupino Drivo ~ncho?a~o, Alaska 00501 Dear Mr. Chatterton: Attached in lriplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipaled Start Date 1G-06 Tbg. Comm. April, 1989 2D-14 Stimulate April, 1989 2 D- 0 8 Scale Treatmenl April, 1989 2D-15 . Fracture: April, 1989 WSW -2&7 Conversion May, 1989 WSW -8&9 Conversion May, 1989 WSW -10&11 Conversion May, 1989 2V-16 Perforate April, 1989 If you have any questions, please call me at 265-6840. Sincerely, (~. B. Sma"llwood' Senior Operations Engineer GBS:kr Attach~nenls CC: H. F. Blacker ATO 1126 J. Gruber ATO 1478 KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichlieldCompany ALASKA OIL AND GAS CONSERVATION COMMISo,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska. Inc. 3. Address I Stratigraphic P. O. Box 100360, Anchorage, AK 99510I Service 4. Location of well at surface 321' FNL, 1180' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 924' FSL, 1377' FEL, Sec. 4, T11N, R10E, UM At effective depth 1100' FSL, 1400' FEL, Sec. 4, T11N, R10E, UM At total depth 1285' FSL, 1434' FEL, Sec. 4, T11N, R10E, UM _ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program ~ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ Exploratory _ 12. Present well condition summary Total Depth: RKB 1 O0 7. Unit or Property name Kuparuk River Unit 8. Well number WSW 9 9. Permit number 82-196 10. APl number so-029-20868 11. Field/Pool Upper Ugnu measured 3 8 9 9' true vertical 3 4 2 4' feet Plugs (measured) feet None Effective depth: measured 3 6 0 O' true vertical 33 5 O' feet Junk (measured) feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 3 6 9' 1 0 Intermediate Production 3 8 6 4' 7" Liner Perforation depth: measured 3135'-3526' MD true vertical 2950'-3200' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 tbg w/tail @ 3076' MD Packers and SSSV (type and measured depth) GP pkr @ 2927' 3/4" Cemented Measured depth 200 SX Permafrost 1400 SX AS III & 250 SX AS I 250 SX Class G 116' MD 2405' MD 3899' MD True vertical depth 116' TVD 2200' TVD 3424' TVD 113. Attachments Description summary of proposal X Conversion from water producer to injector 14. Estimated date for commencing operation May 1 989 1G. If proposal was verbally approved Name of approver 17. Si~ned _,/~_/.Z_~ Date approved Detailed operation program BOP sketch Status of well classification as: __ Gas __ Suspended Service Water Disoosal Well I hereby certify that the foregoing is true and correct to the best of my knowledge. .~ /~'~,'~f'~ '4~itle Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness IIAppr°val No.~ f,~,~~ Plug integrity_ BOP Test m Location clearance Mechanical Integrity Test _ Subsequent form ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH Form 10-403 Rev 06/15/88 r'--e q u i r.._R, p~ p-o~d._~? py Date SUBMIT IN TRIPLICATE Sundry Notices WSW 2 WSW 7 WSW 8 WSW 9 WSW 10 WSW 11 These wells were drilled for use as creataceous source water in Increment 1 Waterflood at Kuparuk River Field. They are completed in the Upper Ugnu. Water production from these wells to date has been in eXcess of 70 million barrels. The intent is to convert these wells from producers to injectors to dispose of non-hazardous, Class II reserve pit water. Recent correspondance with the EPA has confirmed the Class II classification of reserve pit water. No BOP will be used for the proposed work. The estimated BHP in the Upper Ugnu is 1000 psi. No workover fluids are required. Procedure for WSW Conversion Ii 2. 3. 4. 5. Pull hydraulic jet pump. Pull standing valve. Run 'pump through' jet pump. Install injection piping and associated pumping equipment. Begin injection. 3 i . 1. 5000 PSI ?" WELLHF. AD CONNECTOR Ir LANGE :2. 5000 PSI WIRELIN[ RAJAS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 l/e," FLOW TUBE PACK-OFF N ! REL ! NEBOP EOU I PMENT ,.- IL ARCO ~laska, Inc..~. Post Office~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT:' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 Also enclosed are well completion reports for: 2-1I 1E-23 7-17 1F-2 12-19' 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2'-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska, Inc. is a subsidiary Of AllanticRichlieldCornpany STATE OF ALASKA ---q ALASKA-, .-L AND GAS CONSERVATION CC .,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ Water Source Well 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-196 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20868 4. Location of well at surface 7-~r~,_~ 9. Unit or Lease Name 314' FNL, 1178' FEL, Sec. 9, T11N, R10E, UN JL~CA'hON$ Kuparuk River Unit t VERiFiED At Top Producing Interval 10. Well Number 903' FSL, 1245' FEL, Sec. 4, T11N, R10E, UM iSurf. /~j WSW-9 At Total Depth ~ B. Id.~_ ~j 11. Field and Pool 1125' FSL, 1211' FEL, Sec, 4, T11N, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Lower Tertiary (Upper Ugnu) 102' RKB ADL 25648, ALK 466 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/07/82 12/11/82 12/20/82 N/A feet MSL 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 3835'MD,3457'TVD 3719'MD,3347'TVD YES IX1 NO [] N/A feet MDI 1625' (approx) 22. Type Electric or Other Logs Run GR/SP/DLL, D IL/SP/GR, GR/CNL/CDL, CBL/VDL/CCL/GR, NFD 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 80' 24" 240 sx AS II 10-3/4" 45.5# K-55 Surf 2477' 13-1/2" 1400 sx AS III & 250 sx AS I 7" 26.0# K-55 Surf 3807' 8-3/4" 350 sx Class G & 110 sx AS I 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) 3135'-3178' 3306'-3310' 3-1/2" See Tubing Deta 1 Sheet 3186'-3205' 3316'-3342' 3213'-3226' 3356'-3396' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 3241 '-3254' 3407'-3508' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3259'-3278' 3519'-3525' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GASiOIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MC~.: WATER-BBL ;OILGRAVITY-API (corr) Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,~_'~ · Alast~a Oil 7_4 /'l"'.2;horage . , Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC23 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC M, AR KERS TRUE VERT. DEPTH MEAS. DEPTH 30. FORMATION TESTS Include interval tested, pressure data. all flu~d~ ,ecove~ed and qrav~ly. GOR.and time of each phase Top Upper Ugnu I! 3213' il 2878' Top Lower Ugnu il 355~' ii 3192' ., ,I N/A 31 LIST OF ATTACHMENTS Drilling History~ Tubing Detail Sheet, Gyroscopic Survey (2 copi¢~) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /_--g~,' / -- , _ 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- ing 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". WSW-9 DRILLING HISTORY NU 20" Hydril & Diverter. Spudded well @ 0400 hrs, !2/07/82. Drld 13-1/2" hole to 2500'. Ran 62 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2477'. Cmtd 10-3/4" csg w/1400 sx AS III & 250 sx AS I. Pumped 100 sx AS I top job. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 10.1 ppg EMW. Drld 8-3/4" hole to 3835'TD (12/11/82). Ran GR/SP/DLL, DIL/SP/GR & GR/CNL/CDL. Ran 91 jts, 7", 26#/ft, K-55, BTC csg w/shoe @ 3807'. Cmtd 7" csg w/350 sx Class G. Arctic packed 7" x 10-3/4" ann w/150 bbls H20, 220 bbls Arctic Pack & 110 sx AS I. Milled out inside of 7" pup below 7" hanger. Tstd 7" csg to 2500 ps~ - ok. Ran CBL/VDL/CCL/GR. Disp well to NaC1. Tstd csg to 2500 psi - ok. Ran Gyro. (PBTD = 3719'). Set sump pkr @ 3541'. Perforated the following intervals: 3135' - 3178' 3186' - 3205' 3213' - 3226' 3241' - 3254' 3259' - 3278' 3306' - 3310' 3316' - 3342' 3356' - 3396' 3407' - 3508' 3519' - 3525' Performed cased-hole gravel pack over perforated interval. Ran NFD. Ran 3-1/2" compl, assy. (see tubing detail). ND BOPE. NU tree. Tstd packoff to 3000 psi - ok. Disp well to diesel. Secured well & released rig @ 0230 hrs, 12/20/82. JG'ltc FO5 -. CA~.....".~IG / TUBING / LINER DETA~" -Cb / / DRILL S,, ,'" ARCO Alaska, Inc. ~r Page / of Subsidia~ of AtlanticRichfieidCompany pages #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTHDEPTH ~'~ " ~~. '~~5 C~- ~' ~ ~-s~) ~,o~ ~~ ~ ~. ~~s ~T~ ~ ia' ~ ~ 13./~ ' ~ ~.5/ ~~e~ ~~e~ SC-IL ~e. 7o8~ 4.2~ ~e~ ~~o~~ E~~s~ ~o~ 5 5.75 I ~ ~~e~~c~ .oo~ 4~~ ~~ ~~-T~ ~~ ?. 8~ 85 38, ~zs X. o . zo ~ I. o8 35 sO~OM OF TUS~NG ~A~L Remarks 111 1'7 C,~"~G I TUBING i LINER DET ~- '" ARCO Alaska, Inc.'~r Page / of / pages Subsidiary of AtlanticRichfieldCompany #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ~oTfUzy-'/'~cE Fmc H~~ ~'~" ?& 5~-" ~~e~ 1~ ~~~cb .oo66~& ~~ 3Ya ~0 Io~ 462.55 3o 7~.5~ ~~e~~cb ,oo~ ~~a ~~ ~~-T~ ~~ 9. 85 55 38, ~7 ~~5 X.o. ~0, ~. ~e. ~fiS& 77 ~/////jjj// ' BOSOM OF TUBING TAIL Remarks j~g, N '_.:' /-~ ':2::~8~i /? _?m. ~" it.i;'?": i','' COMPLETIONS.REPORT ~RcOi'ALRS~a,,;INC ..... . 2YROSCOPIC SURVEY ~DI. US OF CURVATURE METHOD OF COMPUTATION '. ;OHPUTED FOR ~ TRUE qEAS, DRIFT VERTICAL )EPTH AHGLE DEPTH : ,100 :0 25 3,00 0 7 GUB SER WELL KB ELE¥:.. 1:02 FTo SURVEY DA'TE 15 DEC, 82 : JOB HO,, RECORD OF. SURVEV .~;:..':. qg?~'" · ' ' . <, %-<,.;.3/~% . DRIFT TOTAL COORD{':'HRTES~: D IREC D ISTRHCE ~HGLE DEG, D H ,00 -1~2,:00 S ,~OE 1.00,0.0 -2,~8 S24;50E 2.:00,00 98,G'O"S43,32E 300,0:0 198,00 H23,35E 400 :0 20 40.0.'00 298,00 S04,8:0E i 58.0 '1 23 499,98 397,98 H 2,~03U '.! 6!00 4 24 59'-3.84 ' 497,84' H 4.. 72E ::': i':~':?,Oo 7 5 699.33 597.33 H I, 5OE 800 .10 28 798,15 696,15 H 4, 9:0~ 14 3 89508~ 793.85 Hll 10:00 17 2 992,19 890.,19 N 9,53~ 11.00 20 3~ '10~6 ~3 984.83 H ~,95~ ~1200 24 18 1'179 23 I:077,23 N 8 1300 27 11 1269 30 1167,30 H10,75~ 1400 31 12 1356 58 1254,58 H 8,22~ .1580 34 7 1440 26 1338.76 N J6.0'0 32 48 1524 19 1422,19 N 7, 1708 32 13 1608,52 15,06,52 N 7..03~ ,~800 32 58 1692,83 1590,83 N 6,22~ ~1900 32 58 1776.80 1674,80 N 6,40~ 2000 33 23 '1860.50 1758,50 H 6,02~ 2100 33 48 1943.80 1841 ,80 H 5,62~ 2280 34 1 2826,79 1924,79 N 5. 77.° 94 H li09,?? H '.1'10,54 1.47,49 H 16,45 190,28 ., 238.38 H 3 291,80 H 39.45 346,42 H 46.97 td 399.71 H 53.8.7 id 453.'12 H 60,.08 U 5:07.'11 H 66, :04 td 561.51 H 71.96 U 616.55 H .77.57 67'2.08 H 82.87 78,'13 N 3 56 8 W 1'10,28 N 5 29 6 id 148,41 H 6 21 47 id 1:91,77 H 7 8 27 U 24'0,50 H 7 36 56 Id 294.45 H 7 41 59 id 349,59 N 7 43 '15 Id 403..33 N .7 40 33 id 4:57,09 H 7 33 8 id 511.39 N ,7 25 12 W 566'.10 N 7 18 11 Id 62t .41 H 7 10 14 Id 677.'17 H 7 1 44 Gl 'DOG LEG SEVERITY DEG?IO.OFT · , :'00 0 ,41.7 .117 ,183 ,21,7' 1 ', 052 3 o ~0'1 ? 2.684 3,389 3,6.06 2,987 3. 567 3. 200 2,910 4,074 2.918 I .318 .616 .662 , 144 .432 .435 .241 SECT I OH b ISTRHCE ,00 - 33 - 86 - 81 - 63 26 5 29 15 26 30 51 51 59 78:04 1:09 98 147 83 1.90 78 239 iO4 .... 292 62 347 4O 4.00 84 454 37 508 48 563 O0 618 16 673 80 GYROSCOPIC SURVEY JOB HO., ,'1339 © SURVEYED '15 DEC:, 82 RECORD OF SURVEY 1,,~:.~ TRUE IE~S, DRIFT VERTICRL )EP.TH RNGLE DEPTH , , D H . ~ .SUB DRIFT SER DIREC DEG., TOTRL COORDIHR'TES CLOSURES D I'STANCE ANGLE !:23'~00 34 8~ 211.09,68 2'0!07,613 N 4,23W 727,.122 24~0~ 35 1'2 2'192,.00 2'090,:00 N 3,7'0W ,784.,47 25~ 35 41' 227.3,4.7 . 21.71,47 N 2,77~ 842, 2600 36 :1 2354,52 22~2 ,.52 H ,3.0~ 900,9.0 2.7~ 34 42 2436,07 2334,07 N'2,20E 958, 280.0 33 .7 2519,:07 2417,07 N 3.72E '1014, ~'1o46 96,36 95.,40 92,52 .733,06 H 6 51 2'1 Id ?8S.,.?e H 6 39 4 Id' 047..67' H 6 25 13 Id 906,:04'N 6 6 17' bi 963.49 H 5 40 56 bi 101 8,6.'7 H .5 12 39 bi ?~00.31' 'I:1 26.03.73 25.01,7.3 H 6,17E 1.067.,4~ H 8.7,93 W 10.71,09 N 4 42 33 W 3iO:.O0 3:0 2~ 2669,66 2387.66 t4 8.:07E 11'18.22 , , o 31~0 26 9 2Z76.91 26,74 9'1 H 8 5.?E 1166 55 32~ 26 9 2865.89 2,763.09 H 6.47E 1211.68 3300 24 18 2956,35 2854,35 H 8,18E 1253,84 H, 340.O. 22 19 3048 , '10 2946 ,10 N 8 , :02E 1293 ,.'01 ' .~,,.5:0,74 .... 35~ 21 5 314'1,~9 3039,.09 N 8.43E 1329.61H 3600 19 28 3234,89 3132,89 H 8,TOE 1363,67 H 3660 18 42 3291,6.0 3189,60 H 9,82E 1383,23 t4 3700 'la 42 3329.49 3227.49 N 9,82E 1395,B? H 38:00 18 42 3424,21 3322,21 H 9.82E 1427,46 N 3635 18 42 3457.36 3355,36 H 9,82E 1438.52 H 45,58 ~ 42°42 U 40,24 bi 34,77 bi 32.06 bi 1364,63 N I 54 5.0 W 1383,00 N i 45 24 W 1396,45 H I 39 4 bi 1427,88 14 1 23 43 bi 1430.89 N 1 18 30 bi DOG LEG SEVERITY 'DEG/I~OiOFT ,329 '1,2:09 ,594 ,916 '1,546 1,647 2,042 ,97'0 2,186 2,~0.00 1.051 '1,903 1,235 1,617 1.2~2 ,'000 .,.000 ..0'00 I~OTTOM HOLE CLOSURE 14~8,09 FEET RT H 1 10 30 Id , . SECTION DI:STANCE 729.63 786.35 844.38 902.06 96'0.6,0' 1016.31 '1:069.20 1119,79' 1'167,95 1212.91 1254,92 1293 96 1330 42 1364 56 1303 84 1396 42 1427 80 1438 89 0 © qRCO B-WS-9 · GYROSCOPIC SURVEY .dOB NO, 1~39 · I'ERSURED DEPTH Atlb OTHER DATA FOR EVERY EVEN 1.0!'0 FEET OF SUB SEA DEPTH, .,~,. !.. !...!~! . TRUE ,:~ MERSL. EED VERTICAL SUB HD-TVD VERTICAL " DEPTH DEPTH SEA DIFFEREt4CE CORRECTION. TOTAL COORDINATES SURVEYED 15 DEC, 82 8 O, '1~02 0 2;82 202, 100 · 3.02 3'02, 200 402 4'02, 300 502 502, 400 iO 602 6'02. 500 · 7..03 7.02, 6 O0 80.4 , B 02, 700 '1 906 902, 800 4 101~0 1002, 900 1116 ' '1102, 1.000 14 1225 1202, 11 O0 23 1337 'I 3'02, 1200 35 14.54 1402. 1300 5 I · 1574 1582, 1400 .? :1692 '160'2, 150 O 9'0 :181'1 1.702. 1600 1 :19.3{) 1802. 1700 128 2:05'0 / 902. lBO0 147 2178 2002, 1900 168 229 1 2'1 '02. 200.0 '168 241 2 22:82, .21 00 21 0 2535 2302. 2200 233 2658 2402, 2300 256 2780 2502. 2400 277 289~ 2602, 2500 295 3.014 2702, 2600 312 3128 2802. 27'00 326 .3240 29.02. 2800 338 335:0 3.002. 2900 347 3458 3'I'02, 3000 356 3565 3282, 31 O0 363 367' t 33.82. :3200 .368 377'7 3402. 3300 374 3035 3457. 3355 377 19 2'1 20 22 23 23 21 18 17 14 12 '9 .? 5 3 523,42 588,82 655,46 722,65 791,53 662,90 934,93 '1003.2~ 1~66.42 1125,32 '1'179.~7 1228,93 1273.78 13'14.49 1352,2~ $386.70 1420.05 1436.52 $ ,'00 ~ S ,51 E S , e:O E $ '1,13 E N 2,~08 E N 2,21 E N 2,.75 E H 2.3:0 E N ;83 ~ H 5,86 U N '11 o44 U N 18,'1 0 14 N 26,93 ~ t4 35,89 W N 45. :02 W N 53,3.7 14 N 60.2'2 ~ N 67,86 W N 74.79 W N 8'1.32 14 N 87,12 Gl N 91.94 W N 95,63 W N 96,10 W H 93.22 14 N 88 .:05 bi 80.59 14 N .72,56 W N 65.22 W t4 58 ..75 W N 52,96 W N 47.36 W N 41 ,82 W N 36,05 W N 32,86 W C) 0 RCO 8;1d$-9 GYROSCOPIC SURVEY HTERPOLATED VALUES FOR EVEll 1;'000 FEET OF HEflSURED DEPTH, : TRUE ' DEPTH DEPTH' ,SEA TOTAL COORDINRTEO ,JOB HO., '."1339 1~0,'0 ~'2,, 89:0. 77,9~ H 5.36 240.0 ',1860. t~56, 561,51H ~:,.96 3~0:8 269:0, 2588, t:1'18.22 H 3835 345,7. 3355. 14.3.8,52 H '3~L, e6 ,rD SURVEYED 15 DEC. 82 iRCO".B'ZWS.79' GYROSCOPIC" SUR,VE¥ .,JOB, HO. :1.330 SURVEYED '15 DEC 82 ~ ~':' IHTERPOLATED TRUE ~ERTICRL DEPTHS~ COORDIHRTE.S AHD CLOSURES FOR' GIVEH DEPTHS ;ODE:' ! ; . [P tip ~ UGHiLI 3:213 [p,, LU: UGHU 31~i54 'BTDi. :' 37:19 rD. , : 3835 HERSURED DEPTH "TRUE ,, ~ERTICRL TOTRL COORD:IHRTE~. DEPTH 3191.63 1,340,.44' N '3347.48 '1401,87 H 345.7.36 't438.,5~'H ' C' L 0 S U R E SUB DXSTRHCE. "IqHGLE ':86..$~ ~ "",~2'19.16" H 3 8 5:0 W 27,75.57 '39,R~ ~ d4~2:,'42 N. 't 36 5 U '3245..46 3R',8~ ~ :1438".89 H ,1 18 3;0 U 3355.36 Alii: Scientific ~[~. Drilling Interr'~ational ' ~ .... i l' ;' ::~: .......... ~ ~'- ' ~- ' ........ TMD =- 5'85"5-" ~ ' ~ , : - ' - .............. " -~:- ......... :- --~:--~ 1----~ ' ' ~-' i:~. :,.~ --i--:-::.;-~,-._::-:::'~:-.:.::::r:....-. ~_ .- :: I I .............. _ ..... :L.,_._ ..... ~ ........ .+ .................... !', ........ . ~ . - ~- ................ i .... _.~ . . .., ~ : , , . · ] .-: Zi --__[- ' ::::::::::::::::::::::::::: -._ ~ ~ -__ :-: _-- L :-_ T ......... : .......... -" · . -_ ........... ~ ....... :_.._..___- ; .......... ~ ...... ~ .......... ~ ......... ~ .................. ......... : ...... ~ ...... !-: ........ ~- ....... !- - ........... _~ .................... - ........ ~__ ; ............ , -. ::'---iT:-:---: :f---:::-'--. .... !::4-::: -' :-.-_:.. -:':_:' :: :: :~-_:.----:: :!- i:1 ~L_:~EP.T~S -S,OW'"':j'~{:_:~-'-_--::--'-':::: :.:::: ::::::::::::::::::::::: _. ................ r- ---T ............ : .;.-- -. ..... -~ - ~ ........ ~ ............... :~ ...... : .......................... : - .- ..... ~-~ ........ ' - ~' ......... i : ..... : .......... ~- --'- '- ~ ................ ' .................. .............. ; .... ~ .............' ':---:-:-:-:--':---! ........ : ....... : " ........ T ......... ~ ...... ~ :-- ...... . ............................ :----~.- -- -r- - -.- :-- --:.- ........ .. ,_- ---~ . - ............. ~ .......~ ............ ..... -.-:.._z !--.--:_-:_'---:-: :-_: .... 7-.'.:: .... .. ":_ ....... : ....... ~ ----~--: ........ :. - T----. .......... ! .... -J ...... ., i .-. i.. :._.5_2.2 ...... · . i : · · '~ --_z.-._--'-_. · , · . 1 [ ; ~: 'i : 'I ~ Y'; ' ! - ; !': J : ;.: _J; !i: ::1: : ,t-:'.:.-.'.~ ''--: :: ;, ~..,~,. t..'~ : :i','-'- I : ~i'~ :ri: . Suggested form to be inserted in each "Active" well folder to ckeck for timely compliance with our regulations. ~ ' Operator, W~,ll Name'and Number Reports and Materials to be received by: !'- !"7- ~, ~ D~t% Required Date Received Remarks Completion Report Yes Well History Yes · . , , 'Samples · Mud ~,cS ///D ..... ~- ,, . --, -.. ~. ,, ..... t . ~ Core ~script~on Registered ~ey Plat 7~J' Inclination S~ey /~'O , 7 .Drill St~ Test Returns ~,4/~''~''- ~/. >.. Digitiz~ rata ~ 5 / // ~ ~ /'"' ...... ., TO: William VanAlen FROM: ~,. ,/~1~ ~,~,.., ~~~ Transmitted herewith are thee following: · ~ PI.~ASE NOTE: BL- BLUELINE, S - SEPIA, F- FII/~, PC - PHOT~PY D. W. Bose/Lorie L. Johnson p~~~PT E RETURN R~CEI~ TO: ARCO ALASKA, INC. ,~ :., ~.,:w.:t-'. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office B 360 ARchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2~11 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 A1 so enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-iOGI 12-20 1E-25 13-6 The survey for 2-22 needs %o be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28'llm Attachments ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKAC AND GAS CONSERVATION CO[ -IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-196 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20868 4. Location of Well at surface 321'FNL, ll80'FEL, Sec. 9, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. L~]~eLDe~i~a~n and Serial No. 102' RKB ALK 466 9. Unit o~ Lease Name Kuparuk R~ver Unit 10. Well No. WSW-9 11. Field and Pool Kuparuk River Field Lower Tertiary (Upper Ugnu) December 82 For the Month of ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0400 hrs, 12/07/82. Drld 13-1/2" hole to 2500'; ran, cmtd & tstd 10-3'/4" csg. Pumped top job. Drld 8-3/4" hole to 3835'TD; ran, cmtd, & tstd 7" csg. Ran logs & Gyro. Perf'd well. Performed cased-hole gravel pack over perforated interval. Ran 3-1/2" compl, assy. Secured well & released rig @ 0230 hrs, 12/20/82. SEE DRILLING HISTORY. 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2477'. Cmtd w/1400 sx AS III & 250 sx AS I. 7" -, 26.0#/ft, K-55, BTC csg w/shoe @ 3807'. Cmtd w/350 sx ClassG. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run GR/SP/DLL DIL/SP/GR , GR/CNL/CDL CBL/VDL/CCL/GR NFD 1 6. DST data, perforating data, shows of H2S, miscellaneous data 3135' - 3178' 3306' - 3310' 3186' - 3205' 3316' - 3342' 3213' - 3226' 3356' - 3396' 3241' - 3254' 3407' - 3508' 3259' - 3278' 3519' - 3525' Alaska 0il & Gas [;0ns. [;0mmissi0r, Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED ~~-~-/~ TITLE Sr. Drilling Engineer PATE //~////~ NOTE--RepOrt on'this f~m is required for each calendar month, regardless of the status of operations, and must be~ filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. FOi;m 10~,04 Submit in duplicate . WSW-9 DRILLING HISTORY NU 20" Hydril & Diverter. Spudded well @ 0400 hrs, 12/07/82. Drld 13-1/2" hole to 2500'. Ran 62 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2477'. Cmtd 10-3/4" csg w/1400 sx AS III & 250 sx AS I. Pumped 100 sx AS I top job. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 10.1 ppg EMW. Drld 8-3/4" hole to 3835'TD (12/11/82). Ran GR/SP/DLL, DIL/SP/GR & GR/CNL/CDL. Ran 91 jts, 7", 26#/ft, K-55, BTC csg w/shoe @ 3807'. Cmtd 7" csg w/350 sx Class G. Arctic packed 7" x 10-3/4" ann w/150 bbls H20, 220 bbls Arctic Pack & 110 sx AS I. Milled out inside of 7" pup below 7" hanger. Tstd 7" csg.to 2500 psi - ok. Ran CBL/VDL/CCL/GR. Disp well to NaC1. Tstd csg to 2500 psi - ok. Ran Gyro. (PBTD = 3719'). Set sump pkr @ 3541'. Perforated the following intervals: 3135' - 3178' 3186' - 3205' 3213' - 3226' 3241' - 3254' 3259' - 3278' 3306' - 3310' 3316' - 3342' 3356' - 3396' 3407' - 3508' 3519' - 3525' Performed cased-hole gravel pack over perforated interval. Ran NFD. Ran 3-1/2" compl, assy. (see tubing detail). ND BOPE. NU tree. Tstd packoff to 3000 psi - ok. Disp well to diesel. Secured well & released rig @ 0230 hrs, 12/20/82. JG'ltc FO5 Gas Cons. CommisSior~ Anchorago KUPARUK ENG~ING TRANS # B3 TO: William VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL- BLUELINE, S - SEPIA, F- FII/~,~- TAPE~, PC ~ PHOTOCOPY ARC'O ALASKA, INC. Alaska 0il & Gas Cons. ATI'N: LORIE L. JOHNSON.- AFA/311 Ancllorage P. O. BOX 360 ANCHORA(~, AK. 99510 TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the follc~ing: Pr~ASE RETtS~ RIDCEIPT TO: ~ __. RE£FIV3.~ 'L~I~ C 2 8 I73 z'~ ~ ARCO ~, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 ...... Ap.c!lotagu 'MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION ~/~ DATE: TO: C.---~~~' ~terton Cha,~~'~'u~-~ FILE NO: 108/E /?;~, Thru: Lonnie C. Smith 'I: Corn. mi s sione r ~....~. FROM: BOIl ~7o~an r~tro!eum Ins~ctor December 17, 1982 TELEPHONE NO: SUBJECT: Witness BOPE Tests on ARCO ' s Kuparuk WSW-9 Sec. 9, Tll~:~', R10E, .~uparuk River Unit T~.ur.s..d. ay,_ .December 9,_ 1982 - I departed my home at 12:20 p.m. for a 12:50 p.m. showup and 1:50 p.m. departure via Alaska Airlines flight #61 for Deadhorse arriving at 3:30 p.m. t,?eather: +2°F, high overcast, no wind.. _Friday_,. December 10, 1982 - DOPE tests began at 1:00 a.m. and. %~re completed_ at 2:45 a.m. BOPE inspection re~ort is attached. DOPE tests on ARCO's Kuparuk 1F-4 were completed, the subject of a separate report. DOPE tests on ARCO's DS 14-6 workover were completed, the subject of a separate report. Saturday, December 11, 1982 - Witnessin9~ of testing of low pilots, SSV's, SSSV's, and. record.ing of annulas pressure on fourteen Sohio _~lls w~s completed, the subject of a separate report. Sunday, DeC_ember 12, 1982 - DOPE tests on ARCO's DD 13-8 ~_~re completed, the sub-jct of a separate report. I departe~ Deadhorse at ~:10 p.m. via Alaska Airlines fli_.~t #56 arriving in ~chorage at 5:50 p.m. and at my home at 6:20 p.m. In summary, I witnessed, successful DOPE tests on ARCO's Kupa ruk W~$- 9. O&G #4 STATE OF ALASKA ALASKA OIL & GAS QgNSERVATION CQV~VfLSSION B .0. P .E. Inspection Report .Inspector Operator. ~ ~-~ Representative. Well ~'/~ ~~3/~1 ~.~~- ~ ~t 9 ~ ~tion: Sec ~' T'/~R/O~I ~' /J~sing Set ~illing ~n~a~or ~~~-~ Rig ~ /~/ Repre~ntative Location, General Wel 1 Sign_ Ceneral Housekeeping Reserve pit Rig Test Pressure ACCUML~ATOR SYSTEM Full Charge Pressure ~ · ~ psig Pressure After Closure/~ ~ psig Pimp incr. clos. pres. 200 psig min /,~sec. Full Charge Pressure Attained: -~ min~?.sec. N2 /~_ ~ ~.__~-~!/ -~ ~ psig Controls: Master (D F~ Remote ~D/~ Blinds switch cover Kelly and Floor Safety Valves - Annular Preventer Pipe ~ams Blind Rams Choke Line Valves__ Upper Kelly. Lo, er Kelly. Inside BOP Test Pressure Test Pressure Test Pressure ~/~.~I'est Press~re H.C.R. Valve Kill Line Valves Check Valve Choke Manifold No. Valves No. flanges. Adj ustab le Chokes Test Results: Failures / Test Pressure Hydrauically operated choke Test T~' / ~--¥~hrs .. RePair or Replac~uent of failed ~quipment to ko made within . days and Inspector/Ccmmission office notified. Remarks :. ~-~--.~-~-~ . _~_~ ~ ~ Dis%ribut ion orig. - AO&OCC cc - Operator cc - Supervisor Inspector November 24, 19~2 Mr. Jeffrey B. Kewin Senior Dril ling 'Engineer ARCO Alaska, Inc. P. O. Box 360 ~chorage, Alask;a 99510 KuparutI P--.tver Unit ~---S~ 9 ARC~ Alaska, Inc. Pe~it No. 82-196 Sur. Loc. 321'~L, llS0'FEL, Sec. 9, TllN, ~tmhole Loc. 12$5'FSL, 1434'FEL, Sec. 4, l'llN, i~.10E, Ult. Dear ~. ~ewin: Enclosed i~ the approved application for permit to drill the above r~fereneed ~-ell. If coring i.s conducted,-a one cubic inch chip fron.' each foot of recovered core is required. Sample~ of ~¥elI cuttings and a r~rad log are not required. A continuous directional survey is required aa per 2~ AAC 25.050(b)(5). If available, a tape containing the digitized log. info'rrnation shall bo submitted on all lo~s for copying except experimental logs, velocity surveys anti- dipmeter ~urveya. ~la~y river~ in Alaska and tl!eir drainage syste~rns have been classified as in~I~ortant for the sparkling or migration of anadromous fish. Operations in these areas are subject to AS 16.05.1170 and the ~o~ilations promulgated thereunder (Title 5, Alaska Admini.~traiive Code). Prior to co~nrneneing of.~erationa you. may be contacted by the Habitat Coordinator's Office, Department of Fish and Pollution of any waters_ of the State is prohibited by AS 46, Chal2ter 3, ?Article 7 an¢i the regulations pro~ul(~_ ~ated therem~der (Title 18, Ala~ka Administrative Code, Chapter 70) and by .the Federal ¥{ater Pollution Control Act, as a~ended. Prior to coa~;~encing operations you may be contacted by a representative of the Department of En¥iro~mental Ccn. servation. TO aid us in scheduling field ~ork, please notify this office 2.4 hours prior to c(~encing in~tallation of the blowout Jeffrey B. gewin I(uparuk River Unit -2- November 24, 1982 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 e~ncing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very truly yours, C. V. ~tert~n-" Alaska Oil' and Gas Conservation Commission -Enc 1 o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enel. CVC:be ARCO Alaska, Inc. Post Office B~. .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 November 15, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk Water Source Well #9 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk WSW #9, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1B-1, 1B-2, 1B-10, 1B-11, and WSW-9. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. o An analysis of well proximity - water source, Well No. 9. As we anticipate spudding this well on or before December 9, 1982, any questions regarding these wells should be directed to Mr. Rich Gremley in our office at 263-4972. Sincerely, J. B. Kewin Senior Drilling Engineer JBK/JG: 1 lm Enclosures GRU2/L39 RECEIVED NOV 1 9 A~aska Oil & Gas Cons. Ocmrnissior~ Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA "-'".. ALASKA O,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL ~[~ REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] Water Source XXDEVELOPMENTOIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE E~x MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 321' FNL, 1180' FEL, Sec. 9, T11N, RIOE, UN At top of proposed producing interval 924' FSL, 1377' FEL, Sec. 4, T11N, RIOE, UM At total depth 1285' FSL, 1434' FEL, Sec. 4, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) 61' GL, 66' PAD, 102' RKB 6. Lease designation and serial no. ADL 25648 ALK 466 9. Unit or lease name Kuparuk River Unit 10. Well number WSW-9 11. Field and pool Kuparuk River Field Lower Tertiary (Upper Ugnu) 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $5007000 13. Distance and direction from nearest town 30 Mi. NW Deadhorse miles 16. Proposed depth (MD & TVD) 3899' MD, 3424' TVD feet 14. Distance to nearest property or lease line 3846 feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed 1B-11 well 167' at 942'MD feet 18. Approximate spud date 12/09/82 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 35 20. Anticipated pressures o (see 20 AAC 25.035 (c) (2) 1537 psig@_JB0° Surface 1500 psig@ 3424 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER Grade Couplingl Length H-40 Welded I K-55 BTC I 2369 ' K'55 IBTC / 3864'__ Hole Casing Weight 24" 16" 65# i3-1/2" 10-3/4" 45.5# 8-3/4" 7" 26# 22. Describe proposed program: SETTING DEPTH MD TOP TVD 80' 36.5'1 36.5' 36' 36' I 34.5' i 34.5' MD BOTTOM TVD 116' Ii 116' 2405'I 2200' I 3899'13424' I I QUANTITY OF CEMENT (include stage data) 250 cf ± PF II 1400 sx Arctic Set III 250 sx Arctic Set I 250 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field, Kuparuk River Unit, water source well to approximately 3899' MD, 3424' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 1537 psig based on warming of a gas bubble rising at constant volume. A 3-1/2" gravel pack screen will be run to ± 2900' TVD and gravel packed. The interval will be produced by a downhole pump set above the gravel pack packer on 3-1/2" 9.2# J-55 BUTT. TBG. Non-freezing fluids will be left in uncemented annuli through the pr~r~al~;~li~t~rval. Selected intervals will be perforated within the Ugnu formation and reported on subseq~j~ri[l~([;~r~s[V 23. I hereby certify that the foregoing is true and correct to the best of my knowledge NOV I 9 ]-482 The space below for Commission use Alaska 0il & Gas Cons. Commission _ TITLESr. Drilling bngineel~nch0rage DATE .~%,--%,~ '~.. CONDITIONS OF APPROVAL Samples required []YES [~NO Permit number APPROVED BY Form 10-401 Mud log required Directional Survey required APl number I-lYES ~.NO [ZlYES I--INO 50_ O 1. ~; --t. c ~ (~¢ / Approval date ,~ .,~9. ,,~ ,, SEE COVER LETTER FOR OTHER REQUIREMENTS '"~//~~~~ ,C O M M,""//'~ SS lONER DATE Novem_he_- _9. 4, ! 9 8_9. Submit in triplicate ANALYSIS OF WELL PROXIMITY WATER SOURCE WELL NO. 9 NOTE: Refer to the attached proximity map. WSW-9/1B-11 The proposed Well WSW-9 will-el-o~ the existing Well lB-11 by a distance of 167' at a measured depth of 942' (in 1B-11) and 900' (in WSW-9). This distance was calculated using the Gyro multi-shot survey on 1B-11 and the proposed course for WSW-9. Well 1B-11 has an ellipse of uncertainty of 29' across its major axis at the depth at which the crossing occurs. WSW-9 will have an ellipse of uncer- tainty of 27' across its major axis at the depth of interest. The areas of uncertainty for the two wells will therefore not intersect. In addition, these wells diverge. In light of the above, we feel we can safely drill Water Source Well No. 9 and avoid proximity problems with the adjacent wellbore. RBG:JG:llm 11/17/82 GRU2/AWP2 Surface Dive~ .r S~,stem I. 16" Bradenhead. · 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi dri.lling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell .nipple. 16" Conductor 5000 PSI ,'RSRRR BOP STRUCK i J '1 PREVENTOR - 9 - BL I ND RRHS ,:.:-'"" .. _r' ' PIPE RRMS '7 ILLING SPOOL 6 PiPE' RR,~S 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3303 PSI casing head · 3. 10" 3000 PSI tubing he=_d 4. 10" 3000 PSI x 13-5/8" 5C~0 ~I .. adapter spool .: ' 5. 13-5/8" 5000 PSI pipe ra~ 6. 13-5/B" 5000 PSI drilling s-po~l u/choke and kill 1 ines -.- - 7. 13-5/8" 5000 PSI pi~'ra~s- .... "...'.. .... 8. 13-5/8" 5000 PS). blind ~ -- 13-5/8" 5000 PSI ann=lar ..... 9~ 13-5/a" EO~ STA~ TEST '-. 4.,,TF_~ ALL CC~*~qr~ TO Z~O : :5 - ' ' 10 ' . '- .- IO~IT~ES. B~D TO ~0 ' . - - .- -. P~E~.. . ' - .. - ::'---.-- . - 7. I~E'P~~ T0 ~ 4 ": ' ' ""' " ' ' ~J' - - - .-'--.. : _~ .= _- . ' S~ED~(ST~LP~~ . /~ ~ · V~V[ ~ ZE~J ~I ~~. HD . ~ - TO~PS~. - 3 ~ . . . ' g, ~ TOP S~ OF PI~ ~ i - - ' S~ ~ PiPE ~. ' CSG' ~ ~ ~ ~ ~ ' 1~. ~ ~ S~ OF PIPE 7. ~ - . · . _ - S~OTOZEROPSZ 'I -' _ f ._ ' " ~ ~ ' OI~ ~;O ~L YAL~ ~ ~ '~ ~ - ~m;'~-~'"'~- ~F~ohor8g~ -- 13. ~ ~OPIP~ Y~Y~ TO / . i -':-' ....... ._ - : -- m m~~L- J J . --.-=". ..'::-" : T~F~SIG,t~OS~ / -' J -.:.~:~ ~-''-.~ ~ ' - .' ~z~ - ~'~ 1. FILL BOP STAI:~ Al'lO 14~"iL=OLD friTH AI~:I'/C O =L~SEL. C'~C~ T'dAT ALL HOLD ~ 'S(:2Z~ A..~. ,~JU.I' RE- ~r.D. PRED;TE~.II~ DF..PTE T~..AT ~ I~ILL SERT NI:D SF~,~,T Ill III~i.I.~. ~ Ill ~ S~ IN YALYES 0:1 I..~"'IIF'OL0. ' / o o o o ~ o o ~( ~, /?9. ~ x ~q. ~*~ ~ /~' I~ ' .... ~ ii I~ i I i i ii T~/Ia .......... i i I II III ARO0 Allleka, Inc. Kup&rUk ProJeot North II®pl I)f'llllnl CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fe__ e /,hi (Z thr~""~) 3. 4. 5. 6. 7. 8. (3) Admin ~}~., ,I,-, ,,,~,,g ~ 9. (~thr~ 11) 10. ·11. (4) Casg '('12 thru 20) // (21 thru 24) (6) Add: 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached . ' ~'")~' Is well located proper distance from property line Is well located proper distance from other wells Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore ~ included ' Is operator the only affected party .... ~ .......... ~11111111.11111~ ' Can permit be approved before ten-day wait .......................... , .... .., REMARKS . Does operat have bond in force ' or a eee..eeeeeeeeeeeeeeeeeeeeeeeeeeeee IS a conservation order needed ...................................... Is administrative approval needed ..................... . ............. Is conductor string provided ... Is enough cement used to Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................'' '' Will surface casing protect fresh water zones . Will all casing give adequate safety in collapg~i Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is deq 11 bor parati pr p ed a bate we e se on o os ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating- Test to .~-~-f) Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. ~4 · Additional Remarks: Geology: Engineering: H~-~- __~ LC~ ~.:ii~. BEW ~--' WVA~ JKT~~'RAD ~ rev: 08/19/82 ~;,, INITZAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC, Wel 1 B-WSW-9 Field KUPARUK County. State N. SLOPE, ALASKA Date 12~12-82 curVe Name (Abbrev.) Standard Curve Name Logs Used Scale ..RS I Resistiv,.ity Short ., DLL .. ~2 ~ 2000 RD " Deep " " __~SP Spontgneous Potential " 0 .- 100 GR1 I Gamma Ray 1 .... " 0~100~ 100-200 DEN .De.n, si, ,ty CD,L 1-2~ 2-3 CORR ,, Correction " -.5 - .5 DENP ,, Dens,i,t,y Porosity, ., CD~/C,N 60 - 0, 120-60 CN Compensated Neutron " 60 ~. 0~ 120-60 L ,, OR Gamma. Ra,y ,,. CDL-CD/CN 0:100~ ,10,9-200 CAL Caliper " 6 - 16 " ?} A ..... ,41ask Oil a Gas Uo~s. . , ., .. · ~ ..... , · . . ARCO ALASKA' INC 0, g, B-WS.~_-_9 10 'C:URVF~ : GRI SP . RS RD C L DEN CnRR CN DENP FRON 23~8~ 00. LEwEL SPACING G2, SAMPLES PER..RECORO .......... _ ....... ...__2_- ~- ~ : -7= - .-" .~ ........... . ..... ....... . ..... ..................... . . . RECEiVE8 'AN'~ i ]983 AlasKa. 0i! & Gas Cons. [JOll~mtSSior~ Anchorage PAGE 1 ARCO ALAGKA D,S. B-WSw-9 _DEPTH .... $R1 ......... RS . RDL ..... SP . SR CAL FT. ...... API .............. FlY_ AP! IN ...... 2355. ..... 0.., .0 ......... 0,0 ...... 0_,_0 ........0,_0 ..... 18,7 _ 9.8 .0358, 0,0 .... 0,0 0.0 0,0 ._19.7 9,8 . . _2_563.. .... 0..0 ...... O..~O ..... 0_,O ...... O.0. ..34.0 _ 9.8 2568, _ 0.0 _ 0,0... Q,O . Q._O . 26.q 9.8 ....... ~.5.7.~, ....... 0_,__0 ........ 0._0 ...... 0~_Q ....... 0_._0_...._22.2 . 9.8 25.78; O-0 ...... O,D __.O.. E. D..O .23.5 9,8 ........ 25_85..._ ..... O,O ......... 0.._O .... 0 .... 0 .... 0_.O . 27.8 9.8 2_588. .. 0.0 0,0_ 0.,0 O,O . 26.6 9.8 ....... 2-.5_.P ~, ........ 0__..0_ ......... .0_.___0 ....... ¢_, Q _.. 0__. 0 ...... 28.0 . . 9.8 2598. 0.0 .... 0. O_ 0,0__ _ 0,0 20.6 ....... 2~_05, .......... Q. 0 ........... 0..__0 ....... _O_.E ....... 0,0 ... _2_5.2 .9.8 · ~ ............. 2 . 8 P 08, 0,0 O,,O 0,0 0,0 2 q' 9, .......... ? ~ .15.., .............. 0 _.__Q ........... 0__, _0_ ............. Q,_.Q ..... 0_.._0 .....2 !. 0_.. 9.8 --;' ,.,, 2 :~ '. - 0','0 - o. b - o.'0- -~ 0. o 25.H 9 2428, 0,0 - 0-0_ -O,O 0,0 21,9 9,8 -;~'q::~5,' "o.o ' .0~0:' o.o"~:'O.o 21.5 9.,~ .... 2~8-; ........ 0;6 - .... O~e;- -- 0,0~.- :'0,0 22.5 9.9 .......P~qS.- .... ...... 26.7-i .... ' -0"G:- _0,0__-~6.~ 25.7 9.8 2 .48. 25.q . 2,2 . O,-O .... 6~.-7. ........... .¢-..5_..~ 9,8 ;:,~55~ ' 2~,82500.0.0. ~_'._o.O.. ...... 6~;_7.._26.5 e.9 ......... 3"~'5-8' ........ i"a;-7 o;s 1.o: ~i.8 23.9 Pq65. 20'825000.0 t.1 68.~ 26.0 9.9 ' ' ~q6A-, .... 2i-;'2 n ', - - ~-. :--- _ _ ._ · ._. ~-.A . u.u 8~.9 .23.2 9.9 P~7~., ..... 5.9,._8_ _ .1Y_-8 ..... q_.._~_ ....77..,_2 .... 42.9.. 15.2 p478., 55,7 19.0 2,7 70.7 57,q. 12,6 -_;,48:~_, ...... ~.7._.~ ..... ~_._~ ....... q-_,8 ...... 6~.._,8 .... ~o..2 . i,+.6 ¢~88. 25.9 25.e 1.5 56.5 28.5 1~.8 . .'_2'%93.. 2_6,1'' ...... 6,_0 ..... 29,_7._ .... 58,_5_ ._ 31.8 15.2 2.498. 27.9` .5-2 . ~-9 64,0 34.5 lq.5 25.0.5. ..... !_1.?_7_.. 2_p_o_8. _ .q. 5-_6 __6.~._9 .. 1!._5 10.2 · ~508, 62.9. I7.O 21.2 50,5 77.1 lO.1 _~515. 79.q 12.q 15.q qq.2 88.0 lO PS18e 7%,~ ~1.8 15.7 q6.9 71.0 9,9 2525. ~5,q- 12.0 15.8 45.2 9~.2 9 8 2528. . 87.9 11.I lq.l ~q,l 92.1 9,7 .... P553._ .... 75..~ ..... !0.__._5 ....... !~,.7 ..... 47.0... 75.9 9,9 2.538. 81.1 _10.6 .... !5,5 50..~ _ 98.1 10.1 P5~3, 59,2 ..... 1~...7. . 15,.7 .... 55._9.. 71.6 10.1 ~548I .q6,l _ 1~.8_ 16.5 65.0 49,5 10,1 2555, ..63..4 ..... i~,0 .... 17...~ ._6_5..5. .66,~ 9.1 ?558. 57.6 i3.6_ _i7.0 6~..0 66.~ 9,2 85.65.. 51,.7 15.6 _. 2_o.~. .6~..o. ~.1 ~.5 2568. 52.2 !3.3 16.6 6~.~ 55.7 9.3 2578. 52.1 _ 15.7 17.7 &q.5 47.3 9.q ?.5'85., . ..5~,9 . !5,5_ !9.6.. 6~.8 . 5~.9 9,2 2588, 67,7 12.5 15.1_. 65.~ 76.8 DEN $/C 0.0 1.7 1.8 1.6 1.7 1.7 1.7 1.7 1.7 1.7 1.6 1.6 1.7 1.6 1.7 1.7 1.5 1.7 1.8 1.7 1.7 1.7 1.7 1.7 2.0 2.1 2.1 2.1 2.1 2.0 2.2 1.5 2.2 2.2 2.1 2.2 2.2 2.1 2.1 2.2 2.1 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.1 CORR 0,0 -1,2 -1.0 -1.1 -1,2 -1,1 -1,1 -1,1 -1,1 -1.2 -1,2 -I,2 -1,2 -I,2 -1.2 -1,1 -1.5 -1,0 -1,1 -1,~ -1,I -1,1 -1,1 -1,~ 0,0 0,1 O.O 0,1 0.0 0,1 -0,0 0.1 0,1 -0.0 0.1 0,0 -0, 0 0,0 0,0 -0,0 -0,0 -0,0 0,0 0,0 -0,0 -0.0 0,1 0.0 CN O~ ,0 0.0 39.7 35.9 45.0 qO.7 ~0.1 38.1 36.3 40.8 39.2 38.2 ~2.1 56.6 59.6 4.2.5 ~1.8 36.6 55.2 56.1 ~q.9 ql.5 52.9 ~7.9 56.0 29.2 ~2.6 29.7 30.7 32.7 56.1 35,1 5~.6 52.8 ~6.5 54.1 37.1 36.1 B2.~ ~.4 ~1.2 ~1.4 ~.6 32.4 32.3 33.1 ~5.6 DENP % 160.6 5&.6 52.7 61.0 5~.1 55.0 55.1 5A.8 . 59.9 6~.q 62.6 . 59.7 61.1 57.3 56.0 69.1 59.0 .. 52.9 57.5 59.2 57.8 5A.8 59.q 37.9 3q.1 52.0 59.2 29.9 6a.2 30.1 2~.8 52.5 2R.7 . 30.0 30.8 30.8 29.9 34.1 51.2 30.2 3~.9 52.7 32.2 34.0 30.7 PAGE 2 ARCO. ALASKA INC, .... D.S. B-WSW-9 · SRZ Zs RUi-'-.~' DEPTH FT. _ . API .... MV API CAL IN 260.3.,_ ..... 5_~_,7 .... !3,_6---__ . i7.9 ...... 72;3_ _ . 53..2 9.0 2608.. 42,6 _I!,3 %5,6. 75.9 ~6.7 9,6 26!5... 57_,_2 ._!3.,6 ..... 18,5 76.9 .. 56.S 8.8 2618. _. ~7..6 15,8_ 18.1 _ 72.5 .39.2 8.9 762~.. ~_,.5 __ Z.O_,_~_ .... ~3.~ .... 66..2 .... 50.2 9.2 p628, . 7G,~ _9-9__ !1,9._ 5!,9 78.8 9.~ ~653, ~2.7 9.a 12.~ 50.9 8q.8 9,~ ~658.. 53,9 10.7 1~.1 _ 5g.2 60,5 .~6~8. 82,5 _~0 10.9. ~5.g 87.7 .... ~6_5~., ._ ff2~_.9. .!2-3 ..... !6,2 ...... 5a,9 __ _~0.7 . 9.7 2658. *0.5 13. ~ 17~8 6~. 2 ~.6 9.5 ........... ~66_~ ..... '7~8 ...... ~_~,~ .... %.8.~ .... 63,5 ..... ~6.5 8.9 ~. ~1.7 ~.~, ~z.z ~.~ ~9.o 9.~ ~7'S'. '- ~:5--- ~s-Z - ..... zs-,'9' ' ~7'~- -"S.6 ~.9 2683, 37,6 1.~.~ 17.7 ; 67 2 36 9 9 P688. ~7.8 11.7 1~.1 60.6 ~7 7 9.0 ~69~. 62.~ 8.S 9.7 ~2.7 ..66.9 ~Tls. ~7.i ~.~ s.~ ~7.~ 7~.~ 9.~ ~71~. 6s.! 6.~ a.s ~s.1 66.s lo.a p.7_2~, .... 60..~ ....... 8,3..10._1 ...... ~.6 ....... 66.9 10.8 ~728, 66,~ 6.9 8.7 ~1.5 65 5 10,5 2755. 68,8 ....... 7.-P .......... G,9 ........~9,~ . 62.~ 10.5 ..... 2738. 6~.5 8.3 10.3 39.8 62.9 10.9 27q3. _ .62_.._Q._ ~ 7_,_9 ...... 9,5 .... ~5_..G ..... 62.8 ~.1 PYg8. _ 6q.5 . 6,7 8.3 g2,~ 70.2 9.2 27_55 ~ ....... ~_!_~ 6 .... 5, P ...... ~-~ ...... ~.2,9 .... 66.9 9.1 2758, 59,7 . 7-~ 9-~ . ~5..5 59.5 9.1 P~6..~. ...... 53,7 .... 8_,_8 !_!_- 3 ..... 5_~..0 .... 6!.0 9,1 ~768, 67, 0 6.3 7.7 ~. 6 6~, 9 9, ...... 277:~, _.. 59.,a ........ 9?0 ..... 1.1,.~ .._~5.,.8__. &l,6 9.2 , - ~ ~ . 2778. 6.2. ~ 8,~ 10.0 5~.2 67.6 9 ~7~. _~5..5 .. 13.i l~.3 _.6~.,0 . ~3.S 9.0 ~79S. ~0.0 13.7 . 17.9 77.2 ~5.1 9. ~o.os_._ . ~..S 9.._i !0..7 ..... 75.!... s5.2 9.~ 28Q8- 52.2 _, 9,8 ._.12,.0 69.7 5~.1 9.2 .~.zs, 5.0,0 .... 9,6 . ll.i . 6S.6_. ~9.s 9.0 2818. 68.5· _7.4 8.2 5~.5 63.8 9,4 2825, _ _q9,2 _ _6,.1. 6_.~ .... 57..~. .50.3 9.7 2828. 56,q 6..2 6.5 5~.5 6g.i 10.1 2633, ..... 57_,1 ....... ~__,~ .... 8,5 .57,3_ 61.6 2838. 59.~ 7.q 8.~ 59.1 66.6 DEN 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.1 2.1 2.2 2.1 2.2 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.2 2.1 1.9 2.1 2.1 2.1 CORR -0.0 -0,0 0.0 0.0 -0.0 -0,0 0.1 0.1 0.0 0,0 0.1 0.0 0.0 -0.0 -0.0 -0.0 0,0 0.0 0.1 O.1 0.1 0.1 0.1 0.1 0.2 0.1 0.1 0.1 0.1 0.0 0,0 0.0 0.0 0.0 0.0 O, 0 0.0 0.0 0.0 0.0 0,1 0.0 0.1 0.0 0.1 0.1 0.0 C N % 33.6 37.5 ~1.6 ~0.8 31.5 ~1.9 ~5.8 38.! 52.0 55.4 36.7 32.2 32.3 52.! 32.9 52,4 36.6 31.5 ~6,6 36,8 36.7 39,5 41,5 38,1 37.2 38.5 36,7 34,5 35.7 38.9 38.7 38.0 34.2 ~4.2 36.9 32.6 37.5 33.5 30.1 30.4 31.2 37.9 36.3 35.8 55.9 37.8 35.8 59.2 DENP % 32.5 3,~.2 5.1..4 32.2 32.7 3O.6 29.7 51.7 30.9 30.7 5q,2 35.6 34.1 3.5.5 3~ .9 32.0 31 .5 30.8 28.9 32.7 2.5.7 28.6 31 .0 27.5 51..7 5~.0 51 .7 32.4 33.4 3.%.6 33.3 27.7 50.7 29.9 33.2 42.9 32.4 31.8 32.3 PAGE 3 ARCO ALA$.~iA iNc, ........ i'_' ii 'i _ D,S. B-WSW-9 ..... DEPTH GR_I._ RS. . RD _ SP . GR CAL FT,_ . . API ...... M~ AP1 IN · 2858, 38,5 8,5 10,1 64.~ ~6.5 9,8 . _2__6_65, 5.1,4. __. !0 .... 3 .... 12.2 .... 6/4.0 .. 49.0 9.3 2868, 51,0 12.1 _ i~,7 _ 6~,~ ~8,q 9,0 .... 2.875., ....... 43_..7 ...... 7,9 .... 9,1 ..... 6G..8. 50.8 9.2 p878. _ 95.9 . 10..7 . 1~.5 _70.7 ~8.2 9.1 .... ~885., .__ ~2_.,.7 _ 8_._0_ _.~0.~ .... ~5.5_ ~2.5 9.7 2888. 65,8 5.6. 6.~ 51.8 61.9 9.2 . .. 2893, ..... ~9,8 .... 6._1 ~ _7.1...~S_.a.. .5~.9 9.1 2898, 63,0 . 7,5 8,~ 52,5 67,2 9,3 2908. 99.2 9.5. 12.1 7~.7 50.8 9,~ ...... 2_91.3., ....... %_~ ,_Z ....... l_O~..5 ........... !3 ,_8_ ..... 80_.6 ..... ~. 5 9.9 p918. ql.1 9.7 12.6 80.5 ~7 5 9,~ 2923. ~.1 10,_9 ........ %.3,! .... ~7_.6_ _ . ~5..5 8,9 .............................. ..- - $ 2938. ~7.5 8,7 ~0,5 . ~1.2 ~8.1 9.0 ..... ~_~, _ .7~._g::. 7'~ s..~: so.7 7~.~ ~.5 ~9~. 69.0 6.~ _ 7.5_.55.7 ........ 6a. 5 .~.~ 2965. 52,6 11.~ 13,1 7B,~ 5~, ~ 8,9 ...... ~'~/~S,' -_ ~-i';b ~..~ . zo.o_. _~.~ ~.s ~.~ ...... ~_9.8~, ....... 5_~._, ~ ......... 9,_~ ........ l_o ~_! 70,7 .... 5~,.~ . 2988. 5.~-9 . ia.Q_ 1~.9_ 78.3 56.s 8.9 ........ ?993_· ..... .3~.,.5 ...... ~.~_,..! ..... ~_.-_2 ...... 8~5 .. 32..~ .. 9.0 ...... ~0~_., .... _~2.?_5 ..... %0_.._$ .......... 12.,_~ .... ai.,_O ..... ~0,.0 9.5 ~00.~_. __~5-g _ ZO.Q __Z~.9_ S_5.~ . S2.O 9.5 soz3. 5~.~ zo.o zz.~ s~.~ .... 57.z . ~.7 ~028~ _. 51,3 .11.2_ _ 12__,_7 _~.2 32.2 8.7 ....... 3.0 ~.5_. .... 65?9 ......... 9,5 ....... !_0~,_ ~ ..... _72~, 0 .... 65.1 8.7 30~8. __ 59-6 1!,6 13~0. 75.~ _ ~9.9 8.7 _ . . ~O.~m,__ _5Z~_5 ~0..! ...... !0,6 ........ YO_,! _ .5t.7 . _ 50~8- . 62.0 9. y. . I0.,5. .&7.& 65.6 8,8 .~058,' 38.7 10,9 12.3 _ 7~,e 57.6 8.6 3068. ~3_.3 10.5 12.3 82.q 32.0 8.6 ..3073~... ~27_~ .... 1~_..~ ._ !1,~_.~ 82.~.. 52.9 3078. ,2.0 9.7 10.5 79.2 ,7.1 8.6 ' ~0'837 . .3'.7 _ _!e~,_2 ..... 1~,~_ _82.7 ~.0 8.6 DEN G/C 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.1 2.1 2.1 1.8 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.1 2.2 2,1 2.0 2.1 2.2 2.1 2.2 2.2 2.1 2.1 2.1 2.1 2.1 2.1 2.1 2.1 CORR 0,1 -0,0 0,0 0,0 0.0 0,1 0,0 -0,0 0,1 0,0 0,1 0,0 0,0 -0.0 0,0 -0o0 -0,0 0,0 0,1 0,1 0,0 0,0 -0o0 0,0 -0,0 0.1 0,0 -0,0 0,0 0,0 0,0 0,0 0,0 -0.0 -O.O -0.0 0_, 0 -0,0 O,O 0,1 -0,0 0,0 0.0 -0,0 -0,0 0,0 0,0 0,0 CN ,% 32,2 33.2 32.2 33,7 31.9 33.0 36,1 28.9 39.2 57,8 42,5 31.7 36.6 31,3 34.6 38.3 31.6 59.0 32.3 3~.5 36.2 28.6 ~7,2 52.1 ~0.6 ~0.5 29.8 2D.1 33.9 52,8 33.6 ~7.5 59.1 33.6 32.8 52.7 51.8 35.5 MO.7 DENP ~0 35-5.9 29.~+ 30.8 32.0 39_.8 3P_.l 33.2 33.0 3P.O 31.'4 30.5 2A.3 39_.6 39.2 39.8 31.5 3~ .9 27.1 3~ .7 31.8 33.1 3P.1 55.2 25.2 30.5 3~.~ 3~.2 3~.8 3~.1 2~.~ 35.3 3~.8 3~.0 27.3 35.2 29.9 22.9 35.1 PAGE ARCO ALASKA INc' O.S. B-WSW-9 6R1 'Is R~N WITH DL~, ..... DEPTH GR! RS RD SP GR Fl'... . AP1 ~V AP1 CAL IN . 3108. 78,2 ._ 5.9 . 6.4.. 5q.1 82.9 8.8 . .3!13.. .68.8 __ 6_..._9 7._~ . 48.~ . 78.5 10.6 3118. 69,0 6.8 7.2 ~+5.8 72.9 9.9 ~128.. 7~.1 _6.Q 6,5 ~2,~ 69,9 8.6 . . ~!~5.. __. 75~_6 _.. 6.2 ..... 6.6 .~3.7. .76.7 8.5 3~38, 53,3 9.6 _ lo.~ ~9.7 51.5 8.5 ..... ~.!~, ..... 56,8 ..... 8..,.~ ..... 9._~ ..... 5~,_7 .. 53.5 8.g ~1~, 5S,0 7.8 _ 8.0 53,2 ~9.2 8,5 .... 5!55.~ 5_0_,..8 ..... S.,_~ ........9,.0 ..... 52,1 . b. 9., 6 8.5 5158. 52.8 __ 7.9 8,5 51.~ 52.7 ........... ~_1.6.~_, ....... 55~.6 ........... 8_,_1 ...... ~._9 ..... ~5.2 .... 55.5 8., 5168. ~2.7 8.7 9.9 .... 56..a ,6.0 8.~ 9-,8 . 9.5 57.7 8.5 ' '5178' .... 6-i;8 ;- .... 7.'0-: --'. '7;3 ..... 50.~ 60.2 8.~ ~183' '&3;8 %a-: 7.0; ~7.3 ' 61.2 8.~ ~195. ~s.aJ < 5.9. '-6-,~_- 5e.~ .~.~ ..... ~'1-9-8; ........ ~Z,-6 - 9.0.. i0.2 ...... 6.7..5 .... ~2.8 ~203. '~.0-7"""-:-;-_6,2_'__' "6.6'. &~._7 .......... ~:~.5 8.~ o.z ...... aam, ...... ........ ..... o.5 ........ 66,5 ..... ~8... ~ . 8,4 ~ 23_8.. _ 5.9-5_ 9_~_3 10.2. 63,5 60.~ 8.5 .... ~.~_5., ..... ~_8.._0 .... %0_,Z ....... !!,_5~ ....... 7~2_.~ .... 56.2. 8.~ ~258.~. _68.1. lQ.o__ i0,7 . 6.~.6 65.7 8.~ ....... 5265. _ ~..5~_~ .... 1_2,__2 .... !.3.,? .......7~_._1 ..... 59.6 8.5 ~5268. , !.9.0_ ._8.9 10.1 85.8 17.9 8,4 ~278_, 59,~. 9,5 . 9,9_. 70,Z 6~,5 8,5 . . .~285_, 7_7.,~ ..... B_,6 ....... 8.,.5_ ...... 5_7,._~ ___8_~,6 8,5 ........ _:-s29-5_,.. 71.5 .......lO,__~ ....... ~0.,._0 ....... 5~.5. 74.5. 8.5 3298, ~77,3 .. 8.9__ . 8-6_ 46.__9 73.6 8.7 ....... · ~0_5_. ..... 7_6,6 .... 10_,.~ .......10_,3~ ..4_9,5 7.5.9 . 8.3 . 3~08. . q-_6.q ._ 10.7 ___11.4__ 60._8 41.4 8.2 ...~313.... 6~,_7 ... !O.,.~ .... !0,8 .... 62.5 66.5 6.2 3318. . 56.1 10.2. !0.9 . &&.~ 60.5 8.2 .......... ~323. .... 35,_~ ....... 9_,~ ........ l_O~! ..... 7q..9 ..... 59,8 .~328. 36,8 %0.0 11.1 80.A 58.1 . . ~55.. 3~,q _.~8_,~. ~1.,6 . 85.2_ 56.5 8.3 5538. 37.5 . lQ,.9 11.6 79.~ 55.0 DEN 6/C 2.1 2.2 2.1 2.1 2.1 2.1 2.2 2.1 2.3 2.1 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.1 2.1 2.1 2.1 2.2 2.1 2.1 2.1 2.2 2.2 2,1 2.1 2.2 2.2 2.1 2.1 2.1 2.2 2.2 2.5 2.~ 2.5 2.2 2.1 2.2 2.2 2.1 2.1 2.1 2.1 CORR 0,0 0,0 0,1 0,0 0,1 0,1 0.1 0.0 0,0 -0.0 0,0 -0,0 0.0 0,0 0,0 0,0 0,0 0,0 0,0 -OoO -0,0 0,1 0,0 -0,0 -0,0 0,l 0,1 0,0 0,0 0,0 0.0 0,1 0,1 0,1 0,0 0,0 0., 1 0,1 0,1 0.1 0,1 -0,0 0,0 0,0 -0,0 -0,0 -0,0 0,0 C N % 28.5 39.6 39.4 37.8 q3.7 32.9 35.5 28.9 30.0 30.7 30.7 32.4 ~2.3 30.2 34.1 37.7 39.7 30.~ 35.4 33.9 29.9 37.1 53,8 ~5.5 36.6 32.8 35.2 30.8 3~.0 52.5 M6.1 31.0 ~2.0 36.6 32.9 36.5 35.6 57.2 ~7.3 39.6 30.0 55.6 35.6 30.7 29.% 31.8 30.4 DFMP % 31.8 2~.6 3~ .6 3O .9 31.4 30.6 30.3 30.7 23.9 31.7 31.0 27.1 30.5 31.5 31 .7 30.9 3.1.4 29.7 35.1 33.5 31.4 30.7 30.9 29.1 32.4 3.1_ .4 51.2 28.6 2~.7 32.2 30.6 27.~ 27.2 3.5.1 35.1 29.5 29.5 22.0 2P.3 2,~.2 29.0 30,8 27.2 31.7 30.9 31.7 PAGE 5 _. ARCo ALAsKA.iN-c' . ii D.S. B-WSW-9 .. . uR1 I$ _RUIN WITH DLL DEPTH.· .GR1 _. RS.__ RD.. _ 8P GR CAL .FT, _.AP1 MV AP1 IN 3358. 5;5.4 9_.7 10.8 66.2 49.0 .5563, ..... 51.9 .__!0,0 .... il..1 ...... 7~.5 31.5 8.2 S~68. 47.2 9..2 10.~ 7~.5 4~.~ 8.2 . . .~7~. ...... 24,1 ........ 8._~...9.5__ ~8~..2_. 21.~ 8.3 3378._ 22.8 .... 8,.! 9.3_. 85.2 26.;5 8.4 5385. ..... 56,_~ ..... ~_.7 ...... 9,6 .... 83.~ . ~!.S 8,4 saa. s5.o si 9 ....... ~ . · ....... 559..~ ..... ~9_,_~ ....... ~,_~ ...... !.0,3_ .7~.2. .46.5. 8.2 3398. 58,0 .__ 8,9_ 9,5 .~.5 59.1 8.2 S~ ...... ~_0_,__2 ..... 8.~_~ .......... 9., ~ ..... 62. ~ _ 62.4 .8,2 · ~.0.~. 56.4 8. a. 9.5 6.7. ~ 56.1 8.2 ................ ~.~.~ ..... 5~,_6 .............. 9>_~ ........ !.O.Z ........ Z.~.,2 ..... 52.1 ~.2 3418. ~7.8 9.~ 10.2 7q.4 46.5 8,1 3~28. 41.8 _ 9'~ - 9o7~ ~78.~ 40.7 8.2 s6.a _ ._ao_.7 ..... 8.2 ~,~58. -' 40.~"~-9;-7---1.0._~;:__~_ta~.e__.' :31...5 .... 8.2 o.a ......................................... Mq68. ~6,8 9.9 10.8 8~.~ ;55.0 8.1 ~47~, 47.1 11.~ 12.1 78.~ 48.1 8.2 ~48~. 55.3 10.9 10.4 6~.9 56.2 8.2 S~88, ~9.5 9.1 9.6 7~.6 ;58.5 8,2 5q95. ~4.0 9.~ 10.1 76.? ~4.~ 8.2 ....... ~5_0_~., ........ ~_Y_~_7 ..... ~_0 ~_8 ....... !1~..6 ..... %q_,6 ....... 5.0,5 ~50_8. 51.5 10.1 1.0,2 . 72,5 §~.8 ~,1 _ . 351~, .... 6~0 ...... !2.5 ..... !2,_6 .... ~_,.~_ . 66.6 8.2 551.8. 73.8 11,2 11.;5 ~1.6 ~9.0 . . . ~2~.. ........ ~,~ ...... ~._~ .....~.~ .....70,4 .....~..0 8.2 3528. 85~0 . 7,7 ~ . 6~9 59,0 92.5 8.4 ._ 5.5~.. ..... 79,_P .... !O,J~ ....... 9._S .......52,!.. 81.7_ 8.4 353~._. 8~.~ lO.q _ 1o.~ _~6_.6 .85.6 ~543. ~0.7 lO.~ 10.7 ~6.o 76.3 ~ 4 · 554.8, .64,5 .10,1 _ 10.~ . 50.0 72.7 8.4 .. 5553? .... a!..i ...... 9_,6 ..... :~..6 ...... ~4,1 .... 7.,+.2 ~58. 58.o .9,? .~o.o _59.~ 59.9 s.5 5568. 34.2 6.0 6.8 70.~ ;5~.0 8.5 _ . ..... ~57~., .~0,? .... 7_,.~ ..... ~,7__ 79..3 26.~ 8.5 . ~578. gl.9 9.2 _ . 10.1 _76.8 46.7 8.5 ~o85, '7.3 ..... P, 2 ..... 10.0. _71,o 51.~ 6.5 5588, 62,2 8.7 8,8 .61.5 58.0 8.5 DEN G/C 2.2 2.2 2.2 2.1 2.1 2.1 2.1 2.1 2,1 2.2 2.2 2,2 2.2 2.2 2.2 2.1 2.1 2.2 2.2 2.2 2,2 2.1 2.1 2.1 2,1 2.2 1.9 2,1 2.1 2.1 2.1 2,1 2.2 2.2 2.;5 2.2 2.~ 2.2 2.3 2.;5 2.3 2.2 2.2 2.2 2.1 2.1 2.2 2.2 2.2 CORR 0,1 0.0 0.0 -O.O 0.0 0,0 0.0 0,0 O.O 0,1 0,0 -0,0 O.O 0,0 0,0 O,U 0,0 0.0 0,0 0,0 0.0 0,0 -0,0 -0.0 -0.0 -0.0 -0,0 0,0 -0,0 0,0 0,0 0.0 -0.0 0.0 0.. 1 0,0 0.0 -0,0 -0.0 0,0 -0,0 -0.1 -0,0 -0,0 -0,0 0,0 CN O~ /0 33.6 29.2 ~2.2 34.0 29.1 29,6 35.0 35.4 34.1 32.2 ~2.~ 29.7 30.2 32.0 36.4 36.0 ~1.6 34.8 33.5 35.7 30,8 29.4 30.~ 34.3 44.7 ~5.0 30,5 29.4 30.8 ~2.? 32.7 BO.~ 30,7 30.4 ~2.6 30,5 33.6 ~3.6 32.8 30.4 34.7 32.9 2~.7 28.7 35.0 DENP 27,6 27.4 27,z 31.9 31.1 35.4 35.3 3~.0 27.2 27,;5 29.1 2~.9 ~,1 30.4 31.5 2R.5 3n.O 27.3 ~2.2 29.4 ~.6 ~1..6 5~.0 27.1 2g.g 2~.~ 29.8 2~.7 2M.1 2M.Y 22.~ 2~.2 2~.B 3~.7 2~.~ 2~.6 27.8 PAGE 6 ._ ARC_() AEASKA iNc,. _ '- . p.s. B-WSw-9 ' GR1 IS RUN WITH-DLL. · .DFPTH .."_'.'GRI'- .' _RS_ RD .... SP GR CAL FT. API ....... MV AP1 IN 3608. .73,2 _. 11.4 11.1_ ~5..5 _ 80.0 8.6 361~. 7!.0 . 9.2 __9.,~_. 50.8 76.1 ~.5 ...... 3623, ...... 77,.3 .... .~0 ._6 .... !0_.9 ...... ~2_.7 ...... E628.. 79~8_ !!.1 ._ ~1..6_ _.5~.8__~ 76.1 8,5 B638, 80.,5 _ 9._1__ 9.2.. ~6,8 8~.2 8.6 ......... ~.~_, .... 67_,_~ ......... !P, 6 ...... !0,8_ .... 59~3 _ ._66..2 _ 8,6 ::6~.. ,8.s 8.9 .... 9..o _~.l " :~ ....... $~':'~"-'-' ~'~:"'g :-"_----A:-~.: .... ~0.~:' -~'".: ~. o B698. 64,9. 7.0 7.~-: 5g,.1 3738, _ 2S~6 .... 9~1 . 10..0_. 72.2 .. . :7~_~, ...... ~_5.,._g .......... 5_,7 ........... ~_,_.o~ ._ 6~._7_ .. 37.~8, 67,5 6.9 . 7.3. 55.2 ~758.. 28._6 _. 5.8 6,~ .65.5 q~. 9 9.0 . . .3763, 67~_0 .... 6,__~ ....... 6,_8 .... 51,0_ . 69..0 8,7 37~8. 52,_0 _7.6 7.5 51,3 46.8 8.5 .......... 3773~ .... _~.7,2 _. _1_5,_5 .... !5._~ .... 51,6 ..... B2.9 8.6 . .377.8. 3~,7 _ 16.1 _ _!~.6. 51.~ 56.~ 9.6 ..... ~.783. ....... 5.3,3 ........ 6.,0 ....... 5_,9_ __ 5_0,_9. _ Z!l.7 8.~ 3788, ~6,8. 7,5 . 7.7 50,9. 66.3 ~.~ . ..3795....65-.~ 7..9 ..... 7.,_~ .... 50..9_. 95.9 8,0 M798, 57.9 7. ! 7.1 50.9 66.7 7.9 . S~03, . 53,2 ..... 6,f~ ...... 6,_9 ..... 50,.9_ 63.9 8.2 ~8_08. 60,g 6-6 . 6.9 _50.9 65.2 5,q ~.~z~. 5~.5. . 6.5 ........ 6..9_ 50.9 . M818. 58,9 . 6.7 6.9 50.9 6.6 4.8 ...... M823_, ..... 62..9 _.. 6,7 G,~...50.9 . . ~828,-__PO9,1 ..... 6.7 6.9 50.9 DEN G/C 2.2 2.2 2.3 2.3 2.3 2.~ 2.3 2.2 2.3 2.2 2.1 2.1 2.2 2.2 2.i 2.1 2.1 2.1 2.1 2.1 2.2 2.2 2.2 2.2 2.2 2.2 2.2 2.0 2.2 2.2 2.2 2.2 2.1 2.3 2.3 1.9 2.0 2.2 2.2 2.2 2.~ 2.1 1.8 1.9 1.9 2.0 0.0 CORR 0,0 0,1 0.0 0,0 0,0 0,0 0.0 -0.0 0,0 0,0 0.1 0.0 -0,0 0.0 0,0 0,0 --0o0 0,! -OoD 0,0 0,0 -0,0 0,0 -0,0 -0,0 0,0 0,1 0,1 0,1 0,0 0.0 0.1 0,1 0,1 0,1 0.2 0,1 O, 1 0,1 0,1 0,1 -0,0 0,2 0,0 0,1 0,1 0,0 CN % 38.7 32.9 33.5 29.9 29.0 34.9 32.0 27.9 32.0 31.7 33.5 35.0 32.7 33.4 30.0 30.4 33.6 31.7 30.6 32.0 31.7 ~2.2 31.7 35.5 31.0 36,1 34.9 30.5 33,2 32.2 30.7 36.4 52.! 26.7 31.5 34.8 32.8 32.9 30.0 33.8 31.1 31.5 0.0 0.0 0.0 DENP % 29.9 2~.2 . 22.3 22.4. 2B.7 24.1 2B.6 25.4. 23.8 28.0 34.7 32.2_ 27.5 2a.8 30.6 33.2 3S.O . 35.1 .. 3~.7 32.4 25.1 25.9 27.7 25.8 2~.4 25.0 39.6 30.1 24.8 24.4 30.1 31.2 24.2 22.~ 4A.O _ 4~.0 2A.4 27.4 27.0 2~.6 31.5 49.1 43.9 ~2.9 41.5 160.6 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 3,476.0 WSW-09 10/14/2024rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled slipstop & IsoSleeve. Set gauges, slipstop, & Isosleeve. Update Tag depth WSW-09 10/15/2024rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WSR Review 9/11/2023 pproven Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 36.080.080.065.00 H-40 WELDED SURFACE 10 3/4 9.95 35.1 2,476.8 2,254.6 45.50 K-55 BTC PRODUCTION 7 6.28 32.3 3,807.3 3,431.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.0 Set Depth … 3,553.7 Set Depth … 3,191.4 String Max No… 3 1/2 Tubing Description TUBING-GRAVEL PACK Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.030.00.12 HANGER 8.000 TUBING HANGER FMC3.500 2,883.92,590.031.49 NIPPLE 4.500 JET PUMP PROFILE NIPPLE BHA w/XOs. EXACT ID UNKNOWN. BELIEVED TO BE 2.47"-2.55" National 2.500 2,922.0 2,622.6 31.00 SEAL ASSY 5.000 MODEL G-22 LOCATOR/SEAL ASSEMBLY (SEALS STUN IN 13' OF 13.15') Baker2.985 2,922.5 2,623.0 30.99 PACKER 5.968 MODEL SC-1L PACKER Baker 4.000 2,926.7 2,626.7 30.96 EXTENSION 5.000 PERFORATED EXTENSION MODEL S Baker4.400 2,932.5 2,631.6 30.91 SBR 5.560 80-40 SEAL BORE RECEPTACLE Baker 4.000 2,934.02,632.930.89 EXTENSION5.000 LOWER EXTENSION4.400 2,942.4 2,640.130.82 SAFETY JT 3.500 SHEAR OUT SAFETY JOINT 2.992 3,075.62,755.5 28.68 SCREEN 4.140 BAKERWELD .006 GAUGE SCREEN 2.992 3,538.13,176.7 20.47 O-RING 4.250 BAKER O-RING SEAL SUB 1.250 3,538.7 3,177.3 20.46 SCREEN 4.140 BAKERWELD .006 GAUGE LOWER TELL-TALE SCREEN 2.992 3,549.6 3,187.5 20.28 LOCATOR 5.000 OTIS LOCATOR 3.500 3,550.0 3,187.9 20.27 SUMP PACKER 5.875 OTIS SUMP PACKER, MODEL 'WD' 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,880.02,586.7 31.57 GAUGES NO GO gauge hanger w/ gauges set on top of slipstop (2.313" external F/N) (OAL = 57") 10/15/2024 0.000 2,881.0 2,587.5 31.55 SLIP STOP Slip stop set on top of IsoSleeve (2.313" G F/N) (OAL= 19") 10/15/2024 1.750 2,883.9 2,590.0 31.49 ISO-SLEEVE National Jet Pump IsoSleeve w/AVA seals (OAL = 19") 10/15/2024 2.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 3,140.03,182.02,812.32,849.812/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,191.0 3,213.0 2,857.9 2,877.6 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,220.0 3,229.0 2,883.9 2,892.0 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,244.0 3,248.0 2,905.6 2,909.2 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,263.0 3,297.0 2,922.8 2,953.6 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns 3,321.0 3,461.0 2,975.6 3,104.8 UGNU C, WSW- 09 12/15/1982 12.0 IPERF 60° ph; 5" Baker Csg Guns WSW-09, 10/18/2024 9:43:39 AM Vertical schematic (actual) PRODUCTION; 32.3-3,807.3 FLOAT SHOE; 3,805.5-3,807.3 FLOAT COLLAR; 3,761.1- 3,762.7 SUMP PACKER; 3,550.0 LOCATOR; 3,549.6 SCREEN; 3,538.7 IPERF; 3,321.0-3,461.0 SCREEN; 3,075.6 IPERF; 3,263.0-3,297.0 IPERF; 3,244.0-3,248.0 IPERF; 3,220.0-3,229.0 IPERF; 3,191.0-3,213.0 IPERF; 3,140.0-3,182.0 SAFETY JT; 2,942.4 EXTENSION; 2,934.0 SBR; 2,932.5 EXTENSION; 2,926.7 PACKER; 2,922.5 SEAL ASSY; 2,922.0 NIPPLE; 2,883.9 ISO-SLEEVE; 2,883.9 SLIP STOP; 2,881.0 GAUGES; 2,880.0 SURFACE; 35.1-2,476.8 FLOAT SHOE; 2,474.9-2,476.8 FLOAT COLLAR; 2,397.8- 2,399.4 COLLAR; 2,377.6-2,382.3 CONDUCTOR; 36.0-80.0 HANGER; 35.1-37.6 HANGER; 32.3-37.9 HANGER; 30.0 KUP DISP KB-Grd (ft) 41.01 RR Date 12/20/198 2 Other Elev… WSW-09 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292086800 Wellbore Status DISP Max Angle & MD Incl (°) 36.02 MD (ftKB) 2,600.00 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU WSW-09 (PTD 182-196) Report of failed MITOA Date:Wednesday, December 11, 2024 12:50:07 PM Attachments:WSW-09 Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, December 11, 2024 12:38 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU WSW-09 (PTD 182-196) Report of failed MITOA Chris, KRU WSW-09 (PTD182-196) failed a MITOA during pre-rig workover diagnostics yesterday 12/10/24. CPAI plans to have DHD continue diagnostics as weather permits, to determine if the cause of the failure is due to a broken-down shoe or a surface casing leak. The well has been shut in for decades and will remain so. A 90 day TIO plot has not been provided due to the length of time the well has been shut in. A wellbore schematic is attached for reference. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374
