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Home My WebLink About181-134MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-09 KUPARUK RIV UNIT 1B-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 1B-09 50-029-20655-00-00 181-134-0 W SPT 6228 1811340 1557 1933 1936 1936 1936 0 0 0 0 4YRTST P Josh Hunt 6/18/2025 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 1B-09 Inspection Date: Tubing OA Packer Depth 720 2810 2690 2675IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250620081838 BBL Pumped:2 BBL Returned:1.8 Thursday, July 24, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-09 KUPARUK RIV UNIT 1B-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2025 1B-09 50-029-20655-00-00 181-134-0 G SPT 6228 1811340 1557 2744 2746 2749 2750 0 0 0 0 INITAL P Kam StJohn 4/22/2025 As per Sundry # 324-699 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 1B-09 Inspection Date: Tubing OA Packer Depth 280 1995 1910 1890IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250422132359 BBL Pumped:1.6 BBL Returned:1.6 Tuesday, June 10, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 999 9 ¿ 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.06.10 15:30:45 -08'00' 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 8550'feet 7827', 8154'feet true vertical 6822'feet None feet measuredEffective Depth 8371'feet 7611', 7728', 7961', 8097' feet true vertical 6700'feet 6134', 6228', 6407', 6507' feet Measured depthPerforation depth True Vertical depth 3-1/2"Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" 3-1/2" L-80 L-80 L-80 L-80 7746' 7974' 8108' 8202' 6242' 6417' 6516' 6583' Packers and SSSV (type, measured and true vertical depth)7611' 7728' 7961' 8097' 6134' 6228' 6407' 6507' 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: Contact Name: Contact Email: Contact Phone: 6306-6366', 6364-6369', 6416-6438', 6584-6587', 6587-6597', 6600-6602', 6602-6635' 7828-7906', 7904-7910', 7973-8002', 8203-8207', 8207-8221', 8226-8229', 8229-8275' 2235'2486' 20" 13-3/8" CollapseBurst Intermediate 7" Scab 37' Casing 6801'8519' 6190'7680' 2457' 80'Conductor Surface 51' measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-134 50-029-20655-00-00 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/ Kuparuk River Oil Pool KRU 1B-09 Plugs measuredJunk Length 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) Well Not Online Gas-Mcf MDSize 80' N/A 325-054 Sr Res Eng:Sr Pet Geo:Sr Pet Eng: WAGWINJ Water-BblOil-Bbl N/A Packer: INNOVEX Inflatable Packer: Baker Model F Packer: Baker Model F Packer: Baker Model F SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 7"8493' ServiceDevelopment SPLUGSUSPGINJ Gas WINJ WAG Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: RWO/CTD Engineer By Gavin Gluyas at 1:37 pm, Feb 27, 2025 JJL 4/9/25 DSR-2/28/25 RBDMS JSB 030325 Page 1/17 1B-09 Report Printed: 2/20/2025 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) 1/20/2025 09:00 1/20/2025 14:30 5.50 MIRU, MOVE RURD P Mobilization remove cutting box. Jack pit mod. Remove rig mats, jack sub base and pull mats, Spot sub and pits over 1B -09. Make up interconnect cellar berming. Rig ready to take on fluids at 14:30. Rig Accept at 14:30. 0.0 0.0 1/20/2025 14:30 1/20/2025 23:00 8.50 MIRU, MOVE RURD P Take on 9.5 ppg fluid to pits. RU cellar, RU hardlines. PT hardlines OA/IA/T= 0/0/0 0.0 0.0 1/20/2025 23:00 1/21/2025 00:00 1.00 MIRU, WELCTL CIRC P Circulate well over to 9.5 NaCl NaBr. 3.5 BBL/ min @ 550 PSI. 0.0 0.0 1/21/2025 00:00 1/21/2025 04:30 4.50 MIRU, WELCTL KLWL P Circulate in 500 BBLS 9.5 Brine. OWFF, observe fluid U-tubing from presumably the OA, Diesel, Old mud, and other fluids. Line up and pump 100 BBLS more 9.5 until returns cleaned up. 0.0 0.0 1/21/2025 04:30 1/21/2025 05:00 0.50 MIRU, WELCTL OWFF P OWFF 30 min. Static. Blow down lines, and P/U T-bar and put on BPV. 0.0 0.0 1/21/2025 05:00 1/21/2025 06:00 1.00 MIRU, WELCTL MPSP P Set BPV, and perform Rolling test to 1000 PSI for 10 min. 0.0 0.0 1/21/2025 06:00 1/21/2025 11:00 5.00 MIRU, WHDBOP NUND P NU/ND BOP. 0.0 0.0 1/21/2025 11:00 1/21/2025 16:30 5.50 MIRU, WHDBOP BOPE P Test BOPS high/2,500 psi 250 psi low test joint & 3.5" test joint, 1.) Blind Rams, CMV 1,2,3, & 16, Rig Floor Kill, Outter test spool valve, HT38 Dart Valve. 2.) Blind Rams, CMV 4,5, and 6, HCR Kill, Inner Test Spool Valve (Open CMV 2, Rig Floor Kill, Outer Test Spool Vlave) 3.) LWR Pipe Rams, CMV 7,8,9 and 14, Manual Kill, JT-38 TIW (Open CMV 4-5-6, HCR Kill) 4.) Hydraulic Super Choke & Manual Adjusta ble Choke (1,500 psi Test) (Open CMV 7,9, and 14) 5.) CMV 10-11 (8), Manual Kill 6.) UPR Rams, 3.5 FOSV, CMV 12-13- 15 (8) (Open CMV 10-11) 7.) CMV 14 (Open CMV 10-11) 8.) HCR Choke, Hyd IBOP (Open CMV 14) 9.) Annualr, Manual Choke, Man IBOP (Open HCR Choke) Perform Koomey Drawdown Test. Manifold Pressure 1500 psi, Accumulater Pressure 3,000 psi Pressure after all rams functioned=1,750 psi Upper Ram=5sec Lower Ram=5sec Annular=29 Blind=5sec HCR Kill=1sec HCR Choke=1sec 200 psi Recovery=14sec Full System Recovery=100sec 5 Koomey Bottles @ 2,100 psi 0.0 0.0 1/21/2025 16:30 1/21/2025 17:30 1.00 MIRU, WHDBOP PULL P R/D test Equip And R/U GBR casing Equip 0.0 0.0 1/21/2025 17:30 1/21/2025 18:00 0.50 MIRU, WHDBOP MPSP P P/U T-bar, and pull BPV. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 2/17 1B-09 Report Printed: 2/20/2025 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) 1/21/2025 18:00 1/21/2025 19:30 1.50 COMPZN, RPCOMP THGR P M/U landing joint to hanger, kelly up to top drive. Set down 10K. BOLDS. Pull hanger to the floor. String moving @ 90K HKLD. L/D tubing hanger and pups joints. 0.0 7,708.0 1/21/2025 19:30 1/21/2025 20:30 1.00 COMPZN, RPCOMP CIRC P CBU @ 252 GPM @ 589 PSI. 7,708.0 7,708.0 1/21/2025 20:30 1/22/2025 00:00 3.50 COMPZN, RPCOMP TRIP P POOH racking back 3.5" HYD 563 tubing. L/D Seal assy. 7,708.0 2,650.0 1/22/2025 00:00 1/22/2025 01:30 1.50 COMPZN, RPCOMP TRIP P Cont. to POOH racking back 3.5" HYD 563 tubing F/ 2650' to surface. L/D Seal assy. 2,650.0 0.0 1/22/2025 01:30 1/22/2025 02:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 1/22/2025 02:00 1/22/2025 02:30 0.50 COMPZN, RPCOMP OTHR P Set wear bushing. 0.0 0.0 1/22/2025 02:30 1/22/2025 03:30 1.00 COMPZN, RPCOMP ELNE P R/U YJOS E-line 0.0 0.0 1/22/2025 03:30 1/22/2025 06:30 3.00 COMPZN, RPCOMP ELNE P YJOS P/U CBL tools, and RIH F/ Surface to 2550'. Logging F/ 2550' t/Surf R/D logging unit 0.0 2,550.0 1/22/2025 06:30 1/22/2025 12:00 5.50 COMPZN, RPCOMP PUTB P M/U Baker Test Packer and w/ RBP RIH T/ 2550' P/U t/ 2500' (COE) and set RBP Pull up hole and set Baker 9 5/8"packer 2,550.0 2,415.0 1/22/2025 12:00 1/22/2025 13:00 1.00 COMPZN, RPCOMP PRTS P Test RBP t/ 2000PSI f/ 15 mins: GOOD TEST. 2,415.0 2,415.0 1/22/2025 13:00 1/22/2025 19:30 6.50 COMPZN, RPCOMP OTHR P Pull up hole 70' R/U dump box and dump sand down drill pipe @ 10-15 mins sack. Let sand fall for 1 hour. Build 9 5/8" test joint while waiting on sand to settle. RIH and tag top of sand @ 2434' 2,415.0 2,434.0 1/22/2025 19:30 1/22/2025 20:00 0.50 COMPZN, RPCOMP CIRC P Circulate one string volume. 2,434.0 2,434.0 1/22/2025 20:00 1/22/2025 21:00 1.00 COMPZN, RPCOMP TRIP P POOH racking back drill pipe. 2,434.0 27.0 1/22/2025 21:00 1/22/2025 21:30 0.50 COMPZN, RPCOMP BHAH P L/D Test plug, and RBP running tool. 27.0 0.0 1/22/2025 21:30 1/22/2025 22:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Bring MSC to rig floor. 0.0 0.0 1/22/2025 22:00 1/23/2025 00:00 2.00 COMPZN, RPCOMP TRIP P RIH F/ Surface to 2245 0.0 2,245.0 1/23/2025 00:00 1/23/2025 00:30 0.50 COMPZN, RPCOMP TRIP P Pump @ 2 BBL/min @ 300 PSI. Locate collar @ 2257', set down 5 K to confirm. Cont. Slack off to 2267' 2,245.0 2,267.0 1/23/2025 00:30 1/23/2025 01:00 0.50 COMPZN, RPCOMP CPBO P Increase flow rate to 210 GPM @ 825 PSI. Cont rotary @ 65 RPM. Make cut @ 2267'. Observe TQ drop, and 400 PSI Decrease in pump pressure, observe TQ decrease to 1.3 K. P/U 1', and slack off and set down 5K W/ Rotary on cut to confirm. 65 RPM @ 1.3 K Free TQ, 2.8- 5K TQ. 210 GPM @ 825 PSI. 2,267.0 2,267.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 3/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Depth (ftKB) End Depth (ftKB)OperationTime P-T-XActivity CodePhaseDur (hr)End TimeStart Time 1/23/2025 01:00 1/23/2025 03:00 2.00 COMPZN, RPCOMP P Close upper pipe rams. Line up to pump down drill pipe, and take returns out the OA. Pressure up to 1800 PSI. Hold for 5 min, and dump pressure, Repeat 5 times. Line up to pump down OA taking returns up the drill pipe. Pressure up to 1800 PSI, observe minor flow out of the string. Dump pressure and repeat 5 times. LIne up and pump down the drill pipe, and taking returns out of the OA, unable to get returns. Suspect the returns are coming out of the leak @ 64'. 2,267.02,267.0 1/23/2025 03:00 1/23/2025 04:00 CIRC1.00 COMPZN, RPCOMP P Line up and CBU X2 until hole cleaned up. 2,267.02,267.0 1/23/2025 04:00 1/23/2025 06:00 TRIP2.00 COMPZN, RPCOMP P POOH F/ 2267 to surface and Knife blades in good shape 2,267.02,267.0 1/23/2025 06:00 1/23/2025 07:00 Clean and clear rig floor. Pull wear ring.1.00 COMPZN, RPCOMP Set test plug. 0.00.0 1/23/2025 07:00 1/23/2025 11:00 NUND4.00 COMPZN, RPCOMP P Change lower pipe rams to 9 5/8" Fixed. Rig up test equipment, and flood stack. Attempt to test lower pipe rams. Wellbore fluid leaking our of weep hole on single gates. Clear fluid coming out of weep hole indicating wellbore side piston seal is leaking. 0.00.0 1/23/2025 11:00 1/23/2025 13:00 BOPE2.00 COMPZN, RPCOMP T N/D Double gates, and remove from cellar. Set BOP mud cross on to test spool and bolt up. Take single gates to the shop to be rebuilt. 0.00.0 1/23/2025 13:00 1/23/2025 22:00 Rebuild single gate rams. Rig crew9.00 COMPZN, RPCOMP work on preventative maintenance, and house keeping through out the rig. Build lay down area for 9 5/8" CSG. 0.00.0 1/23/2025 22:00 1/24/2025 00:00 Bring single gates into the cellar. N/U2.00 COMPZN, RPCOMP single gates to BOP. 0.0 1/24/2025 00:00 1/24/2025 04:30 NUND4.50 COMPZN, RPCOMP T Cont. N/U Lower pipe rams. Install lower 9 5/8" Fixed body pipe rams. 0.00.0 1/24/2025 04:30 1/24/2025 05:30 BOPE1.00 COMPZN, RPCOMP T M/U 9 5/8" Test joint. Fill stack, and flush lines. Test lower pipe rams to 250 low 2500 PSI high for 5 min each. R/D test equipment. 0.00.0 1/24/2025 05:30 1/24/2025 10:30 BOPE5.00 COMPZN, RPCOMP P N/D BOP and pull out Tubing spool and N/U BOP t/ casing head 0.00.0 1/24/2025 10:30 1/24/2025 12:00 BHAH1.50 COMPZN, RPCOMP P M/U Baker Tools w/ 9 5/8" RIH spear w/ pack off BOLDS 0.00.0 1/24/2025 12:00 1/24/2025 13:00 FISH1.00 COMPZN, RPCOMP P Attempt to Pull 9 5/8" casing Start Working up pull T/ 110Kt/175K No mement W/ 1500 psi on Casing No circ Release spear R/D spear 0.00.0 1/24/2025 13:00 1/24/2025 13:30 BHAH0.50 COMPZN, RPCOMP P M/U BHA # 3 W/ Baker MSC w/ new knives 30.00.0 1/24/2025 13:30 1/24/2025 15:30 FISH2.00 COMPZN, RPCOMP P RIH w/ cutter and Locate Coller @ 992' and P/U 2' and Start cutting casing @ 990' Line up on OA and moniter OA 990.030.0 1/24/2025 15:30 1/24/2025 16:00 0.50 COMPZN, RPCOMP CPBO P Cut CSG @ 990' 990.0 1/24/2025 16:00 1/24/2025 17:30 CIRC1.50 COMPZN, RPCOMP P Line up on OA and close Pipe rams Start pumping down DP Take returns out of OA t/ tiger tank @ 52sks w/520 psi All good 990.0990.0 1/24/2025 17:30 1/24/2025 18:30 TRIP1.00 COMPZN, RPCOMP P POOH F/ 990' to surface. MSC blades show indications of a good cut. 0.0990.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 CIRC Page 4/17 1B-09 Report Printed: 2/20/2025 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) 1/24/2025 18:30 1/24/2025 19:00 0.50 COMPZN, RPCOMP BHAH P P/U Spear (BHA #4). Engage CSG in well head. 0.0 26.0 1/24/2025 19:00 1/24/2025 21:00 2.00 COMPZN, RPCOMP FISH P Attempt to pull CSG Free from Cut @ 990'. Work up to 220 K w/ and w/o pumps. Bring pump pressure up to 1800 PSI and attempt to work pipe free, no success. Pump High vis sweep while continueing to work pipe. Sweep came back early. 26.0 26.0 1/24/2025 21:00 1/24/2025 21:00 COMPZN, RPCOMP BHAH P Release spear, and L/D P/U Cutter. 26.0 0.0 1/24/2025 21:00 1/24/2025 22:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ Surface to ~546' turn on pumps @ 120 GPM @ 240 PSI, locate collar @ 544' set down 5 K to confirm. P/U 2'. 0.0 546.0 1/24/2025 22:00 1/24/2025 22:30 0.50 COMPZN, RPCOMP CPBO P Make cut @ 542'. 252 GPM @ 540 PSI. 60 RPM @ 1.3 K TQ. Observe pressure drop off to 240 PSI. Set down 5 K W/ 60 RPM @ 800 TQ. 546.0 542.0 1/24/2025 22:30 1/24/2025 23:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 542' to surface. 542.0 0.0 1/24/2025 23:00 1/24/2025 23:30 0.50 COMPZN, RPCOMP BHAH P L/D Cutter, P/U spear. 0.0 0.0 1/24/2025 23:30 1/25/2025 00:00 0.50 COMPZN, RPCOMP FISH P Spear CSG in wellhead. P/U, String started to move @ 87K, Cont. to pick up weight between 150-110 K Picking up. Get joint, pack off and spear to rig floor. 0.0 542.0 1/25/2025 00:00 1/25/2025 01:30 1.50 COMPZN, RPCOMP PULL P R/U GBR equipment on the rig floor. R/U False table. Set CSG in slips, release spear. Run spear into mouse hole break out and L/D joint of drill pipe from top of spear. M/U lift sub to spear. Set grapple on spear, and stab back into CSG. P/U CSG to collar, set slips, break out, and L/D cut joint of CSG w/ Spear. 542.0 528.0 1/25/2025 01:30 1/25/2025 03:30 2.00 COMPZN, RPCOMP PULD P Cont. POOH L/D CSG patch, and CSG. 12 joints, and one cut joint 39.75' 528.0 0.0 1/25/2025 03:30 1/25/2025 06:30 3.00 COMPZN, RPCOMP BOPE P R/D casing tools Service rig R/U Test plug and set in casing head 0.0 0.0 1/25/2025 06:30 1/25/2025 09:00 2.50 COMPZN, RPCOMP BOPE P Test Casing Head Flange 250/2500 All good L/D test Equip 0.0 0.0 1/25/2025 09:00 1/25/2025 11:30 2.50 COMPZN, RPCOMP BHAH P M/U BHA #8 W/ spear 0.0 223.0 1/25/2025 11:30 1/25/2025 14:00 2.50 COMPZN, RPCOMP TRIP P RIH and Tag up @ 485' wash down 4' No go POOH Stand Back D.C L/D spear 80 RPM @ 850 Ft/lbs free torque, 1260 TQ on bottom Pump 336 GPM @ 220 PSI 223.0 0.0 1/25/2025 14:00 1/25/2025 15:30 1.50 COMPZN, RPCOMP BHAH P M/U BHA # 9 W/ Clean out Assy 0.0 210.0 1/25/2025 15:30 1/25/2025 18:30 3.00 COMPZN, RPCOMP REAM P RIH and Tag up 487' wash and ream to 542'. Circulate around high vis sweep. Rack back one stand of drill pipe. 210.0 487.0 1/25/2025 18:30 1/25/2025 20:00 1.50 COMPZN, RPCOMP SLPC P Hang blocks cut and slip drilling line. 487.0 487.0 1/25/2025 20:00 1/25/2025 21:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #9 (Clean out BHA). No noticable/ major wear on string mill. Aprox 46.7' of 1" High pressure hose recovered on BHA. 487.0 0.0 1/25/2025 21:30 1/25/2025 23:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA # 10 (second clean out BHA). 0.0 213.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 5/17 1B-09 Report Printed: 2/20/2025 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) 1/25/2025 23:00 1/25/2025 23:30 0.50 COMPZN, RPCOMP CLEN P RIH W/ BHA to 213', RIH 4 more stands tag @ 542'. P/U and engage rotary @ 10 RPM 650 TQ. Slack off observe bobble at top of 9 5/8" CSG, cont to slack off to 584' 213.0 584.0 1/25/2025 23:30 1/26/2025 00:00 0.50 COMPZN, RPCOMP CIRC P Pump high vis sweep @ 420 GPM @ 300 PSI. 584.0 584.0 1/26/2025 00:00 1/26/2025 00:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 584' to surface. 584.0 213.0 1/26/2025 00:30 1/26/2025 01:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 10, P/U BHA # 11 (spear BHA). 213.0 237.0 1/26/2025 01:30 1/26/2025 02:00 0.50 COMPZN, RPCOMP TRIP P RIH F/ 237' to 542' PUWT: 50K SOWT: 50K 237.0 542.0 1/26/2025 02:00 1/26/2025 03:15 1.25 COMPZN, RPCOMP JAR P No-go out on top of 9 5/8" w/ Spear. P/U to 25 K to confrim grapples bit. P/U to 25 K over. Warm up jars between 40K, and 100K. Fire jars working up to Jarring @ 175K , and straight pull to 220 K. Fire jars 50 times. 542.0 552.0 1/26/2025 03:15 1/26/2025 04:00 0.75 COMPZN, RPCOMP SFTY P Perform derrick inspection after 50 hits of the jars. Pump 50 BBL High VIS sweep. Chase sweep @ 420 GPM @ 600 PSI. Broken CMNT fragments returned to surface, send second 20 BBL sweep. Fewer CMNT fragments returned. 552.0 552.0 1/26/2025 04:00 1/26/2025 05:30 1.50 COMPZN, RPCOMP FISH P Resume jaring on 9 5/8" CSG. Jarred 50 Hits W/ 225K over string wt r Attempt to release spear No go order Down jars M/U Down jars and release spear 552.0 552.0 1/26/2025 05:30 1/26/2025 11:00 5.50 COMPZN, RPCOMP OTHR P Attempt to release spear No go order Down jars wait on surface jars for Baker shop. M/U Down jars and release spear. 552.0 552.0 1/26/2025 11:00 1/26/2025 14:30 3.50 COMPZN, RPCOMP BHAH P POOH last stand D.C flushed out the last stand due to gravel and cement chunks see photos. L/D Spear M/U cutter 552.0 0.0 1/26/2025 14:30 1/26/2025 17:30 3.00 COMPZN, RPCOMP CPBO P RIH w/ Casing cutter Locate collar @790' Pick 4' and make cut @ 786' 0.0 786.0 1/26/2025 17:30 1/26/2025 18:30 1.00 COMPZN, RPCOMP CIRC P Circulate around high vis sweep @ 10 BBL/Min @ 500 PSI. 786.0 786.0 1/26/2025 18:30 1/26/2025 19:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 790' to Surface. L/D MSC. 786.0 0.0 1/26/2025 19:00 1/26/2025 19:30 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment 0.0 0.0 1/26/2025 19:30 1/26/2025 20:30 1.00 COMPZN, RPCOMP BHAH P P/U Fishing BHA. RIH to top of fish @ 542' 0.0 542.0 1/26/2025 20:30 1/26/2025 21:00 0.50 COMPZN, RPCOMP FISH P Engage top of fish P/U to 125K, Fish pulled free. P/U 10' observe 200K HKLD, fell off to 90 K. 542.0 780.0 1/26/2025 21:00 1/26/2025 21:30 0.50 COMPZN, RPCOMP CIRC P Circulate 2 high vis sweeps @ 504 GPM @ 650 PSI, Observed large amount of cement fragments with each sweep. Hole cleaned up after second sweep. 780.0 780.0 1/26/2025 21:30 1/26/2025 22:30 1.00 COMPZN, RPCOMP BHAH P POOH L/D BHA to CSG 780.0 248.0 1/26/2025 22:30 1/26/2025 23:00 0.50 COMPZN, RPCOMP RURD P R/U GBR on the rig floor to L/D CSG. 248.0 248.0 1/26/2025 23:00 1/27/2025 00:00 1.00 COMPZN, RPCOMP PULL P L/D CSG F/ 248' to surface, tignt connection on first joint of CSG. 248.0 168.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 6/17 1B-09 Report Printed: 2/20/2025 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) 1/27/2025 00:00 1/27/2025 01:00 1.00 COMPZN, RPCOMP PULL P POOH L/D 9 5/8" CSG. All connections extremely tight. 168.0 0.0 1/27/2025 01:00 1/27/2025 01:30 0.50 COMPZN, RPCOMP RURD P R/D GBR CSG equipment on the rig floorl 0.0 0.0 1/27/2025 01:30 1/27/2025 02:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Mobilize components for next BHA to the rig floor. 0.0 0.0 1/27/2025 02:00 1/27/2025 05:00 3.00 COMPZN, RPCOMP BHAH P P/U and RIH w/ Clean out BHA F/ Surface to 797' 0.0 797.0 1/27/2025 05:00 1/27/2025 07:00 2.00 COMPZN, RPCOMP BHAH P POOH and L/D BHA # 14 Clean out run/ M/U #15 W/ Spear 797.0 0.0 1/27/2025 07:00 1/27/2025 12:30 5.50 COMPZN, RPCOMP FISH P RIH and Latch up on Fish @ 786' Start Jarring W/ 200K-350K Pulled free 55 jars and Circ Sweep Around w/ with no heavy cutting pump out of hole 64' POOH 0.0 786.0 1/27/2025 12:30 1/27/2025 15:30 3.00 COMPZN, RPCOMP BHAH P POOH w/ drill pipe L/D spear and R/U GBR casing tool/ L/D 9 5/8" casing 5 tot jts cut jt 3.3' . 786.0 0.0 1/27/2025 15:30 1/27/2025 16:30 1.00 COMPZN, RPCOMP M/U Clean out BHA and RIH to 786'. Tag up set down 5K PUWT: 60K SOWT: 60K 0.0 786.0 1/27/2025 16:30 1/27/2025 18:30 2.00 COMPZN, RPCOMP REAM P M/U and RIH w/ clean out BHA. start washing down @ 800' T/ 990' 80 RPM @ 1.5- 3K TQ Punmping 500 GPM @ 800 PSI. Pump around high vis sweep. 786.0 990.0 1/27/2025 18:30 1/27/2025 19:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 990' to 221'. 990.0 22.1 1/27/2025 19:00 1/27/2025 20:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA F/ 221' to surface. 221.0 0.0 1/27/2025 20:30 1/27/2025 21:00 0.50 COMPZN, RPCOMP BHAH P P/U MSC 0.0 30.0 1/27/2025 21:00 1/27/2025 21:30 0.50 COMPZN, RPCOMP TRIP P RIH to 1652'. PUWT: 55K SOWT: 55K 30.0 1,652.0 1/27/2025 21:30 1/28/2025 00:00 2.50 COMPZN, RPCOMP Locate collar @ 1700', P/U and make cut @ 1696' 80 RPM 2.1K TQ. Locate collar and make cut @ 1502' same parameters as before. 1,652.0 1,502.0 1/28/2025 00:00 1/28/2025 01:00 1.00 COMPZN, RPCOMP CUTP P Locate collar and cut 9 5/8" @ 1295' 1,295.0 1,295.0 1/28/2025 01:00 1/28/2025 01:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1295'. 1,295.0 0.0 1/28/2025 01:30 1/28/2025 02:00 0.50 COMPZN, RPCOMP BHAH P L/D MSC. Mobilize BHA to rig floor. 0.0 0.0 1/28/2025 02:00 1/28/2025 06:00 4.00 COMPZN, RPCOMP BHAH P P/U Spear BHA F/ surface to 221' t/990' latch up @ 990' Hit 3 Times Spear release POOH / Change out grapple 0.0 221.0 1/28/2025 06:00 1/28/2025 13:00 7.00 COMPZN, RPCOMP FISH P M/U BHA # 19 RIH and Latch up start jarring @ 275K-350K No moment 105 hits Attempt to Circ w/ no moment Release Spear pres up t/ 1500 psi no moment 221.0 1/28/2025 13:00 1/28/2025 15:00 2.00 COMPZN, RPCOMP TRIP P POOH L/D Spear and M/U cutter RIH Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 7/17 1B-09 Report Printed: 2/20/2025 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) 1/28/2025 15:00 1/28/2025 17:00 2.00 COMPZN, RPCOMP CPBO P Start Cutting @ 1,421' and Pull up hole and cut @ 1,137' 1,420.0 1,136.0 1/28/2025 17:00 1/28/2025 18:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/1,136' T/BHA 1,136.0 45.0 1/28/2025 18:00 1/28/2025 18:30 0.50 COMPZN, RPCOMP BHAH P LD and inspect cutter BHA (good) 45.0 0.0 1/28/2025 18:30 1/28/2025 19:30 1.00 COMPZN, RPCOMP BHAH P MU Spear assembly BHA #21 0.0 249.5 1/28/2025 19:30 1/28/2025 20:30 1.00 COMPZN, RPCOMP TRIP P TIH, engage fish @ 990' PUW=62k, SOW=60k 249.5 990.0 1/28/2025 20:30 1/28/2025 21:15 0.75 COMPZN, RPCOMP FISH P Attempt to pump 900 psi, unable to break circulation, bleed pressure off, 50 jar licks, fish moving up hole 6'. 990.0 984.0 1/28/2025 21:15 1/28/2025 21:45 0.50 COMPZN, RPCOMP SFTY P Perform derrick inspection. 984.0 984.0 1/28/2025 21:45 1/28/2025 22:30 0.75 COMPZN, RPCOMP FISH P Jar on fish 50 times 984.0 980.0 1/28/2025 22:30 1/28/2025 23:00 0.50 COMPZN, RPCOMP SFTY P Perform derrick inspection. 980.0 980.0 1/28/2025 23:00 1/28/2025 23:30 0.50 COMPZN, RPCOMP FISH P Continue to jar on fish 5 licks, fish moving up hole, 150-300k, LD 1 stand, KBU, circulate 12 bpm/450 psi, cement chunks in returns 1-1-1/2 inch in size, 346 bbls pumped SXS 980.0 890.0 1/28/2025 23:30 1/29/2025 00:00 0.50 COMPZN, RPCOMP TRIP P Pump out 1 stand @ 3 bpm/50 psi, break out and rack back stand, blow down top drive. Continue TOOH on stands. F/820' T/720' 890.0 720.0 1/29/2025 00:00 1/29/2025 01:00 1.00 COMPZN, RPCOMP TRIP P Continue TOOH on stands F/720' T/BHA 720.0 249.5 1/29/2025 01:00 1/29/2025 01:30 0.50 COMPZN, RPCOMP BHAH P LD BHA 249.5 0.0 1/29/2025 01:30 1/29/2025 02:00 0.50 COMPZN, RPCOMP BHAH P RU GBR and false bowl 0.0 0.0 1/29/2025 02:00 1/29/2025 03:00 1.00 COMPZN, RPCOMP BHAH P Unable to release grapple, RU surface down jars. Release from fish. 0.0 0.0 1/29/2025 03:00 1/29/2025 05:00 2.00 COMPZN, RPCOMP BHAH P LD fish 147' . connections over torqued. 0.0 0.0 1/29/2025 05:00 1/29/2025 06:00 1.00 COMPZN, RPCOMP BHAH P MU cleanout BHA #22 0.0 222.0 1/29/2025 06:00 1/29/2025 10:00 4.00 COMPZN, RPCOMP TRIP P TIH F/surface T/850' cleanout T/1,137' PUW= 70K SOW=65K 222.0 1/29/2025 10:00 1/29/2025 12:00 2.00 COMPZN, RPCOMP BHAH P POOH L/D C/O Run M/U spear RTIH and Latch up on Fish @ 1137' 1/29/2025 12:00 1/29/2025 16:00 4.00 COMPZN, RPCOMP FISH P Start Jarring 275K up and Straight pull 350K Jarred 125 W/ no movement -Attempt to circ @ 1/2 BBl min w/ 75 psi and could not keep that constant 75 psi 1500 psi 1/29/2025 16:00 1/29/2025 18:00 2.00 COMPZN, RPCOMP TRIP P Had to P/U surf jarrs to Release Spear POOH L/D spear M/U Muliti String Cutter 1/29/2025 18:00 1/29/2025 20:00 2.00 COMPZN, RPCOMP BHAH P MU Multi String Cutter assembly, BHA #24 0.0 45.0 1/29/2025 20:00 1/29/2025 20:30 0.50 COMPZN, RPCOMP TRIP P TIH, F/BHA T/1,047' 45.0 1,047.0 1/29/2025 20:30 1/29/2025 22:00 1.50 COMPZN, RPCOMP SLPC P PSJM with Rig Crew, Slip and cut DL 5 wraps/34' PUW=60k, SOW=60k 1,047.0 1,047.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 8/17 1B-09 Report Printed: 2/20/2025 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) 1/29/2025 22:00 1/29/2025 23:30 1.50 COMPZN, RPCOMP CPBO P Continue IH F/1,047' T/1,222' locate collar, PUH T/1,218', cut 9-5/8" Pump 6 bpm/500 psi, 83 RPM, Free torque 1,200 ft/lbs, Pump 6bpm/620 psi, 83 RPM, Torque 1,780-3,000 ft/lbs cuttings 1,047.0 1,218.0 1/29/2025 23:30 1/30/2025 00:00 0.50 COMPZN, RPCOMP Circulate 12 bpm/950 psi 1,218.0 1,218.0 1/30/2025 00:00 1/30/2025 00:30 0.50 COMPZN, RPCOMP TRIP P TOOH on stands F/1,218' T/BHA 1,218.0 45.0 1/30/2025 00:30 1/30/2025 01:00 0.50 COMPZN, RPCOMP BHAH P LD and inspect cutter (good) 45.0 0.0 1/30/2025 01:00 1/30/2025 02:00 1.00 COMPZN, RPCOMP BHAH P PU spear assembly BHA #25 0.0 231.0 1/30/2025 02:00 1/30/2025 02:30 0.50 COMPZN, RPCOMP TRIP P TIH, PUW=60k, SOW=60k Engage fish @ 1,137', bleed jars, straight pull 325k continue PUH 150k ratty T/1,075' 231.0 1,137.0 1/30/2025 02:30 1/30/2025 03:30 1.00 COMPZN, RPCOMP CIRC P Circulate BU, working rate to 12 bpm/500 psi 1,137.0 1,075.0 1/30/2025 03:30 1/30/2025 04:00 0.50 COMPZN, RPCOMP TRIP P TOOH F/1,075' T/BHA 1,075.0 45.0 1/30/2025 04:00 1/30/2025 04:30 0.50 COMPZN, RPCOMP CPBO P RU GBR 45.0 45.0 1/30/2025 04:30 1/30/2025 05:00 0.50 COMPZN, RPCOMP PULL P LD and inspect BHA, LD fish total length (81.54') 45.0 45.0 1/30/2025 05:00 1/30/2025 09:00 4.00 COMPZN, RPCOMP REAM P M/U BHA # 26 w/ C/O Run T/ 1137' wash t/ 1218' TOF w/ 500 GPM w/ 450 PSI 0.0 0.0 1/30/2025 09:00 1/30/2025 11:30 2.50 COMPZN, RPCOMP BHAH P POOH L/D C/O Run M/U Baker Spear BHA # 27 0.0 0.0 1/30/2025 11:30 1/30/2025 13:30 2.00 COMPZN, RPCOMP TRIP P RIH and Latch up on fish @ 1218' 0.0 0.0 1/30/2025 13:30 1/30/2025 15:30 2.00 COMPZN, RPCOMP FISH P Start Jarring 225K t/ 325K Straight pull 20 Hits pulled free pulled over 100K 63' Service Rig in Free Zone 0.0 0.0 1/30/2025 15:30 1/30/2025 17:30 2.00 COMPZN, RPCOMP TRIP P TOOH F/1,218' T/231' 1,218.0 231.0 1/30/2025 17:30 1/30/2025 18:30 1.00 COMPZN, RPCOMP BHAH P LD Spear BHA 231.0 0.0 1/30/2025 18:30 1/30/2025 22:30 4.00 COMPZN, RPCOMP BHAH P Release spear, RU GBR, break out and LD Fish OAL of fish 76.92', Ended up picking up suface jars to released spear. RD GBR and ship out 9-5/8" equipment. 0.0 0.0 1/30/2025 22:30 1/30/2025 23:30 1.00 COMPZN, RPCOMP BHAH P M/U Clean out Run T/ Top fish @ 1295' 0.0 231.0 1/30/2025 23:30 1/31/2025 00:00 0.50 COMPZN, RPCOMP TRIP P TIH w/BHA #28 F/surface T/975' 231.0 975.0 1/31/2025 00:00 1/31/2025 01:00 1.00 COMPZN, RPCOMP TRIP P Continue IH w/12-1/4" Cleanout BHA #28 975.0 1,218.0 1/31/2025 01:00 1/31/2025 02:15 1.25 COMPZN, RPCOMP WASH P Wash/cleanout F/1,218' T/1,295' ROT=80 rpm, ROTW=53k PUW=62k, SOW=60k 1,218.0 1,295.0 1/31/2025 02:15 1/31/2025 02:45 0.50 COMPZN, RPCOMP CIRC P Circulate BU w/25 bbl sweep 12 bpm / 450 psi 1,295.0 0.0 1/31/2025 02:45 1/31/2025 03:15 0.50 COMPZN, RPCOMP TRIP P TOOH, LD CO BHA #28 1,295.0 231.0 1/31/2025 03:15 1/31/2025 05:15 2.00 COMPZN, RPCOMP BHAH P LD CO BHA 231.0 0.0 1/31/2025 05:15 1/31/2025 07:15 2.00 COMPZN, RPCOMP BHAH P MU cleanout BHA w/8-1/2" Tri-cone Rock Bit 0.0 288.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 9/17 1B-09 Report Printed: 2/20/2025 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) 1/31/2025 07:15 1/31/2025 08:15 1.00 COMPZN, RPCOMP TRIP P TIH w/8-1/2" rock bit cleanout BHA #29 288.0 2,269.0 1/31/2025 08:15 1/31/2025 14:15 6.00 COMPZN, RPCOMP WASH P Start Washing F/2269 T/ 2444' POOH 20' Cont Circ @ 175 Sk w/ 750 psi and pump 45 bbls HV Sweep around 2,269.0 2,444.0 1/31/2025 14:15 1/31/2025 17:00 2.75 COMPZN, RPCOMP TRIP P TOOH, LD rock bit BHA 2,444.0 0.0 1/31/2025 17:00 1/31/2025 18:30 1.50 COMPZN, RPCOMP BHAH P PU RCJB BHA 0.0 261.2 1/31/2025 18:30 1/31/2025 20:00 1.50 COMPZN, RPCOMP TRIP P TIH w/cleanout BHA #30 PUW=85k, SOW=70k 261.2 2,424.0 1/31/2025 20:00 1/31/2025 21:30 1.50 COMPZN, RPCOMP WASH P Wash down F/2,424' T/2,432', Pumping 5 bpm/87 stks/min/1,800 psi ROT=50 rpm, Rot TQ=2800 ft/lbs,ROTSW=73k/5-10k DW 2,424.0 2,433.0 1/31/2025 21:30 1/31/2025 22:30 1.00 COMPZN, RPCOMP CIRC P Circulate SXS w/25 bbls sweep 5 bpm/87 stks/min/1,860 psi 2,433.0 2,433.0 1/31/2025 22:30 1/31/2025 23:30 1.00 COMPZN, RPCOMP WASH P Make connection, continue to wash down F/2,432' T/2,440' Pumping 5 bpm/87 stks/min/1,800 psi ROT=50 rpm, Rot TQ=2800 ft/lbs,ROTSW=73k/5-10k DW 2,433.0 2,440.0 1/31/2025 23:30 2/1/2025 00:00 0.50 COMPZN, RPCOMP CIRC P Circulate SXS w/25 bbls sweep 5 bpm/87 stks/min/1,860 psi Note: Load DP into pipe shed sim-ops 2,440.0 2,440.0 2/1/2025 00:00 2/1/2025 01:00 1.00 COMPZN, RPCOMP CIRC P Continue circulating sweep to surface 5 bpm/87 stks/min/1,860 psi Note: Load DP into pipe shed sim-ops. 2,440.0 2,440.0 2/1/2025 01:00 2/1/2025 02:00 1.00 COMPZN, RPCOMP TRIP P TOOH, w/RCJB 2,440.0 261.2 2/1/2025 02:00 2/1/2025 03:30 1.50 COMPZN, RPCOMP BHAH P At surface, LD BHA and inspect JB, 1/2 of test plug rubber and green looking cement 261.2 0.0 2/1/2025 03:30 2/1/2025 05:00 1.50 COMPZN, RPCOMP CLEN P LD 6 DC, and clear RF of un-needed Baker Tools. 0.0 0.0 2/1/2025 05:00 2/1/2025 07:00 2.00 COMPZN, RPCOMP BHAH P PU, RPB retrieval tool, 0.0 45.0 2/1/2025 07:00 2/1/2025 08:30 1.50 COMPZN, RPCOMP TRIP P TIH w/BHA #31 45.0 2,400.0 2/1/2025 08:30 2/1/2025 10:30 2.00 COMPZN, RPCOMP WASH P Wash down F/2,400' T/Top of plug PUW=50k, SOW=50k, 200 stks/min, 12 bpm, 800 psi, 10 RPM, FTQ=2000 ft/lbs 2,400.0 2,489.0 2/1/2025 10:30 2/1/2025 11:00 0.50 COMPZN, RPCOMP OWFF P Check well for flow 2,489.0 2,489.0 2/1/2025 11:00 2/1/2025 12:30 1.50 COMPZN, RPCOMP TRIP P TOOH, PUW=84k, SOW=74k, F/2,430' T/2255' 2,489.0 45.0 2/1/2025 12:30 2/1/2025 13:30 1.00 COMPZN, RPCOMP BHAH P LD BHA, LD G-loc plug and retrivel tool. 45.0 0.0 2/1/2025 13:30 2/1/2025 14:30 1.00 COMPZN, RPCOMP BHAH P PU BHA w/Inflatable Bridge Plug 0.0 54.4 2/1/2025 14:30 2/1/2025 18:00 3.50 COMPZN, RPCOMP TRIP P TIH w/BHA #32 on stands. F/54' T/2,510' Ream through casing cut @ 1295', PUW=50k, SOW=50k 54.4 2,510.0 2/1/2025 18:00 2/2/2025 00:00 6.00 COMPZN, RPCOMP TRIP P Single IH, F\2,510' T/6,770' @ 60 fpm per Baker Rep PUW=124k SOW=84k 2,510.0 6,770.0 2/2/2025 00:00 2/2/2025 02:00 2.00 COMPZN, RPCOMP TRIP P Continue singling in hole w/DP F/6,770' T/7,714' 6,770.0 7,714.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 10/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/2/2025 02:00 2/2/2025 07:00 5.00 COMPZN, RPCOMP CIRC P Fill DP from RF fill hose and Set IBP @ 7711' Stage up pres T/ 2000 All good release Pres P/U 10 ' Monitor well 10 mins 7,714.0 7,714.0 2/2/2025 07:00 2/2/2025 10:30 3.50 COMPZN, RPCOMP TRIP P POOH 7,714.0 54.0 2/2/2025 10:30 2/2/2025 11:00 0.50 COMPZN, RPCOMP TRIP P Drop out Running tool PU DP 3.5" Muleshoe 54.0 0.0 2/2/2025 11:00 2/2/2025 14:30 3.50 COMPZN, RPCOMP TRIP P RIH w/ Mule shoe T/ 7630" 0.0 7,630.0 2/2/2025 14:30 2/2/2025 20:30 6.00 COMPZN, RPCOMP OTHR P Dump 17 60# sacks of Sand Down Drill string @ 7,630' using the KB-1000. 7,630.0 7,630.0 2/2/2025 20:30 2/2/2025 22:30 2.00 COMPZN, RPCOMP TRIP P TIH to tag sand F/7,630' T/7,706', no sand, PUH Line up pits to pump clean/fresh 9.5 ppg. Move fluid out of pit #5, fill Pit #5 and trip tank with clean 9.5 ppg. 7,630.0 7,600.0 2/2/2025 22:30 2/3/2025 00:00 1.50 COMPZN, RPCOMP CIRC P Pump 16 bbls every 30 mins 7,600.0 7,600.0 2/3/2025 00:00 2/3/2025 02:00 2.00 COMPZN, RPCOMP CIRC P Continue pumping 2 bpm at 160 psi, 16 bbls every 30 mins, TIH for a tag, 7,708' no tag, PUH, confer with town team 7,600.0 7,708.0 2/3/2025 02:00 2/3/2025 14:00 12.00 COMPZN, RPCOMP OTHR P Standby for 16/20 frac sand, allow river sand to fall out. And Dump Frac Sand and RIH Tag @ 7681 All good 7,708.0 7,708.0 2/3/2025 14:00 2/3/2025 17:30 3.50 COMPZN, RPCOMP TRIP P POOH and Rack Back 3 1/2" D.P 7,708.0 0.0 2/3/2025 17:30 2/3/2025 18:30 1.00 COMPZN, RPCOMP FRZP P R/U test Casing to 1500 PSI F/ 15 mins, good test 0.0 0.0 2/3/2025 18:30 2/3/2025 20:00 1.50 COMPZN, RPCOMP BOPE P P/U Test Plug RIH and C/O Bottom set ( 9 5/8" Rams T/7" ) 0.0 0.0 2/3/2025 20:00 2/4/2025 00:00 4.00 COMPZN, RPCOMP BOPE P Perform Bi-weekly BOP Test, chance to witness AOGCC, waived by Brian Bixby. 250 Low / 2,500 psi. Test BOPS high/2,500 psi 250 psi low test joint & 3.5" test joint, and 7" test joint 1.) Blind Rams, CMV 1,2,3, & 16, Rig Floor Kill, Outter test spool valve, IBOP 2.) Blind Rams, CMV 4,5, and 6, HCR Kill, Inner Test Spool Valve Manual IBOP (Open CMV 2, Rig Floor Kill, Outer Test Spool Vlave) 3.)3.5" Test joint, Annular, 3.5" FOSV, CMV 7-8-9, Manual Kill HT-38 Dart 4.) Hydraulic Super Choke & Manual Adjusta ble Choke (1,500 psi Test) (Open CMV 7,9, and 14) 5.) 3.5" test joint, UPR, CMV 10-11, Manual Kill 6.) 7" test joint, LPR, HT-38 TIW 7.) 7" test joint, Annular 8.) CMV 12-13-15 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 11/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/4/2025 00:00 2/4/2025 01:00 1.00 COMPZN, RPCOMP BOPE P Continue BOPE testing 250 Low/ 2,500 High / 2,500 Annular 9.) CMV14 10.) HCR Choke 11.) Manual Choke Perform Koomey Drawdown Test. Manifold Pressure 1500 psi, Accumulater Pressure 3,000 psi Pressure after all rams functioned=1,550 psi Upper Ram=6sec Lower Ram=6sec Annular=20 Blind=6sec HCR Kill=1sec HCR Choke=1sec 200 psi Recovery=20sec Full System Recovery=125sec 5 Koomey Bottles @ 2,125 psi 0.0 0.0 2/4/2025 01:00 2/4/2025 02:00 1.00 COMPZN, RPCOMP RURD P Blow down and RD testing equipment. 0.0 0.0 2/4/2025 02:00 2/4/2025 03:30 1.50 COMPZN, RPCOMP CLEN P Prep RF for running casing operaitons 0.0 0.0 2/4/2025 03:30 2/4/2025 04:00 0.50 COMPZN, RPCOMP SFTY P PJSM, with Rig crew and casing hands. 0.0 0.0 2/4/2025 04:00 2/4/2025 12:45 8.75 COMPZN, RPCOMP PUTB P TIH w/7" 26# TXP casing per approved tally. TQ turn TXPM connections 14,750 ft-lbs using BOL AG 2000 pipe dope. Install one centralizer per joint. Filling casing on the fly every joint and top off every 10 jts. Place 60' of frac sand on top of pre- loaded 7" RBP. Continue TIH, set down 2,269' 9-5/8" cut, rotate 1/4 turn continue TIH. 0.0 4,019.0 2/4/2025 12:45 2/4/2025 13:15 0.50 COMPZN, RPCOMP SVRG P Rig service to grease draw works and Iron rough neck. Sim ops to change out hose on pipe handler. 4,019.0 4,019.0 2/4/2025 13:15 2/4/2025 20:30 7.25 COMPZN, RPCOMP PUTB P Continue TIH F/4,019'/ T/7,681' Tag Sand at 7,681' w/5k down, PUH T/7,682' (Mule Shoe) PUW=215k, SOW=138k 4,019.0 7,682.0 2/4/2025 20:30 2/4/2025 22:30 2.00 COMPZN, RPCOMP RURD P RD GBR, tongs and equipment, RU GBR Casing Running Tool (CRT) and install bail extentions, Sim-ops prep to split BOPE stack. RU open top tank on drillers side of rig for cement job to OA. 7,682.0 7,682.0 2/4/2025 22:30 2/4/2025 23:30 1.00 COMPZN, RPCOMP OWFF P Observe well for flow (NO FLOW) 7,682.0 7,682.0 2/4/2025 23:30 2/5/2025 00:00 0.50 COMPZN, RPCOMP NUND P PJSM, ND/break stack apart, 7,682.0 7,682.0 2/5/2025 00:00 2/5/2025 01:00 1.00 COMPZN, RPCOMP NUND P Install 7" slips, slack off T/138k, Note: ECP Data Top=7617.11' COE=7,622.14' BTM=7,627.12' 7,682.0 7,680.0 2/5/2025 01:00 2/5/2025 02:00 1.00 COMPZN, RPCOMP NUND P Set down stack and NU Sim-ops remove bail extentions. 7,680.0 7,680.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 12/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/5/2025 02:00 2/5/2025 03:00 1.00 COMPZN, RPCOMP PRTS P Function closed Annular Preventor on 7" PT back side to 500 psi to check flage break. 7,680.0 7,680.0 2/5/2025 03:00 2/5/2025 04:00 1.00 COMPZN, RPCOMP OTHR P PT casing to 500 psi and set Baker ECP packer per BR. Walk pressure up in 500 psi increments, observe 7,680.0 7,680.0 2/5/2025 04:00 2/5/2025 05:00 1.00 COMPZN, RPCOMP SFTY P PJSM with HES, Nabors, and MI SWACO RU Cementers 7,680.0 7,680.0 2/5/2025 05:00 2/5/2025 06:00 1.00 COMPZN, RPCOMP CIRC P Function open the ES II cementer Circulate BU x 2: 10 BPM @ 1350 psi 7,680.0 7,680.0 2/5/2025 06:00 2/5/2025 07:00 1.00 COMPZN, RPCOMP PRTS P PT cementers surface lines to 3,500 psi Safety meeting with everyone involved with cement job. 7,680.0 7,680.0 2/5/2025 07:00 2/5/2025 11:30 4.50 COMPZN, RPCOMP CMNT P Pump 30 BBLs spacer Red Dye down 7" followed by 359BBLs 15.3ppg class G CMT. ICP at 3 BPM = 600 and at 4.75 BPM = 1100 psi. Install cement plug, follow with 10 bbls water and chase with 278 BBLS of 9.5 ppg brine using rig pumps to bump plug. FCP 2300 psi at 5 BPM. Slowing down to 3BPM to bump plug at right at calculated 4802 strokes. 76 BBLs of good cement returned to surface. Cement in place @ 11:00. Pressure up from 2300 psi FCP to 3800 psi to shift HES closed. Bleed off pressure and verify cementer is closed. Flush rig and surface lines with contam pill and blow down lines. RD Casing Running Tool and HES cementers. Suck out stack. 7,680.0 0.0 2/5/2025 11:30 2/5/2025 12:00 0.50 COMPZN, RPCOMP OWFF P Open up well and observe well for flow. Good test no flow. 0.0 0.0 2/5/2025 12:00 2/5/2025 16:00 4.00 COMPZN, RPCOMP NUND P Break bolts on wellhead flange and PU BOP 3'. RU Wachs cutter and cut 7" casing, install new packoffs, nipple up TBG spool and test pack off T/3000 psi. Good Test. 0.0 0.0 2/5/2025 16:00 2/5/2025 19:00 3.00 COMPZN, RPCOMP NUND P NU BOP center under rig floor, TQ bolts and install riser, center up and secure to cellar walls. 0.0 0.0 2/5/2025 19:00 2/5/2025 22:00 3.00 COMPZN, RPCOMP NUND P Confirm TQ on BOPE Flange break FIll stack, attempt to PT, unable to get test plug to hole, pull and inspect test plug. Shell test 250/3500 psi (good test) install wear ring Note: Sim-ops continue to empty Cement Job fluids and returns. Straighten up Yard 0.0 0.0 2/5/2025 22:00 2/5/2025 23:30 1.50 COMPZN, RPCOMP BHAH P PJSM, PU Cleanout/milling assembly BHA #33 XO 3.5" IF x HT-38, 4-3/4" Drill Collar(s) x 3, 4-3/4" Oil Jar, 4-3/4" LBS, 5-5/8" string magnet, Bit Sub, 4-3/4" Boot Basket(s) x 2, 6-1/8" Roller/Tricone BIT w/1/2" jets. 0.0 136.3 2/5/2025 23:30 2/6/2025 00:00 0.50 COMPZN, RPCOMP TRIP P TIH w/milling BHA #33 136.3 1,238.0 2/6/2025 00:00 2/6/2025 03:30 3.50 COMPZN, RPCOMP TRIP P Continue TIH T/7,540' 1,238.0 7,540.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 13/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/6/2025 03:30 2/6/2025 04:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 7,540.0 7,540.0 2/6/2025 04:00 2/6/2025 06:15 2.25 COMPZN, RPCOMP MILL P TIH F/7,540' T/7,584.75' Milling 80 rpm, ROWT=117, Free TQ=8300 ft/lbs 7,540.0 7,620.0 2/6/2025 06:15 2/6/2025 07:45 1.50 COMPZN, RPCOMP CIRC P Stand back a stand. Circulate a 20 BBL 200 vis sweep all the way around. 6BPM at 1135 psi Observed sand at the shakers 7,620.0 7,510.0 2/6/2025 07:45 2/6/2025 16:15 8.50 COMPZN, RPCOMP RGRP T Change out service loop hydraulic line on top drive. Current WC is -51 degrees F. 7,510.0 7,510.0 2/6/2025 16:15 2/6/2025 20:30 4.25 COMPZN, RPCOMP TRIP P TOOH w/BHA #33 7,510.0 136.3 2/6/2025 20:30 2/6/2025 21:00 0.50 COMPZN, RPCOMP BHAH P Stand back1 stand of DC LD BHA and inspect. Bit in good condition. 136.3 0.0 2/6/2025 21:00 2/6/2025 21:30 0.50 COMPZN, RPCOMP BHAH P MU RCJB BHA #34 XO 3.5 IF x HT 38, 4-3/4" DC x 3, 4-3/4" Oil Jar, 4-3/4" LBS, 5-5/8" String magnet, Bit Sub, 4-3/4" Boot Basket x 2, RCJB 6-1/8" OD 4-3/4" RID 0.0 144.0 2/6/2025 21:30 2/7/2025 00:00 2.50 COMPZN, RPCOMP TRIP P TIH w/cleanout RCJB BHA #34 F/BHA T/4,400' 144.0 4,400.0 2/7/2025 00:00 2/7/2025 01:30 1.50 COMPZN, RPCOMP TRIP P Continue IH F/4,400' T/7,616' PUW=170k, SOW=95 4,400.0 7,616.0 2/7/2025 01:30 2/7/2025 02:30 1.00 COMPZN, RPCOMP FISH P Wash down T/7,649', PUH PUW=180k, work pipe free PUH Rot= 30 RPM, ROTW=117k, ROTQ=8400 ft/lbs Recep pipe until clean 7,616.0 7,649.0 2/7/2025 02:30 2/7/2025 03:30 1.00 COMPZN, RPCOMP CIRC P Circulate BU, Frac sand in returns. 7,649.0 2/7/2025 03:30 2/7/2025 04:00 0.50 COMPZN, RPCOMP OWFF P Observe well for flow 7,649.0 7,649.0 2/7/2025 04:00 2/7/2025 07:30 3.50 COMPZN, RPCOMP TRIP P TOOH F/7,620' T/BHA 7,649.0 144.0 2/7/2025 07:30 2/7/2025 09:00 1.50 COMPZN, RPCOMP BHAH P LD BHA #34 and inspect RCJB Large chuck of very hard cement wedged in Junk Basket. Both Baskets had most of the finger broke off and left in hole on sand on RBP. 144.0 0.0 2/7/2025 09:00 2/7/2025 10:00 1.00 COMPZN, RPCOMP WAIT T Wait for another RCJB to arrive at rig. 0.0 0.0 2/7/2025 10:00 2/7/2025 11:00 1.00 COMPZN, RPCOMP BHAH P MU RCJB BHA #35 0.0 149.0 2/7/2025 11:00 2/7/2025 14:00 3.00 COMPZN, RPCOMP TRIP P TIH F/149 T7621' PUW=170k, SOW=95 149.0 7,621.0 2/7/2025 14:00 2/7/2025 15:30 1.50 COMPZN, RPCOMP WASH P Wash down to 7649' Recep pipe until clean 7,621.0 7,649.0 2/7/2025 15:30 2/7/2025 18:30 3.00 COMPZN, RPCOMP TRIP P POOH standing back drillpipe. 7,649.0 149.0 2/7/2025 18:30 2/7/2025 20:00 1.50 COMPZN, RPCOMP BHAH P LD and inspect Junk Baskets Recoverd 15 missing fingers from Junk Basket still missing 1 finger, lots of cement chunks. 149.0 0.0 2/7/2025 20:00 2/7/2025 20:30 0.50 COMPZN, RPCOMP BHAH P PU RCJB BHA #36 0.0 149.0 2/7/2025 20:30 2/7/2025 23:00 2.50 COMPZN, RPCOMP TRIP P TIH F/BHA T/6,294' SOW=88k 149.0 6,294.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 14/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/7/2025 23:00 2/7/2025 23:30 0.50 COMPZN, RPCOMP SVRG P Rig Service 6,294.0 2/7/2025 23:30 2/8/2025 00:30 1.00 COMPZN, RPCOMP SLPC P Slip and cut DL 16 wraps/112' 6,294.0 6,294.0 2/8/2025 00:00 2/8/2025 00:30 0.50 COMPZN, RPCOMP SLPC P Slip and cut DL 16 wraps/112' 6,300.0 6,300.0 2/8/2025 00:30 2/8/2025 01:00 0.50 COMPZN, RPCOMP CIRC P Circulate DP volume before continuing IH to clean BHA of debris 6,300.0 6,300.0 2/8/2025 01:00 2/8/2025 01:30 0.50 COMPZN, RPCOMP TRIP P Continue IH F/6,300' 6,300.0 7,617.0 2/8/2025 01:30 2/8/2025 03:00 1.50 COMPZN, RPCOMP WASH P Bring pump online 6.0 bpm/2,530 psi TIH slowly recep pipe, 7,616'-7,650' ROT=80 rpm, ROTW=156k, ROTQ=7800 ft/lbs Clean pickup PUW=170k, SOW=119k Blow Down Top Drive Grease Top Drive Rails 7,617.0 7,650.0 2/8/2025 03:00 2/8/2025 03:30 0.50 COMPZN, RPCOMP SVRG P Service Top Drive and washpipe 7,650.0 7,650.0 2/8/2025 03:30 2/8/2025 07:00 3.50 COMPZN, RPCOMP TRIP P TOOH on stands F/7,650' T/149' 7,650.0 149.0 2/8/2025 07:00 2/8/2025 08:00 1.00 COMPZN, RPCOMP BHAH P LD BHA #36 Clean Magnets, boot baskets and RCJB and recovered the last broken finger. 149.0 0.0 2/8/2025 08:00 2/8/2025 08:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #37 G-plug (RBP) retrieval tool. 0.0 49.0 2/8/2025 08:30 2/8/2025 10:30 2.00 COMPZN, RPCOMP TRIP P TIH on stands F/49' T/7649' UWT=160K/ SOW=90K 49.0 7,649.0 2/8/2025 10:30 2/8/2025 11:00 0.50 COMPZN, RPCOMP MPSP P Circ 3 BPM at 330 psi Engage 7" G-plug at 7652' Release and let relax 15 min. 7,649.0 7,649.0 2/8/2025 11:00 2/8/2025 12:30 1.50 COMPZN, RPCOMP CIRC P Circulate BU 6 BPM at 1050 psi. OWFF no flow. 7,649.0 7,649.0 2/8/2025 12:30 2/8/2025 16:30 4.00 COMPZN, RPCOMP TRIP P TOOH with G-plug standing back DP. F/7649 T/49 UWT=160K / SOW=90K 7,649.0 49.0 2/8/2025 16:30 2/8/2025 17:30 1.00 COMPZN, RPCOMP BHAH P LD and inspect G-plug 49.0 0.0 2/8/2025 17:30 2/8/2025 18:30 1.00 COMPZN, RPCOMP BHAH P MU RCJB/Cleanout XO-Sub 3.5" IF x HT-38, 4-3/4" DC x 3, 4-3/4" Oil Jar, 4-3/4" LBS, 5-5/8" string magnet, Bit Sub, 4-3/4" boot basket x 2, XO-Sub (PXP), RCJB Top Sub, XO bushing, WP EXT, 5-3/4" Extension, 6- 1/8" OD Shoe. 0.0 148.7 2/8/2025 18:30 2/8/2025 21:00 2.50 COMPZN, RPCOMP TRIP P TIH with BHA #38 148.7 7,621.0 2/8/2025 21:00 2/8/2025 23:00 2.00 COMPZN, RPCOMP WASH P PUW=160, SOW=100 Circulate 4 bpm/530 psi Tag sand at 7,675' Rotate 60 rpm, FTQ=6,700 ft/lbs Increase rate to 5.5 bpm/2,630 psi Tag plug @ 7722.26' 7,621.0 7,722.3 2/8/2025 23:00 2/9/2025 00:00 1.00 COMPZN, RPCOMP CIRC P Circulate BU with sweep 7,722.3 7,722.3 2/9/2025 00:00 2/9/2025 00:30 0.50 COMPZN, RPCOMP CIRC P Continue circulating BU w/sweep SxS 5.5 BPM at 2620 psi OWFF - Static LD single 7,722.3 7,715.0 2/9/2025 00:30 2/9/2025 04:30 4.00 COMPZN, RPCOMP TRIP P TOOH racking back DP F/7715 T/148 PUW 165K 7,715.0 148.7 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 15/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/9/2025 04:30 2/9/2025 06:30 2.00 COMPZN, RPCOMP BHAH P LD BHA #38 Clean magnets and boot baskets and remove circ ball. 148.7 0.0 2/9/2025 06:30 2/9/2025 07:00 0.50 COMPZN, RPCOMP BHAH P PU BHA #39 IBP retrevial tool 0.0 48.0 2/9/2025 07:00 2/9/2025 09:00 2.00 COMPZN, RPCOMP TRIP P TIH F/48' T/7700' UWT 165K/ SOW 95K 48.0 7,700.0 2/9/2025 09:00 2/9/2025 10:00 1.00 COMPZN, RPCOMP WASH P Wash down at 4 BPM / 630 PSI Set down 5K at 7727.5' w/no pressure increase. Set down on on top of PBR, assume IBP pushed fell down inside PBR. 7,700.0 7,727.5 2/9/2025 10:00 2/9/2025 12:00 2.00 COMPZN, RPCOMP TRIP P TOOH F/7727.5' T/48' UWT 165K / SOW 95K 7,727.5 48.0 2/9/2025 12:00 2/9/2025 12:30 0.50 COMPZN, RPCOMP BHAH P LD BHA #39 IBP retrieval tool 48.0 0.0 2/9/2025 12:30 2/9/2025 13:00 0.50 COMPZN, RPCOMP BHAH P PU BHA #40 IBP retreival tool with 2- 1/16" CSH 0.0 63.0 2/9/2025 13:00 2/9/2025 14:30 1.50 COMPZN, RPCOMP TRIP P TIH T/1860' UWT 60 K / SOW57K 63.0 1,860.0 2/9/2025 14:30 2/9/2025 18:30 4.00 COMPZN, RPCOMP SFTY P Safety Standown 1,860.0 1,860.0 2/9/2025 18:30 2/9/2025 21:00 2.50 COMPZN, RPCOMP TRIP P Continue IH F/1,860' T/ PUW=80k, SOW=57k Note: Current Top of plug @ 7,727.5' 1,860.0 7,722.0 2/9/2025 21:00 2/9/2025 22:00 1.00 COMPZN, RPCOMP FISH P Push plug down T/7,729' Pull plug free, confirm with pressure plug is still on the hook PUW=165k, SOW=95k 7,722.0 7,729.0 2/9/2025 22:00 2/10/2025 00:00 2.00 COMPZN, RPCOMP TRIP P TOOH LD/DP IBP is inside 7 inch 7,729.0 7,100.0 2/10/2025 00:00 2/10/2025 00:30 0.50 COMPZN, RPCOMP CIRC P Continue circulating and condition mud Drop dart and shear pump out sub at 2500 psi Circ 5 BPM at 800 psi 7,100.0 7,100.0 2/10/2025 00:30 2/10/2025 01:00 0.50 COMPZN, RPCOMP OWFF P Observe well for flow: Static BD top Drive 7,100.0 7,100.0 2/10/2025 01:00 2/10/2025 07:30 6.50 COMPZN, RPCOMP PULD P Continue TOOH sideways F/7100 T/148 PUW 150K 7,100.0 148.0 2/10/2025 07:30 2/10/2025 09:00 1.50 COMPZN, RPCOMP BHAH P LD BHA #40 IBP retrieval tool and IBP. Remove wear bushing 148.0 0.0 2/10/2025 09:00 2/10/2025 09:30 0.50 COMPZN, RPCOMP PRTS P PT 7" casing T/2500 psi for 10 min charted: Good test 0.0 0.0 2/10/2025 09:30 2/10/2025 10:00 0.50 COMPZN, RPCOMP RURD P RU to run 3-1/2" Hyd-563 completion Verify running order and Tally 0.0 0.0 2/10/2025 10:00 2/10/2025 14:30 4.50 COMPZN, RPCOMP PUTB P Run completion in the hole. Jewelry from pipe shed and used tubing form stands stood back in derrick. 0.0 7,730.5 2/10/2025 14:30 2/10/2025 17:30 3.00 COMPZN, RPCOMP PUTB P Install XO on joint #248 and circulate down @ 1 bpm/50 psi, Locate seals @ 7,730.5' Observe pressure increase to 400 psi, shut down pump, open bleeder, slack off T/7,734 Set down 10k unable to locate no-go, circulate and condition hole, circulate BU x 2 until clean @ 7,728' Pumping 10 bpm/2,000 psi, observe oil/sand at shaker. returns cleaned up. Repeat with no success 7,730.5 7,730.5 2/10/2025 17:30 2/10/2025 18:00 0.50 COMPZN, RPCOMP TRIP T Confer with town team 7,730.5 7,730.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 16/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2025 18:00 2/10/2025 22:00 4.00 COMPZN, RPCOMP TRIP T TOOH racking back tubing in stands F/7,730' T/Surface 7,730.0 0.0 2/10/2025 22:00 2/10/2025 23:00 1.00 COMPZN, RPCOMP T Install Wear Ring PU 3.5" L-80 Mule Shoe joint Prep RF for TIH operations 0.0 30.5 2/10/2025 23:00 2/10/2025 23:30 0.50 COMPZN, RPCOMP T Load and tally 9 spare joints into pipe shed. 30.5 30.5 2/10/2025 23:30 2/11/2025 00:00 0.50 COMPZN, RPCOMP T TIH with 3.5" L-80 563 as work string 30.5 346.0 2/11/2025 00:00 2/11/2025 06:00 6.00 COMPZN, RPCOMP TRIP T Continue TIH F/346' T/7,730' w/3.5" L- 80 Completion per workstring tally UWT 100K / DWT 65K 346.0 7,713.0 2/11/2025 06:00 2/11/2025 07:30 1.50 COMPZN, RPCOMP WASH T Wash sand F/7728' T/7750' Set down 10K on NO Go Circ 9BPM at 1600 psi off bottom and 1700 psi on bottom 7,713.0 7,750.0 2/11/2025 07:30 2/11/2025 08:30 1.00 COMPZN, RPCOMP CIRC T Pump 45 bbl 240 vis sweep surface to surface at 9BPM /1600 psi 7,750.0 7,749.0 2/11/2025 08:30 2/11/2025 12:00 3.50 COMPZN, RPCOMP TRIP T TOOH F/7749 Tsurface UWT 100K / DWT 65K Pull wear ring 7,749.0 0.0 2/11/2025 12:00 2/11/2025 15:30 3.50 COMPZN, RPCOMP TRIP T TIH with 3.5", 9.3#, L-80, HYD-563 TBG from the derrick per tally TQ connections to 2900ft/lbs 0.0 7,673.0 2/11/2025 15:30 2/11/2025 17:00 1.50 COMPZN, RPCOMP TRIP P Cont RIH w/ completion from 7673' Tag top of PBR. Orient string, set No-go out on top of PBR @ 7749'. Set down 5K to confirm. L/D 3 joints, P/U space out pups, and P/U one full joint of tubing. P/U tubing hanger and M/U to string. 7,673.0 7,729.0 2/11/2025 17:00 2/11/2025 19:00 2.00 COMPZN, RPCOMP CIRC P Reverse circulate in CI Brine @ 168 GPM @ 390 PSI. 7,729.0 7,729.0 2/11/2025 19:00 2/11/2025 20:00 1.00 COMPZN, RPCOMP THGR P Land tubing hanger. RILDS. 7,729.0 7,746.0 2/11/2025 20:00 2/11/2025 21:00 1.00 COMPZN, RPCOMP RURD P R/U to test tubing IA. 7,746.0 7,746.0 2/11/2025 21:00 2/11/2025 22:00 1.00 COMPZN, RPCOMP PRTS P Line up on tubing, and pressure test to 3500 PSI for 30 min: . Bleed tubing to 2000 PSI, and hold. Line up on IA and attempt to pressure test to 3000 PSI. Observe flow past tubing hanger into stack. 7,746.0 7,746.0 2/11/2025 22:00 2/12/2025 00:00 2.00 COMPZN, RPCOMP RURD T R/D Test equipment. Pull hanger to rig floor flush attempt to flush seating profile in well head. Observe damage to seals on tubing hanger were lock down screws were run in on seals of tubing hanger. Redress tubing hanger. 0.0 0.0 2/12/2025 00:00 2/12/2025 01:30 1.50 COMPZN, RPCOMP CIRC T R/U and attempt to flush well head by closing annular, puming down kill line, taking returns out of IA to tiger tank. Pump 40 BBLS. Open annular. Run water hose down to well head and flush. 0.0 0.0 2/12/2025 01:30 2/12/2025 04:00 2.50 COMPZN, RPCOMP THGR T Cont. Trouble shoot Tubing hanger. Grease bottom of tubing hanger, and attempt to land Tubing hanger. Pull hanger to floor. 0.0 0.0 2/12/2025 04:00 2/12/2025 04:30 0.50 COMPZN, RPCOMP THGR T Observe 10.25" ID ring in grease on bottom of tubing hanger. Discover missing ring from test plug. Call and discuss with town. 0.0 0.0 2/12/2025 04:30 2/12/2025 06:30 2.00 COMPZN, RPCOMP NUND T Split BOP stack from well head. Remove Seal, and junk ring from test plug from tubing hanger profile. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Page 17/17 1B-09 Report Printed: 2/20/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2025 06:30 2/12/2025 07:30 1.00 COMPZN, RPCOMP NUND T Set stack back on tubing spool, and N/U. 0.0 0.0 2/12/2025 07:30 2/12/2025 12:30 5.00 COMPZN, RPCOMP THGR P Land hanger, ROLDS,UWT 97K / SOW67K. PT tubing 3500 psi for 30 minutes and chart. Good test. Bleed tubing to 2000 psi and PT IA to 3000 psi for 30 minutes and chart. Good test. Dump tubing pressure and shear out SOV. LD landing joint/ test equipment. 0.0 0.0 2/12/2025 12:30 2/12/2025 13:00 0.50 COMPZN, RPCOMP MPSP P Set BPV and pressure test from below to 1000 psi for 10 min. Good test. 0.0 0.0 2/12/2025 13:00 2/12/2025 14:00 1.00 COMPZN, WHDBOP OTHR P Flush BOP stack/choke/kill line & Gas buster w/deep clean pill. BD lines. 0.0 0.0 2/12/2025 14:00 2/12/2025 18:00 4.00 COMPZN, WHDBOP OTHR P Clean flow box, remove riser. Change out LPR to 2 7/8"x5" VBR. Open doors on BOP, and perform between wells maintenenace of BOPs 0.0 0.0 2/12/2025 18:00 2/12/2025 19:30 1.50 COMPZN, WHDBOP NUND P N/D BOP and rack back. 0.0 0.0 2/12/2025 19:30 2/12/2025 22:00 2.50 COMPZN, WHDBOP NUND P Clean and inspect tubing hanger, install test dart and SBMS seal. N/U tree and adaptor flange. FMC rep test hanger neck void to 5000 PSI for 10 min. 0.0 0.0 2/12/2025 22:00 2/12/2025 23:30 1.50 COMPZN, WHDBOP SEQP P R/U and fill tree with diesel, purge out air and test tree to 5000 PSI for 10 min: Good test. 0.0 0.0 2/12/2025 23:30 2/13/2025 00:00 0.50 COMPZN, WHDBOP MPSP P Pull test dart and BPV. R/U LRS, and circulating lines. 0.0 0.0 2/13/2025 00:00 2/13/2025 01:00 1.00 COMPZN, WHDBOP FRZP P R/U LRS. Pressure test lines. Freeze protect well w/ 80 bbls of diesel. 0.0 0.0 2/13/2025 01:00 2/13/2025 02:00 1.00 COMPZN, WHDBOP FRZP P Line up tubing to IA. U-tube well for one hour. Rig released @ 0200 hrs. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/13/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set PXX plug. Pulled DV leaving empty pocket. 1B-09 10/2/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Post-2025 RWO, IA is 3.5"x7" to 7680' then 3.5" x the original 9-5/8" to the pkr at 7728'. 2/5/2025 spilch NOTE: 2025 RWO cemented new 7" to surface. I.e. OA is cemented to surface. 2/5/2025 spilch 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT Intermediate 9 5/8 8.86 60.4 8,518.9 6,800.7 47.00 L-80 BTC 7" Scab 7 6.28 26.4 7,680.1 6,189.6 26.00 L-80 TXPM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,747.3 String Max No… 3 1/2 Set Depth … 6,242.6 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 24.9 24.9 0.05 Hanger 13.460 FMC Gen II Hanger w/ pup HTD563 pin FMC TC-1A- EMS 3.900 2,256.4 2,063.8 41.06 Nipple - X 4.251 2.813" X Nipple, 3.5", 9.3#, HYD563 (~2251') SN 4829273-04 HES 2.81 "X" 2.813 7,667.8 6,179.8 37.40 Mandrel - SOV 5.960 3.5"x1.5" MMG, SN 24135-16 SLB MMG 2.920 7,727.0 6,226.7 37.97 Locator 4.500 80-40, Locator BOT 2.992 7,727.9 6,227.3 37.98 Seal Assembly 3.980 80-40,Seal Assembly (Spaced out 2' off tag) BOT 80-40 2.992 Top (ftKB) 7,728.3 Set Depth … 7,973.5 String Max No… 3 1/2 Set Depth … 6,416.6 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection hyd 563 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) 7,728.3 6,227.7 37.98 Packer 8.681 3.5" by 9-5/8", Baker Model F Packer BOT 4.000 7,732.2 6,230.8 38.02 SBE 5.020 SBE w/5-10' Stroke BOT 4.010 7,827.3 6,305.2 39.13 Nipple - X 4.274 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5069318-09 HES 2.813 7,910.4 6,369.0 40.56 Sleeve - Sliding 4.280 3.5", CMU, 2.813" X BOT 2.810 7,962.3 6,408.1 41.39 Locator 4.500 80-40, Locator BOT 2.992 7,963.1 6,408.7 41.40 Seal Assembly 3.980 80-40, Seal Assembly (Space out 1.5' off tag) BOT 2.992 Top (ftKB) 7,960.8 Set Depth … 8,108.0 String Max No… 3 1/2 Set Depth … 6,515.7 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 7,960.8 6,407.0 41.36 Packer 8.200 3.5" by 9-5/8" Baker Model F Packer (~7957'/ between 7910'-7973') BOT 6.010 7,964.7 6,409.9 41.42 SBE 5.200 SBE w/10' Stroke BOT 4.010 8,019.6 6,450.8 42.22 2.81" X 3.500 2.813" X Nipple, 3.5", 9.3#, HYD563 S#5069318-08 HES 2.813 8,066.6 6,485.5 42.80 Sleeve - Sliding 4.250 3.5" CMU. 2.813" X BOT 2.810 8,097.1 6,507.8 43.18 Locator 4.480 80-40, Locator BOT 2.992 8,098.0 6,508.4 43.19 Seal Assembly 3.980 GBH 22 Seal assembly BOT 2.992 Top (ftKB) 8,096.5 Set Depth … 8,202.0 String Max No… 3 1/2 Set Depth … 6,583.2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 8,096.5 6,507.4 43.17 Packer 8.860 3.5" by 9-5/8" Baker Model F Packer (~8090'/ below 8002') BOT PN: 1017833 94, SN: SG 3369483 -04 2.949 8,100.4 6,510.2 43.22 Seal bore extension 5.010 SBE, w/5-10' Stroke BOT 3.980 8,154.9 6,549.6 44.16 2.81" X 4.500 2.813" X Nipple, 3.5", 9.3#, HYD563 (w/plug installed) S#5069318-06 HES PN: 1017420 11, SN: 5461-9 2.813 8,201.5 6,582.8 44.95 Wireline Guide 4.255 WLEG, 3.5", 9.3#, HYD563 BOT 2.993 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) 26.8 26.8 0.05 EMERGENCY SLIPS 2/7/2025 7.000 1B-09, 2/20/2025 12:20:11 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 7" Scab; 26.4-7,680.1 Mandrel - SOV; 7,667.8 Liner Cement; 27.0 ftKB SURFACE; 28.5-2,486.1 Nipple - X; 2,256.4 CONDUCTOR; 29.0-80.0 EMERGENCY SLIPS; 26.8 Hanger; 24.9 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev… 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 6/23/2024 H2S (ppm) DateComment SSSV: NONE 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) 7,817.0 6,297.2 38.95 OTHER Set P prong into plug body. BAIT SUB (LENGTH=28",OD=2.70"), PRONG (LENGTH=87",OD=1.87") (OAL=115") 10/1/2024 0.000 7,827.0 6,305.0 39.12 TUBING PLUG Set 2.81" PX plug body w/ fill ext. (OAL 52") 10/1/2024 0.000 8,154.0 6,549.0 44.14 TUBING PLUG 2.81" XX PLUG SET IN NIPPLE AT 6/19/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,667.8 6,179.8 37.40 1 GAS LIFT SOV RKP 1 1/2 2/11/2025 2000 psi - shear ed on- rig Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,587.8 6,115.9 36.67 Collar - Stage 7.000 7" HES Type H, ES II Stage Cementer SN#102463867 HAL ES II 6.276 7,610.7 6,134.2 36.84 Packer 7.000 7" Casing Packer INNOVEX Inflatable 80/40 SN#142229-0001 BOT ICP 6.230 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 27.0 7,591.8 27.0 6,119.1 Liner Cement Cement the surface casing 7" x 9-5/8" x 13-3/8" From 7591.76' to Surface, Cement in place at 11:00am 2/5/2025 1B-09, 2/20/2025 12:20:12 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 7" Scab; 26.4-7,680.1 Mandrel - SOV; 7,667.8 Liner Cement; 27.0 ftKB SURFACE; 28.5-2,486.1 Nipple - X; 2,256.4 CONDUCTOR; 29.0-80.0 EMERGENCY SLIPS; 26.8 Hanger; 24.9 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1B-09, 2/20/2025 12:20:12 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 7" Scab; 26.4-7,680.1 Mandrel - SOV; 7,667.8 Liner Cement; 27.0 ftKB SURFACE; 28.5-2,486.1 Nipple - X; 2,256.4 CONDUCTOR; 29.0-80.0 EMERGENCY SLIPS; 26.8 Hanger; 24.9 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8550' 6822' 8371' 6700'2386 None Casing Collapse Conductor Surface Tie-Back String 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 Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 L-80 TVD 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 AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7728'MD/6228'TVD 7961'MD/6407'TVD 8097'MD/6507'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 181-134 P.O. Box 100360, Anchorage, AK 99510 50-029-20655-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 2457' 7974' 8108' 8202' MD 80' 1/10/2025 3-1/2" 3-1/2" 3-1/2" 20" 13-3/8" 51' 63' 80' 2486' 6801'9-5/8" 2235' 63' 8519' Baker Model F Baker Model F Baker Model F SSSV: None Perforation Depth MD (ft): 7827', 8154' KRU 1B-09 7828-7910' 7973-8002' 8203-8221' 8226-8275' 7976-8002'(Squeezed) 7834-7910'(Squeezed) 8493' 6306-6369' 6416-6438' 6584-6597' 6600-6635' 6418-6468' (Squeezed) 6310-6369' (Squeezed) 9-5/8"37' m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Jack Lau 1/31/2025 By Grace Christianson at 3:21 pm, Jan 31, 2025 325-054 Jan 31, 2025 1/10/2025 10-404 JJL 2/3/25 DSR-1/31/25SFD 2/5/2025*&: 2/5/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.05 15:54:51 -09'00' RBDMS JSB 020625 1B-09 RWO Change of Approved Program Kuparuk Injector Repair Production Casing Leak PTD #181-134 Page 1 of 2 Remaining Pre-Rig Work (Complete) 1. Set plug in 2.81” X nipple at 7827’ MD and PT 2. Pull dummy valve from GLM at 7667’ MD’ 3. Packoff testing Rig Work MIRU (Complete) 1. MIRU Nabors 7ES on 1B-09. Circulate well over to ~9.5ppg brine. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 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 Tubing (Complete) 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from SBE at 7,732’ Remove shallow section of 9-5/8” casing (Failed) 6. Rig up E-line. Run cement bond log. 7. Run in hole with plug and test packer. Dump sand, test plug. 8. Run in hole and cut production casing. 9. Circulate out OA until well is static 10. ND BOP. ND tubing head. 11. Spear the casing and pick up casing to remove slips and packoffs. 12. Set casing back down and release the spear. 13. NU BOP to the casing head. a. Can not retest the BOPE at this point. Retest flange break once casing is recovered. 14. Spear casing and pull casing out of hole. Unable to pull 9-5/8” casing from surface, made multiple cuts in 9-5/8” casing and removed casing down to 1,295’ RKB. 15. Retest flange break 16. Dress off production casing stump. Run new 9-5/8” casing and cement to surface 17. Run new production casing with sealing overshot and cementer. 18. Cement new production casing to surface 19. Once adequate cement strength has been obtained, ND BOP and land casing. 20. NU BOPs and test BOP and flange breaks. 21. RIH and mill excess cement and debris cementer. Clean out sand above plug. 22. Pull plug. Run IBP, dump sand and change BOP rams 23. RIH w/ IBP on DP. Set above PBR and test from above to 1500 psi. 24. Swap 9-5/8” fixed rams for 7” fixed rams and perform BOPE test. Run new 7” tie-back liner and cement to surface 25. MU and run 7” liner to ~7650’ RKB with 7” x 9-5/8” (ECP) packer and cementer. 26. ND BOPs and land 7” string. NU BOPs. a. Flange break unable to be tested in this step. 27. Set ECP and cement tie-back liner to surface. 1B-09 RWO Change of Approved Program Kuparuk Injector Repair Production Casing Leak PTD #181-134 Page 2 of 2 28. ND BOPs, cut excess 7” casing and set packoff. NU and test BOPE break. 29. RIH and mill up excess cement and cementer. Clean out sand above IBP. Pull IBP. a. Mill up or remove any plugs used for setting ECP. Run Upper Completion 30. RIH with 3 ½” completion comprising of seals, GLM, tubing to stab into SBE on packer 31. Pick up, space out, circ in CI brine and land tubing into sealbore ~3’ from fully located 32. Land tubing hanger. Install packoffs 33. PT tubing to 3000psi 3500psi for 30 minutes. Holding 2000psi on tubing, PT IA to 2500psi 3000psi for 30 minutes. 34. Shear SOV 35. Install BPV. PT through SOV 36. ND BOP, NU WH 37. Circ in freeze protect tbg and IA Post Rig Work 1. Pull SOV, install GLD 2. Pull plug 3. Open sliding sleeves as needed for injection General Well info: Wellhead type/pressure rating: FMC Gen 2, 3M psi rated Production Engineer: Adam Becia Surveillance Reservoir Engineer: Cody Keith Estimated Start Date: 10/1/24 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion. Replace leaking production casing and run new completion BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MITIA: known leak Tubing pressure test planned pre rig after plug is set IC POT & PPPOT planned pre rig TBG POT & PPPOT planned pre rig MPSP: 2,386 psi using 0.1 psi/ft gradient Static BHP: 3,025 psi/ 6,394’ TVD (measured 9/7/23) Description Set Depth MD Set Depth TVD OD ID Weight Grade Top Conn Run Date Conductor 80 80 20 18.94 91.5 H-40 WELDED 10/17/1981 Surface 2486.1 2235.2 13.375 12.347 72 L-80 BUTT 10/18/1981 Production 8518.9 6800.7 9.625 8.861 47 L-80 BTC 10/31/1981 7" Tie-Back (Proposed)~7650' ~6165 7 6.28 26 L-80 TXPM Proposed Tubing – Lower 7973.5 6416.553 3.5 2.992 9.3 L-80 Hyd 563 6/21/2024 Tubing – Lower 8108 6515.748 3.5 2.992 9.3 L-80 Hyd 563 6/20/2024 Tubing – Lower 8202 6583.181 3.5 2.992 9.3 L-80 Hyd 563 6/19/2024 1B-09 Proposed RWO Completion - 1/30/25 Surface Casing @ 2486' RKB Production Casing Conductor A-sand perfs 8203-8275' RKB C-sand perfs 7973-8002' RKB C-sand perfs 7828-7910' RKB PROPOSED COMPLETION 4 1/2" Gen II Hanger 3-1/2" 9.3# L-80 Hyd563 Tubing to surface 3 1/2" 2.812" X Nipple @ 2251' RKB 3 1/2" MMG Side Pocket Mandrel @ TBD Proposed 7" Cemented Tieback 7" TXPM 26lb/ft Casing to Surface Crossover - 7" TXPM to 7" Hyd563 7" HES Cementer 7" x 9-5/8" External Casing Packer 7" Muleshoe Existing Completion: 3 1/2" x 9 5/8" Baker Model F Packer @ 7,730' RKB Sealbore Extension @ 7,732' RKB 3-1/2" x 2.813" X Nipple Profile @ 7,827' RKB 3-1/2" Sliding Sleeve @ 7,910' RKB 80-40 Locator Seal Assembly @ 7,962' RKB 3 1/2" x 9 5/8" Baker Model F Packer @ 7,960' RKB Sealbore Extension @ 7,964' RKB 3-1/2" x 2.813" X Nipple Profile @ 8,019' RKB 3-1/2" Sliding Sleeve @ 8,066' RKB 80-40 Locator Seal Assembly @ 8,097' RKB 3 1/2" x 9 5/8" Baker Model F Packer @ 8,096' RKB Sealbore Extension @ 8,100' RKB 3-1/2" x 2.813" X Nipple Profile @ 8,154' RKB Casing Cuts @ 1295', 1421', 1502', 1696', 2267' RKB Top of 9 5/8" @ 1218' RKB 11/1/1981 CBL shows partial bonding from ~6652' - 6715' and ~7822' - 7878'. A portion of the C sands were squeezed with 65 bbls of cement in 1994, and the original selective was installed during a RWO in 1995, and replaced in kind during a 2024 RWO. Perforations were made @ 1854' to 1856' and 80 bbls Arctic Pack followed by ~10 bbls AS I were pumped on-rig during the original drill in 1981 to freeze protect the OA. On-rig CBL shows partial cement from ~1300 to 1700'. Known hydrocarbon-bearing intervals behind PC: Ugnu sands: 3,372’ MD (2,775’ SSTVD) – 4,000’ MD (3,216 SSTVD) West Sak sands: 4,000’ MD (3,216 SSTVD) – 4,888’ MD (3,832’ SSTVD) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set PXX plug. Pulled DV leaving empty pocket. 1B-09 10/2/2024 fergusp 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT Tie-Back String 9 5/8 8.68 26.0 63.4 63.4 47.00 L80 HYD 563 Intermediate 9 5/8 8.86 60.4 8,518.9 6,800.7 47.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 7,728.3 Set Depth … 7,973.5 String Max No… 3 1/2 Set Depth … 6,416.6 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection hyd 563 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) 7,728.3 6,227.7 37.98 Packer 8.681 3.5" by 9-5/8", Baker Model F Packer BOT 4.000 7,732.2 6,230.8 38.02 SBE 5.020 SBE w/5-10' Stroke BOT 4.010 7,827.3 6,305.2 39.13 Nipple - X 4.274 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5069318-09 HES 2.813 7,910.4 6,369.0 40.56 Sleeve - Sliding 4.280 3.5", CMU, 2.813" X BOT 2.810 7,962.3 6,408.1 41.39 Locator 4.500 80-40, Locator BOT 2.992 7,963.1 6,408.7 41.40 Seal Assembly 3.980 80-40, Seal Assembly (Space out 1.5' off tag) BOT 2.992 Top (ftKB) 7,960.8 Set Depth … 8,108.0 String Max No… 3 1/2 Set Depth … 6,515.7 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 7,960.8 6,407.0 41.36 Packer 8.200 3.5" by 9-5/8" Baker Model F Packer (~7957'/ between 7910'-7973') BOT 6.010 7,964.7 6,409.9 41.42 SBE 5.200 SBE w/10' Stroke BOT 4.010 8,019.6 6,450.8 42.22 2.81" X 3.500 2.813" X Nipple, 3.5", 9.3#, HYD563 S#5069318-08 HES 2.813 8,066.6 6,485.5 42.80 Sleeve - Sliding 4.250 3.5" CMU. 2.813" X BOT 2.810 8,097.1 6,507.8 43.18 Locator 4.480 80-40, Locator BOT 2.992 8,098.0 6,508.4 43.19 Seal Assembly 3.980 GBH 22 Seal assembly BOT 2.992 Top (ftKB) 8,096.5 Set Depth … 8,202.0 String Max No… 3 1/2 Set Depth … 6,583.2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 8,096.5 6,507.4 43.17 Packer 8.860 3.5" by 9-5/8" Baker Model F Packer (~8090'/ below 8002') BOT PN: 1017833 94, SN: SG 3369483 -04 2.949 8,100.4 6,510.2 43.22 Seal bore extension 5.010 SBE, w/5-10' Stroke BOT 3.980 8,154.9 6,549.6 44.16 2.81" X 4.500 2.813" X Nipple, 3.5", 9.3#, HYD563 (w/plug installed) S#5069318-06 HES PN: 1017420 11, SN: 5461-9 2.813 8,201.5 6,582.8 44.95 Wireline Guide 4.255 WLEG, 3.5", 9.3#, HYD563 BOT 2.993 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) 63.0 63.0 0.12 LEAK - CASING PRODUCTION CASING LEAK IDENTIFIED ON VIVID LDL 7/8/2024 8.860 7,817.0 6,297.2 38.95 OTHER Set P prong into plug body. BAIT SUB (LENGTH=28",OD=2.70"), PRONG (LENGTH=87",OD=1.87") (OAL=115") 10/1/2024 0.000 7,827.0 6,305.0 39.12 TUBING PLUG Set 2.81" PX plug body w/ fill ext. (OAL 52") 10/1/2024 0.000 8,154.0 6,549.0 44.14 TUBING PLUG 2.81" XX PLUG SET IN NIPPLE AT 6/19/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 1B-09, 1/31/2025 3:03:10 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 SURFACE; 28.5-2,486.1 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev… 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 6/23/2024 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 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 1B-09, 1/31/2025 3:03:10 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 SURFACE; 28.5-2,486.1 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1B-09, 1/31/2025 3:03:11 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 SURFACE; 28.5-2,486.1 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… From:Lau, Jack J (OGC) To:Eller, Cy; Loepp, Victoria T (OGC) Cc:Coberly, Jonathan; Hobbs, Greg S; Nezaticky, Peter Subject:RE: [EXTERNAL]RE: 1B-09 RWO (PTD# 181-134) Update Date:Friday, January 31, 2025 1:20:05 PM Thanks Cy. The revised plan below is approved. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Friday, January 31, 2025 12:10 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: RE: [EXTERNAL]RE: 1B-09 RWO (PTD# 181-134) Update Jack, Per our conversation over the phone, please see the updated plan forward below to include PTs of the “new PC”. I have attached a new copy of the proposed schematic as well. I noticed that the current 9-5/8” top was listed incorrectly. Proposed plan forward: Perform cleanout runs and pull 9-5/8” RBP. Install IBP just above the existing upper packer and dump sand on plug. Swap lower BOP rams from 9-5/8” fixed rams to 7” fixed rams and test. MU and RIH w/ 7” tie-back liner assembly w/ 7” x 9-5/8” external casing packer (ECP) and HES cementer. Set the ECP and cement tie-back liner to surface. RIH, mill up excess cement and cementer plugs. Pressure test new tie-back to 1500 psi against IBP. Cleanout above IBP, pull IBP. Run 3-1/2” completion per approved Sundry. Test tubing to 3500 psi for 30 minutes. Test IA to 3000 psi for 30 minutes. Although the P&A of this well in the future is not ideal and will possibly require a rig to place cement behind the 9-5/8” casing, we are confident that it is achievable. Please let me know if you have any questions. 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. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, January 31, 2025 10:49 AM To: Eller, Cy <Cy.Eller@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: [EXTERNAL]RE: 1B-09 RWO (PTD# 181-134) Update CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thanks Cy. I will get back to shortly. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Friday, January 31, 2025 10:40 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com> Subject: 1B-09 RWO (PTD# 181-134) Update Good Morning Victoria, We pulled the 3-1/2” casing per plan on KRU 1B-09 and pulled a CBL on the 9-5/8” production casing, then set an RBP in the 9-5/8” casing to perform our “subsidence style” repair. The decision was made to cut the 9-5/8” casing at 2,267’ RKB. After making the cut in the production casing we were unable to pull the 9-5/8” casing in one piece. We have since made multiple cuts and removed the production casing down to 1,295’ RKB. The progress on pulling the 9-5/8” casing has proven to be difficult and is taking much longer than anticipated. To restore the integrity of the production casing we are requesting your consideration of the below plan to install a 7” cemented tie-back liner. Proposed plan forward: Perform cleanout runs and pull 9-5/8” RBP. Install IBP just above the existing upper packer and dump sand on plug. Swap lower BOP rams from 9-5/8” fixed rams to 7” fixed rams and test. MU and RIH w/ 7” tie-back liner assembly w/ 7” x 9-5/8” external casing packer (ECP) and HES cementer. Set the ECP and cement tie-back liner to surface. RIH, mill up excess cement and cementer plugs. Cleanout above IBP, pull IBP. Run 3-1/2” completion per approved Sundry. Please let me know if you have any questions or concerns. Attached is the proposed schematic for reference. I will follow up this email with a phone call shortly. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8550' 6822' 8371' 6700'2386 None Casing Collapse Conductor Surface Tie-Back String Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 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 Kuparuk River Field Adam Klem adam.klem@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 L-80 L-80 TVD 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7728'MD/6228'TVD 7961'MD/6407'TVD 8097'MD/6507'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 181-134 P.O. Box 100360, Anchorage, AK 99510 50-029-20655-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 2457' 7746' 7974' 8108' 8202' MD 80' 1/10/2025 3-1/2" 3-1/2" 3-1/2" 3-1/2" 20" 13-3/8" 51' 37' 63' 80' 2486' 6801'9-5/8" 2235' 63' 8519' Baker Model F Baker Model F Baker Model F SSSV: None Perforation Depth MD (ft): 7827', 8154' KRU 1B-09 7828-7910' 7973-8002' 8203-8221' 8226-8275' 7976-8002'(Squeezed) 7834-7910'(Squeezed) 8493' 6306-6369' 6416-6438' 6584-6597' 6600-6635' 6418-6468' (Squeezed) 6310-6369' (Squeezed) 9-5/8" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:38 am, Dec 13, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@conocophillips.com , C=US Reason: I am approving this document Location: Date: 2024.12.11 15:22:12-09'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 324-699 X X SFD 12/13/2024 10-404 DSR-12/16/24 Witnessed BOP and Annular Test to 2500 psi. Witnessed MITIA to 2500 psi. Pipe ram(s) must be sized to close on each work string, drill pipe, tubing, and casing run. X JJL 12/20/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.20 10:37:04 -09'00'12/20/24 RBDMS JSB 122424 Adam Klem Staff RWO/CTD Engineer CPAI Drilling and Wells If you have any questions or require any further information, please contact me at +1-907-263-4529 The RWO is to pull the tubing then cut the 9-5/8" around 2000' MD (log dependent). We will then replace the 9-5/8" casing and cement to surface. After that is completed, we will re-run the 3.5" tubing. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 11, 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 Camp Waste Injector 1B-09 (PTD# 181-134). Well 1B-09 was drilled and completed in 1981 as a Kuparuk A/C sand producer. In 1982 it was converted to a gas disposal injector, then converted to water injection. In 1994 some of the C sand was squeezed off, and in 1997 a RWO was completed with a dual selective completion. A one way suspected packer leak was detected in 2023 along with leaking selectives, and a workover to fix those issues was completed in 2024. However, post workover, a shallow leak in the production casing was discovered. Therefore, another workover is required to restore casing integrity. Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.12.11 15:22:22-09'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 1B-09 RWO Procedure Kuparuk Injector Repair Leaking Production Casing PTD #181-134 Page 1 of 2 Remaining Pre-Rig Work 1. Set plug in 2.81” X nipple at 7827’ MD and PT 2. Pull dummy valve from GLM at 7667’ MD’ 3. Packoff testing Rig Work MIRU 1. MIRU Nabors 7ES on 1B-09. Circulate well over to ~9.5ppg brine. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 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 Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from SBE at 7,732’ Remove shallow section of 9-5/8” casing 6. Rig up E-line. Run cement bond log. 7. Run in hole with plug and test packer. Dump sand, test plug. 8. Run in hole and cut production casing. 9. Circulate out OA until well is static 10. ND BOP. ND tubing head. 11. Spear the casing and pick up casing to remove slips and packoffs. 12. Set casing back down and release the spear. 13. NU BOP to the casing head. a. Can not retest the BOPE at this point. Retest flange break once casing is recovered. 14. Spear casing and pull casing out of hole. 15. Retest flange break 16. Dress off production casing stump. Run new 9-5/8” casing and cement to surface 17. Run new production casing with sealing overshot and cementer. 18. Cement new production casing to surface 19. Once adequate cement strength has been obtained, ND BOP and land casing. 20. NU BOPs and test BOP and flange breaks. 21. RIH and mill excess cement and cementer. Clean out sand above plug. 22. Pull plug. Run Upper Completion 23. RIH with 3 ½” completion comprising of seals, GLM, tubing to stab into SBE on packer 24. Pick up, space out, circ in CI brine and land tubing into sealbore ~3’ from fully located 25. Land tubing hanger. Install packoffs 26. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 27. Shear SOV 28. Install BPV. PT through SOV 29. ND BOP, NU WH 30. Circ in freeze protect tbg and IA Page 2 of 2 1B-09 RWO Procedure Kuparuk Injector Repair Leaking Production Casing PTD #181-134 Post Rig Work 1. Pull SOV, install GLD 2. Pull plug 3. Open sliding sleeves as needed for injection General Well info: Wellhead type/pressure rating:FMC Gen 2, 3M psi rated Production Engineer:Adam Becia Surveillance Reservoir Engineer:Cody Keith Estimated Start Date:1/10/25 Workover Engineer:Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations:This well is currently shut in. Well Type:Injector Scope of Work:Pull the existing 3-1/2” completion. Replace leaking production casing and run new completion BOP configuration:Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MITIA: known leak Tubing pressure test planned pre rig after plug is set IC POT & PPPOT planned pre rig TBG POT & PPPOT planned pre rig MPSP:2,386 psi using 0.1 psi/ft gradient Static BHP: 3,025 psi/ 6,394’ TVD (measured 9/7/23) Pipe ram(s) must be sized to close on each work string, drill pipe, tubing, and casing run. - JJL Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set PXX plug. Pulled DV leaving empty pocket. 1B-09 10/2/2024 fergusp 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT Tie-Back String 9 5/8 8.68 26.0 63.4 63.4 47.00 L80 HYD 563 Intermediate 9 5/8 8.86 60.4 8,518.9 6,800.7 47.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,746.4 String Max No… 3 1/2 Set Depth … 6,241.9 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 24.3 24.3 0.04 Hanger 13.460 FMC Gen II Hanger w/ pup HTD563 pin FMC TC-1A- EMS 3.900 1,638.4 1,586.2 32.47 Nipple - X 4.251 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5007477-2 HES 2.81 "X" 2.813 7,667.0 6,179.2 37.39 Mandrel - SOV 5.960 3.5"x1.5" MMG (w/SOV 2000psi) S# 24758-17 SLB MMG 2.920 7,726.1 6,226.0 37.96 Locator 4.500 80-40, Locator BOT 2.992 7,727.0 6,226.6 37.97 Seal Assembly 3.980 80-40,Seal Assembly (Spaced out 2' off tag) BOT 80-40 2.992 Top (ftKB) 7,728.3 Set Depth … 7,973.5 String Max No… 3 1/2 Set Depth … 6,416.6 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection hyd 563 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) 7,728.3 6,227.7 37.98 Packer 8.681 3.5" by 9-5/8", Baker Model F Packer BOT 4.000 7,732.2 6,230.8 38.02 SBE 5.020 SBE w/5-10' Stroke BOT 4.010 7,827.3 6,305.2 39.13 Nipple - X 4.274 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5069318-09 HES 2.813 7,910.4 6,369.0 40.56 Sleeve - Sliding 4.280 3.5", CMU, 2.813" X BOT 2.810 7,962.3 6,408.1 41.39 Locator 4.500 80-40, Locator BOT 2.992 7,963.1 6,408.7 41.40 Seal Assembly 3.980 80-40, Seal Assembly (Space out 1.5' off tag) BOT 2.992 Top (ftKB) 7,960.8 Set Depth … 8,108.0 String Max No… 3 1/2 Set Depth … 6,515.7 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 7,960.8 6,407.0 41.36 Packer 8.200 3.5" by 9-5/8" Baker Model F Packer (~7957'/ between 7910'-7973') BOT 6.010 7,964.7 6,409.9 41.42 SBE 5.200 SBE w/10' Stroke BOT 4.010 8,019.6 6,450.8 42.22 2.81" X 3.500 2.813" X Nipple, 3.5", 9.3#, HYD563 S#5069318-08 HES 2.813 8,066.6 6,485.5 42.80 Sleeve - Sliding 4.250 3.5" CMU. 2.813" X BOT 2.810 8,097.1 6,507.8 43.18 Locator 4.480 80-40, Locator BOT 2.992 8,098.0 6,508.4 43.19 Seal Assembly 3.980 GBH 22 Seal assembly BOT 2.992 Top (ftKB) 8,096.5 Set Depth … 8,202.0 String Max No… 3 1/2 Set Depth … 6,583.2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 8,096.5 6,507.4 43.17 Packer 8.860 3.5" by 9-5/8" Baker Model F Packer (~8090'/ below 8002') BOT PN: 1017833 94, SN: SG 3369483 -04 2.949 8,100.4 6,510.2 43.22 Seal bore extension 5.010 SBE, w/5-10' Stroke BOT 3.980 8,154.9 6,549.6 44.16 2.81" X 4.500 2.813" X Nipple, 3.5", 9.3#, HYD563 (w/plug installed) S#5069318-06 HES PN: 1017420 11, SN: 5461-9 2.813 8,201.5 6,582.8 44.95 Wireline Guide 4.255 WLEG, 3.5", 9.3#, HYD563 BOT 2.993 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) 63.0 63.0 0.12 LEAK - CASING PRODUCTION CASING LEAK IDENTIFIED ON VIVID LDL 7/8/2024 8.860 7,817.0 6,297.2 38.95 OTHER Set P prong into plug body. BAIT SUB (LENGTH=28",OD=2.70"), PRONG (LENGTH=87",OD=1.87") (OAL=115") 10/1/2024 0.000 1B-09, 12/11/2024 2:58:34 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 Hanger; 24.3 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev… 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 6/23/2024 H2S (ppm) DateComment SSSV: NONE 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) 7,827.0 6,305.0 39.12 TUBING PLUG Set 2.81" PX plug body w/ fill ext. (OAL 52") 10/1/2024 0.000 8,154.0 6,549.0 44.14 TUBING PLUG 2.81" XX PLUG SET IN NIPPLE AT 6/19/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,667.0 6,179.2 37.39 1 GAS LIFT Open 1 1/2 10/2/2024 SLB MMG Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 1B-09, 12/11/2024 2:58:35 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 Hanger; 24.3 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1B-09, 12/11/2024 2:58:36 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 TUBING PLUG; 7,827.0 OTHER; 7,817.0 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 Hanger; 24.3 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… Description Top (MD) FMC GEN II HANGER 22 4.5" 12.6#, HYD563 26 4.5" tubing to 3.5" Hyd563 54 Tubing, 3.5", 9.3#, HYD563 75 Tubing Pup, 3.5", 9.3#, HYD563 2245 2.813" X, 3.5", 9.3#, HYD563 2251 Tubing Pup, 3.5", 9.3#, HYD563 2259 Tubing, 3.5", 9.3#, HYD563 2265 Tubing Pup, 3.5", 9.3#, HYD563 7659 3.5" MMG 7665 Tubing Pup, 3.5", 9.3#, HYD563 7673 Tubing, 3.5", 9.3#, HYD563 7679 Tubing Pup, 3.5", 9.3#, HYD563 7710 80-40 Locator Assembly 7716 3.5" by 9 5/8" Baker Model F Packer 7730 SBE w/ 5-10' STROKE 7730 Tubing Pup, 3.5", 9.3#, HYD563 7738 Tubing, 3.5", 9.3#, HYD563 7744 Tubing Pup, 3.5", 9.3#, HYD563 7806 2.813" X, 3.5", 9.3#, HYD563 7812 Tubing Pup, 3.5", 9.3#, HYD563 7820 Tubing, 3.5", 9.3#, HYD563 7826 Tubing Pup, 3.5", 9.3#, HYD563 7888 3.5" CMU. 2.813" X 7894 Tubing Pup, 3.5", 9.3#, HYD563 7902 Tubing, 3.5", 9.3#, HYD563 7910 Tubing Pup, 3.5", 9.3#, HYD563 7941 80-40 Locator Assembly, 7947 3.5" by 9 5/8" Baker Model F Packer 7957 SBE w/ 5-10' STROKE 7965 Tubing Pup, 3.5", 9.3#, HYD563 7975 Tubing, 3.5", 9.3#, HYD563 7981 Tubing Pup, 3.5", 9.3#, HYD563 8012 2.813" X, 3.5", 9.3#, HYD563 8018 Tubing Pup, 3.5", 9.3#, HYD563 8026 Tubing, 3.5", 9.3#, HYD563 8032 Tubing Pup, 3.5", 9.3#, HYD563 8063 3.5" CMU. 2.813" X 8069 Tubing Pup, 3.5", 9.3#, HYD563 8077 80-40 Locator Assembly 8085 3.5" by 9 5/8" Baker Model F Packer 8090 SBE w/ 5-10' STROKE 8098 Tubing Pup, 3.5", 9.3#, HYD563 8108 Tubing, 3.5", 9.3#, HYD563 8114 Tubing Pup, 3.5", 9.3#, HYD563 8145 2.813" X, 3.5", 9.3#, HYD563 8151 Tubing Pup, 3.5", 9.3#, HYD563 8159 Tubing, 3.5", 9.3#, HYD563 8165 WLEG, 3.5", 9.3#, HYD563 8196 1B-09 Proposed RWO Completion - 8/5/24 Surface Casing Production Casing Conductor A-sand perfs 8203-8275' RKB C-sand perfs 7973-8002' RKB C-sand perfs 7828-7910' RKB CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1B-09 (PTD 181-134) Report of failed MITIA Date:Monday, July 1, 2024 11:54:49 AM Attachments:1B-09 90 day TIO & schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, July 1, 2024 11:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1B-09 (PTD 181-134) Report of failed MITIA Chris, KRU 1B-09 (PTD 181-134) slickline reported having a failing MITIA with communication to the OA during post RWO operations. The plan is for DHD to conduct initial diagnostics after which a path forward will be determined. Any required paperwork will be submitted prior to any corrective action or continued injection. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me 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 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Cuts 1B-09 5/22/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: SUSPECT GLM EROSION AT 7791; HAD TO RUN EXTENDED PACKING ON 1.5"" DUMMY VALVE 9/9/2001 triplwj 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT Tie-Back String 9 5/8 8.68 26.0 63.4 63.4 47.00 L80 HYD 563 Intermediate 9 5/8 8.86 60.4 8,518.9 6,800.7 47.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,746.4 Set Depth … 6,241.9 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 24.3 24.3 0.04 Hanger 13.460 FMC Gen II Hanger w/ pup HTD563 pin FMC TC-1A- EMS 3.900 1,638.4 1,586.2 32.47 Nipple - X 4.251 2.813" X Nipple, 3.5", 9.3#, HYD563 (~2251') S# 5007477-2 HES 2.81 "X" 2.813 7,667.0 6,179.2 37.39 Mandrel - SOV 5.960 3.5"x1.5" MMG (w/SOV 2000psi) S# 24758-17 SLB MMG 2.920 7,726.1 6,226.0 37.96 Locator 4.500 80-40, Locator BOT 2.992 7,727.0 6,226.6 37.97 Seal Assembly 3.980 80-40,Seal Assembly (Spaced out 2' off tag) BOT 80-40 2.992 Top (ftKB) 7,728.3 Set Depth … 7,973.5 Set Depth … 6,416.6 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection hyd 563 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) 7,728.3 6,227.7 37.98 Packer 8.681 3.5" by 9-5/8", Baker Model F Packer BOT 4.000 7,732.2 6,230.8 38.02 SBE 5.020 SBE w/5-10' Stroke BOT 4.010 7,827.3 6,305.2 39.13 Nipple - X 4.274 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5069318-09 HES 2.813 7,910.4 6,369.0 40.56 Sleeve - Sliding 4.280 3.5", CMU, 2.813" X BOT 2.810 7,962.3 6,408.1 41.39 Locator 4.500 80-40, Locator BOT 2.992 7,963.1 6,408.7 41.40 Seal Assembly 3.980 80-40, Seal Assembly (Space out 1.5' off tag) BOT 2.992 Top (ftKB) 7,960.8 Set Depth … 8,108.0 Set Depth … 6,515.7 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 7,960.8 6,407.0 41.36 Packer 8.200 3.5" by 9-5/8" Baker Model F Packer (~7957'/ between 7910'-7973') BOT 6.010 7,964.7 6,409.9 41.42 SBE 5.200 SBE w/10' Stroke BOT 4.010 8,019.6 6,450.8 42.22 2.81" X 3.500 2.813" X Nipple, 3.5", 9.3#, HYD563 S#5069318-08 HES 2.813 8,066.6 6,485.5 42.80 Sleeve - Sliding 4.250 3.5" CMU. 2.813" X BOT 2.810 8,097.1 6,507.8 43.18 Locator 4.480 80-40, Locator BOT 2.992 8,098.0 6,508.4 43.19 Seal Assembly 3.980 GBH 22 Seal assembly BOT 2.992 8,108.0 6,515.7 43.35 8,108.0 6,515.7 43.35 Top (ftKB) 8,096.5 Set Depth … 8,202.0 Set Depth … 6,583.2 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 8,096.5 6,507.4 43.17 Packer 8.860 3.5" by 9-5/8" Baker Model F Packer (~8090'/ below 8002') BOT PN: 1017833 94, SN: SG 3369483 -04 2.949 8,100.4 6,510.2 43.22 Seal bore extension 5.010 SBE, w/5-10' Stroke BOT 3.980 8,154.9 6,549.6 44.16 2.81" X 4.500 2.813" X Nipple, 3.5", 9.3#, HYD563 (w/plug installed) S#5069318-06 HES PN: 1017420 11, SN: 5461-9 2.813 8,201.5 6,582.8 44.95 Wireline Guide 4.255 WLEG, 3.5", 9.3#, HYD563 BOT 2.993 1B-09, 6/27/2024 4:44:08 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 FLOAT SHOE; 8,517.0-8,518.9 FLOAT COLLAR; 8,435.0- 8,436.5 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 Wireline Guide; 8,201.5 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 Seal bore extension; 8,100.4 Seal Assembly; 8,098.0 Packer; 8,096.5 Locator; 8,097.1 Sleeve - Sliding; 8,066.6 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SBE; 7,964.7 Seal Assembly; 7,963.1 Packer; 7,960.8 Locator; 7,962.2 Sleeve - Sliding; 7,910.4 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 Nipple - X; 7,827.3 SBE; 7,732.2 Seal Assembly; 7,726.9 Packer; 7,728.3 Locator; 7,726.1 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 FLOAT SHOE; 2,484.2-2,486.1 FLOAT COLLAR; 2,405.3- 2,406.9 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 Tie-Back String; 26.0-63.4 Casing Patch; 57.9-63.4 HANGER; 28.5-32.2 Tubing - XO; 29.2 Hanger; 24.3 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev… 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 6/23/2024 H2S (ppm) DateComment SSSV: WRDP 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) 8,154.0 6,549.0 44.14 TUBING PLUG 2.81" XX PLUG SET IN NIPPLE AT 6/19/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,667.0 6,179.2 37.39 1 SOV 1 1/2 6/23/2024 SLB rek Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 1B-09, 6/27/2024 4:44:08 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 FLOAT SHOE; 8,517.0-8,518.9 FLOAT COLLAR; 8,435.0- 8,436.5 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 Wireline Guide; 8,201.5 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 Seal bore extension; 8,100.4 Seal Assembly; 8,098.0 Packer; 8,096.5 Locator; 8,097.1 Sleeve - Sliding; 8,066.6 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SBE; 7,964.7 Seal Assembly; 7,963.1 Packer; 7,960.8 Locator; 7,962.2 Sleeve - Sliding; 7,910.4 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 Nipple - X; 7,827.3 SBE; 7,732.2 Seal Assembly; 7,726.9 Packer; 7,728.3 Locator; 7,726.1 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 FLOAT SHOE; 2,484.2-2,486.1 FLOAT COLLAR; 2,405.3- 2,406.9 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 Tie-Back String; 26.0-63.4 Casing Patch; 57.9-63.4 HANGER; 28.5-32.2 Tubing - XO; 29.2 Hanger; 24.3 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1B-09, 6/27/2024 4:44:08 PM Vertical schematic (actual) Intermediate; 60.4-8,518.9 FLOAT SHOE; 8,517.0-8,518.9 FLOAT COLLAR; 8,435.0- 8,436.5 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 Wireline Guide; 8,201.5 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 Seal bore extension; 8,100.4 Seal Assembly; 8,098.0 Packer; 8,096.5 Locator; 8,097.1 Sleeve - Sliding; 8,066.6 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SBE; 7,964.7 Seal Assembly; 7,963.1 Packer; 7,960.8 Locator; 7,962.2 Sleeve - Sliding; 7,910.4 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 Nipple - X; 7,827.3 SBE; 7,732.2 Seal Assembly; 7,726.9 Packer; 7,728.3 Locator; 7,726.1 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 FLOAT SHOE; 2,484.2-2,486.1 FLOAT COLLAR; 2,405.3- 2,406.9 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 Tie-Back String; 26.0-63.4 Casing Patch; 57.9-63.4 HANGER; 28.5-32.2 Tubing - XO; 29.2 Hanger; 24.3 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8550'feet 8154'feet true vertical 6822' feet None feet Effective Depth measured 8371'feet 7728', 7961', 8097'feet true vertical 6700'feet 6228', 6407', 6507'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7746' 7974' 8108' 6242' 6417' 6516' Packers and SSSV (type, measured and true vertical depth)7728' 7961' 8097' 6228' 6407' 6507' 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: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 324-218, 324-346 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Model F Packer: Baker Model F Packer: Baker Model F SSSV: None Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013Staff RWO/CTD Engineering Supervisor 8493' 9-5/8" measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 80' N/A 51' measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-134 50-029-20655-00-00 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/ Kuparuk River Oil Pool KRU 1B-09 Plugs Junk Burst Collapse Tie-Back Intermediate 37' Casing 63'63' 8519' 6801' 2457' 80'Conductor Surface 6306-6366', 6364-6369', 6416-6438', 6584-6587', 6587-6597', 6600-6602', 6602-6635' 7828-7906', 7904-7910', 7973-8002', 8203-8207', 8207-8221', 8226-8229', 8229-8275' 2486' 2235' 20" 13-3/8" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:59 am, Jul 23, 2024 Page 1/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/26/2024 00:00 5/26/2024 08:00 8.00 MIRU, MOVE MOB P Mobilize Pits office and shop to 1B from 3T Stage shop office and pits on location. Release Cruz. 5/26/2024 08:00 5/26/2024 16:30 8.50 MIRU, MOVE MOB P Mobilize Sub base F/3T T/3f. Stop for shift change 5/26/2024 16:30 5/26/2024 18:30 2.00 MIRU, MOVE WAIT P Standby at 3F for crew change 5/26/2024 18:30 5/27/2024 00:00 5.50 MIRU, MOVE MOB P Continue to Mobilize F/3F T/Oliktok Y 5/27/2024 00:00 5/27/2024 03:30 3.50 MIRU, MOVE MOB P Continue to Mobilize F/Oliktok Y T/1B- pad well 09 0.0 0.0 5/27/2024 03:30 5/27/2024 08:00 4.50 MIRU, MOVE MOB P Sub Module on location, Prep well for rig, lay rig mats and spread pit liner. Spot sub and pits over well 0.0 0.0 5/27/2024 08:00 5/27/2024 16:00 8.00 MIRU, MOVE MOB P Spot auxiliary equipment, cuttings tank Bridal down. Hook up steam and air to pits. Get RKB measurements. Complete acceptance checklist. Take on FWB in pits. 0.0 0.0 5/27/2024 16:00 5/27/2024 16:45 0.75 MIRU, MOVE RURD P Verify lines to the kill tanks are clear. PJSM to kill well. Pressure test lines to the tanks to 200/2500 PSI 0.0 0.0 5/27/2024 16:45 5/27/2024 18:30 1.75 MIRU, WELCTL CIRC P Circulate down the tubing @ 2 bpm @ 30 psi, 847 bbl 9.8 ppg, pressure climbing up slowly, 360 away 266 bls retiurned. 0.0 0.0 5/27/2024 18:30 5/27/2024 19:45 1.25 MIRU, WELCTL CIRC P Shut down pump, line up to pump down the IA taking returns up the tubing, Volume pumped 140 bbl, returned 119 bbl, Bring pump back online 3.5 bpm/127 psi pump 0.0 0.0 5/27/2024 19:45 5/27/2024 21:45 2.00 MIRU, WELCTL OTHR P Shut down pump, dicuss with town team Lighten up working fluid 9.8 ppg to 9.5 ppg. 0.0 0.0 5/27/2024 21:45 5/27/2024 22:15 0.50 MIRU, WELCTL SFTY P PJSM w/rig crew change out. Short day 0.0 0.0 5/27/2024 22:15 5/28/2024 00:00 1.75 MIRU, WELCTL CIRC P Ciculate down the IA taking returns tubing to tiger tank. 0.0 0.0 5/28/2024 00:00 5/28/2024 04:00 4.00 MIRU, WELCTL CIRC P Continue to circulate down the IA taking returns tubing to tiger tank. 3.0 bpm/340 psi, 596 bbl total pumped, shut down pump, blow down surface lines to tiger tank. 0.0 0.0 5/28/2024 04:00 5/28/2024 04:30 0.50 MIRU, WELCTL OWFF P Open up Tubing and IA Monitor well for 30 mins, No flow. 0.0 0.0 5/28/2024 04:30 5/28/2024 05:00 0.50 MIRU, WELCTL MPSP P Bring BPV to the RF Remove tree cap Hang T-bar on tugger. 0.0 0.0 5/28/2024 05:00 5/28/2024 05:30 0.50 MIRU, WELCTL PRTS P Line up to test BPV, down the IA, perform rolling test to 500 psi, BPV is dry, shut down pump, bleed pressure to 0, open IA valve to bucket to confirm no flow. 0.0 0.0 5/28/2024 05:30 5/28/2024 08:30 3.00 MIRU, WHDBOP NUND P ND tree.hang on DS of cellar area Unable to set blanking plug 0.0 0.0 5/28/2024 08:30 5/28/2024 10:00 1.50 MIRU, WHDBOP RURD P Function all LDS RU testing equipment. 0.0 0.0 5/28/2024 10:00 5/28/2024 13:00 3.00 MIRU, WHDBOP WAIT T Stand by for blanking plug. Processing drill pipe. RU floor to test BOPE 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 2/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/28/2024 13:00 5/28/2024 15:00 2.00 MIRU, WHDBOP NUND P Install blank off plug and NU BOPE. Torque studs, install riser and secondary air boot. 0.0 5/28/2024 15:00 5/28/2024 16:00 1.00 MIRU, WHDBOP BOPE P PU test tools and flood lines. Purge air and obtain a good shell test. 0.0 0.0 5/28/2024 16:00 5/28/2024 23:00 7.00 MIRU, WHDBOP BOPE P Initial BOPE test. All tests at 250/2500 PSI for 5 Min each. Test #1 Blind rams, CMV 1-2-3-16, Rig Floor Kill, Outer Test Spool Valve, IBOP, Test #2 CMV 4-5-6, HCR Kill, Inner Test Spool Valve, Manual IBOP, B/D TD M/U Blank Sub T/Dart and TIW, P/U 4.5" Donut Test Joint w/4.5 EUE FOSV, T Off of teats hose T/cellar and blanking sub, Test #3 CMV 7-8-9, Manual Kill UPR, 4.5 EUE FOSV and HT38 dart, Test #4 Hydraulic Super Choke & Manual Adjustable Choke (1,500 psi test), Test #5 Annular, CMV 10, 11, HT38 TIW, Test #6 UPR, CMV 12-13-15 and 3.5" FOSV, Test #7 Annular, CMV 14, Test #8 HCR Choke, Manual Choke. Performed accumulator draw test. Initial pressure=3050 PSI, after closure=16000 PSI, 200 PSI attained =21 sec, full recovery attained =114 sec. 5 back up nitrogen bottles average =2050 PSI. Function tested. UPR=6 Sec, LPR=6 Sec Annular=28 Sec. Simulated Blinds=6, HCR Kill=1 Sec. HCR Choke=1 Sec. Test gas detectors, PVT and flow show. Test waived by AOGCC rep Brian Bixby. Choke HCR Fail/Pass. Replaced valve and functioned properly. 0.0 0.0 5/28/2024 23:00 5/29/2024 00:00 1.00 MIRU, WHDBOP RURD P R/D Testing equipment, Bring joint of DP to pull Blanking plug 0.0 5/29/2024 00:00 5/29/2024 01:00 1.00 COMPZN, RPCOMP MPSP P Pull blanking plug, confirm no pressure under BPV. Pull BPV, LD pulling tools 0.0 0.0 5/29/2024 01:00 5/29/2024 01:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #1 w/Baker 3.947" spear with packoff 0.0 0.0 5/29/2024 01:30 5/29/2024 02:00 0.50 COMPZN, RPCOMP PULL P Stab hanger w/spear, BOLDS, pull hanger to RF. Brake over 153k, PUW=110k, SOW=72k 0.0 0.0 5/29/2024 02:00 5/29/2024 03:00 1.00 COMPZN, RPCOMP PULL P Brake out spear, L\D Hanger and hanger pup 0.0 0.0 5/29/2024 03:00 5/29/2024 05:00 2.00 COMPZN, RPCOMP CIRC P Circulate BU, got 9.1 ppg FWP returns line up to cuttings tank, Dump 118 bbls, bring FWP back in side, continue circulating BU, notice 9.3 ppg going down hole, shut down pump 0.0 0.0 5/29/2024 05:00 5/29/2024 09:00 4.00 COMPZN, RPCOMP CIRC P Bring more fluid on from 1B-storage, condition fluid in pits 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 3/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/29/2024 09:00 5/29/2024 19:00 10.00 COMPZN, RPCOMP PULL P Pulled 3 joints of 4-1/2" IJ-4S tubing. Measured pipe body at 4.58" and connection upset at 4.95". Pipe elevators getting good bite on pipe and too small ID for connection upset to fit through. Called town, sent pictures and descision made to POOH on elevators rather than shut down to hot shot 3 joints of tubing to INNO metal works to get crossovers made and collars bucked onto to be used as lifting nubbings. *** Note: 243 jts 4-1/2" J-55 12.75# IJ- 4S, 6 jts 3-1/2" EUE 9.3# L-80, 1 GLM and cut 1.32'. *** Note, leave hole fill 7,727.0 0.0 5/29/2024 19:00 5/29/2024 20:15 1.25 COMPZN, RPCOMP OTHR P Clean rig floor, load out remaining pipe from pipe shed, Load DC and tally, bring in BHA #2 0.0 0.0 5/29/2024 20:15 5/29/2024 21:00 0.75 COMPZN, RPCOMP OTHR P Service rig, Top Drive, Skate, etc. 0.0 0.0 5/29/2024 21:00 5/29/2024 22:30 1.50 COMPZN, RPCOMP BHAH P MU BHA #2 w/XO Sub HT38 x 3-1/2" IF, 4-3/4" DC x 6, XO Sub 3-1/2" IF x 4-1/2" IF, Oil Jar, LBS, and 8-1/8" Overshot. 0.0 214.1 5/29/2024 22:30 5/30/2024 00:00 1.50 COMPZN, RPCOMP TRIP P TIH w/Fishing BHA #2 , PU DP from pipeshed, 3-1/2" HT38 PUW=55k, SOW=55k 214.1 1,400.0 5/30/2024 00:00 5/30/2024 05:00 5.00 COMPZN, RPCOMP TRIP P TIH w/Fishing BHA #2 , PU DP from pipeshed, 3-1/2" HT38 PUW=55k, SOW=55k 1,400.0 7,724.3 5/30/2024 05:00 5/30/2024 05:30 0.50 COMPZN, RPCOMP FISH P PUW=150k, SOW=98k, slowly RIH, tag fish, set down 10k, PU to brake over 180k, RBIH, set down 6' higher 7,724.3 7,724.3 5/30/2024 05:30 5/30/2024 07:00 1.50 COMPZN, RPCOMP CIRC P Circulate BU strokes, 5 BPM at 550 psi for 459 bbls 7,724.3 7,724.0 5/30/2024 07:00 5/30/2024 11:15 4.25 COMPZN, RPCOMP TRIP P Trip out of hole F/7724' PUW 160K / SOW 100K 7,724.0 0.0 5/30/2024 11:15 5/30/2024 11:30 0.25 COMPZN, RPCOMP OWFF P Flow check-no flow 0.0 0.0 5/30/2024 11:30 5/30/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 5/30/2024 12:00 5/30/2024 15:00 3.00 COMPZN, RPCOMP BHAH P LD BHA #2 cut joint and seal assembly MU BHA #3 fishing BHA to pull packer 0.0 0.0 5/30/2024 15:00 5/30/2024 18:45 3.75 COMPZN, RPCOMP TRIP P Trip in the hole with BHA #3 0.0 7,730.0 5/30/2024 18:45 5/30/2024 21:15 2.50 COMPZN, RPCOMP FISH P PUW=160k, SOW=100k, Pump=98k, Engage fish 7,730' set down 15k, PUW= 220k, SOW75k, fish is on, work pipe up and down to wear down seals. Bring, pumping 2 bpm/310 psi - 2 bpm/630 psi. F/7,693' T/7,725' PUW=155k-200k, SOW=98k-68k, final circulating pressure 5 bpm/950 psi/loss rate 4 bph. 7,730.0 7,693.0 5/30/2024 21:15 5/31/2024 00:00 2.75 COMPZN, RPCOMP TRIP P Pump out of hole, displacing pipe displacement 7,693.0 6,095.0 5/31/2024 00:00 5/31/2024 10:30 10.50 COMPZN, RPCOMP TRIP P Continue TOOH at 50 FPM pumping pipe displacement F/6095' 135K PUW/ observing 5K drag At 2400' PUW 70K At 711' weight fell off from 51K to 43K At surface no fish. 6,095.0 0.0 5/31/2024 10:30 5/31/2024 11:30 1.00 COMPZN, RPCOMP TRIP P Rerun BHA #3 with new grapple. PUW 36K/ SOW 36K 0.0 700.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 4/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/31/2024 11:30 5/31/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig rough neck and draw works 700.0 700.0 5/31/2024 12:00 5/31/2024 16:00 4.00 COMPZN, RPCOMP TRIP P TIH F/700' T/7,730' PUW=165k /SOW 700.0 7,730.0 5/31/2024 16:00 5/31/2024 17:00 1.00 COMPZN, RPCOMP FISH P PUW=160k, SOW=98k, Latch into fish, PUW=165k, SOW=98k 7,730.0 7,730.0 5/31/2024 17:00 5/31/2024 18:30 1.50 COMPZN, RPCOMP CIRC P Circulate BU @ 5 bpm 7,730.0 7,730.0 5/31/2024 18:30 5/31/2024 19:00 0.50 COMPZN, RPCOMP SVRG P Service rig 7,730.0 5/31/2024 19:00 6/1/2024 00:00 5.00 COMPZN, RPCOMP TRIP P TOOH, on elevators @ 50 fpm F/500' 7,730.0 500.0 6/1/2024 00:00 6/1/2024 00:30 0.50 COMPZN, RPCOMP TRIP P Continue TOOH F/500 T/BHA PUW 42K/ 500.0 214.0 6/1/2024 00:30 6/1/2024 02:30 2.00 COMPZN, RPCOMP BHAH P LD BHA #4 (Spear w/packer,1 jt 3.5" tbg, GLM and cut jt=15.10') 214.0 0.0 6/1/2024 02:30 6/1/2024 03:30 1.00 COMPZN, RPCOMP BHAH P Clean and clear the rig floor and install wear ring. 0.0 0.0 6/1/2024 03:30 6/1/2024 05:30 2.00 COMPZN, RPCOMP BHAH P Pull fish out of overshot. MU BHA #5 with new grapple. 0.0 214.0 6/1/2024 05:30 6/1/2024 09:30 4.00 COMPZN, RPCOMP TRIP P TIH, w/fishing BHA #5 with baker overshot Top of fish @ 7,785 PUW 155K/ SOW 101K Set down 10K and PU 183K breakover T/161K Pull 20' 214.0 7,785.0 6/1/2024 09:30 6/1/2024 11:30 2.00 COMPZN, RPCOMP CIRC P Circulate and condition mud 7,785.0 7,785.0 6/1/2024 11:30 6/1/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig draw works and iron rough neck 7,785.0 7,785.0 6/1/2024 12:00 6/1/2024 17:00 5.00 COMPZN, RPCOMP TRIP P Trip out of hole 7,785.0 214.0 6/1/2024 17:00 6/1/2024 20:00 3.00 COMPZN, RPCOMP BHAH P At surface, LD fishing BHA #5, 5 steel blast joints, CMU and cut joint 2.98' Load out Fish 214.0 0.0 6/1/2024 20:00 6/1/2024 20:30 0.50 COMPZN, RPCOMP OTHR P Clean RF 0.0 0.0 6/1/2024 20:30 6/1/2024 21:00 0.50 COMPZN, RPCOMP SVRG P Service RIG 0.0 0.0 6/1/2024 21:00 6/1/2024 21:30 0.50 COMPZN, RPCOMP BHAH P Load, bring tools to RF and check ID's 0.0 0.0 6/1/2024 21:30 6/1/2024 22:00 0.50 COMPZN, RPCOMP BHAH P MU fishing BHA #6 w/Baker Overshot 0.0 214.1 6/1/2024 22:00 6/2/2024 00:00 2.00 COMPZN, RPCOMP TRIP P TIH, with Fishing BHA #6 w/Baker overshot 214.1 4,945.0 6/2/2024 00:00 6/2/2024 02:15 2.25 COMPZN, RPCOMP TRIP P Continue tripping IH, with Fishing BHA #6 w/over shot 4,945.0 7,903.0 6/2/2024 02:15 6/2/2024 02:45 0.50 COMPZN, RPCOMP WASH P Set some weight down, PUH, PUW=155k, SOW=101k, bring pump online 5 bpm/430 psi, rotate down 20 rpm/TQ=5,600 ft/lbs 7,903.0 7,953.0 6/2/2024 02:45 6/2/2024 03:45 1.00 COMPZN, RPCOMP FISH P Latch onto fish, perform 33 jar licks 225k -275k, straight pull 300k-350k 7,953.0 7,953.0 6/2/2024 03:45 6/2/2024 05:30 1.75 COMPZN, RPCOMP CIRC P Rotate off of fish successfully, Circulate BU 8 bpm/1,230 psi 7,953.0 7,953.0 6/2/2024 05:30 6/2/2024 09:00 3.50 COMPZN, RPCOMP TRIP P TOOH F/7,953' T/BHA PUW 165K 7,953.0 214.1 6/2/2024 09:00 6/2/2024 10:00 1.00 COMPZN, RPCOMP BHAH P LD BHA#6 Overshot Retrieved the fish (TBG stub and anchor/seal assy) 214.1 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 5/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/2/2024 10:00 6/2/2024 11:30 1.50 COMPZN, RPCOMP BHAH P PU BHA #7 packer milling assy 0.0 247.0 6/2/2024 11:30 6/2/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service draw works and replace dies in iron roughneck 247.0 247.0 6/2/2024 12:00 6/2/2024 14:45 2.75 COMPZN, RPCOMP TRIP P TIH with BHA #7 Tag fill, rotate and circualate to find top of packer Rot=40 rpm, Rot TQ=8,100, ROTW=118k, Pumping 2 bpm/167 gal/min @ 445 psi 247.0 7,952.0 6/2/2024 14:45 6/2/2024 18:00 3.25 COMPZN, RPCOMP MILL P Mill middle packer F/7952' T/7955' Rot=50 rpm, Rot TQ=9200 ft/lbs, ROTW=120k, pumping 4 bpm/448 psi 7,952.0 7,952.8 6/2/2024 18:00 6/3/2024 00:00 6.00 COMPZN, RPCOMP MILL P Continue to mill middle packer F/7952.8' T/7,954' Rot=40 rpm, Rot TQ=9,300 ft/lbs, ROTW=115k, pumping 4 bpm/448 psi 7,952.8 7,954.0 6/3/2024 00:00 6/3/2024 01:00 1.00 COMPZN, RPCOMP MILL P Continue to mill middle packer F/7954'' T/7,954.2' Rot=45 rpm, Rot TQ=9,100 ft/lbs, ROTW=116k, pumping 2 bpm/199 psi 7,954.0 7,954.2 6/3/2024 01:00 6/3/2024 03:00 2.00 COMPZN, RPCOMP CIRC P Circulate BU/Condition hole 9.5+ppg In/9.5 ppg, pump dry job 17 bbl 10.8 ppg 7,954.2 7,954.2 6/3/2024 03:00 6/3/2024 06:00 3.00 COMPZN, RPCOMP TRIP P TOOH, w/milling BHA #7 7,954.2 247.0 6/3/2024 06:00 6/3/2024 08:00 2.00 COMPZN, RPCOMP BHAH P LD BHA #7 Milling assy Mill is 1/16" under gauge MU BHA #8 spear for packer 247.0 233.0 6/3/2024 08:00 6/3/2024 11:30 3.50 COMPZN, RPCOMP TRIP P TIH with BHA #8 fishing spear for packer. PUW 158K/ SOW 104K 233.0 7,954.0 6/3/2024 11:30 6/3/2024 12:00 0.50 COMPZN, RPCOMP SVRG P Service rough neck and top drive. 7,954.0 7,954.0 6/3/2024 12:00 6/3/2024 14:00 2.00 COMPZN, RPCOMP FISH P Engage fish and attempt to jar free. 50 jars licks at 225K Free pulled 375K several times 7,954.0 7,943.0 6/3/2024 14:00 6/3/2024 16:30 2.50 COMPZN, RPCOMP CIRC P Release from fish, pull T/7943' and pump Hi-Vis sweep at 6 BPM/820 psi Perform derrick inspection and pump dry job. OWFF - static 7,943.0 7,943.0 6/3/2024 16:30 6/3/2024 20:00 3.50 COMPZN, RPCOMP TRIP P TOOH With BHA #8 fishing spear for Packer F/7943' PUW 158K / SOW 104K 7,943.0 233.0 6/3/2024 20:00 6/3/2024 21:30 1.50 COMPZN, RPCOMP BHAH P LD Fishing BHA #8, Baker Spear 233.0 0.0 6/3/2024 21:30 6/3/2024 23:00 1.50 COMPZN, RPCOMP BHAH P MU Milling BHA #9 0.0 232.6 6/3/2024 23:00 6/4/2024 00:00 1.00 COMPZN, RPCOMP TRIP P TIH, w/baker milling assembly BHA #9 burnshoe 232.6 1,217.0 6/4/2024 00:00 6/4/2024 03:00 3.00 COMPZN, RPCOMP TRIP P Continue TIH, w/baker milling assembly BHA #9 burnshoe F/1,217' T/7,915' 1,217.0 7,915.0 6/4/2024 03:00 6/4/2024 03:30 0.50 COMPZN, RPCOMP MILL P Obtain parameters PUW=157k, SOW=123k Rot=40 rpm, ROT TQ=7,800 ft/lbs, ROTW=126k RIH slowly down hole 7,915.0 7,954.0 6/4/2024 03:30 6/4/2024 07:30 4.00 COMPZN, RPCOMP MILL P Mill ahead Rot=40 rpm, ROT TQ=8k ft/lbs, ROTW=132k 7,952' bring pump online 1.5 bpm/62 spm/222 psi 7,954.0 7,956.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 6/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/4/2024 07:30 6/4/2024 10:00 2.50 COMPZN, RPCOMP CIRC P Pump Hi Vis sweep at 7 BPM/294 GPM/1030PSI Saw packer gas at 4600 strokes, MW out 8.6 ppg, MW in 9.5 ppg. Circulate out packer gas. 7,956.0 7,947.0 6/4/2024 10:00 6/4/2024 10:30 0.50 COMPZN, RPCOMP OWFF P OWFF static, Pump dry job. 7,947.0 7,947.0 6/4/2024 10:30 6/4/2024 15:00 4.50 COMPZN, RPCOMP TRIP P TOOH F/7947' T/250' PUW 165K 7,947.0 250.0 6/4/2024 15:00 6/4/2024 16:00 1.00 COMPZN, RPCOMP BHAH P LD BHA clean magnets and boot baskets. 250.0 0.0 6/4/2024 16:00 6/4/2024 16:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear the rig floor. function test BOP. 0.0 0.0 6/4/2024 16:30 6/4/2024 17:30 1.00 COMPZN, RPCOMP BHAH P P/U M/U BHA #10 Per Baker fishing rep to 237' 0.0 237.0 6/4/2024 17:30 6/4/2024 20:30 3.00 COMPZN, RPCOMP TRIP P RIH F/ 237' to 7,331'. PUWT SOWT 237.0 7,331.0 6/4/2024 20:30 6/4/2024 22:30 2.00 COMPZN, RPCOMP SLPC P Cut and slip drilling line. 7,331.0 7,331.0 6/4/2024 22:30 6/4/2024 23:00 0.50 COMPZN, RPCOMP SVRG P Rig service adjust draworks equalizer bar. Grease crown, and inspect upper section of derrick. 7,331.0 7,731.0 6/4/2024 23:00 6/4/2024 23:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 7731' to 7936' Obtain parameters. 100K SOWT 170K PUWT Pump @ 1.5 BBL/Min @ 350 PSI. 7,731.0 7,936.0 6/4/2024 23:30 6/5/2024 00:00 0.50 COMPZN, RPCOMP FISH P Attempt to engaguge fish, stack out on top of fish on first attempt. P/U to break over and attempt 2nd time. Observed pressure increase from 350 PSI to 660 PSI. Set down 10K on NO-GO. P/U and observe Break over @ 195K. Pressure increase remained. 7,936.0 7,956.0 6/5/2024 00:00 6/5/2024 02:30 2.50 COMPZN, RPCOMP CIRC P CBU. Pump 4 BBL/Min @ 3000 PSI. 7,956.0 7,956.0 6/5/2024 02:30 6/5/2024 03:00 0.50 COMPZN, RPCOMP OWFF P Flow check well 15 min. 7,956.0 7,956.0 6/5/2024 03:00 6/5/2024 03:00 COMPZN, RPCOMP TRIP P POOH F/ 7956 to 7880 pulled 20K over at 7880'. Attempt to work through. 7,956.0 7,880.0 6/5/2024 03:00 6/5/2024 04:00 1.00 COMPZN, RPCOMP TRIP P Kelly up to string, and bring pumps up to 4 BBL/min @ 2880 PSI. work though tight tight spots from 7880' to 7,721'. Over pull form 20 K to 80 K. PUWT: 170K SOWT: 160K Pumping 4 BBL/Min @ 2880 PSI. 7,880.0 7,721.0 6/5/2024 04:00 6/5/2024 04:30 0.50 COMPZN, RPCOMP CIRC P Line up and pump down string at 1.5 BBL/ Min @ 600 PSI to verify fish still engaged. B/D top drive. 7,721.0 7,721.0 6/5/2024 04:30 6/5/2024 10:30 6.00 COMPZN, RPCOMP TRIP P TOOH F/7721 T/237' UWT 140K/DWT90K 7,721.0 237.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 7/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/5/2024 10:30 6/5/2024 12:00 1.50 COMPZN, RPCOMP BHAH P LD BHA #10 Spear LD milled up packer, GLM and blast joints Cut Jt 14.3' 237.0 0.0 6/5/2024 12:00 6/5/2024 13:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor 0.0 0.0 6/5/2024 13:00 6/5/2024 14:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #11 overshot 0.0 234.0 6/5/2024 14:00 6/5/2024 17:00 3.00 COMPZN, RPCOMP TRIP P RIH F/ 234' to 7995'. 234.0 7,995.0 6/5/2024 17:00 6/5/2024 17:30 0.50 COMPZN, RPCOMP FISH P Obtain parameters prior to engaging fish. PUWT: 170 K SOWT: 100 K ROTWT: 125 K @ 10 RPM. Pumping @ 2BBL/Min @ 280 PSI. Shut down rotary, wash down over stump @ 8036' set down 10k to engage stump. P/U to 190K. Engage rotary at 10 RPM, set down 10K again. Shut down rotary, and P/U to 225K observe seals come out of seal bore. 7,995.0 8,036.0 6/5/2024 17:30 6/5/2024 19:30 2.00 COMPZN, RPCOMP CIRC P P/U to 8015'. Increase flow rate to 6 BBL/Min @ 710 PSI. Circulate around High vis sweep. Suspected packer rubber seen at shakers. 8,036.0 8,015.0 6/5/2024 19:30 6/5/2024 20:00 0.50 COMPZN, RPCOMP OWFF P Flow check well 15 min: Static. Pump dry job. 8,015.0 8,015.0 6/5/2024 20:00 6/6/2024 00:00 4.00 COMPZN, RPCOMP TRIP P POOH F/ 8015' to 761'. 8,015.0 761.0 6/6/2024 00:00 6/6/2024 01:00 1.00 COMPZN, RPCOMP TRIP P POOH racking back drill pipe from 761' 761.0 281.0 6/6/2024 01:00 6/6/2024 02:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 11, and 47' of fish. 281.0 0.0 6/6/2024 02:00 6/6/2024 02:30 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment, clean and clear rig floor. 0.0 0.0 6/6/2024 02:30 6/6/2024 04:30 2.00 COMPZN, RPCOMP BHAH P P/U Clean out BHA, and RIH (BHA # 12). 0.0 262.0 6/6/2024 04:30 6/6/2024 09:00 4.50 COMPZN, RPCOMP TRIP P RIH W/ BHA # 12 F/ 262' to 7698' UWT 160K/ DWT 97K 262.0 7,698.0 6/6/2024 09:00 6/6/2024 11:30 2.50 COMPZN, RPCOMP WASH P Wash and ream F/7698' T/8070' 50 RPM / RTW 121 at 8BPM at 1280 psi / TQ 7.8 Slow pump rate 2 BPM at 220 psi Wash the seal bore and tag no-go at 8083' 7,698.0 8,083.0 6/6/2024 11:30 6/6/2024 14:30 3.00 COMPZN, RPCOMP CIRC P PU to 8074' Circulate 30 BBL Hi-Vis Sweep at 7 BPM at 1100 psi 8,083.0 8,074.0 6/6/2024 14:30 6/6/2024 18:00 3.50 COMPZN, RPCOMP TRIP P POOH racking back drill pipe F/8074' T262 8,074.0 262.0 6/6/2024 18:00 6/6/2024 20:00 2.00 COMPZN, RPCOMP BHAH P L/D BHA #12. Recovered 38 LBS of metal and debris from magnets, and Junk baskets. Wear observed on bottom of scraper pads, and on string mill. 262.0 0.0 6/6/2024 20:00 6/6/2024 20:30 0.50 COMPZN, RPCOMP CLEN P Remove BHA components from the rig floor. Clean rig floor, and prepare for next BHA. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 8/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/6/2024 20:30 6/6/2024 21:00 0.50 COMPZN, RPCOMP BHAH P P/U and M/U BHA #13 (G plug test packer). 0.0 58.8 6/6/2024 21:00 6/6/2024 23:30 2.50 COMPZN, RPCOMP TRIP P RIH F/ 58.8' to 3554' on drill pipe out of the derrick. 58.8 3,554.0 6/6/2024 23:30 6/7/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease crown, top dive, and other rig floor/ Derrick equipment. 3,554.0 3,554.0 6/7/2024 00:00 6/7/2024 02:00 2.00 COMPZN, RPCOMP TRIP P Continue to RIH W/ BHA # 13 (RBP) F/ 3554' - 8003'. 3,554.0 8,003.0 6/7/2024 02:00 6/7/2024 02:30 0.50 COMPZN, RPCOMP CIRC P Obtain parameters. Circulate 1.5 X string volume. PUWT: 165 K SOWT: 95 K 200 GPM @ 670 PSI. 8,003.0 8,030.0 6/7/2024 02:30 6/7/2024 03:00 0.50 COMPZN, RPCOMP MPSP P P/U single of Drill pipe. Rotate string 5X to the right, and slack off. Set down 10K, and P/U 35K To verify set. 8,003.0 8,030.0 6/7/2024 03:00 6/7/2024 04:00 1.00 COMPZN, RPCOMP RURD P P/U 5' pup joint and rig up test equipment. 8,030.0 8,030.0 6/7/2024 04:00 6/7/2024 04:30 0.50 COMPZN, RPCOMP PRTS P P/U Pull slips and set down 30K to open valve on RBP. Line up and attempt to test lower completion packer at 8030'. Leak observed up annulus. 8,030.0 8,030.0 6/7/2024 04:30 6/7/2024 08:30 4.00 COMPZN, RPCOMP MPSP P R/D surface test equipment, release plug. P/U single and try to RIH 30' deeper. Unable to get deeper tried several times. Pull up hole to 7730' (planned upper production packer depth) and test 9-5/8" casing and test packer to 2500 psi for 15 minutes. Good test. Retreive packer. Called town and make discision to POOH, LD test packer and PU milling BHA to mill up last DB packer at 8033'. 8,030.0 7,730.0 6/7/2024 08:30 6/7/2024 14:00 5.50 COMPZN, RPCOMP TRIP P TOOH with test packer BHA. At surface No Test Packer. 7,730.0 0.0 6/7/2024 14:00 6/7/2024 14:30 0.50 COMPZN, RPCOMP CLEN P Clean rig floor 0.0 6/7/2024 14:30 6/7/2024 15:00 0.50 COMPZN, RPCOMP SVRG P Service rig grease crown, Blocks, Top drive, Wash pipe, Drawworks and adjust brake. 0.0 0.0 6/7/2024 15:00 6/7/2024 18:30 3.50 COMPZN, RPCOMP TRIP T TIH to retrieve test packer. 0.0 7,700.0 6/7/2024 18:30 6/7/2024 20:30 2.00 COMPZN, RPCOMP MPSP T P/U Single joint of DP. KU to the string. Obtain parameters. S/O and engage plug @ 7714' (16' high from where orginally thought). Pump @ 1 BBL/ Min @ 300 PSI. Work right hand torque down to the plug at a max 10K torque. working between PUWT 157K and 200K HKLD. 7,700.0 7,714.0 6/7/2024 20:30 6/7/2024 22:00 1.50 COMPZN, RPCOMP CIRC T Suspected debris on top of plug preventing full release, and relaxing of RBP. Bring flow rate up to 8 BBL Min, and Circulate around High vis sweep 2X. First sweep brought back sand and other debris. Second sweep did not bring increase in debris back to surface. 7,714.0 7,714.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 9/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/7/2024 22:00 6/7/2024 22:30 0.50 COMPZN, RPCOMP MPSP T P/U 30' and observe string moving free with extra ~ 8 K drag, apply right hand rotation while picking up to ensure plug dies, and element are disengaged. Stop for 15 min, and allow element to relax. S/O to 7712' (2' past set depth) to verify plug still on running tool, and released. 7,744.0 7,714.0 6/7/2024 22:30 6/7/2024 22:45 0.25 COMPZN, RPCOMP OWFF P Flow check well: Static. Blow down top drive. 7,714.0 7,714.0 6/7/2024 22:45 6/8/2024 00:00 1.25 COMPZN, RPCOMP TRIP P POOH F/ 7714' to 5500' 7,714.0 5,500.0 6/8/2024 00:00 6/8/2024 04:00 4.00 COMPZN, RPCOMP TRIP P POOH F/ 5500' to surface w/ RBP. No obvious signs of damage to RBP, some sand found on top of die blocks of RBP. 5,500.0 0.0 6/8/2024 04:00 6/8/2024 04:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 13 (RBP). 0.0 0.0 6/8/2024 04:30 6/8/2024 05:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor prepare BHA # 14 components, and mobilize to rig floor, and pipe shed. 0.0 0.0 6/8/2024 05:00 6/8/2024 05:30 0.50 COMPZN, RPCOMP SVRG P Rig service, grease/ service rig floor equipment, and draworks clutch. 0.0 0.0 6/8/2024 05:30 6/8/2024 07:00 1.50 COMPZN, RPCOMP BHAH P MU BHA #14 Burn over shoe for packer milling. 0.0 263.0 6/8/2024 07:00 6/8/2024 07:30 0.50 COMPZN, RPCOMP SVRG P Change out air boot on riser 263.0 263.0 6/8/2024 07:30 6/8/2024 11:00 3.50 COMPZN, RPCOMP TRIP P TIH With packer milling BHA #14 T/8060 UWT 165K/ DWT 100K 263.0 8,013.0 6/8/2024 11:00 6/8/2024 21:30 10.50 COMPZN, RPCOMP MILL P Circ 4BPM/ 520 psi/ ROT 40 RPM/ TQ off bottom 8K/ RTW 126K RIH and tag @ 8077' and start milling TQ on bottom 8.9/ WOB 1 .5K MIll F/8076' T/ 8080' 40RPM / 2 BPM / 82 GPM / TQ ON 8- 9K / WOB 1.5K - 3.5K 8,060.0 8,080.0 6/8/2024 21:30 6/8/2024 22:30 1.00 COMPZN, RPCOMP CIRC P Circulate around high vis sweep. Packer rubber, and debris back to surface while pumping. Circ @ 380 GPM @ 1550 PSI. 8,076.0 8,076.0 6/8/2024 22:30 6/8/2024 23:15 0.75 COMPZN, RPCOMP MILL P Come back down and dry mill on packer. Suspected packer spinning. 10-40 K WOB 40 RPM @ 7-10 K TQ 8,076.0 8,080.0 6/8/2024 23:15 6/8/2024 23:45 0.50 COMPZN, RPCOMP CIRC P Circulate bottoms up @ 380 GPM @ 1550 PSI. No increase in cuttings/ Debris on bottoms up. 8,080.0 8,076.0 6/8/2024 23:45 6/9/2024 00:00 0.25 COMPZN, RPCOMP OWFF P Flow check well 15 min: Static. 8,076.0 8,076.0 6/9/2024 00:00 6/9/2024 04:00 4.00 COMPZN, RPCOMP TRIP P POOH F/ 8076' to 250' UWT 175K/ DWT 100K 8,076.0 250.0 6/9/2024 04:00 6/9/2024 05:00 1.00 COMPZN, RPCOMP BHAH P POOH and L/D BHA #14. Only wear on the outside and nose of burn over shoe. No wear on inside of burn over shoe. 250.0 0.0 6/9/2024 05:00 6/9/2024 05:30 0.50 COMPZN, RPCOMP BHAH P PU BHA #15 junk mill 0.0 246.0 6/9/2024 05:30 6/9/2024 06:00 0.50 COMPZN, RPCOMP SVRG P Service rig grease top drive. 246.0 246.0 6/9/2024 06:00 6/9/2024 09:00 3.00 COMPZN, RPCOMP TRIP P TIH with BHA #15 junk mill F/246 T8009' UWT 160K/ DWT 100K 246.0 8,077.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 10/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/9/2024 09:00 6/9/2024 21:00 12.00 COMPZN, RPCOMP MILL P Obtain parameters, RIH tag at 8077.75' Start milling per Baker fishing rep. 30 RPM, RTW 129K, pumping 1.5 BPM at 270 psi, TQ off bottom 7K TQ ON 9K, WOB 1 to 5K. Little progress made after 8077.8'. Torque spikes ,and over pulls encountered around 8077'. Suspected junk in the hole. 8,077.0 8,078.0 6/9/2024 21:00 6/9/2024 22:30 1.50 COMPZN, RPCOMP MILL P Attempt to work string and remove junk from top of packer. Set down weight, and work string to "pin" junk in place and attempt to mill, or move junk away from the bottom of the mill. Over pull of ~ 40K encountered multiple times at 8077, and torque stalls from 8077' to 8078' up to 12K torque when rotary stalled. 8,078.0 8,077.0 6/9/2024 22:30 6/10/2024 00:00 1.50 COMPZN, RPCOMP CIRC P Pump 30 BBL HiVis sweep. attempt to move junk into junk basket, or away from mill. Pump at max rate, Rotate and work BHA as Sweep comes out of mill, and moves around BHA. Packer gas @ ~ 4670 strokes. 380 GPM @ 1560 PSI. 8,077.0 8,078.0 6/10/2024 00:00 6/10/2024 01:30 1.50 COMPZN, RPCOMP CIRC P Circulate out packer gas, and sweep. 8,078.0 8,078.0 6/10/2024 01:30 6/10/2024 03:30 2.00 COMPZN, RPCOMP CIRC P CBU @ 9BPM @ 1550 PSI. 8,078.0 8,078.0 6/10/2024 03:30 6/10/2024 04:00 0.50 COMPZN, RPCOMP OWFF P Flow check 15 min: Blow down top drive. 8,078.0 8,078.0 6/10/2024 04:00 6/10/2024 04:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 8078' to 7815 8,078.0 7,815.0 6/10/2024 04:30 6/10/2024 05:30 1.00 COMPZN, RPCOMP SLPC P Cut and slip drilling line. Cut off 94' 7,815.0 7,815.0 6/10/2024 05:30 6/10/2024 10:30 5.00 COMPZN, RPCOMP TRIP P TOOH with packer milling BHA #15. UWT 160K/ DWT 100K 7,815.0 246.0 6/10/2024 10:30 6/10/2024 11:00 0.50 COMPZN, RPCOMP SFTY P Nabors safety meeting due to several accident in L48. 246.0 246.0 6/10/2024 11:00 6/10/2024 12:00 1.00 COMPZN, RPCOMP BHAH P LD BHA #15 246.0 0.0 6/10/2024 12:00 6/10/2024 12:30 0.50 COMPZN, RPCOMP CLEN P Clean rig floor 0.0 0.0 6/10/2024 12:30 6/10/2024 14:00 1.50 COMPZN, RPCOMP BHAH P PU BHA #16 burn over shoe. 0.0 249.0 6/10/2024 14:00 6/10/2024 17:00 3.00 COMPZN, RPCOMP TRIP P Trip in hole with BHA #16 249.0 8,077.0 6/10/2024 17:00 6/10/2024 20:30 3.50 COMPZN, RPCOMP MILL P MIlling on packer F/8077 T/8183' UWT 165 / DWT 100 / RWT 125 WOB 30 RPM, 9-10 TQ, 3 BPM at 400 psi 8,077.0 8,183.0 6/10/2024 20:30 6/10/2024 22:00 1.50 COMPZN, RPCOMP CIRC P Circulate around High vis sweep at 8154 STK 8 BPM @ 1550 PSI. No increase in debris noticed. 8,183.0 8,183.0 6/10/2024 22:00 6/10/2024 23:30 1.50 COMPZN, RPCOMP MILL P Attempt to work packer further down hole. Set down up to 60K (string weight) multiple times, no movement. 8,183.0 8,183.0 6/10/2024 23:30 6/11/2024 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF 15 min: Static. Pump slug. 8,183.0 8,183.0 6/11/2024 00:00 6/11/2024 03:30 3.50 COMPZN, RPCOMP TRIP P POOH F/8130' to 8,183.0 249.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 11/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/11/2024 03:30 6/11/2024 04:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA. Packer rubber wedged ~1' inside of burning shoe. 52 LBS of metal on magnets, 8 lbs of debris in boot baskets. Good indications of sucessful milling run. 249.0 0.0 6/11/2024 04:30 6/11/2024 06:00 1.50 COMPZN, RPCOMP BHAH P P/U and M/U BHA # 17 (spear). 0.0 265.0 6/11/2024 06:00 6/11/2024 08:00 2.00 COMPZN, RPCOMP TRIP P RIH w/ BHA # 17 (Spear run) 265.0 8,130.0 6/11/2024 08:00 6/11/2024 08:30 0.50 COMPZN, RPCOMP FISH P Obtain Parameters. S/O to 8182' See 5- 6K Drag from Grapple from 8184 to 8187'. Also observe 50 PSI SPP increase. NO-GO out at 8187'. P/U to 250 K (75K over) S/O to 100K to warm up hydraulic fluid in jars. P/U to 250K fire jars weight fall off to 175K. P/U 15' observe 5-10K extra drag. P/U to 8118' PUWT: 175 K SOWT: 100 K 415 PSI @ 60 GPM 8,182.0 8,118.0 6/11/2024 08:30 6/11/2024 11:30 3.00 COMPZN, RPCOMP CIRC P CBU @ 160 GPM @ 1500 PSI. 8,118.0 8,118.0 6/11/2024 11:30 6/11/2024 15:15 3.75 COMPZN, RPCOMP TRIP P POOH F/ 8118' to 265' . 8,118.0 265.0 6/11/2024 15:15 6/11/2024 16:15 1.00 COMPZN, RPCOMP BHAH P L/D BHA & no fish. Spear grapple broken. 265.0 0.0 6/11/2024 16:15 6/11/2024 19:45 3.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. Pull wear ring . RU to test BOP's. Johnnie wack the stack. Drain stack. Set test plug fil the stack with water. 0.0 0.0 6/11/2024 19:45 6/12/2024 00:00 4.25 COMPZN, RPCOMP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 12/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2024 00:00 6/12/2024 02:00 2.00 COMPZN, RPCOMP BOPE P Finish testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = 127 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBRs=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. . Test Witness Waived by AOGCC rep Adam Earl. 0.0 0.0 6/12/2024 02:00 6/12/2024 03:00 1.00 COMPZN, RPCOMP RURD P Blow down lines, R/D BOP test equipment. Pull test plug. 0.0 0.0 6/12/2024 03:00 6/12/2024 03:30 0.50 COMPZN, RPCOMP SVRG P Rig service 0.0 0.0 6/12/2024 03:30 6/12/2024 04:00 0.50 COMPZN, RPCOMP OTHR P Set wear ring and RILDS. 0.0 0.0 6/12/2024 04:00 6/12/2024 04:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 18 (Spear run) Per Baker fishing rep. 0.0 266.0 6/12/2024 04:30 6/12/2024 07:30 3.00 COMPZN, RPCOMP TRIP P RIH W/ BHA # 18 F/ 266' to 8186' PUW=170K SOW=100K 266.0 8,186.0 6/12/2024 07:30 6/12/2024 08:45 1.25 COMPZN, RPCOMP FISH P Spear packer washed down to packer at 40 SPM at 800 PSI. speared packer after 10 attempts. trapped 1400 PSI in DP spear engaged. Pulled 1 jar hit 80 over. Straight pulled to 280K 110 K over string, packer started moving. 8,186.0 8,186.0 6/12/2024 08:45 6/12/2024 09:45 1.00 COMPZN, RPCOMP TRIP P Started TOOH F/8186' pulling heavy at every casing collar PU wt to 180K weight breaks back. PUH to 7650' Dropped opening dart for circ sub. presssured up to 350 PSI. opend circ sub and established circulation at 1 BPM 500 PSI. 8,186.0 7,646.0 6/12/2024 09:45 6/12/2024 11:30 1.75 COMPZN, RPCOMP CIRC P Circulate BUS at 9 BPM at 1800 PSI. 7,646.0 7,646.0 6/12/2024 11:30 6/12/2024 18:30 7.00 COMPZN, RPCOMP TRIP P TOOH F/7646' PUW=170K pulling heavy at every collar. 7,646.0 285.0 6/12/2024 18:30 6/12/2024 20:30 2.00 COMPZN, RPCOMP BHAH P POOH, L/D BHA. L/D fish. Recovered remainder of packer, 2 pup joints, XN nipple, and shear out sub. Tail pipe above XN nipple was packed off with parafin and other debris. Recovered 6 pieces of packer slip die on packer. 285.0 0.0 6/12/2024 20:30 6/12/2024 21:00 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment. Perform derrick inspection, and inspect drill line. 0.0 0.0 6/12/2024 21:00 6/12/2024 22:30 1.50 COMPZN, RPCOMP BHAH P P/U BHA # 19. (clean out run with junk mill). 8K Below jars. 0.0 263.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 13/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2024 22:30 6/13/2024 00:00 1.50 COMPZN, RPCOMP TRIP P RIH w/BHA # 19. F/ 263' to 3292' PUWT: 55 K SOWT: 55 K 263.0 3,292.0 6/13/2024 00:00 6/13/2024 01:00 1.00 COMPZN, RPCOMP TRIP P Continue to RIH F/ 3292' to 4252' 105 K PUWT 75 K SOWT 3,292.0 4,252.0 6/13/2024 01:00 6/13/2024 01:30 0.50 COMPZN, RPCOMP TRIP P At 4252 encounter obstruction. Set down 20K 2X. P/U and kelly up to top drive. Start rotary @ 10 RPM @ 3.5K TQ. Slack off and set down 10K @ 4252' stall rotary @ 6K. P/U full stand and S/O to 4289', no obstrution encountered. Kill rotary and continue to S/O to 4326', no obstruction encountered. P/U full stand and drift back through 4252, and continue to kelly down. No obstruction encountered. 4,252.0 4,326.0 6/13/2024 01:30 6/13/2024 02:45 1.25 COMPZN, RPCOMP TRIP P Continue to RIH F/ 4326' to 7428' 170K PUWT 95K SOWT 4,326.0 7,428.0 6/13/2024 02:45 6/13/2024 03:15 0.50 COMPZN, RPCOMP TRIP P @ 7428' encountered obstruction. Set down 20K. P/U to neutral weight turn on rotary to 10 RPM @ 7.5K TQ. S/O w/ rotary to 7484'. Observe 5-10K bobble on weight indicator. Turn off rotary, and P/U to 7424. S/O and drift through to bottom of stand. 7,428.0 7,484.0 6/13/2024 03:15 6/13/2024 05:30 2.25 COMPZN, RPCOMP REAM P Continue to RIH, scrape intervals from 7700-7800', 7900-8000', 8030' to 8100'. 20 RPM @ 7-8 K TQ Pumping @ 220 GPM @ 700 PSI ROTWT: 125 K 7,484.0 8,178.0 6/13/2024 05:30 6/13/2024 07:45 2.25 COMPZN, RPCOMP CIRC P Circulate SxS till 9.5 in and out at 9 BPM 1600 PSI. 8,178.0 8,178.0 6/13/2024 07:45 6/13/2024 09:00 1.25 COMPZN, RPCOMP REAM P Establish milling/reaming parameters PUW= 170K SOW= 100K ROT at 40 RPM, ROT WT= 125 Free Tq= 7.5K PR=9 BPM at 1900 PSI Mill ream F/8178 T/8306' Erratic torque to 14K WOB=0-5K Work through bad casingF/8213' T/8306' Over pulls seen at 8213', 8224' 8306' PUW=225K. 8,178.0 8,306.0 6/13/2024 09:00 6/13/2024 11:15 2.25 COMPZN, RPCOMP CIRC P Circulate SxS pump 15 BBL high vis sweep condition well 9.5# in and out 9 BPM at 1800 PSI. Reciprocate DP while circulating. 8,306.0 8,306.0 6/13/2024 11:15 6/13/2024 11:30 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 8,306.0 8,306.0 6/13/2024 11:30 6/13/2024 14:45 3.25 COMPZN, RPCOMP TRIP P TOOH W BHA #19 F/8306 T/ 8,306.0 263.1 6/13/2024 14:45 6/13/2024 15:45 1.00 COMPZN, RPCOMP BHAH P LD BHA #19 F/263.11 T/surface. 263.1 0.0 6/13/2024 15:45 6/13/2024 16:45 1.00 COMPZN, RPCOMP BHAH P MU BHA #20 Yellowjacket AS-1 RBP. 0.0 18.9 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 14/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/13/2024 16:45 6/14/2024 00:00 7.25 COMPZN, RPCOMP TRIP P RIH F/ 18.9' to 7700' with Yellowjacket AS-1 RBP. Encountered possible junk @ 1723', 4256', 4656', 4692' PUWT: 140 K SOWT: 90 K 18.9 6,739.0 6/14/2024 00:00 6/14/2024 00:30 0.50 COMPZN, RPCOMP TRIP P Cont to RIH W/ RBP F/ 6739'-7689 6,739.0 7,689.0 6/14/2024 00:30 6/14/2024 02:30 2.00 COMPZN, RPCOMP MPSP P Set RBP @ 7747' 7,689.0 7,747.0 6/14/2024 02:30 6/14/2024 04:00 1.50 COMPZN, RPCOMP RURD P R/U test equipment. Close UPR, and purge lines. 7,747.0 7,680.0 6/14/2024 04:00 6/14/2024 05:00 1.00 COMPZN, RPCOMP PRTS P Test RBP to 2500 PSI 30 min: 7,680.0 7,680.0 6/14/2024 05:00 6/14/2024 05:30 0.50 COMPZN, RPCOMP RURD P RD testing equipment 7,680.0 7,680.0 6/14/2024 05:30 6/14/2024 07:30 2.00 COMPZN, RPCOMP TRIP P TOOH F/7687' T/3986' PUW=90K SOW=60K 7,687.0 3,986.0 6/14/2024 07:30 6/14/2024 07:45 0.25 COMPZN, RPCOMP BHAH P PU Storm packer 3,986.0 3,986.0 6/14/2024 07:45 6/14/2024 08:30 0.75 COMPZN, RPCOMP MPSP P RIH to 96' Set storm packer COE=96' 3,986.0 4,082.0 6/14/2024 08:30 6/14/2024 10:00 1.50 COMPZN, RPCOMP NUND P ND BOP's 4,082.0 4,082.0 6/14/2024 10:00 6/14/2024 12:00 2.00 COMPZN, RPCOMP RURD P RU PESI tensioning device. 4,082.0 4,082.0 6/14/2024 12:00 6/14/2024 17:00 5.00 COMPZN, RPCOMP RURD T BOLDS and prep to Drill out 2 LDS. Increase force to 345K on tensioning tool. 3 LDS siezed back off 4,082.0 4,082.0 6/14/2024 17:00 6/14/2024 19:00 2.00 COMPZN, RPCOMP RURD P All LDS backed off. Started growing casing. Grew casing 3 3/8" inches. 4,082.0 4,082.0 6/14/2024 19:00 6/14/2024 19:30 0.50 COMPZN, RPCOMP RURD P R/D hydratight equipment, and R/U to pull tubing spool. 4,082.0 4,082.0 6/14/2024 19:30 6/14/2024 21:00 1.50 COMPZN, RPCOMP NUND P N/D and Pull tubing spool, and casing pack off. 4,082.0 4,082.0 6/14/2024 21:00 6/14/2024 22:30 1.50 COMPZN, RPCOMP OTHR P Check and change out 7 LDS on casing spool. P/U 9 5/8" spear, and prepare to stretch casing. 4,082.0 4,082.0 6/14/2024 22:30 6/15/2024 00:00 1.50 COMPZN, RPCOMP OTHR P Engage 9 5/8" CSG w/ spear. Work casing up to 400k HKLD. Continue to work CSG between 50K, and 400K HKLD. 4,082.0 4,082.0 6/15/2024 00:00 6/15/2024 01:30 1.50 COMPZN, RPCOMP NUND T Continue to attempt to stretch CSG working up and down at various weights bertween 50K, and 400K. 4,082.0 4,082.0 6/15/2024 01:30 6/15/2024 03:00 1.50 COMPZN, RPCOMP NUND T Disengage spear, and Pull to rig floor. Set pack off on mandrel, and R/U Pesi hydratight equipment. 4,082.0 4,082.0 6/15/2024 03:00 6/15/2024 04:00 1.00 COMPZN, RPCOMP NUND T Attempt to seat mandrel hanger, and pack off. Compress pack off and hanger W/324K on hydratight. achieved 1" of compression. 4,082.0 4,082.0 6/15/2024 04:00 6/15/2024 05:00 1.00 COMPZN, RPCOMP NUND T RD Hydratight and remove packoff from casing hanger. 4,082.0 4,082.0 6/15/2024 05:00 6/15/2024 09:30 4.50 COMPZN, RPCOMP CLEN T Clean rig and cellar while developing plan forward. 4,082.0 4,082.0 6/15/2024 09:30 6/15/2024 12:00 2.50 COMPZN, RPCOMP NUND T NU tubing spool and BOP's install riser and turn buckles. Set test plug. 4,082.0 4,082.0 6/15/2024 12:00 6/15/2024 12:30 0.50 COMPZN, RPCOMP BOPE T Test break on BOP to 250/2500 PSI. for 5 minutes 4,082.0 4,082.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 15/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/15/2024 12:30 6/15/2024 13:30 1.00 COMPZN, RPCOMP RURD T RD from testing RU to pull storm packer drain stack pull test plug set wear ring. 4,082.0 4,082.0 6/15/2024 13:30 6/15/2024 14:30 1.00 COMPZN, RPCOMP MPSP T RIH to to of storm packer at 83' equalize storm valve and release packer. allow element to relax for 30 minutes. pull sotrm packer to the floor. LD storm packer. 4,082.0 4,082.0 6/15/2024 14:30 6/15/2024 15:30 1.00 COMPZN, RPCOMP BHAH T MU yellowjacket storm packer to string. 4,082.0 4,082.0 6/15/2024 15:30 6/15/2024 16:30 1.00 COMPZN, RPCOMP TRIP T RIH with storm packer to 504'. 4,082.0 4,082.0 6/15/2024 16:30 6/15/2024 18:00 1.50 COMPZN, RPCOMP MPSP T Set storm packer @ 501' (top of storm packer is 477') , and dump 42 sacks of sand. 4,082.0 4,082.0 6/15/2024 18:00 6/15/2024 18:30 0.50 COMPZN, RPCOMP RURD T R/D Sand hopper, POOH stand of drill pipe. Clean and clear rig floor. 4,082.0 4,082.0 6/15/2024 18:30 6/15/2024 20:30 2.00 COMPZN, RPCOMP ELNE T Spot in and R/U AK eline logging unit. Hang sheaves. Bring up and M/U CBL, and CCL tools on the rig floor and calibrate. 4,082.0 4,082.0 6/15/2024 20:30 6/15/2024 21:30 1.00 COMPZN, RPCOMP ELOG T AK E line RIH to 466'. Perform CCL and CBL logs from 466' to surface. CMNT/ Casing pack off at ~ 250'. 4,082.0 4,082.0 6/15/2024 21:30 6/15/2024 22:30 1.00 COMPZN, RPCOMP ELNE T R/D AK eline equipment on the rig floor. Stage equipment on the rig floor. 4,082.0 4,082.0 6/15/2024 22:30 6/16/2024 00:00 1.50 COMPZN, RPCOMP RURD T C/O Saver sub and handling equipment to use 4 1/2" IF 5" DP. 4,082.0 4,082.0 6/16/2024 00:00 6/16/2024 01:00 1.00 COMPZN, RPCOMP RURD T Continue to C/O Handling equipment. Change out dies on grabber on top drive. 4,082.0 4,082.0 6/16/2024 01:00 6/16/2024 01:30 0.50 COMPZN, RPCOMP RURD T M/U Running tool, and pull wear bushing. 4,082.0 4,082.0 6/16/2024 01:30 6/16/2024 04:00 2.50 COMPZN, RPCOMP CPBO T Attempt to trap torque in string for string shot. While increasing torque slowly to 12 K torque dropped off and RPM increased. Release spear and pull to surface. Broken grapple. all of grapple recovered. 4,082.0 4,082.0 6/16/2024 04:00 6/16/2024 06:00 2.00 COMPZN, RPCOMP BHAH T Break down spear, and remove grapple. Check all connections on the spear. 4,082.0 4,082.0 6/16/2024 06:00 6/16/2024 07:00 1.00 COMPZN, RPCOMP CPBO T Reset spear, PU 55K 25K over blocks. 4,082.0 4,082.0 6/16/2024 07:00 6/16/2024 11:00 4.00 COMPZN, RPCOMP ELNE T RU E-Line RIH with 2 wraps 80 gr. shot. Place shot across collar at 150 CCL depth 133' fire shot not result. POOH W/Eline redress shot rod with 2 wraps 80 gr. MU and RIH W/E-Line to 133 CCL depth shot across collar at 150" fire shot. POOH W/Eline redress shot rod with 3 wraps 80 gr. MU and RIH W/E-Line to 133 CCL depth shot across collar at 150" fire shot. POOH W/Eline redress shot rod with 3 wraps 80 gr. MU and RIH W/E-Line to 133 CCL depth shot across collar at 150" fire shot. 17K torque before shot,16.6K after shot. Shot rod missing. Rack back E-line. 4,082.0 4,082.0 6/16/2024 11:00 6/16/2024 13:00 2.00 COMPZN, RPCOMP BHAH T Pull Spear and LD. PU Magnet BHA to fish 4,082.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 16/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/16/2024 13:00 6/16/2024 14:30 1.50 COMPZN, RPCOMP TRIP T TIH W/ Magnet BHA F/ 15.89' T/478' Top of storm packer TOOH W/Magnet to surface no shot rod recovered. 6/16/2024 14:30 6/16/2024 15:00 0.50 COMPZN, RPCOMP SVRG P Service rig 6/16/2024 15:00 6/16/2024 17:00 2.00 COMPZN, RPCOMP TRIP T RIH F/surface T/ 376' 6/16/2024 17:00 6/16/2024 18:30 1.50 COMPZN, RPCOMP CIRC T Displace well over to 9.5 PPG Brine. 6/16/2024 18:30 6/16/2024 21:00 2.50 COMPZN, RPCOMP OTHR T R/U lines, and KB1000. Dump 42 sacks of sand (50'). R/D lines and KB1000. 6/16/2024 21:00 6/16/2024 23:00 2.00 COMPZN, RPCOMP TRIP T RIH tag top of sand @ 430'. POOH. 6/16/2024 23:00 6/17/2024 00:00 1.00 COMPZN, RPCOMP MPSP T P/U YJOS test packer and RIH to 37''. Rig up and test 6/17/2024 00:00 6/17/2024 00:30 0.50 COMPZN, RPCOMP RURD T Rig up to test CSG, and purge lines. 6/17/2024 00:30 6/17/2024 01:30 1.00 COMPZN, RPCOMP PRTS T Test CSG between 430', & 37' to 1000 PSI for 30 min: GOOD 6/17/2024 01:30 6/17/2024 02:00 0.50 COMPZN, RPCOMP RURD T R/D test equipment. 6/17/2024 02:00 6/17/2024 03:15 1.25 COMPZN, RPCOMP BHAH T Pick up Back CSG cutter, and M/U. 6/17/2024 03:15 6/17/2024 04:00 0.75 COMPZN, RPCOMP CPBO T Locate collar @ 72'. Collar on first full joint @ 60''. Verify calculation, and space out for patch. 6/17/2024 04:00 6/17/2024 04:30 0.50 COMPZN, RPCOMP CPBO T Cut CSG @ 60'. Pump 4.3 BPM @ 250 PSI Rotate 70 RPM @ 525 free TQ. Engaged at 63 RPM @ 1200 tq Torque dropped off Ft/Lbs Tq. fell off passed through cut. 6/17/2024 04:30 6/17/2024 05:00 0.50 COMPZN, RPCOMP BHAH T POOH with BHA #23 LD 6/17/2024 05:00 6/17/2024 06:00 1.00 COMPZN, RPCOMP BHAH T MU BHA#24 9-5/8" Spear spear casing cut joint and LD BHA #24 and cut joint. Casing flaired at cut. 6/17/2024 06:00 6/17/2024 07:30 1.50 COMPZN, RPCOMP BHAH T MU BHA #25 Dress off mill assembly 6/17/2024 07:30 6/17/2024 09:30 2.00 COMPZN, RPCOMP MILL T RIH and work through tight spots at 28' and 32' Dress off 6" from top of 9-5/8" cut at Establish milling parameters Rot 40 RPM PR=2BPM 45 PSI Rot Wt=37K Freee Tq=325 Ft/Lbs Mill off 6" F/60' T60.5" PU back to surface dry drift multiple times to top of cut at 60.5' hole clean. 6/17/2024 09:30 6/17/2024 10:00 0.50 COMPZN, RPCOMP BHAH T LD BHA 6/17/2024 10:00 6/17/2024 11:30 1.50 COMPZN, RPCOMP RURD T Clear floor RU to run 9-5/8" Casing. 6/17/2024 11:30 6/17/2024 12:00 0.50 COMPZN, RPCOMP SVRG T Service top drive. 6/17/2024 12:00 6/17/2024 14:30 2.50 COMPZN, RPCOMP PUTB T RIH with 9-5/8" casing to 60.5' Pull 200K 170K over. 6/17/2024 14:30 6/17/2024 15:00 0.50 COMPZN, RPCOMP RURD T RU to test casing. Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 17/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/17/2024 15:00 6/17/2024 15:45 0.75 COMPZN, RPCOMP PRTS T Pressure test casing patch to 1000 PSI for 30 minutes. 6/17/2024 15:45 6/17/2024 16:00 0.25 COMPZN, RPCOMP RURD T RD testing equipment. 6/17/2024 16:00 6/17/2024 16:45 0.75 COMPZN, RPCOMP NUND T Drain stack remove turn buckles pull riser. Split wellhead to set casing slips. 6/17/2024 16:45 6/17/2024 17:30 0.75 COMPZN, RPCOMP CUTP T Suck out casing. FMC rep make Cut. Pull Casing joint, and L/D 6/17/2024 17:30 6/17/2024 21:30 4.00 COMPZN, RPCOMP WWSP P FMC install 9 5/8" CSG pack off. N/U tubing spool/BOP. 6/17/2024 21:30 6/17/2024 22:30 1.00 COMPZN, RPCOMP WWSP P Test casing pack off to 3000 PSI for 15 min: GOOD TEST. 2 LDS on casing head will not function. 6/17/2024 22:30 6/17/2024 23:30 1.00 COMPZN, RPCOMP NUND P Finish N/U BOP. Rig up and adjust turn buckles. Install riser, and inflate air boots. 6/17/2024 23:30 6/18/2024 00:00 0.50 COMPZN, RPCOMP OTHR P Install wear bushing. 6/18/2024 00:00 6/18/2024 00:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor/ cellar, mobilize BHA components to rig floor. 0.0 0.0 6/18/2024 00:30 6/18/2024 01:15 0.75 COMPZN, RPCOMP BHAH P P/U BHA # 26. 0.0 51.6 6/18/2024 01:15 6/18/2024 01:30 0.25 COMPZN, RPCOMP TRIP P RIH F/ Surfrace to 430'. Tag Sand @ 411' 51.6 411.0 6/18/2024 01:30 6/18/2024 02:30 1.00 COMPZN, RPCOMP CIRC P Clean sand off of storm packer F/ 411' to 425'. @ 430' observe 3K torque spike, unable to make progress, suspected junk due to torque spike and stop of downward movement. Circulate hole clean. 30 RPM @ 0.5 K TQ 460 GPM @ 215 PSI ROTWT: 35K 411.0 425.0 6/18/2024 02:30 6/18/2024 03:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 425' to surface. L/D BHA to pipe shed. 425.0 0.0 6/18/2024 03:00 6/18/2024 03:45 0.75 COMPZN, RPCOMP BHAH P P/U BHA # 27 (RCJB). 0.0 50.0 6/18/2024 03:45 6/18/2024 04:00 0.25 COMPZN, RPCOMP TRIP P RIH W/ RCJB F/ Surface to 428'. 50.0 428.0 6/18/2024 04:00 6/18/2024 04:45 0.75 COMPZN, RPCOMP WASH P Wash Sand F/ 428' to 440' @ 380 GPM @ 1160 PSI. Circulate hole clean. 428.0 440.0 6/18/2024 04:45 6/18/2024 05:30 0.75 COMPZN, RPCOMP TRIP P POOH F/ 440' to surface. 440.0 0.0 6/18/2024 05:30 6/18/2024 06:00 0.50 COMPZN, RPCOMP BHAH P LD BHA RCJB 1/2" HP hose recovered in shoe of junk basket. Shot rod in extension at drive top. 0.0 0.0 6/18/2024 06:00 6/18/2024 06:30 0.50 COMPZN, RPCOMP TRIP P TIH to top of storm packer clean off top of storm packer 428 to 440' 0.0 440.0 6/18/2024 06:30 6/18/2024 07:30 1.00 COMPZN, RPCOMP CIRC P Circulate hole 8 BPM at 175 PSI pump 35 BBL sweep. Chase with 3500 STKS. till clean. 440.0 4,400.0 6/18/2024 07:30 6/18/2024 08:00 0.50 COMPZN, RPCOMP TRIP P TOOH F/top of storm packer at 500'. Lay down wash over shoe. 440.0 440.0 6/18/2024 08:00 6/18/2024 08:15 0.25 COMPZN, RPCOMP BHAH P MU storm packer retrieval tool. 0.0 0.0 6/18/2024 08:15 6/18/2024 08:45 0.50 COMPZN, RPCOMP TRIP P RIH 5 stands. to top of storm packer. 0.0 440.0 6/18/2024 08:45 6/18/2024 10:15 1.50 COMPZN, RPCOMP MPSP P Wash down into storm packer to retrieve. work to get packer free. equalize and release storm packer. 440.0 4,900.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 18/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/18/2024 10:15 6/18/2024 10:45 0.50 COMPZN, RPCOMP TRIP P TOOH W/storm packer to surface. PUW=60K 4,900.0 4,400.0 6/18/2024 10:45 6/18/2024 11:00 0.25 COMPZN, RPCOMP BHAH P LD storm packer. 4,400.0 4,300.0 6/18/2024 11:00 6/18/2024 11:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Clean floor clean under draw works. Service roughneck. 4,300.0 4,300.0 6/18/2024 11:30 6/18/2024 13:00 1.50 COMPZN, RPCOMP SLPC P Slip and cut drill line. 4,300.0 4,300.0 6/18/2024 13:00 6/18/2024 14:00 1.00 COMPZN, RPCOMP TRIP P TIH F/4300' T/7700' PUW= XXK SOW=XXK 4,300.0 7,700.0 6/18/2024 14:00 6/18/2024 14:30 0.50 COMPZN, RPCOMP CIRC P Circulate 300 Vis 20 BBL sweep at 10 BPM 1650 PSI. Circ sweep OOH 7,700.0 7,700.0 6/18/2024 14:30 6/18/2024 15:00 0.50 COMPZN, RPCOMP MPSP P Latch up to RBP at 7700' equalize and release. 7,700.0 7,700.0 6/18/2024 15:00 6/18/2024 15:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 7,700.0 7,700.0 6/18/2024 15:30 6/18/2024 22:00 6.50 COMPZN, RPCOMP TRIP P POOH F/ 7700' to surface. L/D Yellow jacket RBP. 7,700.0 0.0 6/18/2024 22:00 6/18/2024 22:15 0.25 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Start to mobilize GBR casing equipment to rig floor. 0.0 0.0 6/18/2024 22:15 6/18/2024 22:45 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment, grease crown and block sheaves. 0.0 0.0 6/18/2024 22:45 6/18/2024 23:15 0.50 COMPZN, RPCOMP RURD P R/U to run Lower packer and tail pipe. Load completions equipment into the shed, and verify x/o's and other components. PJSM for running upper completion. 0.0 0.0 6/18/2024 23:15 6/19/2024 00:00 0.75 COMPZN, RPCOMP PUTB P P/U and RIH W/ Lower completion packer. 0.0 121.5 6/19/2024 00:00 6/19/2024 05:00 5.00 COMPZN, RPCOMP TRIP P RIH w/ Lower completion packer on DP F/ 121' to 8202' '. 121.5 8,202.0 6/19/2024 05:00 6/19/2024 06:15 1.25 COMPZN, RPCOMP PACK P Space out, and verify packer on depth. Drop 1 7/16" Activation ball. Pressure up to 2000 PSI to set packer. Leave 2000 PSI on running tool, pulled 55K to release off of packer. Attempted to shear setting sleeve pressured up to 3200 PSI. unable to shift sleeve. shut down pump and had 1450 PSI trapped in drill pipe. pressured back up to 3200 PSI unable to shift sleeve established circulation at 40 STKS/Min. at 1800 PSI. 8,202.0 8,202.0 6/19/2024 06:15 6/19/2024 09:00 2.75 COMPZN, RPCOMP TRIP P TOOH F/ 8096', top of packer, to surface PUW=170K. L/D Running tool. 8,096.0 8,056.0 6/19/2024 09:00 6/19/2024 09:30 0.50 COMPZN, RPCOMP BHAH P LD Baker "J" hydraulic setting tool. 10.0 0.0 6/19/2024 09:30 6/19/2024 10:00 0.50 COMPZN, RPCOMP OWFF P OWFF while cleaning rig floor and break down setting tool 0.0 0.0 6/19/2024 10:00 6/19/2024 10:15 0.25 COMPZN, RPCOMP SFTY P PJSM to run test packer CPAI, Nabors, Yellowjacket. 0.0 0.0 6/19/2024 10:15 6/19/2024 11:00 0.75 COMPZN, RPCOMP TRIP P P/U and RIH w/ YJOS test packer from surface to 1200' 0.0 1,200.0 6/19/2024 11:00 6/19/2024 11:15 0.25 COMPZN, RPCOMP SFTY P Kick while tripping drill RD 1,200.0 1,200.0 6/19/2024 11:15 6/19/2024 13:45 2.50 COMPZN, RPCOMP TRIP P TIH F/1200' T/8050' PUW=170K 1,200.0 8,050.0 6/19/2024 13:45 6/19/2024 14:00 0.25 COMPZN, RPCOMP MPSP P Set test packer at 8050' attempt to pressure up on plug pressured up to 1200 PSI appeared good. RU test lines. 8,050.0 8,050.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 19/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/19/2024 14:00 6/19/2024 16:00 2.00 COMPZN, RPCOMP MPSP P Attemtped to pressure up to 2500 PSI. unable to build pressure. PUH to 8040' Pump 1.2 BPM 300 PSI Set plug 2 more times unable to build pressure set plug at 8048' pack off plug 30K over up and slack off 25K on plug 3 times. Pull into tension. PU to 210K 45K over. Pressure up to 2500 PSI 8,050.0 8,050.0 6/19/2024 16:00 6/19/2024 17:00 1.00 COMPZN, RPCOMP PRTS P Pressure test packer at 8096' to 2500 PSI for 15 minutes: Good. Release test packer. 8,050.0 8,050.0 6/19/2024 17:00 6/19/2024 19:30 2.50 COMPZN, RPCOMP CIRC P Displace well over to 9.5 PPG Brine. 231 GPM @ 960 PSI. 8,050.0 8,050.0 6/19/2024 19:30 6/19/2024 20:00 0.50 COMPZN, RPCOMP OWFF P Observe well for flow 30 min: Good. 8,050.0 8,050.0 6/19/2024 20:00 6/19/2024 21:30 1.50 COMPZN, RPCOMP OTHR P Clean troughs, and under shakers, clean trip tank. Load fluid into the pits. 8,050.0 8,050.0 6/19/2024 21:30 6/20/2024 00:00 2.50 COMPZN, RPCOMP TRIP P POOH F/ 8050' to XXXX'. 160K PUWT. 8,050.0 2,921.0 6/20/2024 00:00 6/20/2024 01:30 1.50 COMPZN, RPCOMP TRIP P POOH F/2921' to Surface. L/D YJOS test packer. 2,921.0 0.0 6/20/2024 01:30 6/20/2024 02:00 0.50 COMPZN, RPCOMP SVRG P Service top drive, and other rig floor equipment. 0.0 0.0 6/20/2024 02:00 6/20/2024 03:30 1.50 COMPZN, RPCOMP ELNE P Spot YJOS E-LIne unit, and rig up. P/U Gama, CCL, and 40 arm caliper tools. 0.0 0.0 6/20/2024 03:30 6/20/2024 07:00 3.50 COMPZN, RPCOMP ELOG P YJOS RIH W/ Reed logging tools on E- line. Perform Perf coralation log. Tag top of packer @ 8086' ELMD. Log up. RD E-Line and start processing log data. 0.0 0.0 6/20/2024 07:00 6/20/2024 09:00 2.00 COMPZN, RPCOMP RURD P RU GBR casing Prep to run completion. Verify running order. Change out dies on rough neck. 0.0 0.0 6/20/2024 09:00 6/20/2024 11:00 2.00 COMPZN, RPCOMP WAIT T Wait for log processing for packer set depth. 0.0 0.0 6/20/2024 11:00 6/20/2024 12:00 1.00 COMPZN, RPCOMP RCST P PU lower completion per tally. 0.0 148.0 6/20/2024 12:00 6/20/2024 17:00 5.00 COMPZN, RPCOMP TRIP P TIH with middle completion F/148' T/ 148.0 6/20/2024 17:00 6/20/2024 17:30 0.50 COMPZN, RPCOMP PACK P No go out on top of packer @ 8111' (Seal ASSY). P/U to 8098', and displace 25 BBLS CI brine around packer and tail pipe. (TOP of lower Packer 8100') 8,111.0 8,098.0 6/20/2024 17:30 6/20/2024 19:30 2.00 COMPZN, RPCOMP PACK T Attempt to sting back into packer. Stack out on top of Lower packer @ 8100'. P/U and orient string. Slack off and enter Packer/PBR. Stack out 2' high with 30K (8098'). P/U and attempt to reach space out depth. Pressure up to 300 PSI, and pull out of PBR with seals until pressure dropped 3 times attempting to clean out any junk. 8,098.0 8,109.0 6/20/2024 19:30 6/20/2024 20:45 1.25 COMPZN, RPCOMP PACK T Call town, and discuss plan forward. 8,109.0 8,098.0 6/20/2024 20:45 6/20/2024 22:15 1.50 COMPZN, RPCOMP PACK T Build high vis sweep. Isolate pits, and bring lube concentration in active system to 1%. 8,098.0 8,098.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 20/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/20/2024 22:15 6/21/2024 00:00 1.75 COMPZN, RPCOMP PACK T Circulate around High Vis sweep (200 VIS), and work string attempting to move any junk. Chase sweep with Brine with 1% Lube. Start working pipe after sweep is in the annulus. Starting pressure 500 PSI @ 1 BBL/Min. Final Presswure 500 PSI @ 4 BBL/Min. 8,098.0 8,098.0 6/21/2024 00:00 6/21/2024 00:30 0.50 COMPZN, RPCOMP PACK T Pressure up to 500 PSI, and hold for 5 min to verify seals on seal assy are still good. Increase pressure to 3000 PSI, P/U to 175K (30K over) S/O to 150K, and Bleed pressure to 0. S/O to 70K (40K set down). P/U ot 175K, increase pressure to 3000 PSI, and hold for 3 min. Bleed off to 0 PSI, and slack off to 70K. P/U to 210 K, S/O to 100K. Release runnig tool, and P/U. 8,098.0 7,961.0 6/21/2024 00:30 6/21/2024 03:00 2.50 COMPZN, RPCOMP CIRC P Circulate out high vis sweep, and condition fluid. 160 GPM @ 500 PSI. 7,961.0 7,961.0 6/21/2024 03:00 6/21/2024 03:15 0.25 COMPZN, RPCOMP OWFF P OWFF 15 min: 7,961.0 7,961.0 6/21/2024 03:15 6/21/2024 06:30 3.25 COMPZN, RPCOMP TRIP P POOH F/ 7960' to surface. L/D Baker packer running tool, and send to Baker shop to be redressesed, and stabbed into next packer. 7,961.0 0.0 6/21/2024 06:30 6/21/2024 07:30 1.00 COMPZN, RPCOMP BHAH P MU Baker test packer 0.0 20.0 6/21/2024 07:30 6/21/2024 11:00 3.50 COMPZN, RPCOMP TRIP P TIH W/Test Packer T/7953' 0.0 7,953.0 6/21/2024 11:00 6/21/2024 12:00 1.00 COMPZN, RPCOMP MPSP P Set test packer. purge surface lines circulate 3 BBL's. 7,953.0 7,953.0 6/21/2024 12:00 6/21/2024 12:30 0.50 COMPZN, RPCOMP PRTS P Pressure test permanent packer at 7961' to 2500 PSI for 15 minutes. 7,953.0 7,953.0 6/21/2024 12:30 6/21/2024 15:30 3.00 COMPZN, RPCOMP TRIP P TOOH F/7950' T/surface PUW=170K LD test packer 7,953.0 0.0 6/21/2024 15:30 6/21/2024 18:30 3.00 COMPZN, RPCOMP WAIT T Wait on upper packer and seal assemblies to start in hole with completion. 0.0 0.0 6/21/2024 18:30 6/21/2024 19:30 1.00 COMPZN, RPCOMP RURD P R/U to Run upper completion packer, and tail pipe. Verify straps on packer and Seal assy. PJSM. 0.0 0.0 6/21/2024 19:30 6/21/2024 20:30 1.00 COMPZN, RPCOMP PUTB P P/U tail pipe, and packer. M/U w/ GBR power tongs. 0.0 245.0 6/21/2024 20:30 6/22/2024 00:00 3.50 COMPZN, RPCOMP TRIP P RIH W/ Upper completion packer, and tail pipe from 245' to 7069' 245.0 7,069.0 6/22/2024 00:00 6/22/2024 00:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 7069' to 7910' 7,069.0 7,910.0 6/22/2024 00:30 6/22/2024 01:00 0.50 COMPZN, RPCOMP PACK P Kelly up to string. break circulation and pump @ 1 BBL/min @ 60 PSI. Slack off @ 7963' Set down 10K. P/U to break over (135K) + 10'. S/O, and again set down 10K @ 7963'. P/U, and rotate string 1/2 turn to the left. Work stand up 60'. S/O again, and enter PBR @ 7965'. Shut off pumps, and continue to S/O to 10K down on NO-GO @ 7976'. Pressure up to 350 PSI and P/U and observe pressure dump @ 7963'. P/U to 7961' 7,910.0 7,961.0 6/22/2024 01:00 6/22/2024 01:30 0.50 COMPZN, RPCOMP CIRC P Spot 25 BBLs of CI, 20 BBLS in the annulus leaving 5 BBLS in the string. 7,961.0 7,961.0 Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Page 21/21 1B-09 Report Printed: 7/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/22/2024 01:30 6/22/2024 02:00 0.50 COMPZN, RPCOMP PACK P Slack off, and relocate, w/ 10K down P/U and space out 1.5' off of fully located bottom of seal assy, 7973.45, Top of packer @ 7728.28'. Pressure up to 3000 PSI. P/U to 165K (30K over PUWT). Bleed pressure. Slack off to 75K, P/U to 165K, and increase pressure to 3000 PSI, hold 1 min. Bleed to off. S/O to 75K. P/U to 200K, Slack off to 125K 7,961.0 7,728.0 6/22/2024 02:00 6/22/2024 02:30 0.50 COMPZN, RPCOMP PRTS P R/U and pressure test packer 2500 PSI 15 min: GOOD. 7,728.0 7,728.0 6/22/2024 02:30 6/22/2024 02:45 0.25 COMPZN, RPCOMP PACK P Right hand release running tool from packer. 7,728.0 7,700.0 6/22/2024 02:45 6/22/2024 03:15 0.50 COMPZN, RPCOMP SVRG P Rig service, adjust brake bands, blow down top drive, and Kill line. 7,700.0 7,700.0 6/22/2024 03:15 6/22/2024 09:45 6.50 COMPZN, RPCOMP PULD P POOH L/D DP F/ 7700' to surface. 7,700.0 0.0 6/22/2024 09:45 6/22/2024 21:30 11.75 COMPZN, RPCOMP PUTB P P/U and RIH w/ 3.5" 9.3#/fit HYD 563 tubing from surface to 7728', 0.0 7,728.0 6/22/2024 21:30 6/22/2024 22:00 0.50 COMPZN, RPCOMP HOSO P M/U X/O to JT and KU to the string. Come on with the pumps @ 1 BBL/min @ 60 PSI. Observe pressure incease (Seals in seal bore) @ 7731'. Shut down pumps bleed off, and continue Tag at 7750' w/10K down/ 7748' in tension. 7,728.0 7,748.0 6/22/2024 22:00 6/22/2024 23:45 1.75 COMPZN, RPCOMP HOSO P L/D JTS 248, 247, and 246. P/U 8.09', and 3.83' pup joints, and M/U. P/U and M/U JT. 246. C/O Elevators. P/U landing joint, R/U X/O's and circulating lines to landing joint. P/U hanger, and M/U hanger to landing joint. P/U and M/U hanger, and landing joint to string. 7,748.0 7,728.0 6/22/2024 23:45 6/23/2024 00:00 0.25 COMPZN, RPCOMP CIRC P Displace well over to CI 9.5 Brine. 120 GPM @ 188 PSI. 7,728.0 7,728.0 6/23/2024 00:00 6/23/2024 02:30 2.50 COMPZN, WHDBOP CIRC P Cont. to circulate around 9.5 CI brine. 168 GPM @ 380 PSI. 7,728.0 7,728.0 6/23/2024 02:30 6/23/2024 03:00 0.50 COMPZN, WHDBOP THGR P Drain stack. Land hanger, verify landed out. RILDS. 7,728.0 0.0 6/23/2024 03:00 6/23/2024 05:00 2.00 COMPZN, WHDBOP PRTS P Rig up, and pressure test tubing to 3000 PSI for 30 min. Bleed tubing to 1500 PSI, and hold. Line up and pressure up annulus to 2500 PSI for 30 min. line up on tubing, and bleed off. Observe shear out. 0.0 0.0 6/23/2024 05:00 6/23/2024 06:00 1.00 COMPZN, WHDBOP RURD P R/D circulating line, and pull landing joint. 6/23/2024 06:00 6/23/2024 06:30 0.50 COMPZN, WHDBOP MPSP P Dry rod in BPV. Line up on the annulus and pressure test BPV from bellow to 1000 PSI for 10 min: Good. 6/23/2024 06:30 6/23/2024 07:30 1.00 COMPZN, WHDBOP NUND P N/D BOP. 6/23/2024 07:30 6/23/2024 09:30 2.00 COMPZN, WHDBOP NUND P N/U Tree and adapter flange. test adapter to 5000PSI for 15 minutes. 6/23/2024 09:30 6/23/2024 10:00 0.50 COMPZN, WHDBOP RURD P RU LRS to circualting manifold in cellar. RU Tbg and IA to Circulating manifold. Fill tree with diesel. Test tree to 5K PSI for 10 minutes. Pull BPV. 6/23/2024 10:00 6/23/2024 12:00 2.00 COMPZN, WHDBOP FRZP P LRS pumped 152 BBL's Down IA at 2 BPM. RD LRS and U-tube well. RD hardline in cellar. Rig: NABORS 7ES RIG RELEASE DATE 6/23/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Casing leak added at 63' RKB 1B-09 7/8/2024 jconne 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT Tie-Back String 9 5/8 8.68 26.0 63.4 63.4 47.00 L80 HYD 563 Intermediate 9 5/8 8.86 60.4 8,518.9 6,800.7 47.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 7,746.4 String Max No 3 1/2 Set Depth 6,241.9 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 24.3 24.3 0.04 Hanger 13.460 FMC Gen II Hanger w/ pup HTD563 pin FMC TC-1A- EMS 3.900 1,638.4 1,586.2 32.47 Nipple - X 4.251 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5007477-2 HES 2.81 "X" 2.813 7,667.0 6,179.2 37.39 Mandrel - SOV 5.960 3.5"x1.5" MMG (w/SOV 2000psi) S# 24758-17 SLB MMG 2.920 7,726.1 6,226.0 37.96 Locator 4.500 80-40, Locator BOT 2.992 7,727.0 6,226.6 37.97 Seal Assembly 3.980 80-40,Seal Assembly (Spaced out 2' off tag) BOT 80-40 2.992 Top (ftKB) 7,728.3 Set Depth 7,973.5 String Max No 3 1/2 Set Depth 6,416.6 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection hyd 563 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) 7,728.3 6,227.7 37.98 Packer 8.681 3.5" by 9-5/8", Baker Model F Packer BOT 4.000 7,732.2 6,230.8 38.02 SBE 5.020 SBE w/5-10' Stroke BOT 4.010 7,827.3 6,305.2 39.13 Nipple - X 4.274 2.813" X Nipple, 3.5", 9.3#, HYD563 S# 5069318-09 HES 2.813 7,910.4 6,369.0 40.56 Sleeve - Sliding 4.280 3.5", CMU, 2.813" X BOT 2.810 7,962.3 6,408.1 41.39 Locator 4.500 80-40, Locator BOT 2.992 7,963.1 6,408.7 41.40 Seal Assembly 3.980 80-40, Seal Assembly (Space out 1.5' off tag) BOT 2.992 Top (ftKB) 7,960.8 Set Depth 8,108.0 String Max No 3 1/2 Set Depth 6,515.7 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 7,960.8 6,407.0 41.36 Packer 8.200 3.5" by 9-5/8" Baker Model F Packer (~7957'/ between 7910'-7973') BOT 6.010 7,964.7 6,409.9 41.42 SBE 5.200 SBE w/10' Stroke BOT 4.010 8,019.6 6,450.8 42.22 2.81" X 3.500 2.813" X Nipple, 3.5", 9.3#, HYD563 S#5069318-08 HES 2.813 8,066.6 6,485.5 42.80 Sleeve - Sliding 4.250 3.5" CMU. 2.813" X BOT 2.810 8,097.1 6,507.8 43.18 Locator 4.480 80-40, Locator BOT 2.992 8,098.0 6,508.4 43.19 Seal Assembly 3.980 GBH 22 Seal assembly BOT 2.992 Top (ftKB) 8,096.5 Set Depth 8,202.0 String Max No 3 1/2 Set Depth 6,583.2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 8,096.5 6,507.4 43.17 Packer 8.860 3.5" by 9-5/8" Baker Model F Packer (~8090'/ below 8002') BOT PN: 1017833 94, SN: SG 3369483 -04 2.949 8,100.4 6,510.2 43.22 Seal bore extension 5.010 SBE, w/5-10' Stroke BOT 3.980 8,154.9 6,549.6 44.16 2.81" X 4.500 2.813" X Nipple, 3.5", 9.3#, HYD563 (w/plug installed) S#5069318-06 HES PN: 1017420 11, SN: 5461-9 2.813 8,201.5 6,582.8 44.95 Wireline Guide 4.255 WLEG, 3.5", 9.3#, HYD563 BOT 2.993 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) 63.0 63.0 0.12 LEAK - CASING PRODUCTION CASING LEAK IDENTIFIED ON VIVID LDL 7/8/2024 8.860 8,154.0 6,549.0 44.14 TUBING PLUG 2.81" XX PLUG SET IN NIPPLE AT 6/19/2024 0.000 1B-09, 7/17/2024 11:02:30 AM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 Hanger; 24.3 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 6/23/2024 H2S (ppm) DateComment SSSV: NONE 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) 7,667.0 6,179.2 37.39 1 GAS LIFT DMY RK 1 1/2 0.0 6/30/2024 SLB MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 1B-09, 7/17/2024 11:02:31 AM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 Hanger; 24.3 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL 1B-09, 7/17/2024 11:02:32 AM Vertical schematic (actual) Intermediate; 60.4-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 2.81" X; 8,154.9 TUBING PLUG; 8,154.0 2.81" X; 8,019.6 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 Mandrel - SOV; 7,667.0 SURFACE; 28.5-2,486.1 Nipple - X; 1,638.4 CONDUCTOR; 29.0-80.0 LEAK - CASING; 63.0 Tie-Back String; 26.0-63.4 Hanger; 24.3 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-06-20_21182_1B-09_20-Jun-24_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21182 KRU 1B-09 50-029-20655-00 Caliper Survey w/ Log Data 20-Jun-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 181-134 T39062 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.27 08:38:26 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8550' 6822' 8371' 6700'2386 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: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 1B-09 7828-7910' 7973-8002' 8203-8221' 8226-8275' 7976-8002'(Squeezed) 7834-7910'(Squeezed) 8493' 6306-6369' 6416-6438' 6584-6597' 6600-6635' 6418-6468' (Squeezed) 6310-6369' (Squeezed) 5/15/2024 4-1/2"x3-1/2" Baker FH Baker DB Baker DB 2457' 8519' Perforation Depth MD (ft): 80' 2486' 6801'9-5/8" 20" 13-3/8" 51' Burst 8114' MD 80' 2235' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 181-134 P.O. Box 100360, Anchorage, AK 99510 50-029-20655-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7745'MD/6241'TVD 7959'MD/6405'TVD 8083'MD/6498'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 Elliott Tuttle elliott.tuttle@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:51 am, Jun 17, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips , CN=Elliott Tuttle, E=elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.06.17 11:31:54-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 324-346 SFD 6/17/2024VTL06282024 X DSR-6/17/24 10-404X Victoria Loepp 6/17/2024 BOP test to 2500 psig Annular preventer test to 2500 psig *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.07.01 10:34:06 -08'00'07/01/24 RBDMS JSB 070224 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 17, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior RWO/CTD Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Change of approved Sundry to work over Camp Waste Injector 1B-09 (PTD# 181-134). Well 1B-09 was drilled and completed in 1981 as a Kuparuk A/C sand producer. In 1982 it was converted to a gas disposal injector, then converted to water injection. In 1994 some of the C sand was squeezed off, and in 1997 a RWO was completed with a dual selective completion. A one way suspected packer leak was detected in 2023 along with leaking selectives. Therefore a RWO is planned to address the leaking packer and restore selectivity. Challenges were encountered when replacing the wellhead with new, this request for CAP is in reponse to those challenges. A verbal from Victoria was recieved on 6/15/24 to proceed and this is in response to that. If you have any questions or require any further information, please contact me at +1-907-252-3347 The RWO is to replace the entire selective completion from above the lowest packer. When replacing the wellhead, the production casing needed to be grown out of its landing profile. It did not grow enough to allow the installation of a slips. We were not successful in landing the casing hanger back into the profile either so plan is to back off/ cut casing below the hanger and land new casing across the wellhead in order to install slips and new packoffs. Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN =Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2024.06.17 11:32:23-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 1B-09 RWO Procedure Kuparuk Injector Repair Selective PTD #181-134 Page 1 of 3 Remaining Pre-Rig Work 1. Dummy off GLMs 2. Set plug in 2.25” XN nipple in tail plug at 8,102’ MD and PT 3. Pull dummy valve from GLM at 7677’ MD’ 4. Four pre rig tubing cuts a. ~8040’ MD, ~7950’ MD, ~7804’ MD, ~7,705’ MD Rig Work MIRU 1. MIRU Nabors 7ES on 1B-09. Circulate well over to ~9.5ppg brine. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 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 Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig cut at ~7,705’ 6. RIH w/ DP and fish tubing stub from seals on packer at ~7,705-7,745’ MD Retrieve Upper Packer 7. Fish packer at 7,745’ MD to pre-rig cut at ~7,804’ MD Pull Middle Selective 8. Pull blast rigs from pre-rig tubing cut at ~7,804’ to pre-rig cut at ~7,950’ MD 9. Pull tubing stub from pre-rig tubing cut at ~7,905’MD from packer seals at 7,958’ MD Mill Middle Packer 10. Mill Baker DB permanent packer at 7,958’ MD Pull Lower Selective 11. Pull blast rings from milled packer to pre-rig tubing cut at ~8,040’ MD 12. Pull lower tubing stub from pre-rig cut at ~8,040’ MD out of packer seals at 8,083’ MD 13. Perform cleanout run to cleanout casing and perfs for completion run and cleanout SBE Replace FMC Gen II Wellhead 14. Set plug in the 9 5/8”and PT to 2,500psi for 30 min 15. ND BOP 16. ND FMC Gen II WH a. Based on similar 1B-10 RWO in 2019, might need to spear and grow and stretch 9 5/8” and set emergency slips b. Growth of 9 5/8” was 3.5”, will not stretch enough to get slips installed. NU Hydratight, attempt to press hanger back into spool, no success. Change of plan: Spear 9 5/8” casing, apply LH torque. RU Eline and RIH with string shot. Fire string shot to attempt blind backoff of 9 5/8” Production casing. (Unsuccessful) POOH lay down same. MU 9 5/8” 40lb/ft BTC casing and thread back in. Pull casing into tension, Set in slips and new packoff. 1B-09 RWO Procedure Kuparuk Injector Repair Selective PTD #181-134 Page 2 of 3 Cut Casing @ 64’ RKB, lay down casing from cut. Land 9 5/8” 40lb/ft Casing and External casing patch from cut to surface. Land in slips and new packoffs, cut off excess casing. 17. Install new 13 5/8” 5M tubing head 18. Test packoffs 19. NU BOP and test break 20. Pull plug Run Lower Selective 21. RIH with lower 3 ½” completion comprising of seals, tubing, sliding sleeve, nipple and middle packer on DP with test packer to stab into sealbore on remaining lower packer 22. Pick up, space out, circ in CI brine and land tubing into sealbore ~3’ from fully located Set and Test Lower Packer 23. Pressure up against pre rig plug to set middle packer. 24. Release from middle packer, pick up and set test packer. 25. Pressure test below test packer to test middle selective from pre rig test plug up to middle packer. Run Middle Selective, Upper Packer and Upper Completion 26. RIH with middle 3 ½” completion comprising of seals, tubing, sliding sleeve, nipple and upper packer to stab into sealbore on new middle packer 27. Pick up, space out, circ in CI brine and land tubing into sealbore ~3’ from fully located 28. Pressure up against pre rig plug to set upper packer. 29. Fully locate, PU above seals. Circulate in CI brine 30. Land tubing hanger. Install packoffs 31. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 32. Shear SOV 33. Install BPV. PT through SOV 34. ND BOP, NU WH 35. Circ in freeze protect tbg and IA Post Rig Work 1. Pull SOV, install GLD 2. Pull 2.25” plug 3. Open sliding sleeves as needed for injection General Well info: Wellhead type/pressure rating: FMC Gen 2, 3M psi rated Production Engineer: Adam Becia Surveillance Reservoir Engineer: Cody Keith Estimated Start Date: 5/15/24 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. 1B-09 RWO Procedure Kuparuk Injector Repair Selective PTD #181-134 Page 3 of 3 Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion and run new completion BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MITIA: passed 7/2/23 MIT-DDT: failed 7/2/23 IC POT & PPPOT passed 7/2/23 TBG POT & PPPOT passed 7/2/23 MPSP: 2,386 psi using 0.1 psi/ft gradient Static BHP: 3,025 psi/ 6,394’ TVD (measured 9/7/23) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Cuts 1B-09 5/22/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: SUSPECT GLM EROSION AT 7791; HAD TO RUN EXTENDED PACKING ON 1.5"" DUMMY VALVE 9/9/2001 triplwj 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT PRODUCTION 9 5/8 8.86 26.4 8,518.9 6,800.7 47.00 L-80 BTC Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 1B-09, 6/17/2024 11:20:46 AM Vertical schematic (actual) PRODUCTION; 26.5-8,518.9 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 SURFACE; 28.5-2,486.1 CONDUCTOR; 29.0-80.0 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev… 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 5/2/1995 H2S (ppm) DateComment SSSV: WRDP Description Top (MD) FMC GEN II HANGER 22 4.5" 12.6#, HYD563 26 4.5" tubing to 3.5" Hyd563 54 Tubing, 3.5", 9.3#, HYD563 75 Tubing Pup, 3.5", 9.3#, HYD563 2245 2.813" X, 3.5", 9.3#, HYD563 2251 Tubing Pup, 3.5", 9.3#, HYD563 2259 Tubing, 3.5", 9.3#, HYD563 2265 Tubing Pup, 3.5", 9.3#, HYD563 7659 3.5" MMG 7665 Tubing Pup, 3.5", 9.3#, HYD563 7673 Tubing, 3.5", 9.3#, HYD563 7679 Tubing Pup, 3.5", 9.3#, HYD563 7710 80-40 Locator Assembly 7716 3.5" by 9 5/8" Baker Model F Packer 7730 SBE w/ 5-10' STROKE 7730 Tubing Pup, 3.5", 9.3#, HYD563 7738 Tubing, 3.5", 9.3#, HYD563 7744 Tubing Pup, 3.5", 9.3#, HYD563 7806 2.813" X, 3.5", 9.3#, HYD563 7812 Tubing Pup, 3.5", 9.3#, HYD563 7820 Tubing, 3.5", 9.3#, HYD563 7826 Tubing Pup, 3.5", 9.3#, HYD563 7888 3.5" CMU. 2.813" X 7894 Tubing Pup, 3.5", 9.3#, HYD563 7902 Tubing, 3.5", 9.3#, HYD563 7910 Tubing Pup, 3.5", 9.3#, HYD563 7941 80-40 Locator Assembly, 7947 3.5" by 9 5/8" Baker Model F Packer 7957 SBE w/ 5-10' STROKE 7965 Tubing Pup, 3.5", 9.3#, HYD563 7975 Tubing, 3.5", 9.3#, HYD563 7981 Tubing Pup, 3.5", 9.3#, HYD563 8012 2.813" X, 3.5", 9.3#, HYD563 8018 Tubing Pup, 3.5", 9.3#, HYD563 8026 Tubing, 3.5", 9.3#, HYD563 8032 Tubing Pup, 3.5", 9.3#, HYD563 8063 3.5" CMU. 2.813" X 8069 Tubing Pup, 3.5", 9.3#, HYD563 8077 80-40 Locator Assembly 8085 3.5" by 9 5/8" Baker Model F Packer 8090 SBE w/ 5-10' STROKE 8098 Tubing Pup, 3.5", 9.3#, HYD563 8108 Tubing, 3.5", 9.3#, HYD563 8114 Tubing Pup, 3.5", 9.3#, HYD563 8145 2.813" X, 3.5", 9.3#, HYD563 8151 Tubing Pup, 3.5", 9.3#, HYD563 8159 Tubing, 3.5", 9.3#, HYD563 8165 WLEG, 3.5", 9.3#, HYD563 8196 1B-09 Proposed RWO Completion - 6/17/24 Surface Casing Production Casing Conductor A-sand perfs 8203-8275' RKB C-sand perfs 7973-8002' RKB C-sand perfs 7828-7910' RKB 181-134 T38929 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:45:58 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8550' 6822' 8371' 6700'2386 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: 907-263-4529 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 Kuparuk River Field Adam Klem adam.klem@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7745'MD/6241'TVD 7959'MD/6405'TVD 8083'MD/6498'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 181-134 P.O. Box 100360, Anchorage, AK 99510 50-029-20655-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 8114' MD 80' 2235' 80' 2486' 6801'9-5/8" 20" 13-3/8" 51' Baker FH Baker DB Baker DB 2457' 8519' Perforation Depth MD (ft): KRU 1B-09 7828-7910' 7973-8002' 8203-8221' 8226-8275' 7976-8002'(Squeezed) 7834-7910'(Squeezed) 8493' 6306-6369' 6416-6438' 6584-6597' 6600-6635' 6418-6468' (Squeezed) 6310-6369' (Squeezed) 5/15/2024 4-1/2"x3-1/2" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: Location: Date: 2024.04.15 12:45:21-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 324-218 By Grace Christianson at 2:34 pm, Apr 15, 2024 SFD 4/22/2024 DSR-4/22/24 X VTL 4/23/2024 X X 10-404 BOP test to 2500 psig Annular preventer to 2500 psig *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.23 15:16:22 -08'00'04/23/24 RBDMS JSB 042624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 9, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Camp Waste Injector 1B- 09 (PTD# 181-134). Well 1B-09 was drilled and completed in 1981 as a Kuparuk A/C sand producer. In 1982 it was converted to a gas disposal injector, then converted to water injection. In 1994 some of the C sand was squeezed off, and in 1997 a RWO was completed with a dual selective completion. A one way suspected packer leak was detected in 2023 along with leaking selectives. Therefore a RWO is planned to address the leaking packer and restore selectivity. If you have any questions or require any further information, please contact me at +1-907-263-4529 The RWO is to replace the entire selective completion from above the lowest packer. Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com , C=US Reason: Location: Date: 2024.04.15 12:44:57 -08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 1B-09 RWO Procedure Kuparuk Injector Repair Selective PTD #181-134 Page 1 of 3 Remaining Pre-Rig Work 1. Dummy off GLMs 2. Set plug in 2.25” XN nipple in tail plug at 8,102’ MD and PT 3. Pull dummy valve from GLM at 7677’ MD’ 4. Four pre rig tubing cuts a. ~8040’ MD, ~7950’ MD, ~7804’ MD, ~7,705’ MD Rig Work MIRU 1. MIRU Nabors 7ES on 1B-09. Circulate well over to ~9.5ppg brine. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 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 Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig cut at ~7,705’ 6. RIH w/ DP and fish tubing stub from seals on packer at ~7,705-7,745’ MD Retrieve Upper Packer 7. Fish packer at 7,745’ MD to pre-rig cut at ~7,804’ MD Pull Middle Selective 8. Pull blast rigs from pre-rig tubing cut at ~7,804’ to pre-rig cut at ~7,950’ MD 9. Pull tubing stub from pre-rig tubing cut at ~7,905’MD from packer seals at 7,958’ MD Mill Middle Packer 10. Mill Baker DB permanent packer at 7,958’ MD Pull Lower Selective 11. Pull blast rings from milled packer to pre-rig tubing cut at ~8,040’ MD 12. Pull lower tubing stub from pre-rig cut at ~8,040’ MD out of packer seals at 8,083’ MD 13. Perform cleanout run to cleanout casing and perfs for completion run and cleanout SBE Replace FMC Gen II Wellhead 14. Set plug in the 9 5/8”and PT to 2,500psi for 30 min 15. ND BOP 16. ND FMC Gen II WH a. Based on similar 1B-10 RWO in 2019, might need to spear and grow and stretch 9 5/8” and set emergency slips 17. Install new 13 5/8” 5M tubing head 18. Test packoffs 19. NU BOP and test break 20. Pull plug Run Lower Selective 1B-09 RWO Procedure Kuparuk Injector Repair Selective PTD #181-134 Page 2 of 3 21. RIH with lower 3 ½” completion comprising of seals, tubing, sliding sleeve, nipple and middle packer on DP with test packer to stab into sealbore on remaining lower packer 22. Pick up, space out, circ in CI brine and land tubing into sealbore ~3’ from fully located Set and Test Lower Packer 23. Pressure up against pre rig plug to set middle packer. 24. Release from middle packer, pick up and set test packer. 25. Pressure test below test packer to test middle selective from pre rig test plug up to middle packer. Run Middle Selective, Upper Packer and Upper Completion 26. RIH with middle 3 ½” completion comprising of seals, tubing, sliding sleeve, nipple and upper packer to stab into sealbore on new middle packer 27. Pick up, space out, circ in CI brine and land tubing into sealbore ~3’ from fully located 28. Pressure up against pre rig plug to set upper packer. 29. Fully locate, PU above seals. Circulate in CI brine 30. Land tubing hanger. Install packoffs 31. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 32. Shear SOV 33. Install BPV. PT through SOV 34. ND BOP, NU WH 35. Circ in freeze protect tbg and IA Post Rig Work 1. Pull SOV, install GLD 2. Pull 2.25” plug 3. Open sliding sleeves as needed for injection General Well info: Wellhead type/pressure rating: FMC Gen 2, 3M psi rated Production Engineer: Adam Becia Surveillance Reservoir Engineer: Cody Keith Estimated Start Date: 5/15/24 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion and run new completion BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: State witnessed MIT-IA required after stabilized injection. VTL 04/23/24 1B-09 RWO Procedure Kuparuk Injector Repair Selective PTD #181-134 Page 3 of 3 MIT results: MITIA: passed 7/2/23 MIT-DDT: failed 7/2/23 IC POT & PPPOT passed 7/2/23 TBG POT & PPPOT passed 7/2/23 MPSP: 2,386 psi using 0.1 psi/ft gradient Static BHP: 3,025 psi/ 6,394’ TVD (measured 9/7/23) Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug & gauges. 1B-09 9/7/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: SUSPECT GLM EROSION AT 7791; HAD TO RUN EXTENDED PACKING ON 1.5"" DUMMY VALVE 9/9/2001 triplwj 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT PRODUCTION 9 5/8 8.86 26.4 8,518.9 6,800.7 47.00 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.9 Set Depth … 8,113.6 Set Depth … 6,519.8 String Ma… 4 1/2 Tubing Description TUBING WO 4.5x3.5x2.875 Wt (lb/ft) 12.75 Grade J-55 Top Connection IJ-4S ID (in) 3.96 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) 24.9 24.9 0.05 HANGER 10.800 FMC GEN II HANGER 4.500 1,800.9 1,717.9 38.95 NIPPLE 5.260 CAMCO DB NO GO LANDING NIPPLE 3.813 7,513.3 6,056.0 36.27 XO Reducing 4.500 CROSSOVER 4.5 x 3.5 3.500 7,677.3 6,187.4 37.49 GAS LIFT 5.968 CAMCO MMG 2.920 7,722.7 6,223.3 37.93 NIPPLE 4.500 CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 7,731.0 6,229.8 38.01 PBR 5.062 BAKER PBR w/ 10' STROKE 3.000 7,745.1 6,240.9 38.14 PACKER 8.218 BAKER FH RETRIEVABLE PACKER 3.000 7,836.0 6,312.0 39.28 BLAST JTS 4.500 STEEL BLAST JOINTS (OAL = 98.99') 2.992 7,945.1 6,395.2 41.11 SLEEVE-O 4.500 BAKER; CMU SS w/ CAMCO W-1 SELECTIVE PROFILE - OPEN 11/8/2011 2.812 7,958.1 6,405.0 41.32 SEAL ASSY 6.000 BAKER EBH-22 ANCHOR SEAL ASSEMBLY 3.000 7,958.5 6,405.3 41.33 PACKER 8.125 BAKER DB PERMENANT PACKER 4.750 7,986.3 6,426.1 41.77 BLAST JTS 4.500 STEEL BLAST JOINTS (OAL = 39.6') 2.992 8,067.4 6,486.1 42.81 SLEEVE-C 4.500 BAKER; CMU GS w/ CAMCO D NO GO PROFILE - CLOSED 9/18/2007 2.750 8,081.3 6,496.2 42.99 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 8,083.0 6,497.5 43.01 PACKER 8.125 BAKER DB PERMENANT PACKER 3.250 8,086.6 6,500.2 43.05 SBE 6.000 BAKER SEAL BORE EXTENSION 3.250 8,091.0 6,503.4 43.11 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.441 8,101.7 6,511.2 43.25 NIPPLE 3.668 OTIS XN NIPPLE 2.250 8,112.8 6,519.3 43.44 SOS 2.875 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,045.0 6,469.6 42.54 LEAK - TUBING LEAK SEEN ON 7/7/19 IPROF 7/7/2019 2.992 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) 7,677.3 6,187.4 37.49 1 GAS LIFT DMY RK 1 1/2 8/2/2023 7,790.7 6,276.6 38.56 2 INJ DMY RK 1 1/2 0.0 9/9/2001 Ext Pkg; 4:00 0.000 7,974.3 6,417.1 41.58 3 INJ HFCV RK 1 1/2 0.0 6/18/2013 0.188 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 RPERF; 8 226 0-82290 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 PACKER; 8,082.9 LEAK - TUBING; 8,045.0 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 INJECTION; 7,974.3 PACKER; 7,958.5 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 INJECTION; 7,790.7 PACKER; 7,745.1 GAS LIFT; 7,677.3 SURFACE; 28.5-2,486.1 NIPPLE; 1,800.9 CONDUCTOR; 29.0-80.0 , , , , y q 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 RPERF; 8 226 0-82290 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 PACKER; 8,082.9 LEAK - TUBING; 8,045.0 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 INJECTION; 7,974.3 PACKER; 7,958.5 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 INJECTION; 7,790.7 PACKER; 7,745.1 GAS LIFT; 7,677.3 SURFACE; 28.5-2,486.1 NIPPLE; 1,800.9 CONDUCTOR; 29.0-80.0 RPERF; 8 226 0-82290 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 PACKER; 8,082.9 LEAK - TUBING; 8,045.0 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 INJECTION; 7,974.3 PACKER; 7,958.5 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 INJECTION; 7,790.7 PACKER; 7,745.1 GAS LIFT; 7,677.3 SURFACE; 28.5-2,486.1 NIPPLE; 1,800.9 CONDUCTOR; 29.0-80.0 1B-09 Proposed RWO Completion Surface Casing Production Casing Conductor A-sand perfs 8203-8275' RKB C-sand perfs 7973-8002' RKB C-sand perfs 7828-7910' RKB C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-07-27_22109_KRU_1B-09_LeakPointSurvey_Revised_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22109 KRU 1B-09 50-029-20655-00 LeakPoint Survey 27-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician ** Please replace previous upload with current upload. The change was a 333 W. 7th Ave., Suite 100 depth correction on the Station Stop Counts & Archer Final Report** Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 181-134 T37908 8/31/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.31 10:42:52 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-07-27_22109_KRU_1B-09_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22109 KRU 1B-09 50-029-20655-00 LeakPoint Survey 27-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 181-134 T37908 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.09 10:23:39 -08'00' 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 1B-09 (PTD 181-134) IA Suspect Date:Monday, June 26, 2023 5:18:38 PM Attachments:AnnComm Surveillance TIO for 1B-09.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, June 26, 2023 12:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Byrne, Jan <Jan.Byrne@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1B-09 (PTD 181-134) IA Suspect Chris, KRU 1B-09 (PTD 181-134) was reported by operations for high IA. The well will be shut it and initial diagnostics are being planned. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com 1B-09 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,371.0 1B-09 1/3/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Catcher & RBP, Set A-1 Inj Valve 1B-09 10/30/2022 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/6/2010 ninam NOTE: SUSPECT GLM EROSION AT 7791; HAD TO RUN EXTENDED PACKING ON 1.5"" DUMMY VALVE 9/9/2001 triplwj General Notes: Last 3 entries Com Date Last Mod By SUSPECT GLM EROSION AT 7791; HAD TO RUN EXTENDED PACKING ON 1.5"" DUMMY VALVE 9/9/2001 Admin 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 20 18.94 29.0 80.0 80.0 91.50 H-40 WELDED SURFACE 13 3/8 12.35 28.5 2,486.1 2,235.2 72.00 L-80 BUTT PRODUCTION 9 5/8 8.86 26.4 8,518.9 6,800.7 47.00 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.9 Set Depth … 8,113.6 Set Depth … 6,519.8 String Ma… 4 1/2 Tubing Description TUBING WO 4.5x3.5x2.875 Wt (lb/ft) 12.75 Grade J-55 Top Connection IJ-4S ID (in) 3.96 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) 24.9 24.9 0.05 HANGER 10.800 FMC GEN II HANGER 4.500 1,800.9 1,717.9 38.95 NIPPLE 5.260 CAMCO DB NO GO LANDING NIPPLE 3.813 7,513.3 6,056.0 36.27 XO Reducing 4.500 CROSSOVER 4.5 x 3.5 3.500 7,677.3 6,187.4 37.49 GAS LIFT 5.968 CAMCO MMG 2.920 7,722.7 6,223.3 37.93 NIPPLE 4.500 CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 7,731.0 6,229.8 38.01 PBR 5.062 BAKER PBR w/ 10' STROKE 3.000 7,745.1 6,240.9 38.14 PACKER 8.218 BAKER FH RETRIEVABLE PACKER 3.000 7,836.0 6,312.0 39.28 BLAST JTS 4.500 STEEL BLAST JOINTS (OAL = 98.99') 2.992 7,945.1 6,395.2 41.11 SLEEVE-O 4.500 BAKER; CMU SS w/ CAMCO W-1 SELECTIVE PROFILE - OPEN 11/8/2011 2.812 7,958.1 6,405.0 41.32 SEAL ASSY 6.000 BAKER EBH-22 ANCHOR SEAL ASSEMBLY 3.000 7,958.5 6,405.3 41.33 PACKER 8.125 BAKER DB PERMENANT PACKER 4.750 7,986.3 6,426.1 41.77 BLAST JTS 4.500 STEEL BLAST JOINTS (OAL = 39.6') 2.992 8,067.4 6,486.1 42.81 SLEEVE-C 4.500 BAKER; CMU GS w/ CAMCO D NO GO PROFILE - CLOSED 9/18/2007 2.750 8,081.3 6,496.2 42.99 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 8,083.0 6,497.5 43.01 PACKER 8.125 BAKER DB PERMENANT PACKER 3.250 8,086.6 6,500.2 43.05 SBE 6.000 BAKER SEAL BORE EXTENSION 3.250 8,091.0 6,503.4 43.11 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 8,101.7 6,511.2 43.25 NIPPLE 3.668 OTIS XN NIPPLE 2.250 8,112.8 6,519.3 43.44 SOS 2.875 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,800.0 1,717.3 38.93 WR-SSSV 3.81" DB LOCK W/ A-1 INJ VLV (SERIAL # HACS-0017) (.90" BEAN, OAL= 41" ), HACS -0017 10/30/2022 0.900 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) 7,677.3 6,187.4 37.49 1 GAS LIFT DMY RK 1 1/2 0.0 10/28/2022 11:30 0.000 7,790.7 6,276.6 38.56 2 INJ DMY RK 1 1/2 0.0 9/9/2001 Ext Pkg; 4:00 0.000 7,974.3 6,417.1 41.58 3 INJ HFCV RK 1 1/2 0.0 6/18/2013 0.188 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,828.0 7,906.0 6,305.7 6,365.6 UNIT D, C-4, C- 3, C-2, 1B-09 5/2/1995 5.0 RPERF 51B HyperJet II; 60 deg. spiral 7,904.0 7,910.0 6,364.1 6,368.7 C-2, 1B-09 11/14/1994 0.0 SQZ Squeezed 7/9/94 7,973.0 8,002.0 6,416.2 6,437.8 C-1, UNIT B, 1B- 09 5/2/1995 1.0 RPERF 4.5" 34B HyperJet II;135 deg 8,203.0 8,207.0 6,583.9 6,586.7 A-5, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 1B-09, 10/31/2022 7:53:43 AM Vertical schematic (actual) PRODUCTION; 26.5-8,518.9 FLOAT SHOE; 8,517.0-8,518.9 FLOAT COLLAR; 8,435.0- 8,436.5 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 SOS; 8,112.8 NIPPLE; 8,101.7 SBE; 8,086.6 PACKER; 8,082.9 SEAL ASSY; 8,081.3 SLEEVE-C; 8,067.4 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 INJECTION; 7,974.3 PACKER; 7,958.5 SEAL ASSY; 7,958.1 SLEEVE-O; 7,945.1 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 INJECTION; 7,790.7 PACKER; 7,745.1 PBR; 7,731.0 NIPPLE; 7,722.7 GAS LIFT; 7,677.3 SURFACE; 28.5-2,486.1 FLOAT SHOE; 2,484.2-2,486.1 FLOAT COLLAR; 2,405.3- 2,406.9 NIPPLE; 1,800.9 WR-SSSV; 1,800.0 CONDUCTOR; 29.0-80.0 HANGER; 28.5-32.2 HANGER; 26.5-31.1 HANGER; 24.9 KUP INJ KB-Grd (ft) 31.99 RR Date 11/10/198 1 Other Elev… 1B-09 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065500 Wellbore Status INJ Max Angle & MD Incl (°) 47.33 MD (ftKB) 8,350.00 WELLNAME WELLBORE1B-09 Annotation Last WO: End Date 5/2/1995 H2S (ppm) DateComment SSSV: WRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,207.0 8,221.0 6,586.7 6,596.6 A-4, 1B-09 5/2/1995 8.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,226.0 8,229.0 6,600.1 6,602.2 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. 8,229.0 8,275.0 6,602.2 6,634.5 A-4, 1B-09 5/2/1995 4.0 RPERF 4.5" 43C BH Ultra Pa; 173 deg. CCW. Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,976.0 8,002.0 6,418.4 6,437.8 Cement Both intervals initially squeezed w/ 55 bbl Class 7,834.0 7,910.0 6,310.4 6,368.7 Cement Both intervals squeezed w/ appr. 25 bbl on 11-14-9 1B-09, 10/31/2022 7:53:46 AM Vertical schematic (actual) PRODUCTION; 26.5-8,518.9 FLOAT SHOE; 8,517.0-8,518.9 FLOAT COLLAR; 8,435.0- 8,436.5 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 SOS; 8,112.8 NIPPLE; 8,101.7 SBE; 8,086.6 PACKER; 8,082.9 SEAL ASSY; 8,081.3 SLEEVE-C; 8,067.4 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 INJECTION; 7,974.3 PACKER; 7,958.5 SEAL ASSY; 7,958.1 SLEEVE-O; 7,945.1 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 INJECTION; 7,790.7 PACKER; 7,745.1 PBR; 7,731.0 NIPPLE; 7,722.7 GAS LIFT; 7,677.3 SURFACE; 28.5-2,486.1 FLOAT SHOE; 2,484.2-2,486.1 FLOAT COLLAR; 2,405.3- 2,406.9 NIPPLE; 1,800.9 WR-SSSV; 1,800.0 CONDUCTOR; 29.0-80.0 HANGER; 28.5-32.2 HANGER; 26.5-31.1 HANGER; 24.9 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… 1B-09, 10/31/2022 7:53:48 AM Vertical schematic (actual) PRODUCTION; 26.5-8,518.9 FLOAT SHOE; 8,517.0-8,518.9 FLOAT COLLAR; 8,435.0- 8,436.5 RPERF; 8,229.0-8,275.0 RPERF; 8,226.0-8,229.0 RPERF; 8,207.0-8,221.0 RPERF; 8,203.0-8,207.0 SOS; 8,112.8 NIPPLE; 8,101.7 SBE; 8,086.6 PACKER; 8,082.9 SEAL ASSY; 8,081.3 SLEEVE-C; 8,067.4 Cement; 7,976.0 ftKB RPERF; 7,973.0-8,002.0 INJECTION; 7,974.3 PACKER; 7,958.5 SEAL ASSY; 7,958.1 SLEEVE-O; 7,945.1 SQZ; 7,904.0-7,910.0 Cement; 7,834.0 ftKB RPERF; 7,828.0-7,906.0 INJECTION; 7,790.7 PACKER; 7,745.1 PBR; 7,731.0 NIPPLE; 7,722.7 GAS LIFT; 7,677.3 SURFACE; 28.5-2,486.1 FLOAT SHOE; 2,484.2-2,486.1 FLOAT COLLAR; 2,405.3- 2,406.9 NIPPLE; 1,800.9 WR-SSSV; 1,800.0 CONDUCTOR; 29.0-80.0 HANGER; 28.5-32.2 HANGER; 26.5-31.1 HANGER; 24.9 KUP INJ 1B-09 ... WELLNAME WELLBORE1B-09 Comment 3.81" DB LOCK W/ A-1 INJ VL… Originated: Delivered to:31-Oct-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 N/A Kuparuk River Multi Finger Caliper Field & Processed 29-Sep-22 0 12 1J-102 50-029-23317-00 N/A Kuparuk River Injection Profile Field- Final 9-Oct-22 0 13 1J-102 50-029-23317-00 N/A Kuparuk River Injection Profile Field- Final 10-Oct-22 0 14 3G-13 50-103-20137-00 N/A Kuparuk River Multi Finger Caliper Field & Processed 21-Oct-22 0 15678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:1B-09 PTD: 181134 T372121J-102 PTD: 206110 T372133G-13 PTD: 190116 T372141B-0950-029-20655-00 N/AKuparuk RiverMulti Finger CaliperField & Processed29-Sep-2201Kayla JunkeDigitally signed by Kayla Junke Date: 2022.11.02 08:48:27 -08'00' Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 907383247 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-21 0 12 2M-19 50-103-20158-00 907335394 Kuparuk River Multi Finger Caliper Field & Processed 19-Aug-21 0 13 2M-19 50-103-20158-00 907335394 Kuparuk River Plug Setting Record Field- Final 20-Aug-21 0 14 2M-27 50-103-20175-00 907335397 Kuparuk River Plug Setting Record Field- Final 18-Aug-21 0 15 2M-33 50-103-2024-00 907316545 Kuparuk River Packer Setting Record Field- Final 8-Aug-21 0 16 2N-333 50-103-20525-00 907331967 Kuparuk River Radial Bond Record Field- Final 17-Aug-21 0 17 2N-333 50-103-20525-00 907383501 Kuparuk River String Shot Record Field- Final 13-Sep-21 0 18 2T-207 50-103-20287-00 907326322 Kuparuk River Packer Setting Record Field- Final 15-Aug-21 0 19 2V-04 50-029-21041-00 907398078 Kuparuk River Correlation Record Field- Final 20-Sep-21 0 110 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 1-Sep-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϭϴϭϭϯϰϬͲ^Ğƚ͗ϯϱϲϵϵBy Abby Bell at 10:25 am, Sep 23, 2021 ji S-11- ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVED E C �'\ �C Attn: Diane Williams V G 130 West International Airport Road Suite C OCT 0 9 2019 Anchorage, AK 99518 AOGCC Pdsanchoraoe(&memorvlog.com 08 -Sep -19 1B-09 CD 50-029-20655-00 Date: I ODoq /W K PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(rDMEMORVLOGCOM WEBSITE: WWW.MEMORVLOG.COM https://readca hole my.sharep ii wm/pemonaL'diene williams_readc sedhole_com/Dommentgo AivelACNves/MarteYl'emplateFilesfl'emplaces/DisMbufioNhansmi[mlSheets/ConocoPNllips_Transmit doa No 31312 1ffi1134 _- CASED Memory Multi -Finger Caliper HOLE Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1B-09 Log Date: September 8, 2019 Field: Kuparuk Log No.: 14402 State: Alaska Run No.: 1 API No. 50-029-20655-00 Pipe Description: 4.5 inch 12.6 Ib. J-55 IJ4S Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 7,513 Ft. (MD) Pipe Description: 3.5 inch 9.3 Ib. J-55 IJ4S Top Log Interval: 7,513 Ft. (MD) Pie Use: Tubing Bottom Log Interval: 7,777 Ft. MD Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the cross-over at 7,513.3 feet (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5 inch tubing appears to range from good to fair condition, with a maximum recorded wall penetration of 36% in a line of pits in joint 55 (1,726 ft). Additional wall penetrations ranging from 20% to 35% wall thickness are recorded in 82 of the 247 joints logged. Recorded damage appears as isolated pitting, a line of pits, and corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged The caliper recordings indicate the 3.5 inch tubing logged appears to be in good condition with the exception of a 26% wall penetration in a line of pits in joint 2 (7,576 ft). No other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. 4.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits 36 55 1,726 Ft. (MD) Corrosion 35 57.1 1,806 Ft. (MD) Line of Pits 35 51 1,595 Ft. (MD) Line of Pits 35 38 1,190 Ft. (MD) Line of Pits 34 83 2,584 Ft. (MD) 4.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded. 4.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmericaCa7readcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits 26 2 7,576 Ft. (MD) No other significant wall penetrations (> 19%) are recorded throughout the tubing logged. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 3%) are recorded throughout the tubing logged. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop J. Condio & B. Worthington READ Cased Hole Inc. / P.O. Box 1369, Stafford, 7X 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica()readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipet 4.5 in (32.1'-7,513.3') Well: 1B-09 Pipe 2 3.5 in (7,513.3'- 7,776.9') Field: Kuparuk Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: September 8, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 25 50 75 100 E 125 Z - c O 150 175 200 GLM 1 Bottom of Survey = 7 225 1 7 0 36 754 1,522 2,297 3,067 3,830 50 Damage Profile (% wall) / Tool Deviation (degrees) 4,594 5,359 6,126 6,905 7,514 7,754 100 CASED =_� HOLE Body Region Analysis Well: 1 B-09 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pie 4.5 in. 12.6 f J-55 IJ -45 Analyst: __ Waldrop Pipe Nom.OD Weight Grade & Thread 4.5 in. 12.6 ppf J-55 IJ -4S Penetration (% wall) Damage Configuration (body) u Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Nom.ID Top Depth Bottom Depth 3.956 in. 32 ft. 7,513 ft. Damage Profile (% wall) Penetration body INNER Metal loss body 0 50 100 47 94 144 194 Bottom of Survey = 243.1 CASED _=HOLE � Well: 16-09 Field: Kuparuk jCompany: ConocoPhillips Alaska, Inc. Pipe Description 4.5 in. 12.6 ppf J-55 IJ -4S Tubing - Joint Tabulation Sheet Survey Date: September 8, 2079 Analyst: Waldrop Nom. ID Body Wall Top Depth 3.958 in. 0.271 in. 32 ft Bottom Depth 7,513 ft. Joint Jt. No. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 32 0 0.04 14 1 3 Pup Lt. Deposits,_ 1 36 . 0 0.02 6 1 3.89 Lt. D posits. 1.1 62 0 0.03 11 0 3.84 Pup Lt. Deposits. 1.2 75 0 0.02 7 0 3.84 Pu Lt. Deposits. 1.3 81 0 0_01 4 0 .85 Pup Lt. Deposits. 2 85 0 0.03 12 3 3.90 3 115 0 0.02 8 2 3.89 LL Deposits. 146 0 0.05 17 4 3.90 Shallow Pitting Lt. Deposits 5 178 0 0.04 15 3 3.89 Shallow Pitting., Lt Deposits.. _ - 6 208 0 0.04 15 2 3,90 Shallow Pitting. 7 240 0 0.04 13 3 3.89 Lt. Deposits. 9 271 302 0 0 0.04 0.03 15 11 3 3 3,89 3.88 Shallow Line of Pit5 Lt Deposits. Lt. Deposits. 10 333 0 0.06 21 2 3.90 Line of Pits. Lt. Deposits. 11 12 363 390 0 0 0.04 0.03 15 11 4 3 3.92_. 3.88_ Shallow Pitting. Lt. Deposits 13 421 0 003 10 1 2 3.89 Lt. Deposits. 14 451 0 0.06 23 1 3 3.89 Line of Pits. Lt. Deposits. 15 483 0 0.05 18 2 3.91 Shallow Line of Pits. 16 513 0 0.05 17 2 3.89 Shallow Pitting. Lt. Deposits. 17 545 0 0.07 25 2 3.90 Line of Pits. Lt. Deposits. 18 _ 575 0 0.05 18 3 X89 Shallow Line of Pits. Lt. Deposits. 19 605 0 0.07 26 2 3.89 Line of Pits. Lt. Deposits. 20 636 0 0.07 24 2 3.89 IsolaedPittin Lt. Deposits. 21 64 0 0.08 31 3 3.89_ Line of Pits. Lt. Deposits. 22 23 693 724 0 1 0 0.07 0.06 25 23 5 1 3 3.89 3.91 Line of Pits. Lt. Deposits. Line of Pits. 24 754 0 0.08 29 2 3.87 Line of Pits. Lt. Deposits. 25 26 785 818 0 0 0 0.04 21 14 2 2 3.87 3.90 Isolated Pitfinp Lt. Deposits. Lt. Deposits. 27 848 0 0.04 14 5 3.90 LL De osit . 28 29 30 876 908 938 0 0 0 0.06 0.06 0.06 24 21 23 2_. 2 4'. �. 3.89 3.93 3.89 Line of -Pits. Lt. Deposits. Line of Pits. Line of Pits. Lt. Deposits. 31 970 0 0.07 24 3 1 3.89 Line of Pits. Lt. Deposits. 32 33 1 1001 1030 0 ! 0 0.07 0.06 24 22 4 1 2 1 3.92 1 3.86 Line of Pits. Isolated Pitting, Lt. Deposits. 34 1060 1 0 0.04 13 3 9 L sits. 35 1091 0 0.05 19 3� h I w Line of Pits. Lt. Deposits. 36 1122 0 0.04 13 2 3.89 Lt. Deposits. 37 11 4 0 0.06 21 3 3.89 Line of Pits. Lt. Deposits. 3 1185 0.09 35 3 3.92 Line of Pits. 39 1215 0 0.07 27 3 3.88 Line of Pits. Lt. Deposits. 40 1248 0 0.08 28 3 3.89 Line of Pits. Lt. De osits. 41 1277 0 0.04 15 2 3 0 Shallow Pitting. Lt. De osits. 42 1309 0 24 3 3 Line of Pits. Lt. Deposits. _ 43 1339 0.05 _0.07 0.08 30 4 1 3.86 Line of Pits. Lt. De osits. 44 1370 0 0.08 28 2 3.90 Line of Pits. 45 1401 0 0.06 24 2 1 3.90 Line of Pits. 46 1432 0 0.08 31 1 4 1 3.89 LUne of Pits. Lt. De sits. Penetration Body Metal Loss Body Page 1 == HOLED Well: 1 B-09 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 4.5 in. 12.6 ppf 1-55 I}4S Tubing _ loint Tabulation Sheet Survey Date: September 8, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth _ 3.958 in. 0.271 in. 32 it Bottom Depth 7,513 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile 1 (% wall) 0 50 100 47 48 1463 1494 00.07 0 __ 0.06 25 23 3 2 3.89 3.89 Line of Pits. Lt. Deposits. Line of Pits LL.D-eposits. 49 1522 0 0.09 33 2 3.89 Line of Pits. Lt. De osits. 50 1554 0 0.08 30 3 3.89 Line of Pits, Lt De osits. 51 52 53 1585 1616 1648 0 0 0 0.10 0.07 0.04 35 24 15 3 3 2 3.92 _3.87 3.89 Line of Pits. Line of Pits. Lt. Deposits. Shallow Pitting. Lt. Deposits. 54 1679 0 0.06 20 2 3.89 Isolated Pitting, Lt Deposits. 55 56 1709 1740 0 0 0.10 0.08 36 30 3 3 3.90 3.90 Line of Pits. Line of Pits. 57 1769 0 0.07 24 3 1 3.90 Line of Pits. 57.1 1801 0.06 0.10E24 6 3.87 Pu Corrosion. Lt Deposits. 57. 1806 ' 0 0 0 3.81 Camco DB No Go LandingNipple 57.3 1808 1 0 0.03 0 3.86 Pu Lt. Dep osits. 58 1814 0 0 6 4 3.89 in f i L D i. 59 1842_ 1873 I_ 0 0 0.04 0 03 3 4 3.9060 3.88 Lt. De sits. __61 62 1934 ;_0 0 .05 0.05 2 3 _3.89 3.89 Shallow Line of Pits Lt.D osits.. Shallow Pittin .Lt. De osits63 1965 0 0.05 3 3.89 Shallow Line of Pits. Lt. De osits. 64 1995 0 0.08 28 5 3.88 Line of Pits. Lt. Deposits. 65 2024 0 0.04 14 2 3.85 Lt. Deposits, 66 2052 0 0.03 11 3 3.88 67 2083 0 0.03 11 1 3.88 Lt. Deposits. 68 2113 20 1 2 3yo Isolated Pitting. 69 2141 0 0.06 23 4 3.87 Isolated Pitting. Lt Deposits.. 70 2173 0 0.04 16 3 3.87 Shallow Filling. Lt De os its. 71 2204 0 0.04 16 3 3.89 Shallo Pittin . L[ Deposits. 72 2236 0 0.09 34 3 3.89 Line of Pits. Lt. Deposits. 73 2268 0 0.04 13 2 _ 3.89 Lt. Deposits, f 74 2297 0 0.09 32 3 3.88 Line of Pits. Lt. Deposits. 75 2328 0 0.03 10 2 is. 76 2358 0 0.03 11 _ 4 _3. 3.88 Lt Deposits. 77 2389 0 1 0.04 15 1 2 1 3.88 Shallow Pitting. Lt. Deposits. 78 2421 0 0.08 28 4 3.87 Line of Pits. Lt. Deposits. 79 2451 0 -.0.04 13 3 3.85_ _Lt._Deposits. 80 2480 0 0.04 15 2 3.87 Shallow Line of Pits. Lt. Deposits. 81 2510 0 0.07 26 3 3.87 Isolated Pitting Lt. Deposits. 82 41 0 0.04 14 3 Lt. Denosits. 83 2572 0 0.09 34 4 3.88 Line of Pits. Lt. Deposits. 84 2602 0 0.05 18 3 3.89 Shallow Filling. Lt. Deposits. 85 2630 0 0.04 15 4 3.B5 Shallow Pitting. Lt. Deposits. 86 2662 0 0.06 23 3 3.88 Line of Pits. Lt Deposits. 87 2694 0 0.08 1 28 1 3 3.88 Line Corrosion. Lt. Deposits. 88 2726 0 0.05 19 1 3 3.86 Shallow Line of Pits. Lt. Deposits. 9 2757 0 0.06 23 2 3.88 Isolated Pitting. Lt. Deposits, 90 2787 0 0.05 17 2 hallow Pitfin L De osits. 91 2 817 0 0.04 16 3 3.87 Shallow Pitfin . Lt. De osits. 92 2848 0 0.04 13 3 3.87 Lt. Deposits. 93__.. 2877 - 0_ _ _0.04 13 2 3.88 Lt. Deposits. Penetration Body Metal Loss Body Page 2 Well: 1 B-09 Field: Kuparuk CASED HOLE Inc. Pipe Description 4.5 in. 12.6 ppf J-55 1}4S Tubing joint Tabulation Sheet Survey Date: September 8, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 1 3.958 in. 0.271 in. 32 ft 7,513 ft. Penetration Body Metal Loss Body Page 3 CASED -__� HOLE Well: 1 B-09 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 4.5 in. 12.6 ppf J-55 1}4S Tubing Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss 1. D. (in.) (in.) % (inJ Joint Tabulation Sheet Survey Date: September 8, 2019 Analyst: Waldrop _ Nom. ID Body Wall Top Depth Bottom Depth - - 3.958 in. 0.271 in. 32 it 7,513 ft. amage Profile Com(%wall) F 50 100 144 4446 0 0.04 15 2 a.87 S. sallow Pi .i LLt. Depo 145 4476 0 0.04 15 3 3.87 Sh low Pittin . Lt. De o 146 4506 _ 0 0. 13 3.82 Aen1s Lt. De osits. 147 4536 0 0.05 19 3 3.88 Shallow Line of Pits. Lt. 148 4565 0 0.0_5 17 2 3.86 Shallow Pitting. Lt. De o149 4594 0 0.05 17 3 3.86_ Shallow Pitting. Lt. Depo15 4625 .0 22 2 3.87 Isolated Pittin Lt. De 151 4657 0 0.03 12 2 3.85 Lt. Deposits. 152 153 4687 4717 1 0 0 0.03 0.03 12 13 1 3 3.89 3.88 Lt. De osits. Lt, Denosits. 154 4748 0 0.05 19 3 3.86 Shallow Line of Pits. Lt. Deposits. 155 4776 0 0.04 13 4 3.87 LT. Deposits. _ _ _ 156 4807 T 0 0.05 17 3 3.88 Shallow Line of Pits. Lt. Deposits. 157 4838 1 0 0.03 12 3 3.87 Lt. De osits. 158 159 4868 4899 1 0 0 0.04_ _- 0.04 13 15 2 __- 3 3.90 3.85 Shallow Pitting. Lt. Deposits. 160 4931 0.04 0.04 13 3 3.86 Lt. De osits. 161 4962 0 0.03 11 3 3.83 Lt. Deposits. 162 4995 0 0.04 3 3.86 Shallow Line of Pits. Lt Deposits._ _15 _ 163 5026 0 0.07 26 3 3.84 Isolated Pitting, Lt. Deolosits. 164 5055 0 0.05 17 4 3.85 Shallow Pitting. Lt. De osits. 165 5087 0 0.05 19 3 3.86 Sh llo Pitting. It Deposits. 166 5119 0 0.04 13 3 3.86 Lt. De osits. 167 5149 0 0.06 23 1 3 1 3.85 1 Line Corrosion. Lt. De osits. 168 5180 0 0.04 14 1 2 1 3._86 Lt. De osits. 169 170 5210 5241 0 0 0.04 0.06 16 20 1 4 1 1 2 ' 3.83 3.87 Shallow Line of Pits. Lt. Deposits. Line of Flits. LEDemsiu. 171 5273 0 0.03 11 3 1 3.86 Lt. Deposits. 172 5304 0 0.05 17 2 3.84 Shallow Line of Pits. Lt. Denosits. 173 5331 0 1 0.04 15 2 3.87 Shallow Pitting. Lt. De osits. 174 5359 0 0,i 16 3.88 Shallow Pitting. Lt. De osits. 175 5390 0 0.04 16 3 3.87 Shallow Pitting. Lt. Deposits. 176 5422 0 0.03 10 2 3.87 Lt. Deposits. 177 5454 0 0.03 9 1 3.85 Lt. osits. 17 5485 0 0.04 15 3 3.88 Shallow Pitting. Lt. Deposits. 179 5514 0 0.03 13 2 3.86 Lt. Deposits 180 5546 1 0 0.04 14 1 3 3.88 Lt. Deposits, 181 5577 0 0.04 14 1 4 1 3.86 Lt. Deposits. 182 5607 0 0.06 21 1 2 3$7 Isolated Pitting. Lt. Deposits. 183 184 5637 5668 0 0 0.05 0.05 19 17 4 1 2 ; 3.82 3.84 Shallow Line of Pits. Lt. Deposits. Shallow Pitting. Lt. Deposits. 1 -51 0 0.05 19 3 1 3.87 Shallow Pining. Lt. De osits. 186 5731 0 0.04 14 2 3.88 Lt Deposits. 187 5762 0 0.04 13 3 3.89 Lt. De o it . 188 5792 0 0.04 14 3 3.81 Lt. De osits 189 5824 0 0.05 1 19 3.82 Sh II_Qw Line of Pits. Lt. Deposits. 1905854 0 0.07 24 4 3.87 Line of Pits. Lt. Deposits. 191 5885 0 .04 16 3 3.87 Shallow Line of Pits. Lt. Deposits. 192 5913 0 .03 12 3 3.83 Lt. Deposits. 193 5944 0 0.04 15 3 3.84 Shallow Pitting. Lt. Dei Penetration Body Metal Loss Body Page 4 CASED HOLE Joint Tabulation Sheet Well: 16-09 Survey Date: Field: Kuparuk Analyst: Company: ConocoPhillips Alaska, Inc. Pipe Description 4.5 in. 12.6 Nom. ID J-55 1}4S Tubing 3.958 in. September 8, 2019 Waldrop Body Wall Top Depth Bottom Depth 0.271 in. 32 ft 7,513 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. 1. D. (in.) Comments Damage Profile (% wall) 0 50 1001 194 5976 0 0.04 14 2 3_84-. Lt,. Deposits. Iso ted. Pitting Lt.. Deposits. Line of Pits. Lt. Deposits, 195..._....6006 0 0.05 20 3 8 x196 6034 0 0.06 21 4 3.87 1 197 6066 0 0.04 1 1 3.87 Lt. Deposits. 198 0 0.04 15 3 '.. 3.86 _ _S_hallow Line of Pits._Lt_Deposiis._ Shallow _Pittiny-Lt. Deposits. _ _6095 199 6126 0 18 3 _ __3.85 _ __0.05 200 6158 0 0.05 17 '2166 Shallow Line of Pita. Lt. Deposits. 201_ 6189_ 0 0,05 18 4 '.. 3.86 Shallow Line of Pits. Lt.. Deposits_ 202 6221 _ 0 18 _ 3 3_85 Shallow Pitting Lt. Depositr_____ Shallow Pitting. Lt. Deposits. _0_05 203 6251 0 0.05 1 17 1 2 3.85 204 6282 0 0.04 15 1 3 3.87 Shallow Pitting. Lt. Deposits. 205 6313 0 _0.04_13 3 3.87 Lt. Deposits. Shallow Line of Pits. Lt. Deposits. 206 6344 0 0.05 18 3 3.85 207 6375 0 0.05 17 2 3.86 Shallow Line of Pits. Lt. Deposits. 208 6405 _ 0.05 18 3 3_87 _ Shallow Pitting. Lt Deposits. Isolated Pitting LL Deposits. Lt. Deposits. -0 209 6436 0 0.07 27 4 3.87 210 6467 0 .04 14 3 3.85 211 6499 1 0 14 3 3.87 Lt. Deposits. _ _ ._0.04_. 212 6 2 0 0.04_ 13 1 3.85 Lt. Deposits. 213 6559 0 0.06 21 4 3.85 Line of Pits. Lt. Deposits. 214 6590 0 0.04 15 3 3.87 Shallow Pitting. Lt. Deposits. 215 6623_ 0_06 24 3 3.86 Isolated_ PittingLt_De 21654 _0_ _ 0 0.03 10 x_3_.87 Lt Deposits. _ Shallow Piping. Lt. De osifs. 217 6684 0 0.05 17 1 3 3.85 218 6716 _ 0 0.0.5 _ y 20 2 3._86_ Isolated _Pitting Lt. Deposits. Lt Deposits. 219 6747 0 0.04',_ 14 3 _; 3.88. 22 6779 0 005_ 18 2 3.89 Shallow Pitting. Lt. Deposits. 221 6810 0 0.04 14 3 3.85 Lt. Deposits. 222 6841 0 0_.04 14 3 Lt Deposits. _ _3.87 223 6872 0 0.04 16 2 3.86 Shallow Pitting. Lt. Deposits. 224 6905 0 0.07 1 24 2 3.87 Isolated Pitting, Lt. Deposits. 225 6932 0---0.03 11 2 _3.87 Lt. Deposits. Shallow Line of Pits. Lt. Deposits. 226 6964 0 0.04 153 3.86 227 6995 0 .06 21 2 3.87 1 Line of Pits. Lt. Deposits. 228 229 229 _..7026 705 0 0 ---0.06- .0.07 . 24 22 3 3 3.88 3.87 eposits. __ Line of Pits. Lt. Deposits.--- Line of Pits. Lt. Deposits. 230 7090 0 1 0.03 9 2 3.87 Lt. Deposits. 231 7120 0 0.04 13 2 3.85 Lt. Deposits. 232 7151 00.04 15 3 1_3.87 Shallow Line of Pits. Lt. Deposits.__ 233 _ 7181 0 0.04 16 2 3.85 Shallow Pitting Lt. Deposits. Lt. Deposits. 234 7210 0 003 11 2 3.89 235 7240 0 _.004 13 3 3.86 Lt Deposit_s._. 236 7270 0 0.03 11 2 Lt. Deposits. 237 7300 0 0.05 20 _ 3 _3.85 3.86 Isolated PittinF Lt. Deposits. 7331 0 0.05 17 2 3.88 Shallow Pitting. Lt. Deposits. 7362 73 1 0 0 0.04 0.0 14 2 2 3 3.84 3.85 Lt.Deposits. Line of Pits. Lt. De sits. E23 7422 1 0 0.06 23 3 3.90 Isolated Pittin 7453 7482 I 0 1 0 0.04 0.04L13 16 3 2 3.83 3.86 Shallow Pitting_ Lt. Deposits. 1 Lt. Deposits. 'Penetration Body Metal Loss Body Page 5 CASED HOLE Well: 1 B-09 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 No, 218527 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 55 at depth 1,725.619 ft. Tool speed = 47 Nominal ID = 3.958 Nominal OD = 4.5 Remaining wall area = 97% Tool deviation - 36° Finger = 22 Penetration = 0.097 in. Line of Pits 0.10 in. = 36% Wall Penetration HIGH SIDE = UP =_ CASED HOLE Well: 1 B-09 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubine: 4.5 in. 12.6 oof 1-55 II -45 Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 No. 218527 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: _ Waldrop _. Cross Section for Joint 57.1 at depth 1,805.729 ft. T-1 n--- A - A7 Pipe Nom.OD Weight Grade & Thread 3.5 in. 9.3 ppf J-55 I34S 10 8 6 4 2 0 Penetration (% wall) 0 to 20 to 40 to over 20% 40% 85% 85% Damage Configuration (body) 10 6 6 Nom.ID Top Depth Bottom Depth 2.992 in. 7,513 h. 7,777 ft. Damage Profile (% wall) Penetration body MM Metal loss body 0 50 X100 1 1 1 1 GLM 1 (12:00) CASED HOLE Body Region Analysis Well: 1 B-09 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf J-55 IJ -4S Analyst: Waldrop Pipe Nom.OD Weight Grade & Thread 3.5 in. 9.3 ppf J-55 I34S 10 8 6 4 2 0 Penetration (% wall) 0 to 20 to 40 to over 20% 40% 85% 85% Damage Configuration (body) 10 6 6 Nom.ID Top Depth Bottom Depth 2.992 in. 7,513 h. 7,777 ft. Damage Profile (% wall) Penetration body MM Metal loss body 0 50 X100 1 1 1 1 GLM 1 (12:00) Well- 1 B-09 Field: Kuparuk Company:_ ConocoPhilips AIS Pipe Description 3.5 in. 9.3 ppf 1-55 IJ -4S CASED HOLE Joint Tabulation Sheet Survey Date: September 8, 2019 Analyst: Waldrop Nom. ID 2.992 in. i Wall Top Depth Bottom Depth 4 in. 7,513 ft. 7,777 ft. Penetration Body Metal Loss Body Page 1 CASED HOLE Well: 1 B-09 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 No. 218527 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: _ Waldrop Cross Section for Joint 2 at depth 7,576.070 ft. Tool speed = 50 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 98% Tool deviation = 35° Finger = 6 Penetration= 0.065 in. Line of Pits 0.07 in = 26% Wall Penetration HIGH SIDE= UP KUP )NJ WELLNAME 115-09 WELLBORE 16.09 ConoCoPhillips Well AttribUt" Max Angle S MD TD Firm Nene Wellbore APVUWI WNIMre status nN (') MD IhNB) net BIT Ines) Alaska, Inc. KUPARUK RIVER UNIT SOp292065500 INJ 733 8,350.00 8.5w0 CanmalR Mffi(ppml DN Anrrobnm FM greenKB43ed MIRID RNeaee Dab SSSV:WRDP Lest wO: 512/1995 31.99 11/1011981 teae.mvmleaz>.aa4 Last Tag v.muel+cremmk(stua0 MM&bn evitinian 1 EneoW 1 Weltlue Leet Mee BY LSI T.e Fee 8,3]101/32019 1B4j9 i Inergusp Last Rev Reason HeNOER; RA9 Mnoletvm1 EMOW WNIMrt BY Rev Reason: SMA -1 Injenign valve ]/142019 ji.. hrguAPsp _-.- Ino.Strings _.. CYiq Poaniption OD(in) ID(n) Top IftKB) Set Depb(KKB) 9M De Re 1TVD1...NRILen K..Gede Top TMeW CONDUCTOR 20 18.94 29D 80.0 80.0 91.50 H-00 WEIIBED C.RKDenienei0oO IDgn) Top(fee Ii5.Innet.enI eet.ie('V.).. WBLen ll._Grada -PTbea1 SURFACE 133/8 12.35 285 2,486.1 $235.2 R.00 L$0 BUTT CONDDLTOR; iA.DB0.0 Came DmoliewODINq /OMI TOP IRKS) Sal Dep'n TereI 9M..Per II .. IYBLen 11...Braea TOPTltnal PRODUCTION 9518 8.85 244 8,518.9 6,WD7 4TW L-80 BTC F.f lrpnlbn IPPLE. 8 tegge Tubing Strings TuIng DeaarI7 strim Me...ID( TUBINGWO 412 3.96 Tap lnKB) 24.9 $et ce em M.. 8,113fi set cer (/VDI L.. 8.5198 WI(Iwt1 IN 12(5 mage 155 TovCmMClbn IJJS 45x35x2.8(5 Completion Detalls TopnWD) TeeLCI Naninel KKE) r) 1. Dee Gan 10 (in) Top MB) M 24.9 24.9 TM HANGER FMC GEN II HANGER 4.500 suRFAw;msalm+ 1,]1].9 95 NIPPLE CAMCO 08 NO GO LANDING NIPPLE 3813 ], 1 .3 6, 55.0 .2] XO Retludng R VER Sx 5 5 8,722.7 6.223.3 3].3 NIPPLE CAM W-1 SELECTIVE IANDIN NIPPLE ],]31.0 6,229.8 38.01 PER BAKER PER W 10' STROKE 3.000 7745.1 4240.9 38.14 PACKER BAKER FH RETRIEVABLE PACKER 3.000 cas uFr; T.m.a ],83fi.0 6,312.0 3928 BLASTJi3 STEEL BLAST JOINTS(OAL-90.99') 2.982 7,945.1 6,395.2 41.11 SLEEVE -O BAKER; CMU SS .1 CAMEO W-1 SELECTIVE PROFILE- PEN 2.812 1tB2m1 N1PPLE.7=7 7,950.1 6,405.0 4132 SEALASSY BAKER EBW22 ANCHOR SEAL ASSEMBLY 3000 7,958.5 6,405.3 41.33 PACKER BAKER DB PERMENANT PACKER 6.750 PBR, T}070 PACKER,T.ie5.1 , . 6, LA ]3 41.]] BTJTS STEEL BLAST JOINT (DAL= 29 6,OBZd 6, .1 6281 S(EEVE-C BAKER; CMU GS w/CAM ODNO GO PROFILE- LOSEO 2.750 918200( 8,08 .3 6,495. 2.9 SEAL MY SY BAKERLOCATOR SEALASSEMBLY 0 W37 6,49].5 4 3 PA KER BAKER OB PERMENANT PACKER -71EV 1WEcT0K(7ro.( 8,086.6 8.500.2 43.05 SBE BAKER SEAL BORE EXTENSION 3250 8, 1.0 6,503.4 43.11 XO Redudng CROSSOVER 3.5 x 2.875 2875 8,101.( 8,511.2 4325 NIPPLE OTIS XN NIPPLE 2250 _I 8,T12.81 6,519.31 4344 SOS JBAKERSHEAROUTSUB 2441 _ RPERF; Tp20D(.Ke 0 Cemm1; J,B31.OflKB B1 § Other In Hole (Wireline retrievable pi a, valves, pumps, fish, etc.) T.pRKB) Tmp ) (ne.) TWIMI VI Gs Corn Run Dab ID In) 1,800.0 1]R3 38.93 A-1 lnedion 3.01"D6 LOCK WI A-11NJ VLV SERIAL 4NA03-0554 ]162019 1000 V¢Iv¢ 1".FAN, GAL=40') sOZ:]S<D]9f00- Perforations 6Slots 9Mt BLEEVEO', ]9181 rop R 1m Bmo) DbY IBtMMt T (118.1 Bbn MKB) (6X3))S) RTKO' new ) Can BE.PAER T96et PncKER: 7.956,5 7,828.0 ),908.0 6,305) (TD,Uel,.Zor. 8,365.6 UNI O,C-0, C- YL1995 3, 22,10-09 ET`PeRF 5.0 RPERF 510 HyperJe1 ;60 tle9. 7,9 0 J,9 0.0 .1 , 609 A 9944/ 6,3688 22fl OA SOZ Squeed ]8194 §q,Je m ],J.O ,0 416. , 6,43].821,UNIT-BI B UY1 1.0 RPERF 4.5'48HypaJm 11;135 tleg -09 INJECTIOR 1..3 RPERF:(W3D8 GmeM: >,9]6.ONKB .n. 8,203.0 8,207.0 SUDS 6,586.7 A-5, IB -D) SWIM 40 RPERF .6"4 Cuhn,- in deg. CCW. 8,207.0 0,221.0 6,586.7 6,596.6 AJ, IB -D) 52/1995 8.0 RPERF 4.5"43CBHU4e Re; 1n tlp. CCW. 8,226.0 8,229.0 6.600.1 1 8,6022 A-4.IB-D) 5211995 4.0 RPERF 4.5' 3CBHUIve Pe', UJ tlm. CCW. e"e'P 8,2$.0 6,fi022 4634.5 AJ, iB-09 e"en5 4.0 RPERF 4.543C """'Icep- 173 SLEEV C. a¢Bi.4 deg. CCW. Cement Squeezes SEnlnssv: B.ana Top Irv.) .1. nYD) PAfA¢R .Bc emi. Tm (RKB) Wrr ("% VIKS) (Real, Dee SWI. cam ].9(8.0 8.002.0 8.418.4 8.0318 Cemen15queeze 11/14/199 BdAimervasinitre ysqueezetl w/SS DDI CIess 4 8.834.0 8,010.0 8,310.4 8,388.] Cement Squeeze 11/14/199 Bahinlervels sRueeredM eplX. Non 11-049 4 MPP1e: e.,Dv Mandrel Inserts IR .6 1 808:8112.8 lbennID) N Tip Mea) 1RI(el NIM Ills, Pat She Make Mime!ODIM) Sea Type T In) TRDRun Ki Run DYe Com 8,6A. 87. Neco MMD, 1 i2 GAS LIFT DMY RK 0. 0. 1 017 77 J 6, 806 AM M INJ GUY RK . 0 .0 9 2 01 Etl Pkg; 4 00 RPERF.8A].08,M1.0� 3 7,974.3 449.1 CPMCO MMG 112 INJ HFCV RK 0.186 00 fi/182013 RPERF:"rin'"91 o- Notes: General &Safety Ena gab MmN RPERF: 8.SM.o M0- 9�2�1 NOTE: SUSPECT GLM EROSION AT 7891; HAD TO RUN EXTENDED PACKING ON t 5" DUMMY VALVE EX KPERIF II,RB.DB.Z .- 8IN200 NTE: VIewS emaNc el AbBke ScnB111BNc9.0 PRODUCTION;WeJi.5188- CASING /TUBING / LINER DETAIL 4-1/2"X3.112"x2-7/8"SelectiveSinoleComnletion ARCO Alaska, Inc. Subsidiary o1 Atlantic RlchFlald Company WELL: 1B-09 KRU DATE: 516/95 1 OF 2 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH CAMCO 3.1/2" X 1.1/2" MMG, 48/64" Check, RK latch, 5.968"OD, 2.920"ID 8.39 TOPS RKBtoTublng Head Flange - Parker Ri #141 24.84 5.63 FMC Gen 11, 4-1/2" Tbg H r, 2.72' B X P pup, 5-3/4" LH ACME land the 4.13 24.84 1 JT 4-1/2", 12.75#, J-55, IJ -4S Tubing 28.21 28.97. Space Out Pus 11.90' / 5.73' / 3.76' 21.39 57.18 56 JTS 4-1/2", 12.75#, J-55, IJ -4S Tubing 1716.64 78.57 Pup Joint, 4-1/2" Tubing, L-80 5.60 1795.21 NIPPLE CAMCO 4-1/2" DB No -Go Landing Nipple, 5.260" OD, 3.813" ID 1.55 1800.81 CAMCO 4-1/2" Flow Coupling, 4.940" OD, 3.833" ID 5.46 1602.36 186 JTS 4-1/2". 12.75#. J-55. IJ -4S Tubino 5705.46 1807.82 5 JTS 1 3-1/2". 9.3#. L-80. ABM-EUE Pup Joint, 3-1/2" Tubing, L-80 6.11 7671.17 GLM #3 CAMCO 3.1/2" X 1.1/2" MMG, 48/64" Check, RK latch, 5.968"OD, 2.920"ID 8.39 7677.28 Pup Joint, 3-1/2" Tubing, L-80 5.63 7685.67 1 JT 3-1/2" 9.3#, L-80, ABM-EUE, Tubing 31.38 7691.30 CAMCO 3-1/2" W-1 Selective Landing Nipple, 4.500"00, 2.812"ID 2.25 7722.68 Pup Joint, 3-1/2" Tubing, L-80 6.05 7724.93 BAKER 80-40 PBR, 10' stroke, 8-1/8"OD scoop guide on top, 14.09 7730.98 PBR/Pkr 5-1/16"OD Barrel, 4" Seal Bore, 3" ID Sheared L includes 0,41' Space Out BAKER 'FH' Retr. Pkr, 600 pull or rot. release, 8.218"OD, 3"ID 8.12 7745.07 1 JT 3.1/2", 9.3#, L-80, ABM-EUE, Tubing 31.33 7753.19 Pup Joint, 3-1/2" Tubing, L-80 6.11 7784.52 GLM #2 CAMCO 3-1/2" X 1-1/2" MMG, DV, RK latch, 5.968"OD, 2.9201D 8.39 7790.63 Pup Joint, 3-1/2" Tubing, L-80 5.63 7799,02 1 JT 3-1/2", 9.3#, L-80, ABM-EUE, Tubing 31.35 7804.65 5 SBJs Steel Blast Joints, 3-1/2" ABM-EUE, L-80, 4.5"OD, 2.992"ID 98.99 7836.00 Pup Joint, 3-1/2" Tubing, L-80 10.03 7934.99 SLEEVE BAKER 3-1/2" CMU Silding Sleeve, 2.812" W-1 Profile,4.50"OD Closed 4.92 7945.02 Pup Joint, 3-1/2" Tubing, L-80 8.10 7949.94 BAKER 'EBH-22' Anchor / Seal Assembly, 6" OD 3" ID 0.40 7958.04 DP Pkr BAKER 'DB' Permanent Pkr, 8.125"OD, 4.75" ID Set on DP 5/5/95 3.65 7958.44 Pup Joint, 3-112" Tubing, L-80 6.04 7962.09 Pup Joint, 3-1/2" Tubing, L-80 6.11 7968.13 GLM#1 CAMCO 3-1/2" X 1-1/2" MMG, DV, RK latch, 5.968"OD, 2.920"ID 8.39 7974.24 Pup Joint, 3-1/2" Tubing, L-80 3.62 7982.63 2 SBJs Steel Blast Joints, 3-1/2" ABM-EUE, L-80, 4.5"OD, 2.992"ID 39.60 7986.25 Continued on Pae 2 8025.85 Remarks: String Weights with Blocks: 75K# Up, 44K# Down, 60 Blocks. Re -Ran 243 joints of 4-1/2" tubing. Ran 9 joints of 3-12" L-80 tubing Drifted 4-1/2" tubing & hanger with 3.833" plastic rabbit. Drifted 3-1/2" tubing, GLMs, & SBJs with 2.867" plastic rabbit.Used Arctic Grade API Modified No Lead thread compound on all connections. Top of PBR has internal 4-1/2" RH square thread for packer retrieval. Alignment pin on FMC Tubina Head Is back -seated & frozen In place, alioned hanger manually. 12 Lockdown { CASING / TUBING / LINER DETAIL 4-112"X3-112" X 2.7/8" Sefecflve Sinale Comnleiion WELL: 1113-09 KRU ARCO Alaska, Inc. DATE: 5/6/95 Subsidiary of Atlantic Richtleld Company 2 OF 2 PAGES # ITEMS COMPLETE DESCRIPTION OF EOUIPMENT RUN LENGTH DEPTH TOPS 1 JT 3-1/2", 9.3#, L-80, ABM-EUE, Tubing 31.45 8025.85 Pup Joint, 3-1/2" Tubing, L-80 10.03 8057.30 SLEEVE BAKER 3-1/2' CMU Sliding Sleeve, 2.750" D No -Go Profile,4.50"01)(Closed 3.80 8067.33 Pup Joint, 3-1/2" Tubing, L-80 10.10 8071.13 BAKER Crossover to 2-7/8" / Locator GBH -22 Loc Seal Assv, 7.46' L 1.68 8081.23 Spaced Locator in neutral at top of Packer a=>> _ 8082.91 of Packer BAKER 'DB' Permanent Packer, 8.125"OD, 3.2501D 3.69 8082.91 i BAKER Seal Bore Extension, 3.250"ID 4.35 8086.60 BAKER XO, SBE X 2-78" EUE 0.66 8090.95 Pup Joint, 2-7/8", 6.5#, L-80, EUE Tubing 10.06 8091.61 OTIS 2-7/8" XN Nipple, 2.313" packing bore, 2.250" No Go 1.09 8101.67 Pup Joint, 2-718", 6.5#, L-80, EUE Tubing 10.03 8102.76 BAKER 2-7/8" Shear Out Sub Sheared 0.77 8112.79 Bottom of Tubino Tail == 8113.56 Remarks: 7828' to 7910' ELM I 'Cl' Perf Interval (New & Old): 7973' to 8002' ELM (29') 'A' Perf Interval fNew & Old): 8203' to 8275' ELM Top of Fish (Slickline Too] String) @ 8405' DPM Nordic Rig #t Drilling Supervisor: Don E Breeden & Don McKelvey Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: p/ AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 181134 TRANSMIITALDATE TRANSMITTAL# IR Name Signature Please return via courier or sign/scan and email a copy / Transmittal Receipt signature confirms that a package (box 'J . TZ b( / envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this !r and CPA]. point. SLB Auditor 1 Sch I u m be rge r -Private r 0 • 1-] rn L 1 U+ WN¢ c ~ > ^o c x N cL ONw -o > E L �p (" cn J�: . a.) Ln O +, 3 r Q\Y no a• @ > l <(ro co 4,7 v v O " u a+ > 0 e- r .- r a O v O LI a` ° a) a-' CD W ra O 76 a �n 7 ( L u Q (J p Q 0 r- r- n r r r T er- a� p Os m Q Q a� ai o) of a� a� a> $ a a a 7 3 7 7 7 7 7 -O N Ln W Q Q Q Q Q Q Q fn fA N „, C u L v C VI ~ ,- N N N N M M M (A O _6 r, C Y N Z 0 E \ U Z a .> -C v Q F- O O G OG F" 4-, u '-' ra O F- ra a) -0 U ❑ 0000000000 C L ❑ w a J J J J J J J J J J C y- O y WWLUWUJWWWWWW V) (1,) 'C F 0. 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Q Wz000000000 Ura CC w O ^ 4..0 0 0 0 0 0 0 0 0 0 0 ' OU f6 CD 0 0 0 0 E Y 0 0 0 0 0 0 0 3 vi Q a O .- M ,-(0 N N 0 CO00 n (00 CO00 N in Na n'1 N M N CO (0 CO T' in (0 (0 N N N N N N N N N N N N inL 0) 0) 0) 0) 0) 0) 0) 0) w 0) 0) C o a NNNNNNNNNNN CO u 0 �j 0 0 0 0 0 0 0 0 0 0 0 L O U "' 0 0 0 0 0 0 0 0 0 0 0 a+ w C O C. oo C in N in in N u (n(n (n7 in in d a, O C QI H C E y - a CO ., 'L N -a 2▪ •a Z Ql O a O 0 .— 00 `- N N O O O O � E .O al aJ W Y Q. rrl Z — r o E N a, T, = Ec r` _F W C'1 Y Y Y ti = m m E Z v CI- Q O N (J M M M M r IA yi O O 00 ‘..= r-i U 3 C c y E E F0 L O N5 a to Cil F- a` — F • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 03,2017 TO: Jim Regg P.I.Supervisor 51,(t(7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-09 FROM: Lou Laubenstein KUPARUK RIV UNIT 1B-09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1B-09 API Well Number 50-029-20655-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-134-0 Inspection Date: 4/22/2017 Insp Num: mitLOLl70423071532 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1B-09 Type Inj W TVD 6241 - Tubing 1077 1061 - 1057 - 1053 - 1050 - PTD 1811340 Type Test SPT Test psi 1560 IA 520 1850 . 1825 - 1810 - 1805 - BBL Pumped: 3 - BBL Returned: 2 OA 185 200 200 - 200 - 200 Interval 4YRTST P/F P Notes: SGANNE® AUG 2 4 2'017, Wednesday,May 03,2017 Page 1 of 1 (6( 154o Regg, James B (DOA) From: CPF1 Prod Engr <n1269@conocophillips.com> Sent: Thursday, April 13, 2017 2:14 PM To: Regg, James B (DOA) Cc: NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF1 Ops Supv; CPF1 DS Lead Techs; Targac, Gary; Glessner, Dana; CPF1 DS Operators; NSK Prod Engr Specialist; NSK Optimization Engr; NSK Well Integrity Supv CPF1 and 2 Subject: LPP/SSV Return to Service on 1 B-09 Jim, CPF1 Operations will be performing maintenance on the produced water injection header to Drill Site 16 starting April 24, 2017 until roughly the end of August of 2017. As part of preparation for the project, the CFW injector 1B-09 was blinded from the produced water header on April 12th, 2017. Operations was able to make a seasonal adjustment on the CFW discharge pump(reduced rate) in order to restore the low pressure pilot(LPP) on 1B-09 (PTD#181-134) and the LPP was returned to service today,4/13/17, with a pilot setting of 700 psig. The well is currently stable at a wellhead pressure of 1300 psi and rate at 2200 BWPn. The well has been removed from the "Facility Defeated Safety Device Log". This notification is in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Thank you, Courtney Gallo/ Mitch Autrey CPF1 Production Engineer Office: (907) 659-7493 Cell: (720) 318-5762 WANED EP1 5 7 O1 r 1 • • Regg, James B (DOA) From: CPF1 Prod Engr <n1269@conocophillips.com> Sent: Wednesday, April 12, 2017 3:02 PM To: Regg,James B (DOA); NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF1 Ops Supv; CPF1 DS Lead Techs; CPF1 Prod Engr; CPF1 DS Operators; NSK Prod Engr Specialist; NSK Optimization Engr; Targac, Gary; NSK Well Integrity Supv CPF1 and 2; CPF1 Control Room; NSK West Sak Prod Engr Subject: Defeat LPP/SSV on 1 B-09 CFW Injector Jim, CPF1 Operations will be performing maintenance on the produced water injection header to Drill Site 1B starting April 24, 2017. This requires us to de-pressure and de-inventory the water injection flowline to DS1B. As part of preparation for the shutdown we would like to blind our CFW injector, 1B-09 (PTD#181-134), from the produced water header today April 12th, 2017. From now and for the duration of the shutdown, our CFW injector 1B-09 will remain online with the low pressure pilot (LPP) defeated due to pressure fluctuations while doing flow line maintenance.The LPP and surface safety valves (SSV) have been tagged and the well is recorded in the "Facility Defeated Safety Device Log."The AOGCC will be notified when the LPP/SSV function for this well is returned to normal, in accordance with "Administrative Approval No. CO 432D.009." Thank you for your assistance, and let me know if you have any questions. Regards, Mitch Autrey / Courtney Gallo CPF1 Production Engineer ConocoPhillips Alaska Office : (907) 659 7493 Voicepage: (907) 659 7000 #765 N1269@conocophillips.corn 1 cbl- k34 •AttocttiVet • -� , 410 7 agi WELL LOG TRANSMITTAL#903262433 Annntl To: Alaska Oil and Gas Conservation Comm. May 11, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED S hlti2oiv Anchorage, Alaska 99501 RA.K BENDER RE: Multi Finger Caliper: 1B-09 Run Date: 4/21/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1B-09 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20655-00 Multi Finger Caliper(Field Log) 1 color log 50-029-20655-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. SCANNED Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / - / 1324 WELL WELL LOG TRANSMITTAL DATA LOGGED (./2./2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 :w '' 0 1 ; RE: Multi Finger Caliper(MFC) : 1B-09 Run Date: 4/30/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1B-09 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20655-00 SCANNED JUN 1 2 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC @halliburton.com Date: Signed: MALL-014%-.1) ��;,k; WELL LOG TRANSMITTAL may 1 0 2013 AOG CC To: Alaska Oil and Gas Conservation Comm. April 29, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • -22.5 ,0 RE: WRP Setting Record: 1B-09 7..., Run Date: 4/26/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 matthew.cook@halliburton.com 1B-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20655-00 SCANNED MAR 1 3 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: SI \Cp113 Signed: • 1 a[F „,. u nn /SEAN PARNELL, GOVERNOR lit Li iL CONSERVATION ls COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 February 16, 2012 Ms. Wendy Mahan Environmental Coordinator ConocoPhillips Alaska Inc. 5tAketED FEB 1 7 LU Z P.O. Box 196105 Anchorage, AK 99519 -6105 Re: Photo Processor Fluid Injection Kuparuk River Unit 1B-09 (PTD 1811340) Dear Ms. Mahan: The Alaska Oil and Gas Conservation Commission (AOGCC) sent ConocoPhillips Alaska Inc. (CPAI) a notice of investigation on September 10, 2010 regarding the potential misinjection of photo processor fluid in Kuparuk River Unit (KRU) 1B -09, an enhanced recovery injection well. The AOGCC notice followed a self disclosure of the potential misinjection reported by CPAI on July 15, 2010. The AOGCC letter requested information to help characterize the potential misinjection, including handling of waste and enhanced recovery injection streams at KRU Central Processing Facility #1. A letter from CPAI dated October 11, 2010 responded to the AOGCC notice. Documentation provided by CPAI serves as the basis for AOGCC to deem this investigation closed. Used photo processor fluid is passed through multiple filters to remove silver from the waste stream, generating an effluent stream that is below the Resource Conservation Recover Act limit. This filtration occurs at the Kuparuk Waste Water Treatment Plant. The filtered stream is then commingled with other waste water generated throughout the Kuparuk River Unit, which is eventually pumped to enhanced oil recovery injection wells located on KRU 1B pad. Results from sample tests performed on July 13, 2010 using an EPA - approved test kit revealed that the photo processor fluid had bypassed the filters. Investigation by CPAI following the laboratory analysis of testing performed on July 13, 2010 determined that the use of valves in the flow path of the photo processor fluid allowed for bypassing the filters. Corrective actions immediately taken by CPAI included disabling the bypass valves, labeling them as out -of- service, and revising the filter change procedure to use shut -off valves that prevent flow through the system. Before and after photographs of the bypass and shut -off valves were provided by CPAI with the October 11, 2010 response confirming the corrective actions have been implemented. The CPAI investigation further indicated that not more than 60 gallons total of unfiltered photo processor fluid bypassed the filters from July 4 through July 13, 2010, diluted by an average • Photo Processor Fluid Injection February 16, 2012 Page 2 of 2 waste water stream volume of 110,000 gallons per day, yielding a silver concentration far below hazardous levels. AOGCC review indicates the misinjection will have no negative impact to the enhanced oil recovery performance because of the dilution achieved by mixing the photo processing solution with the normal water injection stream. Sincerely, 4, or Daniel T. Seamount, Jr. Chair, Commissioner • MEMORANDUM TO: Jim Regg Q P.I. Supervisor 7)eef 01i MEMORANDUM TO: Jim Regg P.I. Supervisor 1 ey FROM: Jeff Jones Petroleum Inspector bl14Z'Xz, NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IB -09 KUPARUKRIV UNIT 1B-09 Src: Inspector Well Name KUPARUK RIV UNIT 1B-09 API Well Number 50-029-20655-00-00 Inspector Name: Jeff Jones Permit Number: 181-134-0 Inspection Date: 6/29/2021 Insp Num: mitJJ210701112116 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB -09 (Type Inj W TVD - - PTD 1811340 Type Test SPT Test psi 6241 1560 Tubing IA 1990 - 500 z000� 2000 _ 2600 2490 - 1990 - 2440, BBL Pumped: 43 BBL Returned: 4.1 OA 420 515. 500 - 500 Interval 1 Four Year Cycle — P/F Pass Notes: I well inspected, no exceptions noted. Inspector requested operator to retest the well. Previous MIT early (Apr 2017) due to water header modifications in May 2017. Wednesday, August 11, 2021 Page 1 of 1 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 VINIW JUL 080 Commissioner Dan Seamount 't Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 , r . ;.;3a5. ;'Aw6,:� sman Anchorage, AK 99501 �. :.. ' 3 Li- Commissioner Dan Seamount: t o 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 on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. 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 L veland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y 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 1A -03 50029206150000 1810880 16" N/A 23" N/A 1.7 6/20/2011 1A -04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B -04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21/2011 18-05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 18-07 50029206160000 1810890 72" 1.00 22" 5/9/2011 2.5 6/21/2011 1B-08A i 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1B-09 50029206550000 1811340 SF N/A 23" N/A 5 6/20/2011 1B -10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 1B-12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/2112011 6/21/2011 18-101 50029231730000 2031330 3" N/A 22" N/A 1.7 18-102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 1.7 6/21/2011 1E-05 50029204790000 1800580 19" N/A 19" N/A 1.7 6/19/2011 1E-22 50029208840000 _ 1822140 _ 14" 1.75 17" 3/21 /2011 _ 1.7 6/19/2011 1E-23 50029208580000 1821840 58' _ 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 _ 155" 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L -16 50029212020000 1841810 14'9" 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y -02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 • MEMORANDUM To: Jim Regg P.I. Supervisor ~C~d~p 7(Z~'(~~ ~~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-09 KUPARUK RIV LTNIT 18-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv '~~~ Comm Well Name: KUPARiJK RIV LJNIT 1B-09 Insp Num: miUJ090706091538 Rel Insp Num: API Well Number: 50-029-20655-00-00 permit Number: 181-134-0 Inspector Name: JeffJones Inspection Date: 6/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 1B-09 Type Inj. W T'~ 6240 jA 920 2600 ~ 2500 2460 ~ P.T.D 1811340 TypeTest SPT Test psi isoo . pA ao so so so Interval a~TSr p~ r .~ Tubing 19~o i9so i9as i96o NOtes: 3.7 BBLS diesel pumped. 2nd MIT, well not fluid packed for previous test. 1 well inspected, one exception noted: well head adapter lock ~ downs are leaking, Mr. Colee will address this item. ~r . i ~ ' ~~it~ .'~ t~' ~ a.~. ,,:a ,~ i ~ _ , . ,. ~« Monday, July 06, 2009 Page 1 of 1 • MEMORANDUM To: Jim Regg ~~~ 7~Z~~0 ( P.I. Supervisor FROM: Jeff Jones Petroleum Inspector r~ L_J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHII,LIPS ALASKA INC 1 B-09 KUPARLJK RIV UNI'C 1B-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv,~/'/~ Comm Well Name: KUPARUK RIV iJNIT 1B-09 Insp Num: miUJ090706092030 Rel Insp Num: API Well Number: 50-029-20655-00-00 Inspector Name: ~effJones Permit Number: 181-134-0 Inspection Date: 6/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 1B-09 Type Inj. W T~ 6240 jA 540 1300 P.T+.D 1811340 TypeTest SPT Test psi 1560 QA 80 Interval 4~TST p/F F ~/ Tubing 2~so NOtes• 10 BBLS diesel pumped, well not properly prepazed for MIT (fluid packed), did not pressure up. i t~ 1^~'' ' C ~. {+ `:: ,.~ '~S. t 1 ~;, ~_ l1 . , Monday, July 06, 2009 Page 1 of 1 12/30/08 ---4C-•~ ~- ~~ ~.>~- ,~ ~h~~~b~r~~~e~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ ~ i~~ti ~ n [~ ~ Well Job # Log Description 2U-03 12080460 INJECTION PROFILE "~' Qj 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE - 12/07/08 1 1 1 C-11 12114998 PRODUCTION PROFILE ~} a 12/14/08 1 1 i D-07 12114999 USIT -'T ~ a 12/15/08 1 1 B-09 12115001 INJECTION PROFILE L ~ 12/18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP 12/19/08 1 1 iC-18 12100472 INJECTION PROFILE (' 12/21/08 1 1 1E-21 12115005 INJECTION PROFILE p 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE (~ 3 12/24!08 1 1 i ~~~- N0.5024 Company: Alaska Oil' & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD s ~~ ~J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 ~",.~.....". {L 12/19/06 NO. 4077 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk . Date BL Color CD Sc~lulllbepger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth U"JJl 1751- t34 Well Job# Log Description 1 R-03A (REDO) 11483497 INJECTION PROFILE 11/30/06 1 1 B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1 F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12/08/06 1 1J-136 11534188 USIT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1F-10 11534192 INJECTION PROFILE 12/12/06 1 1Y -27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A SBHP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1 F-05 N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1 H-14 11551835 SBHP SURVEY 12/18/06 1 .. Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . lVlll - l'\...l'\.U lU-V7 . e MIT was witnessed by Inspector 6/17/2006 - his report is attached. Should the injection rate change during a test in the future as it appears to have done during this test, please hold the pressure an additional 15- 30 minutes and provide an explanation of the pressure change. There is no need to retest at this time. Jim Regg AOGCC Content-Type: application/pdf MIT KRU 1B-09 2006-0617.pdf C . b 64 ontent-Encodmg: ase ':-, .', '. 1 of 1 7/25/20064:37 PM ¿ MEMORANDUM e . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Tuesday, July 25, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 1B-09 KUPARUK RlV UNIT 1B-09 FROM: John Spaulding Petroleum Inspector Src: Inspector \ ~ \ ' ,;3 Y- NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 18-09 API Well Number: 50-029-20655-00-00 Inspector Name: John Spaulding Insp Num: miDS060620070038 Permit Number: 181-134-0 Inspection Date 6/17/2006 Rei Insp Num: MITOPOOOOO 1176 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1B-09 ¡Type Inj. i w ITVD ! 6241 I IA 430 1700 1660 1660 I ! I ì I I i i I P.T.Di 1811340 !TypeTest I SPT I Test psi 156025 OA I 40 I 40 40 I 40 I I I I I Tubing : 970 i 970 1500 I 1500 i Interval Four Year Cycle PIF Pass I I ---L-_ Notes: This is the camp water disposal well, apparently injection was ramped up part way thru the test. Does this need to be retested. 11. 8 diesel c...., ¡1 e/·.A.£è f l +0 /rlfe ; £;\)t- U Ì7' :ke,I"""- _-(~ Xi {tt-"t)\...d- MD/¿( -hie¡¿ "..- Di'es S ¿titS I'-V" tct: ! Lfì~~ r\, .!. 4 . "- ./"" i 'L.." è... .' .- JV . '- L~lVl C)Li..'/\ ---tV'-!-. '-~" '"'j. ì i.~! ~.Lk ..' 'J~ [;/-:;,,, LC.J'\.?'j .-r?r '......;. , J~1·t4~ .. f Tuesday, July 25, 2006 Page I of 1 ( (IS1-13i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU /1 B DATE: 01/31/04 OPERATOR REP: Rogers -APC AOGCC REP: S 0 P P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-0131_MIT_KRU_1B-09.xls ~CANNED FEB 0 3 2004. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor~ Chairman DATE: June 16, 2002 THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips 1 B Pad KRU Kuparuk Packer Depth Pretest Initial 15 Min. 30 Min. I I mypelnj. I F I T.V.D. I 6109 I Tubingl 1450 I 1450 I 1450 I 1450 I lntervall 4 I WellI 1B-02 ITypetestl P ITestpsil 1527 I Casingl 150 I 1980 I 1930 I 1920I P/F I P] P.T.D.I 181-133 _ Notes: we,,I ~B-O~ I Type,nJ.I F I T.V.D. I~,o I Tu~,ngl,,00 I~00 I~00 I~,00 I,n,e~,l ~ P.T.D.I 181-065 ITypetestl P I Testpsil 1545 ICasingI 550 I 20501 20501 20501 P/F I P Notes: we,,I ,,-o~ I~,,e,.J.I , I ~.V.D. I~,, I Tubingl~00 I~ ~00 I~00 I~00 I,nte~v~,l 4 P.T.D.I 177-001 ITypetestl P ITestpsil 1585 I CasingI 250 I 20001 1950 I 19251 P/F I --P Notes: I Type,nj.I F I T.V.D. I~ I Tub,ng12350 12350 12350 12350 I,nterva, I 4 I WellI 1B-07 ITypetestl P ITestpsil 1557 1CasingI 1000 I 1950 I 1920 I 1920 I P/F I PI P.T.D.I 181-089 _ Notes: WellI 1B-08 I Typelnj. I F I T.V.D. I 4837 I Tubing I 2500 I 2500 I 2500 I 2500 l intervall 4 I P.T.D.I 197-112 ITypetestl P ITestpsil 1209 I CasingI 0 I 20501 20001 20001 P/F I P I Notes: We,,I ,,-o~ I~,,e,nJ.I , I ~.v.g. I~0~ I~uml~00 I~00 I~00 I~00 I,nterva, I4 P.T.D.I 181-134 ITypetestl P I TestpsiI 1527 I CasingI 550 I 2025 I 20001 2000 I P/FI P Notes: we,,I ,B-~2 I Ty,e,nJ.I , I T.V.D. I~0~, I Tu~,ngl,,,0 I~0 I,~0 I ,~o I,nterv~,l ~ P.T.D.I 193-061 ITypetestl P I Testpsil 1524 I CasingI 0 I 2100 I 20501 20501 P/F I --P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ, G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips lB Pad in the Kuparuk River Field and witnessed the routine 4 year MITs on the above 7 wells. The pretest tubing and casing pressures on all wells was observed and found to be stable. The standard annulus pressure tests were then performed with all 7 wells demonstrating good mechanical integrity. ~.l.T.'s performed: 7 Attachments: Number of Failures: 0 Total Time during tests: 4 Hours cc.' MIT report form 5/12/00 L.G. MIT KRU 1B Pad 6-16-02 CS.xls 6/20/2002 ARCO Alaska, Inc. t (.....~ Post Office Box 1 003bv ~.... Anchorage, Alaska 9951 0-0360 ~., Telephone 907 2761215 ~".. June 6, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: IB-09(Permit No. 81-134) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KR U 1 B- 09. The original single packer completion was pulled and the wellbore was cleaned out. A triple packer completion was re-run for zonal isolation between the 'A', IC' and C2,3,4 sands. Sincerely, ù. .»v.:- ~ . ~~-- W. S. Isaacson Drilling Engineer K uparuk Petroleum Engineering WSI/skad RECEIVED JUN - 7 1995 Alas.Jut .cJd.& Gas Cons Com. . I I ~"ch ,., ... . mISSIon "'" or()l A ,dKA OIL AND GAS CONSERVATION CO .,iSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well O~. r-~ GAS r~ SUSPENDED ~ ABANDONED r-~ SERVK~E ~ WAG INJECTOR 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 81-134 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20655 _.. 4 Location of well at surface 9 Unit or Lease Name 493' FNL, 1462' FEI., Sec 9, T11N, R10E, UM ~ ' Kuparuk River Unit At Top Producing Interval ~ :10 Well Number 1596' FNL, 1582' FEL, Sec.4, T11N, R10E, UM~ i 1B-09 At Total Depth ; 11 Field and Pool 1113' FNL, 1369' FEL, Sec. 4, T11 N, R10E, UM i KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. 93' RKB 66' PADI ADL 25648 ALK 466 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., S usp. or Aband. 115 Water Depth, if offshore 116 No. of Completions Oct. 16, 1981 Oct. 29, 1981 10-Nov-81I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 8550' MD & 6822' TVD 8435'MD & 6744' TVD YES IXl NO I II 1801' feet MD 1650' APPROX 22 Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/GR, CAL, CBL/CClJGR, CBL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 20" 91.5# H-40 Surf 80' 30" 400 sx ASll 13-3/8" 72# L-80 Surf 2486' 17-1/2" 1600 sx Fondu & 400 sx ASII 9-5/8" 47# L-80 Surf 8519' 12-1/4" 2750 sx Class G cmt 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) 4-1/2"x3-1/2" 7514'/8114' 7745 & 7959 & 8083 5 spf 7828' - 7910' M D 6305' - 6369' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 1 spf 7973' - 8002' MD 6416' - 6438' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf 8203' - 8275' M D 6584' - 6634' TVD 1854' - 1856' Arctic Pack job - See Drilling History 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR iOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief descriptiOn of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit tn duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK 7790' 6276' BASE KL~ 8346' 6683' RECEIVED J UN - 7 1995 31. LIST OF A'I-FACHMENTS ~,~o~ ~,, Iz ~1¢l~ bOBS, ~0~JJI].JS~[0JI Workover Activity History~nh .,,,,C,0J.~,~.~ 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~,.¥ ~ ~. ~,,¢,,~.~.,,.._~ Title Dt~l, tr~l~ [~It~.N[E~ DATE ~.e' (.~' O[5 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". Form 10-407 Date: 06/06/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS RECEIVED N - 7 1995 Gas Cons. Commission AIIChOIT ,? WELL: lB-09 WELLID: 998371 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: 998371 TYPE:DEV AFE EST:$ OM/ OM STATE: API NUMBER: START COMP: FINAL: 04/24/95 ( 1) TD: 8550' PB: 8435' SUPV: CJF 04/25/95 (2) TD: 8550' PB: 8435' SUPV:CJF 04/26/95 (3) TD: 8550' PB: 8435' SUPV:CJF 04/27/95 (4) TD: 8550' PB: 8435' SUPV:DB/DCB 04/28/95 (5) TD: 8550' PB: 8435' SUPV:DB/DCB 04/29/95 (6) TD: 8550' PB: 8435' SUPV:DB/DCB 04/30/95 (7) TD: 8550' PB: 8435' SUPV:DB/DCB 05/01/95 (8) TD: 8550' PB: 8435' SUPV:DB/DCB PULL BPV Accept rig @2200 hrs. Prepare site. DAILY:S34,735 CUM:$34,735 ETD:SO EFC:$34,735 SET TEST PLUG IN HANGER MW: 9.1 BRINE Kill well. Set AVA TNE plug in profile in SSSV. DAILY:S41,762 CUM:$76,497 ETD:SO EFC:$76,497 CIRCULATING, PREP TO POH MW: 9.1 NACL/NABR Test BOPE. Fish. Shear plug in SSSV profile. DAILY:S31,762 CUM:$108,259 CBU Fish K anchor. ETD:SO EFC:$108,259 MW: 9.1 NACL/NABR DAILY: $30,700 CUM: $138,959 ETD:SO EFC:$138,959 RIH WITH FTA #3 TO SPEAR PBR BBL MW: 9.1 NACL/NABR POH w/ 3-1/2" DP, FTA %2. Recover metal from junk basket. RIH w/FTA %3 and spear. DAILY:S35,115 CUM:$174,074 ETD:SO EFC:$174,074 CBU MW: 9.1 NACL/NABR RIH with spear and FTA %3. P/U w/fish. DAILY: $30,700 CUM: $204,774 ETD:SO EFC: $204,774 DRILLING CEMENT @ 8050' MW: 9.1 NACL/NABR POH with FTA %4. Jarred & worked fish free at start of trip. LD fish - remnants of packer. Clean out. Drill cement. DAILY: $33,355 CUM: $238,129 ETD:SO EFC:$238,129 WASH SAND@ 8291' MW: 9.1 NACL/NABR Drilling cement f/8050-8136' and from 8128'-8185' · · DAILY: $30,700 CUM: $268,829 ETD:SO EFC: $268,829 Date: 06/06/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT 05/02/95 (9) TD: 8550' PB: 8435' SUPV:DB/DCB 05/03/95 (10) TD: 8550' PB: 8435' SUPV:DEB 05/04/95 (11) TD: 8550' PB: 8435' SUPV:DEB/DRM 05/05/95 (12) TD: 8550' PB: 8435' SUPV:DEB/DRM 05/06/95 (13) TD: 8550' PB: 8435' SUPV:DEB/DRM 05/07/95 (14) TD: 8550' PB: 8435' SUPV:DEB/DRM 05/08/95 (15) DIESEL/SEAWATER TD: 8550' PB: 8435' SUPV: DEB/DRM RD CIRCULAT. LINES-PREP T MW: 9.1 NACL/NABR Wash to 8425'. RIH w/3-1/2" DP to 7689'. DAILY:S68,173 CUM:$337,002 ETD:SO EFC: $337,002 TRANSFER FLUIDS TO WEIGHT MW: 9.1 NACL/NABR Test BOPE. Perforate 'A' and 'C' sands in 8 gun runs. Monitor well, well flowing. Shut in well. DAILY: $30,700 CUM: $367,702 ETD:SO EFC: $367,702 MONITOR WELL FOR FLOW MW:10.0 NACL/NABR Well Shut in. Inject 600 bbls of 10.0 ppg brine into well. Monitor well. DAILY:S66,778 CUM:$434,480 ETD:SO EFC:$434,480 RIH W/'DB' PKR & JEWELRY MW:10.4 NACL/NABR Monitor well. Reverse circulate 3 drillpipe volumes to clean out any remaining perf debris. Shut in well. Well dead. Run 8.40" gauge ring & junk basket to 8112'. POH. Junk basket clean. Set packer @ 8066' ELM. MU completion assembly. DAILY:S84,746 CUM:$519,226 ETD:SO EFC:$519,226 POH W/BAKER HYDRAUL. SET. MW:10.9 NACL/NABR RIH with seal assembly & 3-1/2" tubing & jewelry + Baker 'DB' packer on hydraulic setting tool & bumper sub on 3-1/2" DP. 'DB' Packer set on DP @ 7952' MD. Kill well. DAILY:S65,342 CUM:$584,568 ETD:SO EFC:$584,568 POH W/MA2 PLUG SET. TOOL MW:10.9 NACL/NABR Finish POH with 3-1/2" DP. Found setting tool had stroked properly to set packer. Run 3-1/2" x 4-1/2" completion assembly. Make up MA2 blanking plug, run in hole and set in W-1 nipple @ 7730' SLM. DAILY:S35,871 CUM:$620,439 ETD:SO EFC:$620,439 RIG RELEASED MW: 0.0 Set BPV, OK. Nipple down 13-5/8" BOP stack, nipple up 4-1/8" 5 Ksi FMC Gen II tree. Release rig @ 2030, 5/7/95. DAILY: $164,943 CUM: $785,382 ETD:SO EFC:$785,382 End of WellSummary for We11:998371 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David J o h,..h,..h,..h,..h,.~~, Chairman ~ Blair Wondzell, ~d~ P. I. Supervis.~or_,~ FROM: Bobby Foster,~,"~¢;)'-~ SUBJECT: Petroleum Inspector DATE: May 2, 1995 FILE NO: AAUIEBCD.doc BOPE Test - Nordic #1 ARCO - KRU - CPF 1 Well 1B-9 PTD # 81-0134 Kuparuk River Field Tuesday, May 2, 1995: I traveled this date to ARCO's Kuparuk River well 1B-9 and witnessed the weekly BOPE test. As the AOGCC BOPE Test Report shows there was no failures of the equipment tested. The. only problem I noted on the report was the air powered pump on the accumulator Was not connected to the unit. I requested that this be done ASAP. Shane Mc Geehan, Nordic tooipusher, said he would hook the pump up while on this well. The rig was clean and all equipment seemed to be in good working order. The location was clean and thee was good access to all areas of the rig. Summary: I witnessed the BOPE test on ARCO's KR Field well 1B-9 being worked over by Nordic rig #1- test time 2.5 hours - no failures. Attachmen: AAUIEBCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPR Test Report OPERATION: Drlg:___.__ Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: DATE: 5/2/95 NORDIC Rig No. ~ 81-0134 Rig Ph.# 659-7565 ARCO ALASKA DON BREEDEN I PTD # Rep.: 1B-9 Rig Rep.: SHANE McGEEHAN Set @ 8435' Location: Sec. 9 T. 11.....~N R. 10E Meridian UM Weekly X Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD # YES" Standing Orders Posted YES Well Sign OK Drl. Rig oK Hazard Sec. OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams N / A Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 2 Check Valve N / A Test 300\3500 Pressure P/F 300\3000 P P 300\3500 300\3500 300\3500 300~3500 P MUD SYSTEM: Visual Alarm Trip Tank NONE Pit Level Indicators YES YEs Flow Indicator YEs YES Methane'Gas Det. YES YES H2S Detectors YES YES FLOOR SAFETY VALVES: Quan. Pressure Upper Kelly / IBOP NOTE 300/3500 Lower Kelly / IBOP NOTE 300~3500 Ball Type I I 300/3500 Inside BOP II 300/3500 P/F CHOKE MANIFOLD: No. Valves 11 ! No. Flanges 33 Manual Chokes Hydraulic Chokes Test Pressure 300\3500 30~3500 Functioned Functioned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2 @ 2100 3,000 I P 1,5oo ,P ' minutes sec. minutes 36 sec. yes Remote: yes~ ...... Psig. ,, ,, ,,, ,,, , ,, ,,, ,,,, Number of Failures 0 Test Time 2.50 Hours Number of valves tested 18 Repair Or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Kelly valves tested 4/27/95. NOTE: Air pump is to be hooked up to accumulator ASAP. Distribution: orig-Well File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: v~r~nessed By: BOBBY D. FOSTER FI-021L (Rev. 2/93) AAUIEBCD.XLS MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas ConservatiOn Commission David J o h.,.n.,~~ Chairman ~ Blair Wondzell, d~ P. I. Supervisor 4,f'='/ FROM: L_.o .u G. rimal.di, ~. SUBJECT: l~e[roleum InspecTor DATE: Apdi 25, 1995 FILE NO: AAUJDYCD.DOC BOP test / Rig inspection Nordic rig #1 Arco well #1B-9 PTD # 81-134 Tuesday, April 25, t995: I witnessed the attempted test ofthe BOPE on Nordic rig #1 which was preparing to workover Arco's well #1B-9 in the Kuparuk river field. The test was begun at 0800 hrs and I left location at approximately 2000 hrs. The status when I left was that the Choke manifold had numerous failures and was being worked on to attempt to get the minimum amount of valves alloWable for this equipment in working order. The condition of the Choke manifold indicated that this. equipment is used for routine circulation of well fluids during the workover procedures, and although the valves are greased regularly the wear and tear of the operation's finally caught up and large numbers of failures occurred during this test. The valves on the manifold were not reliable in that some would hold pressure at one point but once they were cycled might not hold pressure again. During the work on the manifold one of the connections on the Choke line started to leak and when the connection was being tightened one of the studs that held the clamps together failed and the connection completely failed. In all, the well control equipment downstream of the HCR valves did not instill confidence in me. The Blind rams' and valves on the mud cross were tested successfully but then the test plug failed and no further tests of the stack were possible. The tubing hanger, was of a peculiar design that was troublesome in getting a test plug to seat and seal in the hanger. More equipment was being rounded up in the hopes of getting a good seal. During the test Don Breden (Arco rep.) Arrived on location and once up to speed I felt confident that i could leave. I requested that once all repairs were made a complete BOP test be performed. Wednesday~ April 267 1995: I spoke with Don Breden this morning and he told me that they had completed a satisfactory BOP test this morning and will be submitting the form to the AOGCC office today. I again conveyed my lack of confidence that I had experienced the previous day and although we did not come to any firm solutions I got the impression that a closer look at the BOPE on this rig will be pursued. AAUJDYCD.DOC (cont.) Recommendations: I strongly recommend a closer frequency of witnessing by the AOGCC Inspectors of this rig on future BOP tests. The complete BOPE should be inspected for out of tolerance conditions (Flange stud and ring groove wear, internal wear and tear of the stack and choke valves including the bodies). SUMMARY: I witnessed the attempted test of the BOPE on Nordic dg #1 which was preparing to workover Arco's well #1B-9 in the Kuparuk river field. Test time 12 hours, 8 failures. Incomplete .Test. Attachments... NONE CC: Kuparuk Drilling Supt. ,, Is o,, , s,o REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown~ Stimulate~ Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of wall at surface Development __ Stratigraphic Service X 493' FNL, 1462' FEL, Sec. 9, T11 N, R10E, UM At top of productive interval 1 600' FNL, 1583' FEL, Sec. 4, T11N, R10E, UM At effective depth 1190' FNL, 1404 FEE, Sec. 4, T11 N, RIOE, UM At total depth 1113' FNL~ 1369' FEL~ Sec. 4r T11 Ny R1 OEp UlVl 12. Present well condition summary Total Depth: measured 8 5 5 0 true vertical 6 8 2 2 Plugging __ Perforate Other X 6. Datum elevation (DF or KB) RKB 98 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 B-09 9. Permit number/approval number 81-134/94-344 10, APl number 50-029-20655 11. Field/Pool Kuparuk River Field/Oil Pool Effective depth: Casing Structural CoNductor Surface Intermediate Production Liner Perforation depth: measured 843 5 true vertical 6744 Length Size 80'. 20" 2447' 13 3/8" 8480' 7" measured 7834'-7910', true vertiCal 6310'-6369', Tubing (size, grade, and measured depth) 4.5", 12.8#, J-55 w/ tail @ 7721' feet feet feet feet Plugs (measured) None Junk (measured) Wireline tools in rathole Cemented Measured depth True vertical depth 400 Sx AS II 80' 80' 1600 Sx Fondu & 2486' 21 37' 400 Sx AS II 2750 Sx Class G 851 9' 6801' 7976'-8002', 6419'-6438', 8207'-8221 ', 6587'-6597', 8229'-8275' 6603'-6637' Packers and SSSV (type and measured depth) PKR: Baker "SAS" @ 7618'; SSSV: Camco TRDP-1A @ 1921' 13. Stimulation or cement squeeze summary Cement squeeze C Sand perforations Intervals treated (measured) 7834'-7910', 7976'-8002' Treatment description including volumes used and final pressure Pumped 65 BBL Class G LARC cement. Final squeeze pressure 3100 psi. 14, Representative Daily Average Production or Injection Data Oil-8bl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 0 Subsequent to operation 0 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct RECEIVED 0 1B 5 Alaska 0il & Gas Cons. Commission Anchoraje Tubing Pressure 0 7000 700 2300 0 360 750 2300 16. Status of well classification as: Oil Suspended Service X to the best of my knowledge. Form 10-404/Re~' 06/15/88 Title Wells Superintendent Date SUBMIT IN DUPLICATE STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing t Repair well Change approved program Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate_ Pull tubing Variance _ Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic __ Service X 4. Location of well at surface 493' FNL, 1462' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1600' FNL, 1583' FEL, Sec. 4, T11N, R10E, UM At effective depth 1190' FNL, 1404 FEL, Sec. 4, T11N, R10E, UM At total depth 1113' FNL, 1369' FEL, Sec. 4, T11N, R10E, UM 6. Datum elevation (DF or KB) RKB 98 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-09 9. Permit number 81-134 10. APl number 5o -029-20655 11. Field/Pool Kuparuk River Field/Oil Pool feet Present well condition summary Total Depth: measured true vertical 12. Effective depth: measured true vertical 8550 feet Plugs (measured) 6822 feet 8 4 3 5 feet Junk (measured) 6 7 4 4 feet None ORIGINAL Wireline tools in rathole Length Size Cemented 400 Sx AS II 3/8" 1600 Sx Fondu & 400 Sx AS II 2750 Sx Class G 80' 20" 2447' 13 8480' 7" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 7834'-791 0', true vertical 6310'-6369', Tubing (size, grade, and measured depth) 4.5", 12.8#, J-55 w/ tail @ 7721' Packers and SSSV (type and measured depth) Measured depth True vertical depth 80' 8 0' 2486' 2137' 8519' 6801' RECEIVED DEC 2 9 1994 7976'-8002', 8207'-8221', 8229'-8275' 6419'-6438', 6587'-6597', 6603'-6637' PKR: Baker "SAB" @ 7618'; SSSV: Camco TRDP.1A @ 1921' 13. Attachments Description summary of proposal ~X Detailed operation program Isolation of the C sands with a cement squeeze. 14. Estimated date for commencing operation 15. November 15.1994 16. If proposal was verbally approved Name of approver Date approved aiaska ~1~ ~t~t~ns_. Commissi~ Anchorage Status of well classification as: Oil __ Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign ~ ~, C., ~c.~4,. Title Wells Superintendent FOR COMMISSION USE ONLY Date' Conditions of approval: Notify Commission so representative may witness IApproval No .... Plug integrity ~ BOP Test _ Location clearance __ I Mechanical Integrity Test Subsequent form require 10- -- "Approved Copy Returned Original Signed By //,-/ Approved b~/ order of the Commission David W..Johnston ' Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment 1 Profile Modification Kuparuk Well 1B-09 ARCO Alaska, Inc. requests Commission approval to shut-in the 'C' sand in Well 09 through the implementation of a cement squeeze. The objective of the treatment is to eliminate excessive water injection into the 'C' sand thief zone located between the depths of 7834' ~ 8002' MD-RKB. This treatment will reduce water cycling in the offset producers of this well and increase oil production by allowing more pressure support to the 'A' sand. The procedure calls for isolating the 'A' sand interval with a sand plug, and injecting 65 bbls of Class "G" cement down coiled tubing to squeeze off the 'C' sand. The fill will then be cleaned out below the 'A' sand. ARCO Alaska, Inc. WE~. lB-09 DATE 11/14/94 DAY TIME 1200 · 1400 1510 1730 1830 DESCRIPTION OF WORK 'C' Sand Cement Re-squeeze CONTRACTOR I KEY PERSON iDowell/Perius Unit #3 (1.75" Coil) OPERATON AT REPORT TIME [~] COMPLETE '[--~ INCOMPLETE II=lEU) EST: $62,169 A KUPARUK RIVER uNIT WELL SERVICE REPORT IAFC/CC~ - SCA# 230DS10BL ACCUMULATED COST $62,169 · Total cement pumped = 20 bbls of neat Class 'G' LARC and 45 bbls of same w/aggregate. 1945 1st ramp: .4 bbls pumped. Pressured f/900 to 1200 psi, bled to 1000 psi after 10 min. I 2nd ramp: .5 bbls pumped. Pressured f/1000 to 1500 psi, bled to 1200 psi after 10 min. 3rd ramp: 1.2 bbis pumped. Pressured f/1200 to 1800 psi, bled to 1450 psi after 10 min. 4th ramp: 1.0 bbls pumped. Pressured f/1450 to 2100 psi, bled to 1850 psi after 10 min. 5th ramp: .5 bbls pumped. Pressured f/1850 to 2400 psi, bled to 2220 psi after 10 min. 6th ramp: .5 bbb pumped. Pressured f/2220 to 2700 psi, bled to 2150 psi after 2 min. 7th ramp: .7 bbls pumped. Pressured f/2150 to 2700 psi, bled to 2400 psi after 10 min. 8th ramp: .97 bbb pumped. Pressured f/2400 to 2900 psi, bled to 2650 psi after 10 min. .. 9th ramp: .51 bbb pumped. Pressured f/2650 to 3100 psi, bled to 2900 psi after 10 min. 10th ramp: .6 bbb pumped. Pressured f/2900 to 3100 psi, bled to 3000 psi after. 5 min. l.lth ramp: .2 bbb pumped. Pressured f/3000 to 3250 psi, bled to 3100 psi after 10 min. 1~. mped a total of 7.1 bbls to bring pressure from 900 to 3100 psi. Good squeeze pressure. Total of 25 bbls behind pipe (BBP). ! THIS BLOCK IF SUMMARY IS CONTINUED ON SACK Weather t Temp. Report AR3B-7031 Final shut-in: 650 psi. Frac pressure approx 1400 psi w/SW to perfs. Begin mixing/shearing cement. Run on-site QC of cement: 78 ced30 min. 1.0" filter cake. Pump 20 bbls of neat cement followed by aggregate cement. Displace cement to nozzle at 7992' (RKB). With cement at nozzle, slowed to I BPM, pinched choke to squeeze and circulate cement to top perf. Put 12 bbls behind pipe. Shut well in and squeezed cmt (6 BBP) while pulling to top perf. SI backside to build squeeze pressure. Build from 900 to 1800 psi. Bleed backside pressure to 1000 psi. Switch to SW and POOH layinl~ 35 bbls of cement @ 1:1. Pulled to safety at 4725' RKB. Performed hesitation squeeze as follows: LOG ENTRY Paaje I of 2 MIRU Dowell (cementers & CTU), MI solids control van, Peak & Little Red. Hold tailgate safety meeting - location condition/job exec. MU BHA - cold roll/XO/2.1" ball drop nozzle. PT lubricator to 4000 psi. Initial pressures: TP - 400 psi; IA -- 250 psi; OA = 50 psi RIH pumping SW @ min rate. Tag @ 7987' CTM. Correct to 7797' RKB Circulate 1-1/2 tbg vol.. Shut-in well and inject 200 bbls of 150° seawater to condition near wellbore region. / REMARKS CONTINUED: Page2 of 2 2145 2300 11/15/94 0245 Dowell (CTU) [Shut well in for 1 hour with 3100 psi on wellhead. Drop ball, begin pumping 1.5# biozan at 1.8 bpm while holding 1500 psi backpressure. Decrease backside pressure to 1200 psi to maintain 1.8 bpm. Recip (3 passes) from 7650' to 7997' with 1.5# biozan. Reduce rate to 1.5 bpm across sqz perfs. POOH to TI' @ 20 f'pm. POOH at 100 fpm & 2.0 bpm from 7650'. Switch to diesel @ 7000'. Continue POOH @ 2.0 bpm. Good cement returns. Returns 1:1 throughout cleanout. On surface. Increase WHP to 1800 psi. SI well and freeze protect surface lines. RDMO Dowell. Final pressures: TP = 1800 psi; IA = 1500 psi; OA = 50 psi. Summary Pumped 65 bbls of Class 'G' LARC cement (20 bbls of neat and 45 bbls of aggregate). Total cement behind pipe = 25 bbls. Performed hesitation squeeze from 1200 to 3100 psi. Held 3100 psi for I hour Estimated PBTD = 7997' RKB. Total fluids pumped: SW = 650 bbls; 1.5# Biozan = 200 bbls: TEA = 20 bbls; Diesel = 150 bbls; Neat cement = 20 bbls; Aggregate cement = 45 bbls. SERVICE COMPANY SCA # DALLY $12,619 Dowell {cement) $30,478 APC/Veco roustabouts $2,100 MI Fluids Hot Oil Peak Veco Vac Truck Diesel 150 bbls. TOTAL FIELD ESTIMATE $5,700 $4,972 $4,200 $2,100 $62,169 ACCUM. TOTAL $62,169 Signed: REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate .~ Other X Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 493' FNL, 1462' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1600' FNL, 1583' FEL, Sec. 4, T11N, RI OE, UM At effective depth 1190' FNL, 1404' FEL, Sec. 4, T11N, R10E, UM At total depth 1113' FNL, 1369' FEL~ Sec. 4~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 5 5 0' feet true vertical 6822' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 98' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1B-09 9. Permit number/approVal number 81 - 134 ~',~ -- ~,z. ~ / ¢~ - · 10. APl number 50-029-20655 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 4 3 5' feet true vertical 6744' feet Junk (measured) None Casing Length Size Structural Conductor 80' 2 0" SurfaCe 2486' 13 3/8" Intermediate Production 8519' 9 5/8" Liner Perforation depth: measured 7834'-7910', true vertical 6310'-6369', Cemented 400 Sx AS I It 1600 Sx Fondue & 400 Sc AS II 2750 Sx Class G 8207'-8221', 6587'-6597', 8229'-82750 66O3'-6637' Tubing (size, grade, and measured depth) 4 1/2" J-55, TT @ 7722' Packers and SSSV (type and measured depth) Baker SA packer @ 7618', Camco TRDP-1A @ 1921' 13. Stimulation or cement squeeze summary Measured depth 80' 2486' 8519' True vertical depth 80' 2137' 6801' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 - 1900 Tubing Pressure 2400 . ..Subsequent to operation -0- 0 - 6000 1600 2350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector x~ ,,. Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title SUBMIT IN DUPLICATE KRU 1B-09 Water injection into 1B-09 began September 10, 1990 with an initial rate of 4750 bbl of produced water per day RECEIVED DEC 1 1 1990 Alaska Oil & Gas Cons. Commissio~ Anchorage ,A, RCO Alaska, Inc.4 . Gul:~lllly of Atllntl~ Richfield Core,piny ............. 'IPBDT ' iRELD- DISTRICT-STATE ~NTRACTOR IOPE~TION AT RE~RT TIME "', icMARKS '" WELL SERVICE REPORT iDAYS ....... tDATE' ..... 0'50 ........... Alaska Oil & Gas COns. Con, mission ['"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK IS'gn~-~~ ~ ~ kn°t' I ~ ARCO Alaska, Inc. ( Post Office Box~uu360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 5, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1 B-09 Perforate September, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 RE£EIVED SEP 1 o ]990 Alas~ 0il & Gas Cons'. G0mm ssi0B Anch0raF~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 10036..0, .Anchorage, AK 99510 4. Location of well at surface 493' FNL, 1462' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1600' FNL, 1583' FEL, Sec. 4, T11N, R10E, UM At effective depth 1190' FNL, 1404' FEL, Sec. 4, T11N, R10E, UM At total depth 1113' FNL, 1369' FEL, Sec..4, T11N, R!0E, UM 12. Present well condition summary Total Depth: measured 8 5 5 0' feet true vertical 6 8 2 2' feet 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X Plugs (measured) 6. Datum elevation (DF or KB) RKB 9~' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-0~) 9. Permit number 81-134 10. APl number 50-029-20655 11. Field/Pool Kuparuk River Field K. uparuk River Oil Pool Effective depth: measured true vertical 8435' feet Junk (measured) 6744' feet 8244' Casing Length Structural Conductor 8 0' Surface 2 4 8 6' Intermediate Production 851 9' Liner Perforation depth: measured 7834'-7910' Size Cemented Measured depth 2 0" 400 Sx AS !1 8 0' 13 3/8" 1600 Sx Fondue & 24 8 6' 400 Sx AS Ii 9 5/8" 2750 Sx Class G 851 9' True vertical depth 80' 2137' 6801' , 8207'-8221', 8229'-8275' RI CEIVED 14. 16. true vertical 631 0'-6369', 6587'-6597', Tubing (size, grade, and measured depth 4 1/2" J-55, TT @ 7722' Packers and SSSV (type and measured depth) Baker SA packer @ 7,6,,!8,1r Camco TRDP~,!,,A,, ~ !,,921' Attachments Description summary of proposal ~ Perforating the, C I, Sand Estimated date for commencing c~erati0n .......... September.,,.,,,15 ...... 19.90 If proposal was verbally approved Name of approver Date approved 6603'-6637' D~t'~ile~' '0Pe'rat'i'on"Pr0gr~"rn _ ' ..... BOP sketch_ i'5' Status of well classification as: Oil ~ Gas ~ Suspended Service _Water Iniector _ _ , , 17. I herekv certify,,~that the f~)~egoing is true and correct to the best of my knowledge. Signed '~~~' ~ .... Ti.t.,.e ~l'~1~.. FOR COMMISSION USE ONLY ConditiOns of ~'pproVaj: 'N0tify"Oornmissi~n so mP;eS~ntaiive may'~i~ness' ' ' Plug integrity m BOP Test m Location clearance ~ Mechanical Integrity Test~ Subsequent form require 10- _Approved by the order Commission Form 10-403 Rev 5/03/89 Commissioner SUBMIT 'IN' TRIPLICATE r" ( ( Well 18-09 Perforate C1 Sand Perforate C1 Sand 1 . MIRU "E" line unit. PT equipment. Verify tubing is open to 3.678" ID. Tag fill. 2. RIH with 3.375" Halliburton JRC DP Gun with 22 gr. charges and a CCl to shoot the following depths. The perforations should be 6 SPF and have 1200 phasing. 18-09 C1 Sand Perforation Depths Depth ZQo.e. (Ft. MD RKB. Dll(â)1 0-29-81) lenoth Shots per foot C1 79761 - 8001 ' 251 6 3. RDMO "E" line unit. RECEIVED SEP 1 0 19~10 '~ ro"~~~ort l~,!aska Oil .& Gas Com;. CQm . .l~..... .e. Anchoraga 3 1. 5000 PSI 7" W[LLH~ OONN[CI'OR FL&NC)[ 2. SOO0 PSi WIR[LIN[ RAIDS (V&RIABL[ SIZ[) ,3.5000 PSI 4 1/6" LUBRIG~I~,TOR 4. 5000 PSI 4 1/S" ri. OW TUB[ PAC:K-Of'F 2 RECEIVED SEP 1 o i990 Al,~s~(a Oil & Bas C~ns. (;~nm._~ss[o-~ o,. co.s..v^T,O. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _.X_ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other Type of Well: Development Exploratory Stratigraphic Service 493' FNL, 1462' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1600' FNL, 1583' FEL, Sec. 4, T11N, R10E, UM At effective depth 1190' FNL, 1404' FEL, Sec. 4, T11N, R10E, UM At total depth 1113' FNL~ 1369' FEL~ Sec..4~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 5 5 0' true vertical 6 8 2 2' Effective depth: measured 8 4 3 5' true vertical 6744' 6. Datum elevation (DF or KB) RKB 98' feet Plugs (measured) feet feet Junk (measured) feet None 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-09 feet 9. Permit number 81-134 10. APl number so,0;~9-20655 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 2 0" Surface 24 8 6' 13 3/8" Intermediate Production 851 9' 9 5/8" Liner Perforation depth: measured 7834'-7910' Cemented Measured depth True vertical depth 400 Sx AS II 80' 80' 1600 Sx Fondue & 24 8 6' 21 3 7' 400 Sx AS II 2750 Sx Class G 851 9' 6801' , 8207'-8221', 8229'-8275' RECEIVED true vertical 6310'-6369', 6587'-6597', Tubing (size, grade, and measured depth 4 1/2" J-55, TT @ 7722' Packers and SSSV (type and measured depth) Baker SA packer @ 7618'~ Camco TRDP-1A ~ !921' i3. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch_ 66O3'-6637' AUG 1 o 1990 Alaska 0il & Gas Cons. C0mnliss[on Anchorage Propose converting well from oil producer to water injector. 14. Estimated date for commencing operation I15. Status of well classification as: August 15, 1990 I Oil __ Gas _ Suspended 16. If proposal was verbally approved Name of approver Date approved Service Water In!ect0r 17. I hereb~certify t_hat the foregoing is true and correct to the best of my knowledge. Sicjned . Title ~ , Date FOR COMMISSION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance - _ Mechanical Integrity Test Subsequent form require Approved by the order Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY ,,,m ~ LONNll- u. 10.,~ IIAppr°v~"'/'-¢'~¢ ~,pproveC~ O~OP¥ Returne° SUBMIT IN TRIPLICATE Drill Site lA Well No. ~ 1A-4 ,~1A-5 1A-7 "1A-9 "1A-11 %~.. ~1A-12 '~1A-14 '~ 1A-15 ' ~-lA-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~ d/ - 517182/. 1/25/82'~j-- 3/23/83/ ,:,z,,. 1/19/83") ~"-' 3/21/83/ 3/8/82 4/1/82 6/5/82 5111182-,,,. ',,. u8/8 / Drill Site 18 Well No. Log Date __ 'X'lB-1 12/26/81 ' ~18-2 6/25/81 '~18-3 11/16-18/81~-~ ~ 3/12/82/ ~'18-6 11/18/81X, '~ 9/I0/82/ ~18-7 - 11/23/81 ~18-8 12/28/81"% "'* 8/4/82/ ~lB-g x 6/24/82,..-~%, x. B/3/84" · ~_ .... Drill Site 1C Wel 1 No. '~lC-1 "~1C-2 "1C-3 ~1C-4 ~w,~ X~lC'5 .. '",'1C-6 ."~1C-7 "~ lC-8 Log-Date 51~19~ 5/8/81 7/13/81 11/8/81'~ 3/9/81/ 2/26/81 11/30/81 5/19/81 5121181 -' Dri 11 Site Wel 1 No. .Log Date 1D "X~ID-1 ~ '~ 5/23/83/.. "'"1D-3 8~5~80 .....-' 1D-4 x7/30/80'",,,' ~ ~ 8/13/80/ '~ ~1D-5 6/11/81 -.- :....- ~1D-6 6/9/81 ': '~lD-7 6/8/81 . ':-: '"'JlD-8 (WS-8) 5/10/-78 ' ':.'- Alaska 011 I Gas Cons.' C~mmission. ARCO Alaska, Inc. Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, Dayton Area Operations Engineer slz Attachment cc: L. M. Sellers E. A. Simonsen R. L. Stramp H. C. Vickers AN0-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments RECEIVEI) DEC 0 ]982 Alaska 0il & Sas Cons. Cc~missior) Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ALASKA ('.'..- AND GAS CONSERVATION CG( 'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . . 1. Status of Well Classification of Service Well . OIL J~ ' GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Thc. 81-13/, 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20655 4. Location of well at surface /.931 FNL, 1/.62' FEL, Sec 9, T11N, R10E, UN 9. Unit or Lease Name Kuparuk River Un±i: . At Top Producing lnterval 1600' FNL, 1583' FEL, Sec 4, T11N, R10E, UN 10. WellNumber 1B-gGI At TotaI Depth 1113' FNL, 1369' FEL, Sec /*, T11N, RIOE, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 98'RKB ADL 256/*8 ALK /*66 . Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/16/81 10/29/81 11/10/81I __ feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafros't- 8550' 6822' 8435' 67/*/*' YES [~( NO []I 1920' feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS. FDC/CNL/GR/Cal. CBL/CCL/Gr. CBL 23. CASING, LINER AND ~EMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER Ft. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · ?fl" 9!_5# N-an $,mf Rn, ]0" anti !3 3/R" 7?# I-Rtl R,n'f ?aRA' 17 1/?"1 lAflfln× Fnnd,, & ann .~ As TT 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) '7834-7910' /~ !/2" 7722' 7618' 8207-8221 ' ', "' 8229-8275' w//* SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ' ' !85/:-!8.~6' ..A_"ot±o po..,, q~,h _ see ., · 27. "' ' PROI~UCTiON TEST MethOd of Operation (Flow. ing, gas lift, etc..) Date First Production . -, --, ---- ~. 1~ ,.~1 ,..-/ v~.. .j . Date of Test Hours Tested PRODUCTI-O~"~-~ OI ~'-~'1' --' ~3~,S-"IVTCF~- W-~,~E'~-"B~B'~' CHOKE SIZE GAS-OI L RATIO I 17/-~1/R1 2'3.5 T.ESTPERIOD.*I FIo~v'fu-bi~'g ~ ' Casing Pressure CALCULATED ' 01L~E~E~I' O~,'~-~IVTCF "WA~-~R-B'BL OI L.'C~I~,~ITY-API ~c~r) . Press: znn I __ 24'HOUR RATE'J~ '"'' " ' ' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit coi'e chips. · ! · DEC 0 1982 r" ' ' ' ' AtaSKa 0i1 & Gas Cons. CcmrnissiOo Anchorage ' ' ,- i-;-2 2 ..... ' - '~ ",'" 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. -- GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk River Form. 7783' 6271 ' N/A Base Kuparuk River Form. 8345' 6683' 31. LIST OF ATTACHMENTS -- 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.~ ~~ Area 0ps. Engr. / //~ Signed , Title Date I I ~' 3 ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. item 28: If no cores taken, indicate "none". Form 10-407 KUPARUK ENGINEERING TRANSMITTAL TO: ~~~.,~ FROM: D.W. Bose/Lorie L. Johnson Transmitted herewith are the following: NOTE:/~L - BLUELIN~J- SEPIAS, F - FILM, T'- TAPE PLEASE 'IPT AcKNowLEDGED: PLEASE RETURN RECEIPT TO: DATE: . A~ask~ 0il & Gas uons. ~ommission ARCO AT,ASKA, INC. Anchorage ATTN: LORIE L. JOHNSON - AFA/311 P; O. BOX 360 ANCHORAGE , AK 99510 KUPARUK ENGINEERING TO: D. W. Bose/Lorie L. Johnson DATE: {//2~/~.~ WELL NAME: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM,~ ~iPT .ACKNOWLEDGED: LEASE RETURN RECEIPT TO: ARCO ALASKA, INC. Anchorage. ~TTN: LORTE L. jOHNsoN - AFA/311 P. O. BOX '360 ANCHORAGE , AK 9 9 510 ARCO Alaska, Inc. Post Office Box =.... Anchorage, Alaska 99510 Telephone 907 277 5637 May 14, 1982 L Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Rorcupine Drive Anchorage, AK 99501 SUB3ECT: Revised Well Completion Reports Dear Mr. Chatterton: Enclosed are revised well completion reports and gyroscopic surveys for the following wells: 1A-13 B-1 B-8 ::IB,gG1 ~ Reports for the three B-pad wells are being resubmitted due to an RKB change. The original 1A-13 completion ~eport indicated that certain items would be submitted at a later date; these items are now included on the revised report. P. A. Van Dusen PAV: JG/llm Enclosures GRUS/B15 RECEIVED 1 8 igB 'Alaska Oil & Gas Cons. Gommission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -~ ALASKA ND GAS CONSERVATION CO ~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG _ ._ 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ., 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-1~34 3. Addres's 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20655 4. Location of well at surface 9. Unit or Lease Name 493' FNL, 1462'FEL, Sec. 9, T11N, RIOE, UM Kuparuk 25648 At Top Producing Interval 10. Well Number 1596' FNL, 1582' FEL, See. 4, TllN, RIOE, UM 1B-gGI At Total Depth 11. Field and Pool 1113' FNL, 1369' FEL, Sec. 4, TllN, RIOE, UM ... Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Desigqation and Serial No. Kuparuk River 0il Pool 98' RKB ADL 25648 ALK 466 -- 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10-16-81 10-29-81 11-10-81I .... feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8550'MD, 6822'TVD 8435'MD, 6744'TVD YES)~] NO[~] 1920' feetMD 1650' (approximate) 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/GR/Cal, CBL/CCL/Gr, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE: WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.51! H-40 Surf 80' 30" ~O0~x AS TT 13-3/8" 72# L-80 Surf 2486' 17-1/2" 1600Sx Fondu & /400sx IA S II 9-5/8" 47# L-80 Surf 8519' 12-1/4" 2750sx Class G cml: 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) 4_ 1 / 2" 7722 ' 7F; 2~ ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. N/A ' DEPTH INTERVAL(MD) AMOUNT & KIND'OF MATERIAL USED 1R5/,' - 1RSA' A_rn~i~ P~cI< ._-Ioh - R~e .Drill- i _n_0 His~.Ory · · ..... · 27. PRODUCTION TEST , -,, Date First Production I Method of Operation (Flowing, gas lift, etc.) ' N/A. IN/A. I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATERIBBL CHOKE SIZE I GAS-OIL RATIO 'TEST PERIOD ~ ! : · . · Flow Tubing Casing Pressure CALCULATED ]l~ OILIBBL GAS-MCF WATER-BBL OIL GRAVITYIAPI (corr) Press. 24:HOUR RATE " ' ' . , 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/^ ' ECEiVED MAY 1.8 198 Al~sk~ 0il & Gas Cons. Commission Anchorag9 Form 10-407 GPU4/A28/29/30 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Kuparuk Base Kuparuk GEOLOGIC MARKERS MEAS. DEPTH 7790' 8346' TRUE VERT. DEPTH 6276' 6683' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/^ N/^ 31. LIST OF ATTACHMENTS Revised Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~?_~~..~ ...,.._..~, ..~~J/_ _ Title S~o P~']q. Erlqro Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Box ~.:!I Anchorage. Alaska 99510 Telepl~one ...,7 277 5637 Hay 11, 1982 Mr. C. V. Chat[etLon Commissioner State off Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: As-Built Conductor Location Plats Dear Mr. ChaLterton: Enclosed are as-built conductor plats for the following wells: 1B-11GI West 'Sak 18 Wesk Sak 20 These items were listed as missing data on the attachment to your April 19, 1982, letter to Mark Major. IF you have any questions, call me at 263-4960. Sincerely, P. A. Van Dusen District Drilling Engineer PAV :JG/hrl Enclosures GRU5/A12 J 82' Al~ska Oil & ~ Cons. commission ~ Chorage ARCO Al~sk;* Inc is .~ c~:!')~i~!i;~,, O! AllanlicRich!it.ldCompany Well Location Data CONDUCTOR HOLE LOCATtCNS WITHIN SECTION STATE PLANE LOCATION WELL GEODETIC COORDINATES COORDINATES IN SECTION LATITUDE LONGITUDE Y(N) X{E} FNL FEL¢ I 70Ol9'40 29" 149035'56.05" 5,969.647 549,458 496 982. , 2 ?Oe19'4.0.Z9" t49055'5Z. 54" 5,969,64.8 5,49,578 ... 497 aGz ~ $ 70°19'40.28" 149055'49.03" 5~969,647 549,698 498 742 4 70~9'40.Z7''''' 14.9o35'45.54" 5~969,$47 549,81e 499 622 , 5 70~9'40.27" 149055'42.05'' 5,969,647 549, 9...'5.8 499 502 ,, 6 70°19'40 26" 14e055'38.53" 5,969,64.7 550,058 500 382. ., 7 ..70°15'40.25'' 149°35'35.04" ~969,64.7 ..... 55~i78 ....501 . Z62 8 70°19'4'0.24" 1490"55'$LSZ'' 5,969,647 55~298 502 142 __ ,,, ,,, ,, GIW I 70°19'40.30'' 1490.~6'00.71'' 5,969,647 549,2.98 50~ 1'i42 GlW $ 70°19'40.~Z'' 149°$6'10.05'' 5,959,647 548,978" 505 1462 ALL LOCATIONS ARE WITHIN SEC. 9, T IN, R~OE, UMIAT MER:E;AN, AK ~ FNL= FROM NORTH LINE ~ FEL= FROM EAST LiNE A,~o~a 0/1 & Ga~ Cons. Co~rn, issiort [~] MON. 7-A / // 300 ' / -0 150' 'o SEWAGE o o~ LAGOON DENOTES WELL + SITE '200' DRILL SITE 120' ~20' 80' GYRO MARKER 5969647. 04 5483482.7 RESERVE PIT z 120' "; 120' 1+ 160' GIW 1+ ~6o' GIW 2~-~ {~ -~ ~.., 160' GIW ~ ,, ~ J wg. No. 3.17--13 i i i i ii ATLANTIC RICHFIELD CO, DRILL SITE "B" GYRO MARKER LOCATION " PREPARED BY ' ' BOMHOFF 5 ASSOCIATI[$, INC. ANCHORAGE ALASKA DATE-'.. 10/25/80. . . J SCALE:. _1"-= 200 ' DRAWN BY: R.R.K. CHECKED BY: ~",~,~ · i __ -- iii i ARCO Alaska, Inc. Post Office Bo 0 Anchorage, Alaska 995!0 Telephone 907 277 5637 April 21, 1982 Mr. C. V. Chatterton St ate of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 Commission Dear Mr. Chatterton: Attached please find Sundry Notices of Intention for Kupaurk Wells 1D-2, 1D-4, 1D-5, 1E-3, 1E-5, 1D-3, 1C-1, lA-7, lA-9, 1A-lO, and lA-11. The work on these wells is scheduled for the latter part of April, 1982. Also attached .is the subsequent notice for Well ~lB-gG~/which was perforated in late December, 1981. We apologize for the untimeliness of this report. A recent review of our records revealed this submission had been overlooked earlier. Sincerely, bi Attachments STATE OF ALASKA ALASKA LAND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-134 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 s0- 029-20655-00 4. Location of Well S.L. 493'FNL, 1462'FEL, Sec 9, T11N, RIOE, UM B.H.L. 1189'FNL, 1404'FEL, See 4, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 98 ' 6. Lease Designation and Serial No. ADL 25648 9. Unit or Lease Name Kuparuk 25648 10. Well Number 1B-9GI 11. Field and Pool Kuparuk River Field Kuparuk River Oil Poo] 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. perforated Kuparuk WeI1 1B-gGI on December 28-29, 1981, with 4 SPF at 180° phasing. The Upper, Middle, and Lower Kuparuk Sands were perforated over the intervals 8229'-8275', 8207'-8221', 7834'-7910' A flow test was conducted on December 29, 30, and 31, 1981, 1n which the well flowed at a rate of 5563 BOPD with an estimated GOR of 420 SCF/STB. Shakeouts revealed no apparent watercut. Ail produced fIuids were flowed to the Central Production FaciIity and to the sales line. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ~~ A~ea Ope~at,ons Eng,neem Si~ned .~ _ ~ ~ . Title Da~e ~,~space beq for Commission usd COnditions of Approval if any' By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports"in Duplicate ARCO Alaska, Inc. Posl Ollicc 361/ Anchorage .... ;~,;kd 995 Telephone ~07 277 February 19, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commis s ion 3001 Porcupine Drive Anchorage, Alaska 99510 Subject- State Reports Dear Sir' Enclosed please find the up-dated Completion Reports for drill siteS: 11-3, 11-5, 13-8, 13-10, 14-12, 15-13, 15-14, IA-10, IA-ii, B-6, ~B'9GI~ B-10GI and West Sak #18. The gyro-multishot surveys enclosed are from drill sites 12-4A, 13-19, 14-12, 14-26, 15-14 and 15-15. The original gyro-n~ltishot surveys for drill sites 11-1, 12-14, 13-6, 13-9, 14-13 and 16-1 were un- satisfactory and are scheduled to be re-run. Information to be submitted on the corresponding completion, along with the accept- able survey, will be forwarded to your office when we receive them. Also included are subsequent sundrics for drill sites 14-9A, ~ 14~18, and 15-10, along with a Sundry of Intent to plug and abandon Kavik #1. · Sincere ly, M. A. Major Area Drilling Engineer Enclosures MAM/GLA'ss 'ARC(; Alaska. htc is a '.:(,b~,,di:;rv ,-)f Atlanlic.q,chfie~ctComp;,,W ARCO Alaska, Inc. Post Office Box 2 Anchorage, Alas .~510 Telephone q07 277 5037 February 9, 1982 Mr. Lonn ie'Smith State of Alaska Al aska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 · Subject' Gyroscopic Surveys Dear S ir' Enclosed please find the completed Gyroscopid Surveys for Drill Sites 11-3, 11-5,'12-8B, 13-10, 15-12, 15-13, 1A-11, 1A-12, B-9GI and B-iOGI. Also included are the completion reports for Drill Sites 1A-10, 1A-11, ":~B-9GI' and B-iOGI Sincerely, P. A. VanD'usen District Drilling Engineer PAV'GA:ltc ' ARCO Alaska. Inc is .3..~t,l~,:;trlin~, of All~nlicRichlioldComp,3ny STATE OF ALASKA " ALASKA ~ AN D GAS CONSERVATION C "~ISSION WELL COMPLETION OR RECOMPL_ETION RI=PORT _ _N_rl LO I - 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-134 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 995]~, 50-029-20655 4. Location of well at surface VERIFIED 9. Unit or Lease Name 493' FNL, 1462' FEL, Sec 9, TllN, R10t ~ur.~..~ Kuparuk 25648 At Top Producing Interval ' 1595 FNL, 1582 FEL, Sec 4 TllN, R10E, ~?_.~ =_ 10. WellNumber · - ' B-9GI At Total Depth 11 Field and Pool 1113 FNL, 1369 FEL, Sec 4, //IN, R10E, UM Kuparuk'River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 93' ADL 25648 AI,K 466 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore [ 16. No. of Completions 10/16/81 10/29/81 11/10/81[ .... feet MSLI 17. Total Depth (MD+TVD) 18,Plug Back Depth (MD+IA/D) 19. Directional Survey 20. Depth where SSSV set 21. lhickness of Permafrost ]550'MD, 6822'TVD 8435'MD, 6744'TVI YES [~ NO [] 1920 feetMD 1650' (approx~ 22. Type Electric or Other L. ogs Run DIL/SP/GR/BHCS, FDC/CNL/GR/Cal, CBL/CCL/Gr, CRL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 20" 91.5# H-40 Surf. 80' 30" 400 _q~r A_S: TI r _ 13-3/8" 72# L-80 Surf. 2486' 17½" 1600 sx Pon&~. g 40~) .qw A_.q_ TI _ 9-'5/8''~ 47# L-80 SUrf. 8519' 12~'! ,. ~:27~0 ~w C.]nqq ~'~ 'ar.ant _ _ 24. Perforations open to Production (MD+TVD.of Top and Bottom and 25. . .'TUBING RECORD interval, size and number) .. . .~ SIZE DEPTH SET(MD) PA(~KI~R SET (MD') 4~_,, 2 7722 ' 7624' .: 'T 0 B E S U B M I T T E D 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' ' . . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 1854' - 1856' Arc. tic Prick .Tnb - ,q=.~ l~l . . · 27. PRODUCTION TE~T Date. First. Production.. ' i ,~ [Method. of: Operation~ .(Fl°wing,. gas.~ lift, etc.)., . ·. - I , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE 1GAS'OILRATIO ~:~ .. TEST, PERIOD * Flow Tubing ' 'Casing Pressure . ~ CALCU:LAIED OI L~BBL 'GAS-~CF , WATER-BBL OIL GRAVITY-APl (cDr'r) Press.' . , .24-F:IOUR RATE* ': '~ ' ~ 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. -- R .CE!VED . · · ' FEF:91 9 , , · A!aska Oil &Gas, C0nsl Hist 29. 3O. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 7790 ' 6276 ' N/A Base Kuparuk 8346' 6683 ' N/A 31. LIST OF ATTACHMENTS ~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~. Title Drilling Engineer / /~v / '- Date , INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. ~:~'~!'::?~::~¢-::?-!;,:.:,~-:- Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · . OIL;~( GAS [] SUSPENDED [] ABANDONED [] rSERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-134 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20655 4. Location of well at surface 9. Unit or Lease Name 493' FNL, 1462' FF.L, Sec 9, TllN, R10F., UM Kuparuk. 25648 At Top Producing Interval 10. Well Number To Be Submitted B-9GI At Total Depth /~.,.[2o ~¢c~,',/~/ v'¢ ,"i~l/y ~ 6, iqlv~,",¢/ 11. Field and Pool TO Be Submitted ~l/~'?~-~ I~(~/F£~. j $~_c ~f E,~, Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and'Serial No. Kuparuk Oil Pool RKB 93' ADL 25648 ALK 466 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/16/81 10/29/81 11/10/81I feet MSLI 1 17. TotaI Depth(MD+TVD, 18.Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost ' 8550' MD G~2P. 84351 MD YESES( NO[-] 192p 'feetMD 1650I (approx,) 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/GR/Cal, CBL/CCL/Gr, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~20,, 91.5# H-40 Surf. 80' 30" 400 sx A.S. II 13-3/8" 72# L-80 Surf. 2486' 173" 1600 s× Fondu ~ 40(3 s× A.F;. TI 9~5/8'' 47# L-80 Surf. '.8519~ . 127' ,.2750 sx Class "G" cement' 24. Perforations open ,to Production (MD+TVD of Top and Bottom and ~ ~25. TUBING RECORD inter?l, size and number.) .. SIZE .. DEPTH SET (MD) PACKER SET (MD) 4~" 7722 ' 7624 ' TO BE SUBM. I T. TED "':~' '' .... · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , ; DEPTH INTERVAL (MD) AMOUNT.& KIND OF MATER A.LUsED' ~" :' '" .... " : " ·" " ' 1854"' 1856' ' ArCtic ?ack Job - See DrZ~;. , , 27. ' PRODOcTION" TEST Date First, Production . ;.. I Method of Operation (El,owing, gas lift, etc.) I . Date of Test Hours Tested TEsTPRODUCTIONpEFIIOD .I~FOR OI L-BBL GAS-MCF .... WATER-BB~ CH'0KE SIZE ' GAS-OIL RATIo " Flow Tubi.ng Casing Pressure CAEC.ULATED I1~ OIL-BBL GAS-MCF WATER~BBL OIU GRAVITY-APl (corr) Press. 24-H0 R R E -r '" ' . · . · . ~.' ,' "' ' : '~- ': '' ,"" 28. CORE DATA · -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' . /"..::,~'.i':::'T::..:~. -'"'~;';0~,. , ' __ ist. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TO BE SUBMI TED 31, LIST OF ATTACHMENTS ..... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t / -" ........... TitleSr.,. .. Drlg. Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. ........ ~::~ev',.'i~-~!i'., ,.: .}:i: ~ 'i-,-? i-~od Pump, Hydraulic Pump, Submersible, Water In- i.;'z::. ~i~::.,: ~. !il. ii :~'~:; J ~-;jectio~'~, ,Sieur-i~, © ~.i~e;'-cxpiain. Item 28' If no cores taken, indicate "none". Form 10-407 . DS B-9GI Drilling History NU hydrill and diverter. Spudded well @ 0800 hrs., 10/16/81. Drld 172" hole to 2505'. Ran multishot. Ran 62 jts 13-3/8" 72# L-80 BUTt csg w/shoe @ 2486. Cmtd 13-3/8" csg w/1600sx Fondu and 400sx AS II. ND hydril and diverter system. Installed 13-$/8" packoff & tested to 2000 psi - OK. NU BOPF~ and test same to 3000 psi - ok. Tsted csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.0 ~" ppg EMW- ok. Drld 12a hole to 8550'. Ran DIL/SP/GR/BHCS and FDC/CNL/GR/Cal. Ran 210 jts 9-5/8" 47# L-80 BTC csg w/shoe @ 8519'. Cmtd 9-5/8" csg w/2750sx Class "G" cmt. Displaced top plug w/NaC1/NaBr brine. LD landing jt and run packoff for 9-5/8" - tstd same to 3000 psi - ok. Ran CBL/CCL/GR. Ran gyro from 8435' PBTD to surface. Ran CBL from 4000' - 1500'. Cycle 9-5/8" csg and annulus press to break formation for Arctic Pack. PU 1t! ~ DP & TIH. Circ. hot brine thru well. Stand back 3~-''2 DP. RIH. w/free point tool and work pipe. Pipe partially stuck at 800' Displace brine w/mud; POH /~1 ~l w/~ DP. RIH and perf 1854 '-1856' w/8spf. Set ~nd test packoff to 5000 psi. RIH and set 9-5/8" RTTS @ 1849'. Pumped 325 bbl H^0, 80 bbl Arctic Pack and 75sx AS I. POOH w/RTTS. Displaced well to NaC1/N~Br brine. Tstd cmt squeeze on perfs @ 1854 '-1856' to 1S00 psi - ok. Ran 244 jts 42" J-55 tbg w/tail @ 7722' and pkr @ 7624' Tstd Arctic Pack job to 1000 psi - ok. Displaced tbg to diesel. Dropped b~ll & set pkr. Closed SSSV @ 1420'. ND BOPR. NU tree and test to 3000 psi - ok. Set B.P.V. in hanger. Secured well and released rig at 1800 hrs. 11/10/81. *Note: The BPV instld at the hanger will be removed subsequent to rig :Skidding-off. KUPARIJK FIELB ~* APRIL =- ~ ~ ..-o~ .JOB NUMBER BOSS--16920 AI_.ASKA ~ ~ ' ":" . - '"~'"" 0('~ I':T ~ ~ KELLY BU.;.,t~ING ELEV -' ;:,: ..... MEASURED VERI"I CAL VERTICAL INCLINATION DIRECTION ._ EVERI TY REL. T AN~$ULAR CF,]RD I NATE.;. VER'I' iCAL.~ DEPTH BEPTH II ER' TH DEG M I N [IEI;~REES :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :;;':!~_i'~?z.':.?*': :'::.* ':**'" ': ::.*' ~!'i ;- 400 400.00 302.00 0 13 N 13.60 W 0.36 0.14 S 0.88 E -0. 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()7 1000 997.17 899.17 10 21 N 20. 0 W 1.93 46.02 N 10.14 W 45. :31 · ~-:~:~ ~:~:~:~:~:~ ~:~:~:~-~:~:~ ~:~:~:~:~:~:~)~:~:~:~:T~ ~:~::~:~:~:~:~:~:~:~.~:~:~:~:::~:~ ~.~:~:~:~4.~:~:~::~:.~4:~-~:?~:,~~:~?::~; :~:~ :~:~:::::.: :~,: :::::: .......... ~::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.. :::::: ::::::::::::::::::::::::::::::::::::::::: :.: ~:~ ~ ~,~.~ 5~- ~ '~'~ ~-' ?'"~'~ 1400 1:377.92 1279. '~2 25 43 N 14. :30 W 4. :37 159.46 N 41.68 W 158.59 1500 1466.76 1368.76 28 55 N 20.30 W 4.22 203.20 N 55.44 W 202.05 -?~*?:*::~:?****?*<***~***?.??~;*?:*:***:'~:**~::;:::?~?:*:::**:';~*:'~ ?~;:;::~:;*~.*************************************************************************************9?*?<::~*?::~**~?**c?***??~<*?~**?;??:?::::~::***~:?:~%***?*~::?:?~***~???;*~**~;~?*::~*?*/?ZF***::?:**~*~*:***~*~****~*~;:*?~?}***:.*/:./.~`*~'~: :*~:~:;*;:.::*;:::~ '::':;:? ~' %:*':; ~,"~ ..::W · ':':' :" ' 4,.*;:" 2000 1870.04 1772.04 40 43 N 7.60 W 0.25 491.02 N 108.94 W 488.7'5 2100 1 '745,, 74 1847.74 40 52 N 7. :30 W 0.24 555.81 N 117.41 W '.55:3.36 _":' '], (] r~ .o ' .~ ~ q:,/- ~'-, .-, n ~ .-, ,- ~ ~: ,-) .-, - -., .............. ..,:::.' .:'..:.:.:.::':.:.::.,..::::~. 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'.:': :;.:.:.:' :: '. ~;, ;**:: .... ,~; .:.; ,~**.; :,::**: ?,.~;***:~::.:,: ~,: :,~:~,~.~:,:,::,.::~,::~,~:~;***,,:**~,~:****~***~,. **?:~;~:,:,::,,~**~,:,,~. ~a** ~ ~**::~:****~**::~, **** ,::~***~ ********* ,.~,:**** *****~****~: :~: *****~** ,~,: ~,;~**** ~,:~,:***: **** ***** ** ********************* ************************************************************** ;,, ,**:,.,. ,: .~., :,:~. ~**:~,,.~.::::***:;::~?.,:~ ,. ,:.. ,:z:..,. ~ :.:.. ?.: .., ;,. .... ,: .:.,, ..,...::, z; 2600 2318.56 2220.56 43 22 N 6.10 W 0.87 886.60 N 156.47 W 883. :30 2700 :2390.77 2292.77. 44 10 N '5.60 W 0.86 955.42 N 163..52 W 951.97 ...... ~ ......... 28()r~ ......... ':' -'~' =- '"'" · ~ -:':.-- . , . ~ /, ' ::'~ ..:.~.:: ::.'.::- .- .?'"':.: :.: ':' ~. ': ~:..:. :.~: . ., ~ .... " ':::"' .................. ....... ' ............................... ' ................................................ ' ...................... ' ........ ..... L':C :' ~'~'~:' .: ':~ ' . 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T~NE~UL~R COORD [ N~TES HD-'TVD VERT ] C~L .~::~.;~.?~*:;~:~;~.~:;~;;:~?;;~;;:?;?;*?:*;~*;~::;~;*.~;:*;*~.~:;:;~;~;E~.*~;;~;~::::?;:~;~.~;~:;~;*;;E;;~;~:~***;;;~;*(¢?*:E~;~(;4*~`**~.;~;~;;;;;;*;;~*~;:~(~;;;~*~(~;(:*~;((~*.~(**~4;~.:~(~;~.;~*~;~*~:;~*~(;;;~:**((~;~;s;((((~;~:~;~;**~**~:~;:~*~**~;;*~4;~;;;*~(;:*4~(;~(;(;~((~((;~*;**((~;~(:~;~4;*;~(~*:(;;~**~;;~;**(~:~:((~(4~(~*((~(((~;~***;(~((~***~(~;~;*~(~;;;~;~;~(~(~;((~((((((((((;~*;(~:~;*~((~((;(~((~(;~;~(~*~(((*~;(~((:~(;((~(~(~(;((**~(~$;~(~(~**(~*(~***(;~*~*(~*-(~(;~;~**~(((~****~;;~(~*~:~*~(~(:~*~:~t*:;~;~:(;(*~*~:**:*;;~;;~;;;;;~;;;~;*~;;~*~:~;;~*.~*~;:`;~*;~;~;~*:~;:t~***~:;;?::;~?~(?~;~***??.~ 2000 1,=,70.04 t 772 04 49t 3'" '--= L~ N 1"':' "" . . uc,. 94 N I . ~.~ 127. 3000 2606 =~ ¢, c,--, .=.-=, . l...,u,=,. 54 1162.70 N t,=,~,. 24 W o~ o. 46 ............ 4, ..... .. ..... ,.~ Z.~, :,~ ..... . ....... ~.= Z. 6,..,:..8 .......... . ............... ~.,..~:~:~...:.::.:. ................... ~.8~,,~.:,.::~:.=..: ....................... .;...:.:..~,=.~ ::. .......... . .::: .:?:.:~...::~.~::~::.?:'...:.:,,?::?.:~:.~:~:.:~:.~:.: :~ ~?.~,~.~..~?:~..~..~:;:~?~?~.?.?.:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~.~....~..~.`..~.~.~??~`.~;~..~~.~.~8~,.~?~:~:~?~?~:~:~*%...,..~...~.~..~`..~`..~:.?:~¥~.:~.~.~`~.?.~ .................. ,~.......C:.,.:. ........ .-:.::..... :.:: .-: . ... ...... . .... .. 8000 6~:]:~,. 16 6~,.=,,:,. 16 4301 .65 N /,5_ _ ,90 W 1 ._~;'o.=, '=' , 84 '"~='"' '-"=' / '-"-' ='-' A5 ~ ~c, N ~ c,. u.:, E 17~,_,. 4,2 164. ~",~: ~= .... ,,..~ 6,=,.¢ 1 ~'~' '~'-' ' '=' ""- . ._,,=, =,7~c,.._,o 4: 5'~ . '- '=' . .. · :.: :..-" .': ............"....:..K ~: ..":.' .,::. ....,':;', .';~ .':-:.. :,.:: .~'-... ::....,': ':. :-"':::..:. '-:.~.?:.'. ..,::.. ~';...~ ,:;..:::.::~.~.~`.:~:;`;.;.;~::,~:;::`::~:.:;.~::.::~.~.:.~:~:;~.;:~::.:.~:::~:::~:~:;:~.~:~`~.::::::::::;:::::::..:::::::`:...::::~:~:~:::~:;~:~:~:~:~:~:::~~:~::.~:~:~:::::~.~.~:~.;;~:~::::~:~:~:;::.~:~:~:~:~:~::.::~:~:;:~:::~:::~:~`~:~:~:~:~:;:~:~:~:~:~.::~:~:;:~`~:~.~:~:~:~.~.~:::~.~:~:~:~`~:~:~.;`:::::~:~:~:~:;.~i~::~.:::~:;;~; ' .,.' .'. :.:.:. ' ..'.; -.: .,.. I<I,..IF'ARLIK FIELD APRIL 6, 1:~82 ,_IDB NUMBER B61:~1S-16'~22'0 ALASKA KELLY BUSHING EI_EV. = '.:):::.00 F'"F. ::":":: ~:iiii~:i~:~i:)!:i:!::~i:!:~:~ii:i:~::!i:i:!:i:::i~!:~i~i~!:::~:ii!i:~i:~:`~:`i:~::::::?i!:!:i~i:i:i!~:iL:ii!i:~::i:::!i:~i~ii!i:ii:~i:!~i:i::!~ i:i:i:i?!::.::i'.:'i:i:. :i~i:::il.i:?i::!.:::i:i!:.iiiii:!iiii: ~.~:~:~:::~:~:~:~:~:'~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:::~::~::~:~:~:~:~:~:~:~:~:~:~::::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~::~:~:~:~:~:~:~:~:~:~:~:~::~:::~:~:~:~:~:~:~:~::~:'~:~::~:~:~:~:~:~:~:~:~:~.~:~::~::~`~::~:`~:~::~:~::::~:~::~::::~:~::~:~:::~:~:~:~:~::~:~ ':il. :::i'::ii.:::}ili:i!!ii?.!.?::::'::.:!:i!iiii!i:']!::.:i:: ':'i'!::!': ':::, :.:: ,i:., Z.., TRUE , ~.,LI~ -:.':.,EA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD--TVD VERTICAL ._ .~". _ . . , "~ , "', - , ,-'-- u - ~^c-"r .,,~.~c."r - -, -. - __ .... , , -' ]:. - · - _ 198 l'F;8.00 100.00 0.36 S 0.30 E - 0.00 0.00 298 2.98.00 200.00 0.40 S 0.68 E 0.00 0.00 . ,: :'::~::(~, ~.~ ~:~:::::::::::::::::::::: ::~ F":~;~.~. ~:.:: '?;:~ ~:~:::~: .':::: :~':"..,~'~': '~'~'~ ::~::~,:. ~.:~:::~:~.:' ~, :. ::;:~??.'~-~:¥:' ~-'" :: :~: '::F?'~:"~' ~.:~ ~':?:::~ ~::~::::: ~ ~'~:' ' ~' ~' ~'::~::~ ::::'~}'~}'~'~'::'~'~ ??::.~::~?~:~::~?:'~'~'~'~?~'~':~?/::.'?:::::¥:' $ '~ ?:::~::?~'::~::::¥:.::'~'~'~' "?: ~ ~ ?:'~::~ ?~"::~$'~'~':~::::?::~?'~'::~ ~" ¥"~'~:: '~ :::?~??: ::'~'~"'"" :.?:?:'~ :?.~'.~'~'"::'?~:- ~':'::: ...... . ..... · :' : '~: ' .~ ' ' .... '. ' ~::~¥~::::~?~:?:~?:~::~:~?:~?:?~A?~:~:~??~?:~:::~::::~?~?~:::::~::~::~::::~A~;~;~?:~:.::~::~?:::~::~?~A~::~::~:~;~::~::~::::?:~::~?:~?:$~::::::::::::::::::::::::::::~?:?:?:?:~?:~?:?:~$~??~2~?~i~::~?:::~?:~?:~::::~?:?~::~::~?:::~::~?:?:::~?:~?:::$~::~::~?~::~?:?:~?:??:~$~??:~?:~?:?~¥~?:~$??:~?:~?~?:?:~?:~:~?~??~:~$~;::~::~?:~::~;~:~?:~::~??::~?~:>::?;?::?¥:~"~ S-?~':;:/~?~'.~ 7'~P8 7t~8.00 700.00 17.52 N 2.53 W 0.60 0. :38 898.00 800.00 30.10 N 5.27 W 1.43 0.8~ ~:~::~::~:~:~:~:~:~:~:~`::~:~.`~:~:~:~:~::::~:~:~:::~:~:~:~:::::~:~:~::~::~::~.~ ~:~:~ ?:~::::~?:~:::~`~'~::~::~:~`~¥::?:~:~:~:~:?~:?~??~?~:::~:~::~*~:?``~:~::~`.~:¥~ .:?¥::?:::~ ................. ~:~:~:::~:~:~ ...................... ~:::~ ............. ..,,,¥..., ................ B:¥:::::::~ ................................... ~::~::~:~ ......... ::::::::::::::::::::::::::::::: ..................... :::::::::::::::::::::::::::::: .......... ~:...~::.¥. :.~. :::::::::::::::::::::::::::::: ~.:-,..::.?:¥.:.::: :~.......~ ......... ¥:.,,.: ,~ ,. .... ....~.~::: :.:.~'?~ :.:: :::,~ ,. ':,~: ~.-' :~., ' ..'... ~:::~:~::~:~:~ .......... ~:.?i??::~ ~::~::~::~?:::~ ~??:~:p~::~::~::~" ~?~:?:::::~::~::~:?:~ ~ ~.~ ~:~?~?:~???:~?~?~?~::?:~?:~??~??:~?~::~?:?:~:~???~?~:;~?:~?:~::~?:~?~?:?~?~:::~??~i~W~::?:::~?:~::~?:~?:?:~?:~::~?:~:~?:~::~ ?.?:~:~:??:~::~?4~?~B~?:~::~?~?:?~?:: :' ~¥~. ~:~ :~:::::~¥~ :~ ~?.?:: ::: :?-%~::::::. ,?~? ¥?' ..... ,, .... _ 1422' 13~8. O0 1300. O0 168.96 N 44.24 W 24.36 9.81 1535 1498.00 1400.00 219.75 N 61.14 W 37.81 13.4.5 ......................... ~ .... ~ ....... ::::: ::~ ':~-:"...: :~': ~z~ .~ : · ~ ~. : : : . : : ..x.: =====================================================================================================================-Z,. "::: · ~,', ~:~ ~ ' ,, .. ~ :~,~'~ ~ ~ ~ ...... ~ :~ .......~ ~::~ ::~ ~-~:~:~:~:..~.~:::.. ~..~: :.. ~:~::~ .~ ~.¥ ................................................. =.. :~ ~ .................................... ~ ............ .................................... ~ .............. ~....~ ~:::~.~ '~ ........... . ................... :: ~ .. ~ ~ ~, i.::UF'ARL~I< FIELD APRIL 6, lt~82 dOB NUMBER BOSS--16920 ALASKA KELLY BUSHING ELEV. = '~8.00 F'"I'. :::: '::":.:: :h :':~ :::',,.'::'....:..':".~S:~':.:::~ : .::.~::.,:::'~:~:~:~i:::::~h~:~?.~.~:Fh'!~' ':' "' !i~"~"tii~:~F-.-.-?: ~i.~i.F~.h.ii...:~:~:j~i:~:~.:y.~:~..~:~...?~..:..i?~?.~iii~:.~.:..~ii~:~?:~i~i~.:::.:::.~i?.~.:::?:~::~?~7..?.::~:~.:~::h?.:.i`i:.~i~.i...`iiiiii` i::~:F:~":"!'~'i'h~?["?'?:i~:~"'~i,:"::'h?'~':"h'i ':?:i"'i~':~' ~.~::~'~:~:~ ?:H~:':~:F '~h~ ~:':::~.~:::::~'::?Lh~:::.~: '~::::, ,~.~ ':~.. ',.: : : ~ '" ================================================================ :::~::::~::::.:`~:~::.~:.~.~:..~:::.:~:~:~.~:~::~::~.:~::~:~.:~N.~F:.:~:[.~::.[.~:D~D[~D~.~::~~:~:~]~:~[~[~:~~.[~:~D:[~:`:~:~:~.~.~:~:~.~:`:~:~:~:::~::~:.~:~:.::~.~::.:~.~.~:;~:.:~.::~..:::~:~:~:~:::..~::::~:: :~ .~'.~:. TRi IL- ..,UB c, EA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORB I NATES MD-TVD VERT I CAL 2301 20~D8.00 2000.00 687.'1'~ N 133.88 W 203.78 32.62 245:5 21'~8.00 2100.00 775.74 N 143. ~-~'~ W 237.74 :.-:".:.::-.:.:":::;~' ~,:-"' ~'-::.:::.:'::.: · :?~:::' 'j :'~:: :': ¥';-'::.: :::::::::::::::::::::::::::::::::::::::: :~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::~-'~?:::::"~::'-::~::::::~.~::~: ~:::':~:~:~::??:~:~:':'-'"'"?':::~:~:::~.~::::'~:::~;~::?~:hh' ~:.~:~:~::?:~h~?:.~:~'.'" '::':~::~;~::"~ i :~: -.~:~ ::':.'::::. :~:~:::L:: .::: :..:...:.:~. :.. ' '...':'..':.':: ' '.. '..' ......... ':: '. :.:':-z :~:.' ........ · ........ ~..: ':.~: ~:::-::: '. ~:: :' ................... ~. ': '-: ': ........................................... '.' ::::::' .::~.:::' '.:' .............................................. ~, ...... ¥"': ................................................... ' ........ ::::-~ ~7~::-::.' ..................................... ~.-::.: ':.', ................ ': .......... ':':' ........... '.:': ": ..... ': - 3266 27'~'~8. C)0 2700.00 1~:47.6'~ N 204.12 W 468. '90 t.'::-?."'i~:i.~t~::.::'~?~:~' ========================================================================================================================================================================================================================================================================================================================================================================================================================================================================================================================================== "~,::::}::'C:~:::~:: '~;:~' :..?'~'~ .... .' '~: ::].. . _ ..' 3976 3298.00 ' 3200. O0 1849.7.1 N 242.27 W 678.55 44. 4123 3398.00 3300.00 1956.82 N 247.41 W 725.18 46. "::: ::::::::::::::::::::::::::::::::::::::::::::::::::: ~:: :::::::::::::::::::::::::::::::::::::::::::::::: ':':':'~ ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::: ~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~':~:"::"/"":~:::::~::~:~ '::'::~?:~:~'~: :::~: ':~:'~::~::?:"':' :':?::'?: ::::::::::::::::::::::::: ...... ========================================':~:~:~: :::::::::::::::::::::::::::::::::::::::::::::::: '::~':':~:::"::~:: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ':: ' :::::" :':: ':"" :' "::' ' ::' '::"::'?: ? ' '~ ~:' ": ' ¥ '' :¥' '" '- : ' 't ' ' ' ' I<UF'ARUK FIELD APRIL 6, 1'282 ,_lOB NUMBER BO:E;S-16'F,20 AL. ASI.::.'A KELLY BLISHZNG ELEV. = 98.00 F']'. TRUE .:, NE~SLIRED VERTiCaL VE'RT]C~L RECTaNGULaR COORDiNaTES ND-TVD VERTICAL 4977 .:,'-":~ 9'-'~~. ,:,. 00 3'PO0. O0 z~'~G 64 . ':~'='~ o N 2&7'. c, = 7 N 979, o '~,:,''' .:: .... u. 9. 9. 511~: 40c/8 O0 400(3 O0 .... ~.6._,./. 79 N o ,=, - =6,:,. 75 N 10 Z 7.69 :37.81 ........................................ ~:.~,~,:~ ................................. ~.~ ~:~.:~.:.(.j~j ...................... ~.~.~., ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ : : : : : ~ ~ : : ~ : i I : ~ :~: ~ r. i : ~. ~ : ~ ] ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ : : ~ ~ } ~ ~ ~ : :. ~. i" ~ ~:: ~ ~i ~l ~ '.]?:~: ~:+" : ~ ] ~ ~ ~ ~] ~ ~:]:~:~:]::: ..:~ ~l i ~ ~'~i:::i~'::~ · ..~0--~. ' ....... ~'~'~'0. i.~.l ..... 5781 45'28. O0 4500. O0 30'~9.84 N 263.73 g 1183. '26 29.80 5909 46%~8.00 4600.00 3178.73 N 261.18 W 1211.36 27.40 (:.,~,./ ./ ...,~.~ ~' c,. %.~1.~ 6518 51'P8.00 5100.00 3525.30 N 254.81 W 1320.07 18.21 6634 5298.00 5200.00 3585.26 N 254.00 W 0 &..' ." '..' ..!. '......,I...l~...' I .!..l. l"4 I~,..& ,~.zr-' / -- l_.l_l{'l[' I_~ I {'"{ I 1 i<LIF',f.~IRUK FIELD 'APRIL ,"_',~ 1:982 ,_lOB NUM£~ER BOS;S-1,/-','~?'.:-.'O ALASI<F.i KELLY BLISHINI3 ELEV, =" '~.?:.:.~:,00 {:'-'l'., - ' '{'71 ' ,,-~ - - ":'"'~- ....................................... TRLIE SUB-SEA TOTAL I'IEASURED VERTICAL VERTICAL RECTANGULAR COORD INAI'ES MD-TVD VERTICAL __ ~ z, . ,j:;~., .. ," - , ' ,-' - . ] E:' /X ,"_" "{" ,¢'{.IE",_-?"F' .... , '- -. .... · - , , "-. .... _ .............................. .~:~ ~ ::[~.~!=:~:'...:.:: ........ : ................ ?~::~~~:?~::?:.: ......................... ~F?'.~~.:~~~~:~?~:~:~:~:~:~:~:~,~,~::,~:~:,~:: ?::?.~:~,~.~,:::::::~::-: ~::~:~:~~~~::~ ...................~:::~:~.!i!i.~i!~!~!iii~ii~i~i~:::.i~i:!:~i~:~!!!i!i:~:{:~ii.:!~.:i.~!::::~i: ................ ~:'~:'~::::~::~::~ ~::~:'~:::~:::~:'~':~:::':~::~:~:~:~:' ~:~::~::~::~::~:::~::~:::.~::~::::::~:~::~::~::~:.~:~:~::~::~::::~::~::::::~::~::~::~:::.~:::.::~::~::::::.~::~::~::.~:::~:~.:: :~...d,.'f'~::.ff:ic'i'~::::}:{ :{ ......................... ~. :(:)~) ....... ' :{ .................................... Z~ ........... i!i::::::!::i~:~:iiiiii:::i::::::::i~i:.:::;::::i?::.i~iii!?:!~::i::i::~::::i::::~::i::~ii::~::i!i~::i::i~i~?i::~::?~i~i~i!::::~i!:~ii!ii?:::ii::~::::!::::?.!:.:~iji::~. ............................................ :::': : ~:~: ::: .:::::::::::::::::::::: : ::: :: :::::::::::::::::::: :::::: :: ::::::::: :::::::::::::::::::: ::::::::::::::::::::::::::::: :: :::::::::::::::::::::::::::::: .................... ~:~-~ ............. ~:::~:~.::~:~:~ ............................... :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ............................................. 7:321 .5:_=:'F;:3. O0 5800. O0 :3'P15.58 N 207.57 W 1423.66 Id.. 46 7441 5'F~:~8. O0 5'PO0. O0 3:~7:9.84 N .. 1 '.90.26 W 1443.7'F/ 20.13 :: ~: :::~::::::~.~:~:~:~:~:~:~:~:::::~:~:.:::~:~:.: ~:~:~::~::~:~:~:::~:~::::~:~:~:~:~:~:~:~:~:~:~:~:~::: :::::::~.::::~ ::~::~:~:.~::~::~:.:~:..::::::~ ......................................... :..*..~.:::!::~::....::::~ ............ ~:::::~.::~:~:~:~ ................... :::::::::::::::::::::::::::::::::::::::::::::::::: :::::::~ ................................................ E-:0:33 64'~8. O0 6400. O0 4:35:::. 6:9 N 43.57 W 15:z:.5. :z:6 :3.5.0:5 :.:::.223 65,?,:=-:. oo 6.500. oo 4442.54 N 4.. 73 W ~ 625. ~ 6 ::-:'~?. :30 :::: , .. i !i :":~ '":~': ~;~.:'::::::::.':::; ::~:: THE CALC:ULATION PROC:EDURES UL=;E A LINEAR' INTERF'OLATION BETWEEN THE NEAREST 20 FOOT MD (FROPI RADIUS OF C:URVATURE) F'OINTS .... ..... i ............... i, ii. i .................... !i..i i..i..i:ii .......... J. ~L.' .-' F--' J. % ---~L..~.....' I,J. J, {~{ 1% J. m,.t[,.~ .,f ' ~_.~..i{-II-' I..! { rl { ,J. I,.ll'4 ~-I{'-{ ! KLIF'ARLIK F I ELD APR I L 6 '-'="-' N..IMBER BI-'i:.~;S-. · 1 ~o... ,_lOB I ' - ' "' .... AL~SKR KELLY BLi.:,H '""1 '-"" TRUE ;:, JB-;:,E~ TOTAL NEARI_IRED VERT I CAL VER r I _.AL REF.'TANGLILAR COORD I NATES; ! !::::.......::-.-..!.~:..-............: .......~.~..:~....:.::...:.:.:.......:..::.....:~T~:~:~;~L~:.:.~:~i~:~i~:~:~:~:~:~::~:~:~.~~~~}~:1.~:~:~:~:~:~:~:~:::~:~:~i~:~:1:~:~:~.~:~:~::~:~:~:~:~:~:~:~::~.~:~::~:}~:1:~:~:~:~i:~.~:~:~:::::~:~:~:~:~::::~:~:~:~.~.:~.~:~:~::.~::.~:~:..:~::~.~::..:.:..: '.:...: .'. '...'::.;.i' :.i::.. :.. 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' ..... I ,.I.' .0--~7-.-# ..,..i. i~ .... ~l. A. -.- # .~..,.. "¥Y i .-.i .M,J ,--il 7~ 7(.{ /_:,~1© '-' ~' :::,' 6 6.:, .1....,, '-' . . ,=,/:, 42A3 ls? N 73.77 W BA:_=;E CIF UPPER ::;AND ::-: .1. '~',~2 ":i ''? ~'~ _"1 - '" '-' 'i . .. (.: .... /..., ¥.?4 64.77. '.~4 ~422.4(-) hi 1 '-' · . o./_',1 W TOP OF:' LLI4ER .=,RN[ .,:3 '":," "~, "~., '-, ,- ~." "~, .' , .... ," ,- ,_"'.~ /_ ,-, " ,-- ....... , ,". ;i::!;!i?i;i iiil!ii !iiiiiiiiiiiiiiiiiiii i !! .;; i;iii ii !; i!:, i ;i ii ii!iiiii iiiii i i ijg( i!ii ii i iiiii!iiii !iii iiiii!? i iiiiiiii i i iii!iii iiiiiiiiiiiiiiiiiiiii iii iiiiiii iii!iiiiiiiiiiiiiii!ii i iiii!ii iii!iil!i iiiiii!?,iiiiiiiili!iii!iiiiiiiiiiiiiiiilliiii!iiiii ii iliiiii iiiiiiiii iiiiiii!iiiiii?:!;iiiii!iiii!iiii iiii!i!iiiiii i i ; iiiiiiiii iB i '-':"'"=P '""-' ,._,c, ~6._,~ ':~'-' '.".~.=~.03 E DRILLER ,::,._,._,., 6o,:.1 :"-' 672.'.:.: .~'-' ='- ...:, N '-'-' 0 0 ~ -' ' DIL DEFTFIc, AND '- .... '" EERIgED USING ~.,PERRY SUN SURVEY D£41'A 'TOP OF' F:::LIF'~RLIt::: 7790 '-'" 6..-7,.,, '-'-' · .. ,::, 417'7. OON i :l '?, E,:3W i-:.: ~ ."u.:.: ~ :::2:1 '::5 3 !:!: i.h: (:'::!.l "l.:::.'::: :l::!.:.:':..:'. :~:i::: :::.::::::::} ::{" { ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::.: . :: ' /. :..-::::::.-:. · ..~,.~i:iu'~ .. '::-: .~ ~.? .~':'..,i".f~, .... ::::::::::..:::~ ========================================= .::: : ::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::'::::~:::':::':':i ~ :.: :: :: : ::::::::::':iN!h'F~ '~ ':'"':' '-:T ":"'..:": : :::::::::::::::::::::: '~x · .: ... .:. :. : . .... ...~.:. ............. ~t, ,E:.~:~..~F::t:~FPER.:.:::~,~ND ..................... 7:-.~:~i ........ · :i':..:':-: :;:. :'.. :!: -."~ ': :...: .. '-':..:'l:: :'.; .1!' ..':.:' :h: ..' :.~';: ~:::::;.:~ :: ¢~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: oo46 a, 6oo, 31 z =,~,,= .:, --,o · ,:,.:,o._,. ~, 1 452:3, ~=N ..:: 1,31E S[IRVEY. DEF'TH ':'-:'.-" ""'-'~=" 66,::,6'~. 02 ~:,._,oo, 02:'~'-' 4...,.,:~,, 'F¢ON:"~':' .",o ~i.-, -" ARCO Alaska, Inc. Our Boss~ Gyroscopic Survey Job No. Boss-16920 Well: B-9 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: November 2, 1981 Operator: Everett Sellers Scale: 1" = 1000' -10~0.00 TRUE NORTH 8550 ~000. O0 ~000. O0 1000,00 Surface Location -) 000. O0 HORIZONTRL PROJECTION ARCO Alaska, Inc. Our Boss Gyroscopic Surevy Job No. Boss-16920 Well: B-9 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska- Survey D~te: November 2, 1981 Operator: Everett Sellers Scale: 1"= 1500' O. O0 1500.00 9000.'00 4500.00 6000.00 7500.00 4660.86' @ N10 8'E ,sbo. oo ~o~0. oo ",~o. oo ...... ~°bo. oo VEBTI C~4L PROJECTION Mr. Bob Hines ARCO Alaska, Inc. ?. O. Box 360 Anchorage, Alaska 99510 December 14, 1981 Dear Mr. Hines: Re: Our Boss Gyroscopic Survey Job No. Boss-16920 Well No. B-9 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: November 2, 1981 Operator: Everett Sellers Please find enclosed the "Original'' and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on th~ above well. · Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures Cons. Gommission NORTH SLOPE~ ALASKA SURVEY DATE NOV, 2~ 1981 GYROSCOP[C SURVEY RECORD OF ,.SURVEY DEPTH ANGLE DEPTH SEA DZREC D[ STANCE ANGLE DEG/~OOFT DZSTANCE _ D H DEG. D N 5 ::~:~:::.~'~~~:'~o~N~~~ :::~w:.::::: o'00° .................... 0-;-0'6 300 0 ~7 299.99 206.99 N76.10E' 0.~6 5 0.75 E 0,79 S 70 ~2 6 E 0,083 -0.25 ~00 0 14 399.99 306.99 N13.60W 0~07 N 0,96 E' 0.96 N 85 ~7 53 E 0~050 0,09 · :? '-' :.. ~:. 'o . :6 :'.'W.:..:-;:':.:'._::.:~..~Z..:'N 2ZZ 28. W...' .~33 ~.ZZ -:900 8 ~5 898,58 805,58 N~3,50~ 30,43 N 5,18 ~ 30~87 N 9 40 10 W 2,767 30~33 1000 10 20 997,19 904,19 N20,OOW 46,31 N 9,96 W 47,37 N 12 8 31 W 1,61~ 1400 25 43 1377.95 1284.95 N14.3OW 1500 29 55 1466.77 1373.77 N20,30W 2000 ~0 ~3 1870.00 1777~00 N 7~60~ 2100 ~0 51 1945.70 ~852,70 N 7~30W 159.77 N 41,59 W 165,10 N lZ+ 35 31 W 4,123 158,91 203.59 N 55,24 W 210.95 N 15 10 51 W 3.z+95 202.z+5 ~--2.-5-1 · 2 O-.N ........... 69.,.19.._.M.~ ..26.0.,.1L_~_l 5_3_1_-(*.1._k~...-._2 · 572 .................. 2~ 9,77 ~:~3'63, 53 :~: ;N:;~'.::'~;?.:'.~:~::~ :92','09~'~:'~:w ~;~:~:~::~.::~:.~375 :' 01:': N'~::::~ ~::;~:i'2'~.~;:~:54' W::.:~:. '' ~. 192 361,63 ~91~4~ N 108~98 W 503,38 N 12 30 l~ ~ 0.233 ~89.17 556~23 N 117~45 W 568,49 N ll 55 25 W 0~185 553.78 ARCO..WELL B=9 BOSS 16920 9 DEC, 81 RECQ~D_O£__$.URV EY ....................................................... MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O S U R E 3 SEVERITY $ DEPTH ANGLE DEPTH SEA DIREC DI STAN¢£ ANGLE DEG/iOOFT DI D ......... M ..................................................................... DEG., ............ _ ..................................................................... ~- ......... ~__.ID_ .... ~ .................. w: ,2_5_0._(L.-~ Z~' ~':· zZ ~6.,..3~'221~. 2., 38:~ ~'j~ ~:::~:819_~,,""' ' ~ '2.~N"~ :~ ~.8.,'.9~ __._~. L:~ ~ ~_2', ~-~:~1.O~_.2~_~ ........... o, ~ ~ ~ ................ 2600 43 22 2318,5~ 2225,53 N 6,10W 887,02 N 156,52 W 900,72 N 10 0 26 W 0,8~ .. ECTION STANCE 749,39 816,13 .... 883,73 2700 44 9 2390.74 2297,74 N 5.60W 955-84 N 163,57 W 969,73 N 9 42 39 W 0,82 _.£&O.O....4.~__.~2___2462., 5 ~__2369__.,.5~.__~_6 · 20.W._~_iO. 25_, 07_.~ ...... 1.70, .72_W ........... 1039 ,. 19_tN.~ 9. _..21._ 2 i_.W ....... 0 · ~ 13 "2900 q, 3.::57.? 'W..-':"::Z]'OSeS. 7-.t' N:! ::::-' 9.: :15 ...'18 W: "' 0,096 Z 3 .i:iN !.i Z:.. ::1 2 0.. 6 3200 44 1~ 2750,08 2657,08 N 5,70W ' 1301,60 N 199,85 W '1316.85 N 8 ~ ~5 W 0,292 3300 44 25 2821.61 2728,61 N 5,30W - 1371,16 N 206,55 W~' 1386,63 N 8 3} 59 W 0,28 _._3.~DO.~ .~4-.3 ~-2892,91 ..... 21~ 9 ,.91_~_5., ~Q~ .... 1~.0 · ~98 ~:_.N .......... 213 · 02 ..w ......... 1456 ,~ 4._ N ~. 8 .... 2.~_~ ~. W ......... 0,18 ~.10 ~_...~.5. 2:25i ~?L 3.t0.5.,.93L]~ 0_1 .Z ,. 9~:'~'.-2'Q~'~.6~.i- ~ ~.. :~...~.2.~ Q*.O 2, _:_.W._.:.2._~ 1667 · ~.1 .._.~7~_~ ~ ~_.~__]. ~..... 0 · ~ 2 3800 45 58 3175,76 3082,76 N 3,70W 1722,94 N 234,95 W 1738,88 N 7 45 55 W 0,60 3900 46 7 3245,15 ~152,15 N 3,40W 1794,80 N 239.4~ W 1810,70 N 7 35 52 W 0,21 ::.41'00 47 "9 "3382'21'~' ~'3289'2177~']~J'~N'~2'50W.~.'~"!940 26 N':.~'".'..:.2g6,97':W'. 1955,91'.N~':7 '15 14 W' ' 0,42 ~:.~200:.:47.:}.].~...~q'~? 3450'2.8>~'~..~3357'28j~N"~2'60W:??'201~,44':.~N :. ~:.t' 250,23. W~. 2028,93-'N~.¥]'.7'. -5 3 .W 0,14 0 952 .......... 1021 1090 1159 1297 0 1~66 3 1436 2 1506 8 1575 9 ............ 1646 8 1717 6 1789 2 ...... 1~62 8 1934 ~ 2008 9 ................ 2080 4400 45 37 3588.,26 3'495,26 N 2.10W 2158.08 N 256,35 W 2173.25 N 6 46 27 W 0,810 4500 45 32. 3658,24 3565,24 N 2.00W 2229,47 N 258,91 W 2244,45 N 6 37 27 W 0,098 .... ..4.600._..~.5_26_.._3.728 · 33 ............. ~ 6.35..,..3~.~,~0.W ...... 23.00,76..._.N .. 261,27 .... W ......... 2315,5~._..N .........6 ..... 28.___~.._ W ................ 0 · 143 .... 4700 44 5~ 3798,81 3705,81':~':"~:'N':-.1.,70W '237~'66 N 263,4~ W 2386.25 N 6 20 18 W 0.536 4800"44 10~:.~} 3870,08 N 265,34. W 2456.16 N.:. 6::ZZ 6 W 0,748 ~~.A~~. ~Ai~..S/.~.8_~.,.R~: L~,:.i_Q~]~] ~..kl,. ~ 8...N ..... C_ 266.., 86..~W ........... 2525, .~ 2__.N:~6 :' 3: ~_.~_, W,. '. __0., 1_97 ........... 5000 43 41 ~0~3,95 3920,95 N 1,OOW 2580~68 N 268,13 W 2594,57 N 5 ~5 54 W 0,35~ 5100 43 13 4086,53 3993,53 N 0.40W 2649.47 N 2152 222~ 2295 2365 2436 2505 2574 268,97 W 2663.08 N 5 47 48 W 0,545 2643 .......... ~ ~ ~3~ ...... ZTll 269,~..W 2731,01 .... ~.~..~__~...~_W ..... ~ .... .40 .47 ... .37 .19 '.16 .37 ,06 ,96 ,69 .0"%.. ,07 ,03 · 84 "' .60 --""' · ................................. : .................................................................... 9 DEC, ARCO. WELL B-9 BOSS 16920 ............... ~.C. QRD__QE ..... $ UR~/.E.Y .................................................................................................. : _: _~.~~RU£.~- MEA5, DRIFT VERTICAL DEPTH ANGLE DEPTH SUB DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY SECTION SEA DIREC DISTANCE ANGLE DEG/iOOFT DISTANCE 0.672 5500 41 0 4382.26 4289,26 N 1.OOE 2918.77 N 268.40 W 29B1.08 N 5 15 14 W 1.169 5600 40 15 4458,14 4365,14 N 1,OOE 298~,89 N 267,26 W 2995,84 N ~ 7 5 W 0,750 6100 35 42 4850.75 4757,75 N ~.80E' 3293,14 N 258,~0 'W 'D303,25 N 4 29 5 W 1,059 6200 35 0 4932,29 4839,29 N 0,80E, 3~51,00 N 256,99 W' 3360,84 N 4 23 7 W 0,774 8400' . ~2-.:: 58 ; -' 5098 ,12-:' 5O05.,"'12.?~:;~?;~N;'TO"I.OE:::?':;::~6z' / N 255,27 W 3472'17 N 4 12 58 W 1"046 6500'31 ~9~.'; 5282.63 5089'.63'~.;:;' N'0.2OE.;]',;: 3516.2~ N 255.~3 W 3525'48 N ~~~.26.~,~'_1.8=~ ~ 1,t 5:-,~~]~Ll~O g-~-9 ~..~.., 00._ N ............ 254 · 59 ..,W ......... ~ 5,7_Z_,g.Z_ 6700 29 52 535~,5b 5261.5~ N 2,60E 36~8.60 N 253,01 W 3627.2~ N 3 59 59 W 0:89~ 6800 29 10 5~1,5~ 53~8.5~ N ~.~OE 3667.60 N 250,00 W 3676.11 N 3 53 58 W N 238.82 W ::' 3769,79 N 3 37 56 W 7300 3L 27 5879~62 5786~62 N13'~OE 390~,96 N 210~56 ~ 3910.6~ N 3 5 10 W 7~00 3fi 22 5963~55 5870~55 N15~60E 3957.58 N 195~93 ~ 3962~7 N Z 50 55 ~ 3~ ;7?' · ,,,. - -'"'"" "" '"-":'"';;' ' '' ' -:':"4 8,6.5 N 1 57'41 W 1 7900 40 23 6360,95 6267.95 N23,50E 4241,71 ~ 92,28 W 4242.71 N 1 14 47 W 1, 8000 41 58 6436,20 6~43,20 N23,10E 4302,19 N 66,24 W 4302,70 N 0 52 55 W 1, 2779,36 2846,50 2912,86 0,820 0,999 0,613 0,439 1,883 891 S900.01 000 3952,88 844 4008,71 .. 135 40~5,61 437 4122,61 027 4180,12 755 4239,04 593 4~00,03 g,41 ....... 4~62.73 - 2977,99 3042,39 3105,66 3167,58 3228,23 3287.35 3~45.2~ 3401,86. 3457.01 3~10,~7 3562.24 .. 3612,66 3661,91 37~6,7- 3802,91 ...38~0,19 . /"-'x MEAS, DRIFT VERTICAL SUB DEPTH ANGLE DEPTH SEA TOTAL COORDINATES C b 0 S U R E $ SEVERITY ,EECTIOhi DRIFT DIREC 8350 47 19 6686.08 6593,08 N24.30E 4526.45 N DISTANCE ANGLE DEG/IOOFT UISTANCE D~ .... S 9!{~: 3 W 1,728 4427,01 .1,.2_5_.. ........ 1.094 ~92.73 ... 32,17 E 4526,57 N 0 24 26 E 2,64g 45g~,20 EXIRAP~QLA~I ED.__TD__ID~., ...... . BOTTOM HOLE CLOSURE 4661.41 FEET AT ,N- 1 8 21 E .. ARcO WELL B-c) ..-. Boss 16920' ~..::.~ i...:.~" ii'.. .:?i?? 9 DEC. -.:'i' .? : . .;: .'' i'. .- "" ':..- !-:.:-. -' ~:?."- '..~ 81 TRUE ~QQJ~ .J~LAS,UBED_ ........ .V.E.~II.CAL T.O TJ~,,~_C~O_~D_I.N. A,]~E~~.__._C_~..L_O _.S_LLS?_g ....... SUB .................................. NAME -'i DEPTH : '::::.::':!-'::'::: :_-========================= I'$:TA:N'(:;;E ':ANGLE ,SEA , : :ii:: '-:---' M s TOP KUP, 7790 6276.02 ~+177.58 N 120.10 W 4i79,30 N 1 38 48 W 6183,02 BS UP 5ND.. 7970:::-. :.tt..-..'7~,36 W ~28~,57 N 0 59 ~0 W 6320,83 TOP .LW ~:'SND.~?~:~: :.:f::: 8:.Z92 t?~f.~?:'?~':~ ::- 6575.* 00~:;~ ~4:.~8~3 i-~O:~.[:':N?-::' ::'~[~;?~t~:;."Z4.. 5.~.:.::W.f.::.:..::..: 442~.22:'-...::'.:.N:.'.:.:".' 0 ZZ Z8 ":W -:-. 6483.00 BS KUP, 83z+6 6683,37. 4523,81 N 30,86 E 4523,92 N 0 23 27 E 6590,37 SURV DEPTH 8350 668.6,08 4526,/-+5 N 32,].7 E 4526,57 N 0 Z4~ 26 E 6.593,08 9 DEC, 81 SEA LDE P~T_td_'~L _ ~.549 3693. 3600 856 42 2264.41 N 259.98 W ........ _&682 3.79 3 · ...... J 'Z_00_~_8_9_9_ ........... fl'~ ................ 2D_6~. 8 ~....N {:~:~.;.~::~'.' ~'... 483 2... '..(. ...... .. ~;38.93, · 40 ~. ' _ : 2464,03 N 52fi5 4193. ~100 2052 $6 2748.~8 N 269.~ 5380 ~293. 4200 1087 ~5 2838.98 N 269.fi~ W 6028 4793. 4700 1235 25 3250.73 N 259.66 W 6152 4893. 4800 I259. 24 3323.29 N 257.91 W ~:~:~;:~.;:-~;.;1;/.-~;.]~;:~':'-6.3~'~;;-;:'~;..?:.',??;f.'-;;~(:?';~(~;~?;.:.: 509~ 3~5 ' .' N:;;f:.:::?:;:::~.- Z . · " 67~ 5393, 5300 1351 15 36~0,19 N 252,08 6859 5~93, 5~00 1366 15 3695~9~ N 2~7,73 "f?:?.~:?:~;: ';'.' 7085::':".;:'-:('"~/ .':.1)?;!;/~. 5693 ..'13 .'. .; .;: 3801.~4.:. N .. ; 2" 7! W 7~35 5993. 5900 1~2 20 3977.35 N 191.57 7559- 6093. 6000 1466 24 ~046.55 N 170.80 W ;..{~:?:?;:?~.~.;~.::._.:~:: :... 7 $ ~ z' :;;~:" 9 ~ .'.:..::~_:~;::~,:z 00::;?::~?:::1 :'~.i $ ~;~}~ t~:.~?E.:..?Et-/.: 27 .:..-:::?.-... ::::::::::::::::::::::::: z 90,06' ~?~:?;~{:~'.794'2':';;'~?~.. ::: ::.?:.: :':: :6.393 42 66' 93 ' N'.'~' l:, 5'8'W - ' 8216 6593. 6500 1623 40 4438.53 N 7.23 W 8360 6693. 6600 1667 44 4533.17 N 35e16 E .. . . HOR IZO NTAL "V I EW ARCO ALASKA~ INC. KUPARUK FIELDs WELL B-9 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE= I" = I000' - DEC. !0, IS81 - - 64( · .... -~' .................................................................................. ~000 ~ TVD TMD = 8550' 48( . . 4400- $600- . $200, 2800. , ~400 400' 800 1200 SURFACE LOCATION IS 495'SNL, 1462' WEL, SEC. 9 T. II N., R. I0 E.,U.M. VER3[ AL SECTION ARCO ALASKA, INC. KUPARUK FIELD, WELL B-9 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: I" = I000' DEC. I0, 1981 44~ 680; TVD = 6822' TMD = 8550 November 3, 1981 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16920 Well No. B-9 (SEC9 TllN RIOE) Kuparuk Field North Slope, Alaska Date of Survey: November 2, 1981 Operator: Everett Sellers Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot DirectiOnal Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures W EL L :.' N. 0': 9.:'S E C :9:!i?:T:ji NORTH SLOPE~ ALASKA ' BOSS SURUEL NL SPERRY-SUN , · .:. : .; ;]:. :. ". : ' '];->f;;~ : '::: ~]: .:...: :; · ~ .::;:::¢?.];.~L.:h: MM EE IA S U R ED ~ ":":' V E R T I C A U:' ~':;:" ~:: :::~ ::':: S E A :::<: ::::::::::;:::::?::IN:: L::I N:A'.T:I'O:N~.~: ::::: ;'::. g IR E C ~:I'O:N:~::? DEPTH DEPTH TVD DEG MIN DEG MIN ?;!i'D:';:~:'.~E" OF SURV'~Y'::;"i :';::NOVEMBER 2, 1981 ~:'C:'g_L:'.'.:_~SECTION DIRECTION N-O1-50-OO-E BOSS-1692-0 i:/:i~i'i~ii!:!?i:~:~?C::T !A :~ G U L :A R: i.. COORDINATES BEG/lO0 NORTH/SOUTH EAST/WEST VERTICAL SECTION 0.00 -,39 -,13 500,00 ~+99,99 ~+01.99 I 3 N 18 24 W .H2 .91 N .55 E ..,,?~'--'T',-~ ...... ~"'~'?'--"~ '..! i.:.~ :: ::J:.~.~.~ -...'. ~' .~.'~.~:'~': '~'~'~'~ '~'" ::' ': -:..".~: ~:.;-!:.= ,~ . ...~'"~ ...~' ....~'~- ...~' ~ "' : ' 900.00 898.56 800,56, 8 q5 N 1~ 30 W 2.78 ~0,22 N 5.29 W 30,Oq 1000.00 997,16 899,16 10 21 N 20 0 W 1.95 ~+6.06 N lO.14 W I: ~ zoo · o o es:, ::.:: ::::::.:~::::.z?. ~5::.:: u { 1200 · 00 :~: 11 91:' 8 q:':: ::~<::~.i 0 93 ,B~-??~:?.~;~;?:.l 6: :'~ ~ :.::::'::"' :' N: ::i: ,. '~ 63 :::N :'~'::~ ': '":.:;;;~/25 ' 56::.' U' · . ~00.00 1286.~6 1~88.~6 21 ~1 N 10 ~2 W 6.28 120.27 N ~,05 W ~5o71 64,07 i 87,76 102.36, .i 119.16 1/+O0.OO 1377.91 1279.91 25 '4'4 N lZ~ 18 W ~+.37 159.52 N 41.69 g 158.11~.,,,~ I800.00 1717.20 1619.20 .... 38 56 N 7 ~2 W ~,61 363.23 N 92,06 W 360.10 1900,00 1794,10 1696,10 /-+0 31 N 7 24 W 1.58 q. 26.58 N 100,/+6 U q23,15 ~:l oO-O: ,+:5.- ~i:.~:.~:~::'~:::~<'i~i!::i'~i:i~i?~i:i,:~ ::::.::i: :::: !.>:: :5 s 1 ' s'~ 2_ 00 ;00 021:'. ::~ii;: .. .... !'j ~i :!.<i: 616,62 2300,00 2096,,6,2 1998,62 /+1 4 N 6, 54 W .20 686,1/+ N 133,76 W 681,51 q7.14 15.77 81.26 49,81 1.8.77 2900.00 2534,46 2456,46 45 58 N 6 18 ~/ ,11 1095,82 N 178,25 W 1087,56 z o :o o. Yb :-.~ ..:: :::::~~-'~ ~0~6 -~:: ::::::..~: :. :::~'~ ~d::'~:'~':~ ::~::?.:.::~:~:>~.~:~:~:::~:':.~~ :~:~:: ~' '..~:~ .:'~::;'~:::~::.~..:~5~:~ ~'"'~ :0.~ :~:~:.~f~?::?:~:~?:??~ ~ o o. o :::::::::::::::::::::::::: ~.~.~, ~:2-::?:?;?(::.~.:::::;~:2'5::8 :;::::~:?~?~:~:~?~;~:~:i'i::~ ~. :~ ~2' 5:~:::.::~'. :~: ~ 2 ~5. ~ 2 3400,00 2892,91 2794,91 44 37 N 5 18 W ,]7 1440,66 N 212,99 W 143~,1] '"'~~"'~-~7 ~~-'~-.~'?~m~:~.~" ~-~'~?~.?~:~7~?;~7~- : :~ .:..: .... : ........ ~.:~ ~ :.:~. ' ~ ------ '~ 3900,00 3245,13 3147,13 46 8 N 3 24 W ,26 1794,49 N 239,38 W 1785,91 4400°00 3588.23 3490,,25 45 38 N 2 6 W °84 2157.78 N 256.32 45 00 ' 00 :' .:: ~'~':5-:~?f~'~~~"~'~b~;~Z'd:~7~4''~~:%~?~: ~;~:~'~ :~ '~:~."~N~:::'.:~; 4900,00 3941,83 3843.83 44 3 N 1 6 ~1 ,25 2511,07 N 266,82 W 2501,25 ~ :;~5 i o'o' o o ::~. ~/:.:;.: :; ~o e ~. 4 ~:~.~.~.:~; :.. :::::::::::::::::::::: :.::;:? .:.2 ~ ~:' ~ 2 ~ ~ ~. 2o .... 53~'-0~-0~ ~'~;~Y ~i'3-~731 ............ 4~='i~: '~' '0 ..... ~-4 ~ ......... :::~' ..... ':';"7~`::'':'':' ~'':' :'' ...... 2~''96':N''~ .... ""~6g,:ei--'W ' 'e77~7~ 5qO0,O0 4307,41 4209,41. 42 8 ~ N 0 12 E .16 2852.11 N 269.06 W 2842.05 ..... -~ 8 o o '. 0 'o 4 &"~o3~~~i~ ~-~ ~ ...... i "~"~""' ~; ............ i .'~ i ~-i i"i · 'z u "NZ'6 ~ · b 2- ~ ....... S i '0 i ' r'~ .......... NORTH SLOPE~ ALASKA BOSS SURWEL ROSS-]6929 NL SPERRY-SUN · :: : : '":: :: :::<': :' ?:.'~:: :::~'F;~:;~:::::':RECORD:::O:F::'~ ::::" .. ': : '<;: ~'<' · DEPTH DEPTH TVD DEG M[N DEG N[N DEG/IO0 NORTH/SOUTH EAST/WEST SECT[ 5900.00 ~;690.55 ~592.55 37 55 N 1 48 E .68 ~317`9.09 N 261.62 6300'00 5014,65 ~916,65 ~3 5B N 1 18 E 1.09 ~07,30 N 255,93 163.10 22~.7~ ........ 282.86 3~0.7~ 397.37 6400.00 5098.06 5000.06 ~2 59 N o 6 E 1.iS $462'.45 N 255.25 W ~ 5 o o. o o :-:.~. 518 2 · 5.5 ~?~?. : :: 5 0 ~ ~ · 5:5~ :?~.:~:::?~?~:-~i::~?~i':?:~:;=~:' :: :::~ ~;~<~;:~i~:;~-~2· ~:::;:~:-~.:~.?.~.:: ~f~:l~;':9'~ :N. :'. ~ 2 5:5, i 1 w.. 66 00 :: :: :: :.:.:::' : · ::' :<~:::::" :' i;?::"~' :';?.' <::~:::"? :<.~?'(:<~--:?:~:2~::~:;:~ :<':.-.~'~';": ':~::<:-;?~:::~:?:d?~:c?:~' E ':': :':'" :::: :::" ." :::<:' 6 7 0 0 · 0 5 3 5 ~ :- ~5 ..~. '.~: ."'~:::~5 ~ 5 6-'..5:.:~:::.:¥~:~:-~.:.::~.:~ .~9 :.5...:?::: :~: .:.:: .::'.:< :.:::' ~ :::: ~::-.~:::.~.:::.:?..¥:::: .. .:.. :':' · "::'-" 6800.O0~5~ql.q6 5~3'q6 29 11 N q 2q E 1.13 3667.28 N 249.99 W 3452.52 3505.97 3557.73 3608.15 3657.ql 6900.00 5529.11 5/~31.11 · 7100.0 570:5' 7300.00 5879.53 5781.53 28 22 N 6 5q E 1.?+5 3715.18 N 245,27 : :: :<" · U::< 1:0 8'07:; ,:) 2 ~.:i:: ::: :'~': ~ 3.0,9 ~ 51 28 N 1~ 24 E 2.02 390q.60 N 210.53 3705,43 3752 3798,58 38~5.95 7~00.00 5963,46 5865,46 3~. 23 N 15 36 E 3.16 3957.20 N 196.89 7800.00 6283.70 6185.70 38 39 N 23 12 E 1.15 ~182.87 N 117.~3 ~004.87 q061,97 q119.20 7900.00 ~360.83 6252.83 40 24 N 23 .90 E 1.76 /+2~+1.29 N 92.20 Q 4236.17 8300.00~ 6651.61 6553.61 q6 I N 24 6 E 1.10 4492.87 N 17.36 E q~91.12 8350,00 6685,91 6587.91 q7 20 ~ N 24 18 E 2.66 4526.05 N 32.27 E q52q.76 'ii~ ':.. :~ ' ~...?':':. ~ .~'~'~ ~-~'?~ ~',~-~-'~-,~,~~,~,~~~--~..~,.~'~'~-.. ..-i : ...... .,. -.,.,........:..>.......:..:~ ..... ~ ~ · -,.. A R C 0 A LAS K: '~-:.' I N C '..'..:.':' ·: . .:: "..... '.'::: :..:: ::: '-.:: :.: ::',.~?:':: :-~.~: ':'.:: ~ ': :.-:..:.:.':~. :-...-.::~.~..:...'::~.:'.':. :,...: :: .':~...:.. :'..:~:::' ',' - :P' A ~'~ .... ~ .............. ~ELL 'NO,'B"9: s'EC :9'::TilN:].~.io'E" ?:": :':?::: SURVEY '~: NOVEMBER 2, 198,1 K UP AR UK · F I ELD. "'..~ '. '~..".:.~: ":..~: .'.. '.-~:.~.~.~.~:~']-.--.." .::-..' CA L':S E C T I ON D I R E CT I ON N-O 1-50 -00 -E . NORTH SLOPE, ALASKA BOSS SUR~[L BOSS-1692~ NL SPERRY-SUN ....... ~.~ ~-~~~~.~,~~~~ ...... ~.~... ~t~ ~ ' .~~:. ?..~,.? ~......., .. ... . ....... _ . , :.....,_ .. , · . '~. ..... ...... ~.:..: :. .~: .... · .~....:'. -:~. ~.~.~. ~:...~.:.....:.::::~>:~:::-~::~::.:~-~ R E C 0 ~:. OF~-...-.-:~ .~. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '... ~.-':': . .: ~.~::.'.'~....'..': .... .... .:~ . .- . .._: :. :::.:~::.'..-:..: ':. ... ~::':':. :.::~.. :-:. ?~.~:'.. :: ::..:-::::?'..'.:'~:.::.:~.:::'============================================= .~. ......: .. -'..:'.:~-::: :::':~::-::.:~. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:.:::~.. :..: ::~..~..>~... ~.~ : ~:~ ..::. : :.:. ~' :' ~:~ :~ ~.:.?:.':~.',; ':~.~..: :c.~'L~c:.oL:~:~:-~:O.:~ ~.':~:~::~.-~:S.~:[~ o':".:::~:~ ~', ['~:~'~:i~":~'~:~:~~'~:."c'~~" v.~ ~.u ~. ~.:.... [~,.H~,:~::::::::~: ..~ HORI2ONTAL DISPLAGEMENT : ~526.16 FEET AT NORTH 0 DEG. 25 MIN. EAST ~TRUE} W E L N 0' ~:B 9' :.:: S' <C'. R iOE ;:.: ::'~.;~?i :: ;:~: :<~: ; ;;i:::;:::.:':::{?~!::;<::;~i.:~::~;::i~::i:!i.. <.: .-:':::>S::<::-::;!?.:'i:;:i!':i:. :::?:: iD"A T E 0 F S U Rv E Y<' :'.':i'::';N 0 V E MB ER ' 198' 1 ~ , ":: :' ' ·.' ':' · ': ': :.; :: · :::':;:.'.~ ; ]~ :S>.::: <::>':>: ::.; : ' '. ; KUPARUK ZELD:: :. :;;:. ~...- ......~ ~: ~SL: ;~'<:?<" ."':'::':" ' ' ..... = - · NORTH SLOPE~ ALASKA BOSS SUR~EL BOSS-1692'0 · :: : · .. : .: ':: .-.: -.' :. '.< -. '." '- · '....z-<-.'h-. ::.::..?.::..~.> :.': · .:: -y ii' ' { >: .:.':.':: ...:::.~:<..<..~:. :: .: ... :' . : : . · ':' . · :i ..~:.i :i ::~ i.i~:. TED RE :ii il/"::.:i>. MEASURED VERTICAL SUB SEA TRUE RECTANGULAR COORDIN DEPTH DEPTH TVD ELEVAT I ON NOR TH/SOJTH EAST / ATES WEST O. E "i O. E ~; l. E 1, E 1, E 1001, 998. 900. -gO0. 46. N 3 · W ............ ! 5. W 10. W 18, W ' 26. W ," ., 61. W 123. W 2710. 2398. 2300. -2~00. 965, N 2849. 2A98. 2z~O0· -2400. 1059. N 144. W 154 · W 164. W 174. W 3267':~::. ':: · 2798 3407. 2898. 35~7. 2998. 00, :. :: ::.:: :.' ..; ::.: ~.:. ?.! :~ .::::.:..i::: :.': :. 2:50 .... :' 11:55: o i:::. :.!< ;..:.:.'.::! 2800. -2800- 14~+6, N 2900, -2900, 1543. N 195, 204. 213. 222. MEASUR~-D VE'P'TI-C-~-E=:::: ..... ":::'::~:~'=:~::~'~'~":~ l~u~. ' '::;"' : RECYAN6UL'AR ':--:'~'~TFS DEPTH DEPTH TVD ELEVA T ION NOR TH/SOUTH EA ST/~EST ~978. 3998. 3900. -3900. 2565. N 2'57 2~3, 268 270. 259. 2~7. 255, W I, 25~. W _.j 2'5'2'; ...... ~ .............. 2~7. ~ · 7322. 7~2. 5998. 5900. -~'8'00. s~ 1~,. N -5900, 3980. N 232. 221 · 190. NORTH SLOPEe ALASKA BOSS SURWEL BOSS- 1692'"D '":'"'"":':':""?:' ':" ............ ' ...................... ~ .... ";:':'"" ?'""'"'"" ...... ........ TOT AL MEASURED VERTICAL SUB SEA TR~JE RECTANGULAR COORDINATES DEPTH DEPTH TVD ELEVA TI ON NOR TH/SOUTH EAST/NEST 7949. 6398. 808~o 6z~98, W W INTERPOLATED COORDINSTES FOR EVERY 100.00 FEET OF SUB-SEA DEPTH FROM 0.00 FFET TO 6587.91 FEET Su~uested form to be inserted in each "Active" well folder to c~,eck for timely cc~liance w-J_~ our regulations. ' ' 0~era-tor, W~I1 ~ame and Number Reports and Materials to be received by: !~-,,/~-Fl Date Required Date Received Remarks · , , Completion Report Yes Well: History'] Yes , · _S~es. l,'o'-Pt ...... _. ....... '::. .. . Mud Log .-. __. . Core Chips. /'~0/~. -e, Core DeScription ' '}Registered Survey Plat ,.?. ~ .~ ..-. ............. ~ ........................... :" , 7 e~ , Inclination Survey . ~~, ' , ,, Directional Drill St~ Test Re~s ' ~ '~' ~ , ,, , , · ...... ~,u~,~n ~LOPE E~iGI;IEERIi;G TRAr'~''''TT';' //7 7 J. J. Pawelek/Ann Simonsen DA'FF- /-' ~ t5-,~ 2.- WELL :'~" Transmitted herewith are the fol'lowing' PL~..~,,,E HOT - BLUEL~E, - SEPIA, · . F - FILM, T - TAPE RECE!?T ?,.CK~:OWLFDG~~_~ .. .... ,'.-.., UR~ f":~.CE ~ ?T TO' DATE' ARCO ALAS~tA, I!~C. ATT~: A:';~ SIMO~iSD! - AFA/31I P.O. BOX 360 ,r',,-~'~'.- ~" ac'51 0 RECEIYEI) F E B,, ~' 2 1982 Alaska 0ii & Gas Cons. Commission - ~horaga NORTH ~LGPE Ei:GI~:EERI~:G TRAi!SMITTAL ~ //~ J. J. Pav;elek/Ann Simonsen DATE' ,' /:'/~- $ 2..- WELL Tra::-'_.mirt~d here:,:ith ake the following' PLEASE HOTE' BL - BLUEL!HE, S - SEPiAi, F - FILM, T - TAPF RECE T PT ACK;:OWLEDQED'P ~ D?v.TIE-:,c, -~,.~' . . = ,.,aiURN I",ECEi?T TO' ARCO AL'AS>EA, I"" P.O. BOX S60 .... '~ ...... aa'lO , ARCO Alaska, Inc~/ Post Offi~ 360 Anchorage'..~:~aska 99510 Telephone 907 277 5637 November 25, 1981 Mr. Hoyl e Hami 1 ton State Of Alaska Alaska Oil and' Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 11-3 DS 15-11 DS 12-14 DS 14-12 DS 13-8 DS A-7 DS 14-13 DS lA-9 DS 14-14 DS B-8 DS 14-15' DS B-9GI Dear Sir: Enclosed please find the following' (1) The Completion Reports for DS 13-8, DS 14-14, DS 14-15, DS 15-11, DS 15-12, DS A-7, DS lA-9 and DS B-8. (2) The Monthly Drilling Reports for DS ll-3, DS 12-14, DS 14-13, DS 15-12, DS lA-9 and DS B-9GI. Si ncerely, P. A. VanDusen District Drilling Engineer PAV' GA: 1 tc Enclosures ARCO Alaska Inc. s a sub'~idiarv of AllanticRichfieldCompany RECEIVED DECO 7 1981 Alaska Oil & Gas Cons. CommJssio~ Anchorage '" '~ ..~' STATE OF ALASKA '~'~ ~I' ' ~ ' ALASKA( _AND GAS CONSERVATION C( )IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-134 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 so-029-20655 4. Location of Well at surface 493'FNL, 1462'FEL, Sec. 9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ^DL 25648 ALK 466 9. Unit or Lease Name Kuparuk 25648 10. Well No. B-9GI 11. Field and Pool Kuparuk River Field Kuparuk 0il Pool For the Month of. October ,1981 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0800 hrs, 10/16/81. Ran & cmtd 13-3/8" csg. Drilled 12¼" hole to 8550', as of 10/31/81 See Attached Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 20", 94# H-40 conductor to 80'. Cmtd w/300sx Permafrost. 13-3'/8", 72# L-80 casing to 2486'. Cmtd s/1600sx Fondu and 400sx A.S. II. See Attached Drilling History 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SP/GR/BHCS Fr/2481 '-8541 ' FDC/CNL/GR/Cal Fr/2481 '-8441 ' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A DEC 0 7 Alaska O~l & Gas Cons. Cmr~rniss~o~ .?mchm-age 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNE~; '~f/J~~---.~'/-),,,,.~.'/-. T,TLESr. Drilling Engineer DATE ' ~ .... or~s- ' - / -' NOTE-Report on this f requ~eed for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservatio~Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 /f Submit in duplicate Rev. 7-1-80 B-9GI - Drilling History - NU hydril & diverter. Spudded well @ 0800 hrs, 10/16/81. Drld 17½" hole to 2505'. Ran' mul ti shot. Ran 62 its 13-3/8" 72# /ft L-80 csg w/shoe @ 2486'. Cmtd 13-3/8" csg w/16OOsx Fondu & 400sx A.S. II. ND hydril & diverter. Instld 13-3/8" pack-off & tstd to 2000 psi-OK. NU BOPE & tstd to 5000 psi-OK. Tstd csg to 1500 psi-OK. Drld FC & cmt. Tstd csg to 1500 psi-OK. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-OK. Drld 12¼" hole to 8550' Ran DIL/SP/GR/BHCS and FDC/CNL/GR/Cal. Rigging up to run 9-5/8" csg, as jf 10/31/81. TRAi!SMITTAL ¢ /4;~y J. J. Pawelek/Ann Simonsen DATE- //-.-~a-o°/ NELL,,,,,.:_~'~"F' Transmi~-'~d here:.:ith are the following' PL=.~..E ~,0TE' BL BLUELT,~E, S - SEPIA, · F - FILM, T - TAPE ,.,.,-, uR,, hr__',,E ,. ?T TO p L E;...,~ :- ,-, ,--= ARCO ALAS>iA, ATTiI: A~-~r~ SI~.~u~ P.O. BO:< 360 .... 9c510 ARCO Alaska, Inc.(~'~*~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 2, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached please find a Sundry Notice of intention to perforate and test Kuparuk Well lB-9 GI. Your early approval would be appreciated. Sincerely, S. Dayton~ ~~- Area Operations Engineer TW/bl Attachment ARCO Alaska, tr~c. is a subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-134 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20655 4. Location of Well OTHER [] Surface Location: 493' FNL & 1462' FEL Sec. 9, TllN, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) KB Elev. = 93' I 6 . Lease Designation and Serial No. ADL 25648 9. Unit or Lease Name Kuparuk 25648 12. 10. Well Number lB-9 G1 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate and flow test selected intervals 7836'-7910', 8207'-8221', and 8229'-8275' MD of the Upper and Lower Kuparuk Sands. All wireline work will be done through a 3000 psi lubricator which will be pressure tested after being installed on the wellhead. Ail produced fluids will be diverted to tankage on location. Expected start date is December 10, 1981 Subsequent Work Beportecl REr. EIVEg DEC- 3 Alaska. 0il & Gas Cons. Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. A ea Signed , ~ . Title The space b for CommissiOn use Conditions of Approval, if any: ~pp~'Ovect, ~Opy Returned Date BY iO~{/~i£ C. Sltlllg sy Order of Approved by. COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" ir~ Triplicate and "Subsequent Reports" i n Duplicate NO~'' ~ OP "" " ~ r,~n ~ E ~,,GINEERI~,G , J. J. Pawelek/Ann Simonsen DATE' .//'" 2....3' - ~,/ WELL ,,,..,,.~._.,,,,..c. Transmi.~ted here:.;ith are the following' PLEASE NOTE BLUEL!~,E, - SEPIA, · F- FILM, T - TAPE DATE: ARCO ALAS>iA, INC. NOV2 5 19.,? ATT~! 'p. O. BoxANN~.~. 360S t MONS E~!~ ,, - AFA/A~ca Oil & GaS Cons. Com[aiS~ior~- A; ~r~n~ ' ocSl 0 ~chOrage J. J. Pa,.-/elek/Ann Simonsen T:'a::smi;tad here,..,,ith are the follo',.:ing' ... pLc'' c- ,,,n~;'. ." _.=..-,,,..,~,_ BL - BLUELT~E, S - SEPIA, F- FILM, / RECEIVED NOV 1 8 Ic.,:.''; ~'. - AFA/.3qi']ska Oil & Gas [ions. Commission Anchora§~ ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Moyle R. Hamilto~ Ch airman Lonnie C. Smith Commissioner Ben LeNorman Petroleum Inspector October 21, 1981 Witness BOPE Test on Sec. 9,~ TllN, R10E, UM .KuParuk River Undefined .Sunday October.. !8- I departed my hame at 3:30 p.m. for a 4:00 p.m. shOWup and scheduled 5:00 p.m. departure for Deadhorse. Rowever, the aircraft was delayed out of Seattle and we finally departed Anchorage at 7500 p.m. arriving in Deadhorse at 8:30 p.m. Weather: +21"F, low overcast, light wind. .,M, onday October_ _19 - Standing by on 1B-9GI. Tuesday October_ 2_0 - BOPE tests on 1B-9GI began at 10:45 a.m. and ~ere' c~pleted at 12:00 noon. BOPE inspe~ion report is attached. I departed Deadhorse via Wien flight %18 at 2:20 p.m. arriving in Anchorage at 4500 p.m. and at my home at 4:30 p.m. In summary, I witnessed successful BOPE tests on ARCO's Kuparuk 1B-9GI. 4/81. B .0. P.E. Inspection Report Operator. Well /~~L//~ Date OC~ ~.._.~:~__/_.../~(~ Permit # Location: Sec ~ T//,,I/R/~9 ~' M t..,;~'F'~ /2~asing Set @ ~ ~~ ft. Eril ling Contractor~'~3~~ Rig Location, General Wel 1 Sign Cenera 1 Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rm~. Blind Rams Choke Line Valves H.C.R. Valve____ Kill Line Valves- Check Va lye Test Pressure ACCUt[UIATOR' SYSTEM __ Ful 1 CJ]arge Pres sure' ~_~a~a___ ps ig Pressure After Closure '/~o<D psig Pump incr. clos. pres. 200 psig / min /4-sec. Full Charge Pressure Attained: ~-- min.3-J-sec. N2 ,~l~l-'d)/~ c/o~/ .~ tQo., .~/o,_-%o. siq_ Controls: ~laster _ ~9/zC R..e3~_..t_e ,0./~_B.!i~nds_ ..s~.i.t..ch~_.c_o. ver ~/~,_~ _ Kelly and Floor Safety Valves Upper Kelly Test Pressure__ Lo~er Kel 1~: Test Pres sure Bal 1 Type_ i ~C)/~ Test Pressure Ins ide BOP .,CD/~!,~ Test Pres sure Test Results: Failures, Repair or Replacement of failed equipment to be made within Inspector/Ccmmission office notified. Remarks:, / ~_~.~-~¢ Choke Manifold No. Valves__ No. flanges _ ~dj ustab le Chokes Hydrauically operated choke , TeSt ~-T~'~'Y>- ~--/-~ Test Pressure days and Distribut ion orig. - AO&G~C cc - Operator cc -Supervisor Inspector /~~_~ .~j_ /J/'ff~F~.~.z.J September 17, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re~ Kuparuk 25648, 1 B-9 GI ARCO Alaska, Inc. Permit No. 81-134 Suro Locol 493'FNL, 1462WFRL, Sec 9, TIIN, R10E, UM. Bottomhole ~.~ 550'FNL, 770'tFEL, Sec 4, TIIN, R10E, UM. Dear Mr. VanDusent Enclosed is the approved application for permit to drill the above referenced well. well samples and a mud log are not required. 'A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs' for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and C~me. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to t~ P~ ~ VanDusen Kuparuk 25648, I B-9 GI -2- September 17, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. TO aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded, we would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advanoe notification so that we may have a witness present. Very truly yours, H. Hamilton Chairman of BY ORDER OF THE COMMISSION Alaska Oil & Gas Conservation Commission Eno lo sure cc~ Depar ~tment .of Fish & Game, Habitat Section w/o encl. Department of Environmental ConservatiOn w/o/enclo ARCO Alaska, Inc.( Post Office I~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August lO, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: ARCO Alaska, Inc. proposes to drill a development well, Kuparuk 1 B-9 GI, commencing on approximately October 7, 1981. Attached please find: 1. A "Permit to Drill" application form. 2~ A plat showing a) surface and target locations, b) ver- tical directional planning. e A plat showing the proposed wellbore in relation to other wells within 200' and other wells on B pad & B pad extension. e A determination of maximum pressure to .which BOPE could be subjected. Diagrams and-operational .procedures for the 20" 2000 psi diverter stack and 13-5/8" 5000 psi RSRRA stack. Please feel free to contact us at 263-4270 if we can be of any assistance. Sincerely, P. A. VanDusen District Drilling Engineer PAV/ELP:sp Attachments $£P l 1981 Alaska Oil & Gas Cons. Con~issia,~ A~Cborage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~,'~"- AND GAS CONSERVATION CO(,,~ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE ~] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address RECEIVED' P.0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 493'FNL, 1462'FEL, Sec 9, TllN, RIOE, UN S~P 1/~ ]981 Kuparuk 25648 10. Well number At top of proposed producing interval ~ Oil & Gas Cons. Corn w~_,o,.1. B-9 G I (Gas Inj Wel 1 ) 1320'FNL, 1320'FEL, Sec 4, TllN, RIOE, · At total depth Anchorage -i'~'.'l~{~ld and. pool 550JFNL, 770'FEL, Sec 4, TllN, RI0E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk Ri ver 0i l Pool 62 'GL/6_6' PAD/93.' RKBI ADL 25648, ALK 466 12. Bond information (see 20 AAC 25.025) TyPeStatewide 0il & Gas [~S,,u.re,~vand/brnumberFed Ins Co. 8088-26-27 Amount $500,000 .. 13. Distance and direction from nearest~o~v~[3''' 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse, 30miles 1320 @ Target, 550 @ TD feet well 160' to 1 B=IO GI feet 16. Proposed depth (MD & TVD) 17, Number of acres in lease 18, Approximate spud date 9121 'MD = 7230"TVD feet 2560 10-7-81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~ psig@~._ Surface Tem[ KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) ~27~ psig@ .6343_ ft.' :TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT · Hole Casing weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 72 Corrug~,ted Cellar Su'rfac~ 5' ~5' Backfil led 30" 20 91.5# H-40 Weld 80' Surfacq 80' ii 80' 400sx AS II 3122' 2700' 1900sx ,.Fondu, +. 300sx_~ 17½" 13-3/8"' 72# L-80 BTC '3122' Surface I . - 12¼" 9-5/8 47# L-80 BTC 9121 Surfac~, 191i~-21 1~7230~ 40:0sx~'ExC.~'G + 30Osx G , 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field Gas Injection Well to 9121' MD = 7.230' TVD. A 20" 2000 psi annulur diverter will be installed on the 20" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOP stack will be installed on the 13-3/8" surface string & tested upon installation and weekly to 3000 psi. The well will be completed w/4½" tbg and pkr. Non-freezing fluids will be left in uncemented annuli thru the permafrost interval.· Selected intervals will be perforated within the Kuparuk formation for injection and reported on subsequent report. A downhole safety valve will be installed with the completion string and ·shut and tested upon conclusion of job. 23. I hereby certify that the f, Rregoing is true and correct to the best of my knowledge SIGNED · ~.,.. TITLEDisto Drilling Engineer DATE 8"'~"~1 The space'below for Commission use CONDITIONS OF: APPROVAL I ' Samples required Mud log required Directional Survey required APl number F-lYES ~J~lO I--lYES [~JO ~,.y ES F-INO 50--~ 'L,~-'7..,O (~ ~ Permit number Approval date ~ ~ ~-'/.? ~ 09/17/81 [ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY.~ ,COMMISSION·ER DATE Septem]:ez: 17, 1.981 _"{~ - by order of the Commission II Form 10~401 Rev. 7-1-80 Submit in triplicate ¥ ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3240 psia = 3225'psig from RFT & pressure buildup date. This pressure @ 6250' SS = 6343' TVD will be balanced by 9.8 ppg mud wt. Normal drilling practice calls for a 10.4 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 198 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a max- imum of 2577 psig during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (165°F, 3240 psia), gas migration to the surface w/o expansion, and cooling to 40°F summer cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psig weekly test pressure. Pi = pressure initial ('.reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) Pf = pressure final (surface) Ts = temperature final (surface) : volume final (surface) PiVi = PfVf -TT- Tf Since Vi = Vf ie no expansion. Pi : Pf Then Pf: PiTi : (13240 psia)(40°F + 460) Ti Tf Ti (165°F +' 460)~ Pf = 2592 psia = 2577 psig. S£P 1, ]98! Oil & (~as Cons, Commission Anchorags · 4. Surface Diverter System 20" Bradenhead. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3.' Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under ans circumstances. RECEIVEI) SEP 1 4 1981 Oil & Gas Cons. Commission Anchorage ,, (~-5/8" 5000 PSI RSRRA BOP STACK~' Iq. NNULRR PREVENTOR 9 BLIND 8 PIPE RRMS ) 7 RILLING SP6OOL ) ) RRMS .F~ ) 1. 20" slip on 2000# WP Bradenhead. 2. 20¼" x 13-5/8" 5000# WP casing head. 3. 13-5/8" x 13-5/8" 5000# WP tubing head. 4. 13-5/8" x 13-5/8" 5000# flange by Graylok Hub adapter spool. 5. 13-5/8" 5000 psi pipe rams. 6. 13-5/8" 5000 psi drilling spool w/choke and kill lines. 7. 13-5/8" 5000 psi pipe rams. 8. 13-5/8" 5000 psi blind rams. 9. 13-5/8".,5000 psi annular. ACCU~IULATOR CAPACITY TEST 1. CHECK AND FILL ACCUNULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCU~1ULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAN.OF THE REGULATOR. 3. OBSERVE Ttt.IE THEN CLOSE ALL UNITS SIHULTANE- OUSLY AND RECORD THE TIHE AND PRESSURE RENAIN- 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERi,IINE DEPTH THAT TEST PLUG WILL SEAT A~;D SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS Ill HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON HA,qIFOLD. 4. TEST ALL CONPONE;;TS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l'O- MINUTES. 8, CLOSE VALVES DIRECTLY UPSTREAH OF CHOKES. BLEED DOWNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST RB. IAINING UNTESTED HANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTRE~'.! OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. - , 9. OPEN TOP SET OF PIPE RANS AND CLOSE BOTTC,.! SET OF PIPE ,RAMs. 10- INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 ttII;UTES. BLEED TO ZERO PSI. ll. OPEN BOTTOH,SET OF PIPE RANS. BACK OFF RUN- ~'~I~.~e- ..... NING J,O,I;IT ~ND PULL OUT OF HOLE. CLOSE .~LIND t. I v !: RA~.IS A,ID TEST TO 3000 PSI FOR 10 HINUTES. IZ. CPE;t BLI~tD RAHS AND ?COVER TEST PLUG. MAKE e~D I S. lO~! SURE NANIFOLD A;iO LI,',ES ARE FULL OF ARCTIC ~ ~ '+ ~' ' DIESEL AND ALL VALVES ARE SET IN DRILLI~;G POS I T I ON. Gas Cons. COI[lJllJ~¢iOEST STANDPIPE VALVES TO 3000 PSI. Anohorago 14. TEST KELLY COCKS A;;D II;SIDE BOP TO 3000 PSI WITH KOO;IEY PUNP., , , 15. RECORD TEST IrIFO~.tATIO,I ON BLO'JOUT PREVE:ITER TEST FORN SIG:I A:;D SEND TO GRILLI:;G SUPER- VISOR. . 16. PERFOml CC~!PLETE BOPE TEST O:;CE A WEEK A:iD FU~ICTIOr~ALLY OPERATE BOPE DAILY. ' 13-5/8" BOP STACK TEST ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUD.1P OFF. RECORD ON IADC REPORT. THE ACCEPTABLE LO',4ER LIMIT IS 45 SECO~;DS CLOSING TIIIE AND 1200 PSI RENAINII;G PRESSURE. CHECK LIST,FOR NEW WELL PERMITS ITEM APPROVE DATE hru 8) Company 1. Is the permit fee attached ......................................... · 2. Is well to be located in a defined pool ........................ 3. Is well located proper distance from property ling .... 1,,1., 1. 4. Is well located proper distance from other wells .......... 5' Is suff£cient undedicated acreage available in this P°°liiii iiiiili'. · 6, Is well to be deviated and is well bore plat included ,. 7. Is operator the only affected party ' ' 8. Can permit be approved before ten-day wait ............. '(~ 'l 1) · lO. ? 11o ( 4 ) C'a s g ~ , ~//S/B! '(12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. thru' 2/4) 21. 22. 23. 24. 25. Lease & Well No. Does operator have a bond in force ................................. Is a conservation order needed ..................................... Is administrative approval needed .................................. Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ........ 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 collapse, .tension and burst. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment .procedure included on 10-403 ........... Is adequate well bore separation proposed ................ : ......... YES NO / · ° ~0,~ . · ~.~ , · REMARKS Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ,~ f,~ ~ ~. Additional requirements ............................................. ~ Additional Remarks: Geology: HWK ~ JAL Engine, e ring: ~ LCS ~ BEW~ JKT --------RAD ~_ rev: 03/10/81 INITIAL 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 APPENDIXl .. No 'special'effort has been made tO chronologically organize this category of information. ~E~ IFICA~I~] ~ bVP 0<)!~.~!® VERiFICATIf]~'~ blSTING PAG~ SE~ViCT< ~A~E :SERVIC DATE RESb ~A~E :REEL ID ** TA~F] HEADER ** SERViC~ ~AME :SgRVIC ORIGi~q ~ 070 TAPE MA,~E :62257 COSTI~L~aTI~N ~ PREViO~3$ TAP~ ** F! b~] VERS I{.]~.~ DATE MAXIMU~'~ LENG~fH : 1024 FILE T>fPE PREVI~],~5 FILC MNE~ CONTENTS CN : ATLANTIC RICHFI~LO CO. WN : FN : KU~ARU~ RANG: SECT: 9 STA. T: Ai~ASKA MNE~{ CONTENTS PRE~: DIbO9l? I.]~IT f~ E CAT~ SIZE CODE o00 000 022 065 000 000 008 065 000 000 008 0~5 000 000 003 065 000 000 003 065 000 000 O01 065 000 000 008 065 O00 000 006 065 000 000 006 065 UNIT TYPE CAT~ $IZg CODE 000 000 007 065 LVP OOq. H05 VERIFICATIO~ ** CO COMPA WELL FIELD COUNT STATE OOB ~ DIL BOTTO~ TOP LDG CASING- BIT Sin TYPE Hf~ DENSITY VISCOSl FLUID i, RMF ~ RMC ~ R~ ~ = IB-9-GI = KUPARUK = N, SLOPE = ALASKA ~0707,~2257 ~1, bOGGED 29'0C bUG I~ITERVAL INTERVAL LOGGER TY HEA~. TEMP. ~EAS. TEMP. ~EA$. TEMP, i~HT = 85 = 24 = I0 = 52 = 9. = 4, = = 2. 5 IN ~2SOLI~S .4 .0 0 0 C3 620 ~ 62 F 570 ~2 LVF 009.H35 FERIFICATIOq 5ISTING PAGE 3 iL, bMC & CNL/FD., SA~ MATRIX A~DSTONE ENTKY ).~LOCKS RECORD REP~ 1 . .iI~ 6~ 0 ~NE~ SKRVICE SERVICE ID ORDER ~ DEPT FY SFLU i)iL ILD )')iL 8P OIL GR DT PHC RHOB ~;D~ DRHu CALl NR~T NCi~L PON FCNL APl AP! A~I FILE SIZE PROCESS 0 0 0 0 0 AP1 70 ~8tF 6 PO G/C3 4~ 34 42 34 0 0 0 0 0 0 0 SA~P LE EPR ODE 68 68 68 68 68 08 68 oB 08 *~ DATA DEPT SP RHO~ NCi~L DEPT SP RHOB NCNL DEP~ SP RHo~ 8600.000 -34,81~ -999.25 -999. 250 Fgr~,, 8500 000 -33;844 -999.25o -999.250 8400,00u SFL~ -1~.750 G~ '1377 DRNO 2.8q8 999.250 CALl .25O }~'.~ ~999, ~50 CALl 999,250 2, ~.n2 IL~~ u. 0~1CA Lt 2 · 867 9;250 N'R/XT 2,479 ILD O5g375 NPhl -999.250 NMAT 2 · 63 1 IbD ~477 NRA~ 2.717 -999.250 -999.250 2 400 -999:250 -999.250 2,549 45.654 3.924 I.,VF NCi~ DEFT SP NCb l, DEFY SP RH£i~ NC~L DEFT SP N C l.i L DEFT SP RPiOC~ NCI~L DEFT SP RHOb NCN6 DEFT SP RHOB NCN6 DEFT SP DEFT SP R H D b NCLL DEFT SP RHOL NCr<L DEPT SP NC~.,.6 0~9.H05 YERIFICAT!Oi: -17.359 2.400 23a4.000 FC~I, 8200.000 -18,344 2.40b 8100.OOU $~'~ -27,875 Ge 2,377 DR~;L~ 2708.000 FCN6 ~000.000 SFLU -59.250 Gk 2.377 DRM,J 2320.000 FCN:~ 7900.000 SFLLi -49.781 G~ 2,311 D~H~ 3092.00{~ FCNL 7800.000 SFLU -28.26b 2326.000 FCNb 7700.000 SFbd -16.6BB GR 2.279 DR~u 1568.000 FCNh 7600.000 SFLU -21.797 GR 2.395 1~30.o00 FCN~ 7500,000 SFbb -23.7~1 GR -999.250 ORHO -999.2~0 FCNb 7400.000 SFLU -25.656 GR -999.250 DRH!) -999.250 FCM~, 7300.000 SP'bd -i8.$25 GR 440.250 5 8~ 0 886 5 0 653 7 57 0 1~59 3 ~13 0 795 18 -99 -99 116 0 413 23 '? -999 -999 . 3.!75 t!.: ~e-840 B~.500 DT 93,563 ~PH! 3o.176 0 023 CAhi l~.iSw ,~k~- 3.~29 716,000 .070 489,250 000 :~i 6.289 ibO ~ ?86 1~8 DT 92.750 NPHI 26:__23 '7 2~, ,~. 2.836 .007 .0o© OO~ CALf 16.906 NRAT ~,189 .000 J68 [750 DT 90~37~ Np~I 201557 CaLz ,00I ' 1~. t81 t~A 2.529 .000' ,~7 lb~ 3.35~ f~D 3.t52 ,500 1,54~ I~L i 470 .I88 UT I30,000 NPHI ~2.969 ~ ~ !~,b94 NMAT : 3,805 ,005 C~L, . .750 1.955 120,625 DT i19,i88 0,076 CALl 1~,875 NRAT 423,50U ~ 750 bT - I06.375 NPMI -999. 50 9.~50 CALl -99W.250 t~aAi 999.250 9.250 .~ - ~.6e8 t~D 2.u50 . 50 ~[-,~ '999.~50 NR~ -999.250 .250 DT : i~4iO00 NP~i - '~99. N C N L NC;~ b SP NCNL DEPT SP DE~;T SP DEP? SP RHO~ NCNL SP DEFY sP O09.H{~b 'V~RiFiCATiO~ .-999 . 7200 . 000 -29.219 -999 . 250 -...v9 250 FC~-~, 7100.00o S~bu -21.32s GE -999.250 FCNt: 700Q.OOU SF[,Li -999.25U DR~{U -999.250 FC~ ogoc,o00 SFL'i '39,688 GR -999.250 [)~HU -999,250 FC~<b -999,250 6700.000 -23,3~4 999,25~ ~g9,250 6600.00o SFLb -999,250 DRM{~ -999,250 FC~b [, I S T I ~ G -999.250 97,5~3 ...... ~ 5 '~ -999.250 .123.875 9~25o -999,250 13~.625 ~999 ~ -999.250 0. 999 172 b75 -999 ' 2r'O -99c. '~50 lb5 750 -999.250 ~.299 16&.250 -999.25(~ -999.25u DEFT 6~00,000 SFLU i.569 BP 27,719 G~ 155.0oo RhOi.~ -999,250 Oa~O NC~S -999,250 FC~ND -999,250 6g00.OO0 SF6iJ -30.26b -999,250 -~99.250 FC~b -31.250 GR -999.250 DRip, iii -999 . 250 FCNL 6200,000 SF[.,(! DEFT SP RHO~ NCSh SP NCNb I .a07 162,I25 999,25© 142. uoO -999,25U -999.250 1. gN6 C a L l CALi [, T D T ,o .t C .a L l DT CAbI CALk t% .t..' ,I. 3.311 ~.~3 li8'375 .9og , ~., ,250 .iL)~,O0 2.99~ 109'i88 -999,250 1.259 '~' 000 -999"250 1.502 105'750 -999,250 1,754 10~.188 ~999"250 ,~.562 102,563 -939.250 i,779 117,563 -999,250 2,375 NPH1 NRAT NaA'l' I RAT NPHZ NRAT NPI~I a~.A l Ibl~ NPl-iI NRAT I LD NPP{1 NRAT I L D NRAT I bi) P~GE -999,250 3.369 -999,250 -999,250 2.781 -999.25O -999.250 2.084 -999.250 -999.250 2.994 -999,250 -999,250 ~.270 -999,250 -999,250 i.523 -999.250 -999.250 1.~74 -999.250 -999,250 1 54~ -999.250 1,821 -999.250 -999.250 2,258 -999.250 -999,25~ 2.439 I~VP NC~ L DEFT SP NCNL DEPT SP R H 0 b N C t;' L DEbT R H U ~ DEFT SP D~gT 6P RH[~6 NC;i'L 0o9.H05 VERIFICAIiOq -31.65u G~ -999,250 D~O -W99.250 FC~ 6200.000 Sf'LO -32.250 GR -~P9.250 DRH[~ -999.25(,) FCNb 6000.000 -33.78i GE -999.250 DRMu -999.250 FCNi~ 5~00.000 SFLO -38.2!9 GR -999.250 -999.Z50 5800.000 SFL~! -36.~50 Gk -999.250 -999,250 5700,00U S~LU -39.~4 GR -999,250 DRHO -999.250 FCNJ.; 5600.000 SFL[{ -~99.250 -999.250 FC~L 5500.000 $~'bU -39.~88 GR -999,250 -999.250 FCNo 540U.000 SFL, O -42,219 G~ -999,250 DRHO -999.250 FC?;~ b~O0,O00 -37.750 GR -999,250 -999.250 FC~i[, -999.250 DR~CJ -999.250 FC%L bISTiNG -999'250 -999.250 2.633 73.6Y5 -999.250 -999.250 2 102 -999 -999 2 10~ 999 2,57~ 95 b25 -999~250 -999.250 3.000 91.87~ -999.250 -999.2g0 2.127 9! -99 22so '99~250 2.449 90.8~3 999'250 4 -999 -999 105 -999 -999 10~ -999 -999 Ib~ 2.793 IhD , 2.~ DY 92.188 NPHf -999.2-50 Cah~ -999.250 ~Rax -999.250 .23g Ib~ 2.367 fhD : 2.447 D"' 103.375 NPH~ -,999.250 500 :250 CALl -909;~50 NRAT '999;250 .250 .312~_~"q] 109,750 NPH~ -999.250 :250250 CaL~ -99~.25u ~,~a~ . -999.250 CALl · -999.250 NRAT '999,250 _ I~f~ ~ 2,94~ IuD 3.09- II0.750 CAL~ W99.2~0 NRAI 999.250 . . Ib~ 2.297 ILl.) 2.398 ~T _ 110,188 NPh~ -999,.250 ~,at, I -999.~0 NRAT '999.250 lh~ 2.590 Zbl> ~2,703 CALZ -~9~,250 NRA~ -999.250 . .301 Ii~ - 3.496 IbP 3.918 .250 bi' 103.563 NP}~i -999,250 .250 CALl -999i250 NRA, T -999'250 .250 002 Ib~i 3.100 ILl/) 3,19i 063 DT i I I. 000 NPHI '999. 250 250 C b! -999,250 NRAT -999,250 ,25O .760 IL~; 3.928 ILD ,{' 19~ ,938 ~ i,0,~00 i~Pa -999.250 ,250 CA~I '999,250 ~RA% -999;250 .250 DEi~T N C ~',i L DEPT SP N C ~ b D E P ~] R ?i ~} r,i SP SP NC~5 $? S? N C !,,; ;~ D E o <f BP R H ~ b N C ~>! b DECT SP N C ¢~ ~ DEPT SP NC~'~ b 009,~5 VE~iF'iCAT~O~~ $1oo. O00 SFLb -999.~50 D~iO -999.25o FCNL 5000.OO0 SFI~U 2,25~ D~O 22~0.00U -49.25O 2776 ~ OOt,:FC 4800 . O0t) -50,21u 2.250 ¢700.~0u -62.375 2510,000 FCNL ~600.000 8~bt., -58.281 GE 2.221 DR~O 2136,000 FC~L 4~00,UOO 8~'Ld 74.750 GR 2,29~ O~},i(j 2206.000 FC~L 4~00.000 -92.750 2.232 2258.0C~U e300.UOU 8b'~d -92.7b0 GR 2.558 DRD~¢3 4100.000 -96.312 2.U92 212B.000 bISI'iNG -9~9 2 0 ~. 1o3 84. '150 0.035 579.000 ~,O2O 2.~46 93 . 'l~: 0,036 5~3,000 76.813 64.~'°21 ~'soo 5.574 85 37 o:o2S 554,500 ';2 71.500 0.052 616,500 6.898 71,438 0.016 154 53~094 ,017 310~,000 1i.359 60 344 0:015 1953.000 .... PT CALl 01' DT C A £~ 3: ALI PT Caf.,,,. ~Abl 1 h!',, -999,250 i~RAT 453 'i4i NRA.i: 9,10~ ibl.~ i0b;56 PPRI 90,375 ~F[{I i7~094 NRAT 1i5.375 NP~I 1'1.t88 N~AT 4. 602 57,594 14,648 ~AT t0.156 !bP 133'000 NP~i ib,14~ N~AT PAGE 3,q34 -999.280 -999.250 3.721 34,717 3.361 4,449 29.785 3.051 3.627 39.893 ].~76 9 312 5: 4o 3.447 7.172 941 3~652 '1 36~621 3.~69 7.172 36.914 3.418 35.2~1 6,299 1,444 9.000 17.383 2.295 15.305 41. 797 ~. 703 009.H05 VERIFICATIi??4 4000. 000 SFLU 2.209 DRHO 1955.000 3900.030 -87.1R8 2.273 2035,0o0 3~00. 000 -~07.750 3700, oO0 SF~d -~3.~ 2198.000 FC~ i., 3600. 000 2,i60 2~18.000 3500. 000 -101,8~3 2.109 2296,000 FC~L 3400. OhO SFLd -92.813 Gk 1944.U00 3300.000 S~LU -73.688 1770.0u0 FC~L 3200. 000 SFL[~ -104,1~ 2.043 2500.000 FC~D 3100,000 SFbo 2,18e ~938,00U 3000. uOo SFLO -104.312 2 · 059 5.55i 0.0~8 8,~95 77.750 0.017 b46.500 7.332 5~,063 0.0!1 5~.500 9.016 59~.500 9.047 5~.125 .008 624,000 0.015 600,500 ~.336 72.3i2 -o~ooo 469,500 ~2'063 0.000 450.750 I1.01~ '4 0'003 614,000 7 578 0.005 472.750 10.414 50.531 ;[ bi~i 9.016 DT 7'375 CALf 14.500 CA L I 1 Ca I 13,523 CAi, i 3 ;969 I b ~: 5.051 O'i' ~ 1~0'375 C l 1.,I 0 O T ~::000 CALl I3 ~8.36 PAGE 6.340 '551 672 3.512 9.688 4~,137 :',582 3.~65 9.430 lO195 8:379 3.471 10.859 ~ ..$~5 4 .627 4'~.529 .709 9.~06 44.824 258 L¥? 00,9,Ho5 VgRIFICATlr~ LISTIit~G ~.344 ~77 RHO~. 2,037 O~O NC:4L 17~0,900 5,i45 377.750 DE ~'~i 2700.000 ~Fbi) SP -98.250 Ga R'H ~] ~i-~ 2 · 039 DRHO NC:?L 206~. ~'00 FC~qL i©,ifl 59,781 ~[O00 2.172 DR!~O 2672,000 FC'~b 1V.250 5b,031 '(!.007 733.~U0 D~'£ 2600,000 SP -101.75o R~O~ 2.070 MCteL, 2370,000 ~t7.0o0 DE~T 2%57. O00 8FLU SP -999,250 RS r~ k5 1,953 -~99.250 -999,250 -0,703 ~2u.500 1024 OR!Gi~ ;1070 TAPd ~E :52257 CALI OT C A L 1 CAL ! oi C~LI 6.902 133.125 1q.234 5"602 13S,375 15-555 135~125 13,519 t3i492 -9~9.250 lz,7bCi NPHi i~P NRAT I LD- N P ~ i NP~4i NRAT N~n'f ILD PAG~ '1.$55 48.047 4.023 6.383 ~0.586 4.199 i2.953 40.967 3.627 15,086 3.119 ~a.703 35.156 3.492 -999.250 4~{.b82 4.023 ~;.~ 00.~.~05 VERiB'ICATi':~i blSTiNG .I 0 ** REEL HEADER ** SERVICE NAME :$ERV£C DATE :82/07/ 7 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SE~V[C DATE :82/07/ 7 ORIGIN :i070 TAPE NAME :65247 CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADER ** FILE NAME :SERVIC,O01 SERVICE NAME VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ** INFORMATION RECORDS MNE~ CONTENTS CN : ATLANTIC RICHFIELD COMPANY WN : 1B-9-GI FN : KUPARUK RANG: 10E TO~N~ SECT: COUN: NORTH SLOPE STAT: ALASKA CTRY= U.S.A. MNEM CONTENTS COMPANY = ATLANTIC WELL c D.S. 1B-9-G! FIELD : KUPARUK COUNTY = NORTH SLOPE BOROUGH jOB NUMBER AT ACC: 10707,65247 RUN #1, DATE LOGGED~ 24 dUN 82 ~ ~<~_i~ ~~2~:~t~~ ~? : t : . - BOTTON DEPTH = 8]34 FT. 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KBA.~~. ...::105..~250::_....<: 2 3.47 7 ~' G'R::~ 560, BACK -999,2500 FBAC CCL -999.2500 SIGN GR -999.2500 ~ACK FTDT -999,2500 CCL DFPT 7641,5000 SIGM GR -999,2500 8ACK FTDT -999.2500 CCL TRAT -999.2500 GR NTDT -999.2500 FTDT FSIG -999 2500 TRAI FBAC 120~1289 NTDT SlGM -999,~500 F$IG BACK -999.2500 FBAC CCL -999,2500 SlGM GR -999 ~500 BACK FTDT -999:~500 CCL -9992~500 F$IG' ' '~999:,'2500 TROT ~": " -999,2500 -999,2500 -999. -999, -999 , -999, -999 2500 682 ~ 12~~ ~DT :~:~ :~" :~': 999~"250D: -999 -999 ' 2B6"6 ** FILE TRAILER FILE NAME :$ERVIC,O01 SERVICE NAME VERSION DATE : MAXIMUM LEN?T~ FILE TYPE NEXT FILE NAME ** TAPE TRAILE~ ** SERVICE NAME :$ERVIC DATE :82/07/ 7 ORIGIN :1070 TAPE NA~ :65247 CONTINUATION # ~01 ~EXT T~PE NAME : COMMENTS ~TAPE CO~ENT$ ** REEL TRAILER ** SERVICE NAME :MERVIC DATE :82/07/ 7 ORIGIN l REEL NAME IRE£L ID CONTINUATION # :01 NEXT REEL NAME : COMMENTS :REEL COMMENTS ********** EOF