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179-095
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 27, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-05 KUPARUK RIV UNIT 1D-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/27/2025 1D-05 50-029-20417-00-00 179-095-0 W SPT 6195 1790950 3000 1774 1776 1777 1774 140 460 435 430 OTHER P Sully Sullivan 12/28/2024 Initial MIT-IA post RWO to MAIP(3000 psi) per AIO 2C.078. 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 1D-05 Inspection Date: Tubing OA Packer Depth 375 3300 3200 3190IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241228165928 BBL Pumped:2.5 BBL Returned:2.2 Monday, January 27, 2025 Page 1 of 1 9 9 9 9 99 999 9 9 99 9 7HVWGXH GLDJQRVWLFVWKHQ6,-5HJJ post RWO AIO 2C.078 James B. Regg Digitally signed by James B. Regg Date: 2025.01.27 00:27:36 -09'00' Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 12 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 13 1A-27 50-029-22124-00 909781603 Kuparuk River Multi Finger Caliper Field & Processed 25-Dec-24 0 14 1B-19 50-029-22475-00 909619036 Kuparuk River Packer Setting Record Field- Final 17-Oct-24 0 15 1B-20 50-029-23164-00 909619415 Kuparuk River Plug Setting Record Field- Final 8-Oct-24 0 16 1B-20 50-029-23164-00 909678322 Kuparuk River Plug Setting Record Field- Final 13-Nov-24 0 17 1C-04A 50-029-20547-01 909677469 Kuparuk River Packer Setting Record Field- Final 23-Nov-24 0 18 1C-158 50-029-23761-00 909810535 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 19 1D-05 50-029-20417-00 909607635 Kuparuk River Correlation Record Field- Final 9-Oct-24 0 110 1D-14 50-029-22950-00 909677466 Kuparuk River Packer Setting Record Field- Final 26-Nov-24 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:T39991T39991T39992T39993T39994T39994T39995T39996T39997T39998190-166190-180194-064203-115217-078223-056179-095199-0891/23/202591D-0550-029-20417-00909607635Kuparuk RiverCorrelation RecordField- Final9-Oct-2401223 056179-095199 089Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:06:40 -09'00' 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 8925'feet None feet true vertical 6902' feet None feet Effective Depth measured feet 8104'feet true vertical 6197'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8275' 6342' Packers and SSSV (type, measured and true vertical depth)8104' 6197' 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: 3077' 2709' Burst Collapse Production 1745' 7146' Casing 1740' 6895' 1775' 8917' 3046' 80'Conductor Surface Tie-Back 16" 10-3/4" 48' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 179-095 50-029-20417-00-00 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: ADL0025650 Kuparuk River Field/ Kuparuk Oil Pool KRU 1D-05 Plugs Junk 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' 324-434 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: BluePack Packer SSSV: None Shane Germann shane.germann@conocophillips.com (907) 263-4597 RWO/CTD Engineer 8402-8499', 8654-8672' 6451-6534', 6668-6684' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov feet6621' 8600' Well Shut-In Well Shut-In By Grace Christianson at 10:11 am, Nov 12, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2024.11.12 09:03:17-09'00' Foxit PDF Editor Version: 13.0.0 Page 1/40 1D-05 Report Printed: 11/11/2024 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) 9/4/2024 21:30 9/4/2024 22:30 1.00 MIRU, MOVE MOB P Pull off of 1D-129 move and spot rig over 1D-05 0.0 0.0 9/4/2024 22:30 9/4/2024 23:00 0.50 MIRU, MOVE MOB P Spot pits. 0.0 0.0 9/4/2024 23:00 9/5/2024 00:00 1.00 MIRU, MOVE RURD P R/U interconnect to the pits. Install berming around herculite. Set support shacks. Load fluid into the pits. 0.0 0.0 9/5/2024 00:00 9/5/2024 03:00 3.00 MIRU, MOVE RURD P Spot in cuttings tank. Spot in and hook up support shacks. R/U interconnect between sub, and pits. Place berming around the rig. R/U circulating lines in the cellar. R/U rig floor. Load 10.4 PPG KWF into the pits. 0.0 0.0 9/5/2024 03:00 9/5/2024 05:30 2.50 MIRU, WELCTL KLWL P Kill well w/ 10.4 PPG brine. Pump 320 BBLS ICP: 250 PSI FCP: 475 PSI 0.0 0.0 9/5/2024 05:30 9/5/2024 06:00 0.50 MIRU, WELCTL OWFF P Flow check well 30 min All good no issues blow down all surf lines 0.0 0.0 9/5/2024 06:00 9/5/2024 07:00 1.00 MIRU, WELCTL MPSP P Cameron rep set BPV. Test from below to 1000 PSI for 10 min: 0.0 0.0 9/5/2024 07:00 9/5/2024 08:00 1.00 MIRU, WHDBOP NUND P N/D Tree, and adaptor flange. Check hanger neck threads. Screw in x/o 12 turns.All Good 0.0 0.0 9/5/2024 08:00 9/5/2024 11:00 3.00 MIRU, WHDBOP NUND P N/U BOP.with double studied adapter 0.0 0.0 9/5/2024 11:00 9/5/2024 17:00 6.00 MIRU, WHDBOP BOPE P Test BOP.witness by AOGCC Rep C.Stjohn Test BOPS 3,000 psi high/2,500 psi low, 7" test joint, 3.5" test joint, 1.) Blinds, CMV 1,2,3, & 16, Rig Floor Kill, OTSP 2.) CMV 4,5 & 6, HCR Kill, ITSP, HT38 Dart Valve. 3,) 7" Test Jt., 3.5" TIW, LWR Rams, CMV 7,8, & 9, Man Kill 4.) Super Choke & Manual Bean Choke (1,500 psi test) 5.) ANN, CMV 10, & 11 6.) 3.5" Test Joint, 3.5" FOSV, Upper Ram, CMV 12,13, & 15 7.) CMV 14 0.0 0.0 9/5/2024 17:00 9/5/2024 17:30 0.50 MIRU, WHDBOP OTHR P R/D test equipment blow down lines. 0.0 0.0 9/5/2024 17:30 9/5/2024 18:00 0.50 COMPZN, RPCOMP THGR P M/U Spear and 1 joint of drill pipe. RIH and engauge hanger. Cameron rep BOLDS. 0.0 0.0 9/5/2024 18:00 9/5/2024 18:30 0.50 COMPZN, RPCOMP THGR P Unseat hanger 110K. Pull hanger to floor. Terminate SSSV line. 0.0 8,125.0 9/5/2024 18:30 9/5/2024 19:30 1.00 COMPZN, RPCOMP CIRC P CBU 5 BBL/Min @ 1000 PSI. R/D and blow down circulating lines. 8,098.0 8,098.0 9/5/2024 19:30 9/5/2024 23:00 3.50 COMPZN, RPCOMP PULD P POOH F/ 8098' to 7125'. 20K over pull observed. Weight fell off to 60K. OWFF. Unable to slack off. Rack back stand of 3.5" Tubing. 8,098.0 1,873.0 9/5/2024 23:00 9/6/2024 00:00 1.00 COMPZN, RPCOMP PULD P Cont. POOH F/ 7125'. Large wad of control line found 3 joints after. 1,873.0 500.0 9/6/2024 00:00 9/6/2024 01:30 1.50 COMPZN, RPCOMP PULD P POOH tubing from 500' to surface. Recovered 6.96 ' of SSSV. 4.32' left in hole w/ 6,342.81' 500.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 2/40 1D-05 Report Printed: 11/11/2024 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) 9/6/2024 01:30 9/6/2024 02:30 1.00 COMPZN, RPCOMP OTHR T Clean and clear rig floor. R/D tubing handling equipment. Clear pipe shed. Set wear ring. 0.0 0.0 9/6/2024 02:30 9/6/2024 04:00 1.50 COMPZN, RPCOMP OTHR T Load, strap and tally drill collars. Bring BHA components into pipe shed. 0.0 0.0 9/6/2024 04:00 9/6/2024 05:00 1.00 COMPZN, RPCOMP OTHR T M/U 6 1/8" String mill to joint of drill pipe, and drift well head. 0.0 0.0 9/6/2024 05:00 9/6/2024 05:30 0.50 COMPZN, RPCOMP BHAH T P/U 4 3/4" BHA. (#2). RIH to 60.5' and tag up. 0.0 0.0 9/6/2024 05:30 9/6/2024 06:30 1.00 COMPZN, RPCOMP BHAH T L/D BHA #2 0.0 0.0 9/6/2024 06:30 9/6/2024 11:30 5.00 COMPZN, RPCOMP ELNE T Call E-line out and R/U to run 3.5 drif w/10' Drif RIH and tag up @ 1864' POOH 0.0 0.0 9/6/2024 11:30 9/6/2024 17:30 6.00 COMPZN, RPCOMP ELNE T P/U RBP 3.5 OD RIH and set @ 1800 POOH R/D E-line 0.0 0.0 9/6/2024 17:30 9/6/2024 18:00 0.50 COMPZN, RPCOMP MPSP T Pressure test IBP to 1000 PSI for 10 min: GOOD test. 0.0 0.0 9/6/2024 18:00 9/6/2024 20:30 2.50 COMPZN, RPCOMP NUND T N/D BOP, remove 13 5/8" X 11" adaptor. Rack back BOP. 0.0 0.0 9/6/2024 20:30 9/6/2024 23:00 2.50 COMPZN, RPCOMP CUTP T Break bolts form tubing spool to CSG head. Leave 4 bolts in CSG head. R/U Cameron grow and stretch tool on well head. 0.0 0.0 9/6/2024 23:00 9/7/2024 00:00 1.00 COMPZN, RPCOMP CUTP T Remove last 4 Bolts. Grow CSG 20.75". 0.0 0.0 9/7/2024 00:00 9/7/2024 00:30 0.50 COMPZN, RPCOMP CUTP T Cont. Grow CSG. Final growth 20.75" 0.0 0.0 9/7/2024 00:30 9/7/2024 01:00 0.50 COMPZN, RPCOMP CUTP T Monitor jacking pressure on Cameron tool for 30 min. 0.0 0.0 9/7/2024 01:00 9/7/2024 01:30 0.50 COMPZN, RPCOMP CUTP T R/D Cameron casing growth tool. 0.0 0.0 9/7/2024 01:30 9/7/2024 02:00 0.50 COMPZN, RPCOMP CUTP T Engauge CSG w/ Spear. P/U to 180 K (150K with out block weight). CSG stretch 11.5" to clear mandrel hanger, and keep collar below clear of slip setting area. Total 31.875" between grow and stretch of 7" CSG. Cameron set slips. Slack off and verify slips set. 0.0 0.0 9/7/2024 02:00 9/7/2024 02:30 0.50 COMPZN, RPCOMP CUTP T Disengauge spear and pull to rig floor. Attempt to pull tubing head off of CSG. Unable to safely pull. 0.0 0.0 9/7/2024 02:30 9/7/2024 03:30 1.00 COMPZN, RPCOMP CUTP T R/U winch lines, and wachs cutter. Cut CSG. L/D Cut 7" w/ tubing spool. 0.0 0.0 9/7/2024 03:30 9/7/2024 04:00 0.50 COMPZN, RPCOMP WWSP T Cameron reps install CSG pack off. 0.0 0.0 9/7/2024 04:00 9/7/2024 07:00 3.00 COMPZN, RPCOMP NUND T Stab 11"x 13 5/8" DSA onto CSG head. Stab BOP onto DSA, and nipple up. 0.0 0.0 9/7/2024 07:00 9/7/2024 08:00 1.00 COMPZN, RPCOMP BHAH T P/U 6 1/8" string mill and attempt to RIH. Made it to 30', able to work down to 64'. POOH L/D string mill, and rack back stand of drill pipe. 0.0 0.0 9/7/2024 08:00 9/7/2024 08:30 0.50 COMPZN, RPCOMP SVRG T Service rig floor equipment. 0.0 0.0 9/7/2024 08:30 9/7/2024 10:30 2.00 COMPZN, RPCOMP BHAH T P/U BHA 6 1/8" Drift BHA. RIH to 268'. Unable to pass POOH Rack back 4 3/4" DC, and L/D BHA. 0.0 0.0 9/7/2024 10:30 9/7/2024 14:00 3.50 COMPZN, RPCOMP PULD T RIH picking up drill pipe from surface to 1347'. Tag out at 1347' set down 15K. PUWT: 65 K SOWT: 45 K 0.0 1,347.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 3/40 1D-05 Report Printed: 11/11/2024 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) 9/7/2024 14:00 9/7/2024 19:00 5.00 COMPZN, RPCOMP MPSP T Dump sand on top of IBP. 1,347.0 1,347.0 9/7/2024 19:00 9/7/2024 20:00 1.00 COMPZN, RPCOMP TRIP T POOH F/ 1347' to surface racking back drill pipe. PUWT: 55 K SOWT: 45 K 1,347.0 0.0 9/7/2024 20:00 9/7/2024 21:00 1.00 COMPZN, RPCOMP ELNE T R/U Yellow Jacket E-line Sheaves. Bring tools to the rig floor. P/U Caliper/ CCL combo. Calibrate tools, and set 0 from rotary table. 0.0 0.0 9/7/2024 21:00 9/7/2024 22:30 1.50 COMPZN, RPCOMP ELOG T Jellow jacket E-line RIH w/ Caliper/ CCL combo. Tag out @ 1150'. Attempt to work through 3 times without sucess. 0.0 1,150.0 9/7/2024 22:30 9/7/2024 23:00 0.50 COMPZN, RPCOMP ELNE T Yellow jacket E- line POOH and inspect tool. Tension spring on lower centralizer was too tight. Install 7' weight bar bellow tools string. 1,150.0 0.0 9/7/2024 23:00 9/8/2024 00:00 1.00 COMPZN, RPCOMP ELOG T Yellow Jacket E-line RIH w/ tools. able to pass 1150'. Tag top of IBP @ 1800'. 0.0 1,800.0 9/8/2024 00:00 9/8/2024 00:45 0.75 COMPZN, RPCOMP ELOG T YJOS POOH logging F/ 1800' to 90' W/ Caliper/CCL combo. 1,800.0 0.0 9/8/2024 00:45 9/8/2024 01:15 0.50 COMPZN, RPCOMP ELNE T Yellow Jacket L/D Caliper/ CCL tools. P/U CBL, and M/U. 0.0 0.0 9/8/2024 01:15 9/8/2024 02:30 1.25 COMPZN, RPCOMP ELOG T Yellow jacket RIH to 1800' W/CBL and log up to surface. 0.0 0.0 9/8/2024 02:30 9/8/2024 03:30 1.00 COMPZN, RPCOMP ELNE T L/D Yellow Jacket tools. Lay Down Crew Time out 0.0 0.0 9/8/2024 03:30 9/8/2024 07:30 4.00 COMPZN, RPCOMP ELOG T Wait on logs to be interpreted.Discussed with engineers about options, decision was made to do mechanical cut w/baker. 0.0 0.0 9/8/2024 07:30 9/8/2024 10:30 3.00 COMPZN, RPCOMP BHAH T M/U Drift Run with baker W/4.75 Bull nose RIH and Tag up @ 1854' with no issues P/U 80' and dump 20 sacks sand 0.0 0.0 9/8/2024 10:30 9/8/2024 13:30 3.00 COMPZN, RPCOMP CIRC T RIH Tag up @ 1839' POOH t/ 1640' Circ Add 3% 776 Friction reducer T/System 0.0 1,839.0 9/8/2024 13:30 9/8/2024 15:30 2.00 COMPZN, RPCOMP TRIP T POOH Stand Back D.P. L/D Bull nose M/U Baker fishing Mech Cutter RIH t/ 1,839.0 0.0 9/8/2024 15:30 9/8/2024 17:30 2.00 COMPZN, RPCOMP TRIP T Locate 7" collars No go @ 1800' POOH check Baker cutter UW 60KK DW 50K Attempt 3 times locate collars no go . 0.0 1,839.0 9/8/2024 17:30 9/8/2024 17:45 0.25 COMPZN, RPCOMP BHAH T Change out blades on cutter. Wrap cutters in bailing wire and tape. 0.0 0.0 9/8/2024 17:45 9/8/2024 19:15 1.50 COMPZN, RPCOMP TRIP T RIH W/ Cutter BHA F/ surface to 1756' 0.0 1,756.0 9/8/2024 19:15 9/8/2024 19:45 0.50 COMPZN, RPCOMP CPBO T Unable to locate Casing collars with multi string cutter. 1,756.0 1,800.0 9/8/2024 19:45 9/8/2024 20:30 0.75 COMPZN, RPCOMP TRIP T POOH to inspect cutter, and blades. PUWT: 60 k SOWT: 50 k 1,800.0 0.0 9/8/2024 20:30 9/8/2024 21:00 0.50 COMPZN, RPCOMP BHAH T Change out cutters on multi string cutter from metal knives to Carbide cutters. 0.0 0.0 9/8/2024 21:00 9/8/2024 22:00 1.00 COMPZN, RPCOMP TRIP T RIH F/ Surface to 1758'. PUWT: 60K SOWT: 50K 0.0 1,748.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 4/40 1D-05 Report Printed: 11/11/2024 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) 9/8/2024 22:00 9/8/2024 22:30 0.50 COMPZN, RPCOMP CPBO T Locate collars w/ multi string cutter. Located collar @ 1748'. P/U and set down 5K @ 1748' again to confirm collar is located. 1,748.0 1,756.0 9/8/2024 22:30 9/9/2024 00:00 1.50 COMPZN, RPCOMP CPBO T Attempt to cut pipe. Mixed indications of wether pipe is cut or not. Start cut @120 GPM @ 440 PSI. After no clear indication of cut on rig floor. Annulus pressure suddenly increased to 160 PSI. 1,756.0 1,756.0 9/9/2024 00:00 9/9/2024 01:00 1.00 COMPZN, RPCOMP CPBO T Mixed indications of cut. Start cut @ 120 GPM @ 440 PSI 1.8K TQ. Increase from there up to 1000 PSI @ 190 GPM. 1,756.0 1,756.0 9/9/2024 01:00 9/9/2024 01:30 0.50 COMPZN, RPCOMP CIRC T Observe jump in annulus pressure from 0 to 160 PSI. Shut Annular, and line up pump down the drill pipe taking returns out of the annulus to the open top tank. Pump 84 GPM @ 260 PSI. 20 BBLS pumped, 20 bbls returned. 1,756.0 1,756.0 9/9/2024 01:30 9/9/2024 01:45 0.25 COMPZN, RPCOMP CIRC T Shut down pumps. Close annulus valve. Annulus pressure build to 60 PSI. Check pressure under annular through choke: 0 PSI. Open annular. 1,756.0 1,756.0 9/9/2024 01:45 9/9/2024 02:00 0.25 COMPZN, RPCOMP CPBO T Verify cut. 3000 PSI 3.3K TQ. Observe toruqe stall @ 6K. Release torque and continue with cut. Observe annulus pressure jump to 100 PSI. 1,756.0 1,756.0 9/9/2024 02:00 9/9/2024 06:00 4.00 COMPZN, RPCOMP CIRC T Pump 40 BBL Deep clean pill. Shut annuluar, Line up on LRS and chase W/ 80 BBLS of diesel. Let soak for 30 min. Chase w/ 40 BBL deep clean pill. Pump 150 BBLS of 10.4 Brine to tanks. 1,756.0 1,756.0 9/9/2024 06:00 9/9/2024 10:00 4.00 COMPZN, RPCOMP CIRC T POOH L/D cutter M/U baker spear Latch up BOLDS Attempt To pull casing Attempt to pull casing 150k/175K no movement serval times Set Down release spear L/D same M/U 5 3/4" Cutter RIH 1,756.0 1,756.0 9/9/2024 10:00 9/9/2024 11:00 1.00 COMPZN, RPCOMP CPBO T Start Cutting casing @ 1756" same spot 1,756.0 1,756.0 9/9/2024 11:00 9/9/2024 11:30 0.50 COMPZN, RPCOMP TRIP T POOH L/D cutter and P/U spear Attempt to pull casing 1,756.0 0.0 9/9/2024 11:30 9/9/2024 12:00 0.50 COMPZN, RPCOMP SVRG T Service top drive and rig floor equipment. 0.0 0.0 9/9/2024 12:00 9/9/2024 13:00 1.00 COMPZN, RPCOMP FISH T Engauge 7" w/ spear. BOLDS. Attempt to pull CSG. Pull up to 200K. Unable to unseat CSG. L/D Spear. Release spear from 7". L/D spear. 0.0 0.0 9/9/2024 13:00 9/9/2024 13:30 0.50 COMPZN, RPCOMP BHAH T P/U Multistring cutter. Dress w/ new knives. 0.0 0.0 9/9/2024 13:30 9/9/2024 14:00 0.50 COMPZN, RPCOMP TRIP T RIH w/ cutter to 1000'. PUWT: 50 K SOWT: 45 K 0.0 1,000.0 9/9/2024 14:00 9/9/2024 14:30 0.50 COMPZN, RPCOMP CPBO T Locate collars w/ CSG cutter. Make cut @ 987'. 168 GPM @ 1100 PSI. 80 RPM @ 1600 Ft/lbs TQ. 1,000.0 987.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 5/40 1D-05 Report Printed: 11/11/2024 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) 9/9/2024 14:30 9/9/2024 15:00 0.50 COMPZN, RPCOMP TRIP T POOH F/ 987' to surface. L/D Multi string cutter. PUWT: 55 K SOWT 45K. 987.0 0.0 9/9/2024 15:00 9/9/2024 16:30 1.50 COMPZN, RPCOMP FISH T P/U Spear and engauge 7". PUll up to 110K no break over. Slack off and come up to 150K broke over, and 7" started moving. 0.0 987.0 9/9/2024 16:30 9/9/2024 20:30 4.00 COMPZN, RPCOMP PULL T POOH L/D 7" F/ 987' to surface. Joints showed signs of severe buckling. 987.0 0.0 9/9/2024 20:30 9/9/2024 21:00 0.50 COMPZN, RPCOMP OTHR T Clean and clear rig floor. R/D GBR 7" power tongs, and pipe handling equipment. 0.0 0.0 9/9/2024 21:00 9/9/2024 22:30 1.50 COMPZN, RPCOMP OTHR T Load 6.5" DC into the pipe shed and strap. Perform post jaring inspection. 0.0 0.0 9/9/2024 22:30 9/10/2024 00:00 1.50 COMPZN, RPCOMP BHAH T P/U DC, and BHA. 0.0 226.0 9/10/2024 00:00 9/10/2024 00:30 0.50 COMPZN, RPCOMP TRIP T RIH w/ Spear F/ 226' to 968' Set down 5K. P/U to break over. PUWT: 55K SOWT: 50K 226.0 968.0 9/10/2024 00:30 9/10/2024 01:30 1.00 COMPZN, RPCOMP CIRC T Bring pumps up to 420 GPM @ 600 PSI, and attempt to wash down. Stacked weight @ 968', String hydrauliced up. Cut pumps and pick up. Attempt again @ 120 GPM @ 70 PSI work down to 972'. Unable to pass obstruction. 968.0 972.0 9/10/2024 01:30 9/10/2024 02:00 0.50 COMPZN, RPCOMP TRIP T POOH F/ 972' to surface. 972.0 226.0 9/10/2024 02:00 9/10/2024 03:00 1.00 COMPZN, RPCOMP BHAH T POOH racking back collars, and L/D spear. 226.0 0.0 9/10/2024 03:00 9/10/2024 05:00 2.00 COMPZN, RPCOMP PRTS T Flush stack, and set test plug. Test Flange break to 3000 PSI. Pull test plug, and set wear bushing. 0.0 0.0 9/10/2024 05:00 9/10/2024 07:00 2.00 COMPZN, RPCOMP BHAH T P/U Clean out BHA 0.0 250.0 9/10/2024 07:00 9/10/2024 10:30 3.50 COMPZN, RPCOMP REAM T Ream into hole to top of fish F/ 250' T/ 987' // Pump 420 gal per min @ 545psi // Tag top fish continue to grind up junk ensure clean top 250.0 987.0 9/10/2024 10:30 9/10/2024 11:00 0.50 COMPZN, RPCOMP CIRC T Circulate SxS 987.0 987.0 9/10/2024 11:00 9/10/2024 12:00 1.00 COMPZN, RPCOMP TRIP T OWFF // TOOH for fishing spear // 987.0 250.0 9/10/2024 12:00 9/10/2024 13:00 1.00 COMPZN, RPCOMP BHAH T Lay down BHA# 18 // Cement in boot baskets, and a control line piece 12" long 250.0 0.0 9/10/2024 13:00 9/10/2024 13:30 0.50 COMPZN, RPCOMP SVRG T Service rig // Pre-jarring checklist // service TD 0.0 0.0 9/10/2024 13:30 9/10/2024 13:45 0.25 COMPZN, RPCOMP BHAH T Pick up BHA# 19 7" fishing spear // RH release spear with packoff 226.8' OAL 0.0 226.8 9/10/2024 13:45 9/10/2024 14:45 1.00 COMPZN, RPCOMP TRIP T TIH to 979' // 55K Up and Dn wt 226.8 979.0 9/10/2024 14:45 9/10/2024 16:00 1.25 COMPZN, RPCOMP FISH T Attempt to fish 7" // Tag up @ 987' work spear into fish // Jar 225K straight pull 300K // Hit fish 20 times no movement 979.0 987.0 9/10/2024 16:00 9/10/2024 17:00 1.00 COMPZN, RPCOMP CIRC T Circulate 5 bbls/min @ 1000psi // perform derrick inspection 987.0 987.0 9/10/2024 17:00 9/10/2024 18:00 1.00 COMPZN, RPCOMP TRIP T TOOH, F/987' T/BHA, PUW 55k 987.0 226.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 6/40 1D-05 Report Printed: 11/11/2024 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) 9/10/2024 18:00 9/10/2024 19:30 1.50 COMPZN, RPCOMP BHAH T LD BHA #19 spear assembly, packoff was damaged and missing grapple, 226.0 0.0 9/10/2024 19:30 9/10/2024 20:00 0.50 COMPZN, RPCOMP SVRG T Service Rig, top drive, iron roughneck, handling equipment, etc, gerneral housekeeping. 0.0 0.0 9/10/2024 20:00 9/10/2024 22:30 2.50 COMPZN, RPCOMP WAIT T Stand by for fishing tools 0.0 0.0 9/10/2024 22:30 9/10/2024 23:00 0.50 COMPZN, RPCOMP BHAH T Tools on location, load into pipeshed, strap and drift. 0.0 0.0 9/10/2024 23:00 9/11/2024 00:00 1.00 COMPZN, RPCOMP BHAH T MU BHA #20 w/fishing assembly 0.0 27.9 9/11/2024 00:00 9/11/2024 00:45 0.75 COMPZN, RPCOMP BHAH T Continue MU Fishing BHA #20 w/magnets 27.9 27.9 9/11/2024 00:45 9/11/2024 01:45 1.00 COMPZN, RPCOMP TRIP T TIH w/ Magents F/ 28' to 968' Set down 3 to 5K. P/U to break over. PUWT: 55K SOWT: 50K 27.9 9/11/2024 01:45 9/11/2024 02:15 0.50 COMPZN, RPCOMP TRIP T 980', bring pump online @ 10 bpm, wash down F/980' T/987', PUH, rotate 1/4 turn RBIH, recep pipe 986.9 986.9 9/11/2024 02:15 9/11/2024 02:45 0.50 COMPZN, RPCOMP TRIP T TOOH on stands F/987' T/BHA, PUW 55k 986.9 27.9 9/11/2024 02:45 9/11/2024 03:15 0.50 COMPZN, RPCOMP BHAH T LD BHA and inspect tools, No sign of fish 27.9 0.0 9/11/2024 03:15 9/11/2024 04:15 1.00 COMPZN, RPCOMP BHAH T MU BHA #21 RCJB, w/cut lip guide 0.0 36.3 9/11/2024 04:15 9/11/2024 05:15 1.00 COMPZN, RPCOMP TRIP T TIH on stands F/Surface T/987 36.3 987.0 9/11/2024 05:15 9/11/2024 06:30 1.25 COMPZN, RPCOMP WASH T Attempt to vac up grapple unable to wash over stump with cut lip 987.0 987.0 9/11/2024 06:30 9/11/2024 07:30 1.00 COMPZN, RPCOMP TRIP T OWFF, TOOH inspect RCJB 987.0 20.0 9/11/2024 07:30 9/11/2024 08:30 1.00 COMPZN, RPCOMP BHAH T Clean out RCJB // large chunks of cement // Consult with town decision made to re-run 20.0 20.0 9/11/2024 08:30 9/11/2024 09:30 1.00 COMPZN, RPCOMP TRIP T TIH to top of stump 20.0 980.0 9/11/2024 09:30 9/11/2024 10:15 0.75 COMPZN, RPCOMP WASH T Pump 10 bpm @ 2600 psi unable to wash over stump @ 987' // PUW 55 SOW 50 980.0 987.0 9/11/2024 10:15 9/11/2024 11:00 0.75 COMPZN, RPCOMP TRIP T OWFF // TOOH inspect BHA 987.0 20.0 9/11/2024 11:00 9/11/2024 11:45 0.75 COMPZN, RPCOMP BHAH T Inspect BHA // RCJB clean // Lay down BHA #22 20.0 0.0 9/11/2024 11:45 9/11/2024 12:15 0.50 COMPZN, RPCOMP BHAH T Pick up BHA# 23 drift BHA // OAL 242.68' 0.0 242.7 9/11/2024 12:15 9/11/2024 13:00 0.75 COMPZN, RPCOMP TRIP T TIH to top of fish @ 980' 242.7 980.0 9/11/2024 13:00 9/11/2024 13:30 0.50 COMPZN, RPCOMP OTHR T Tag top of fish @ 987' // PUW 55 SOW 55 // Set down 10K pipe popped into top of casing // Pump 6 bpm @ 250 psi // Work bull nose T/995' pick up single DP, continue in hole 31' from top of fish SOW while in 7" = 50K 980.0 1,026.0 9/11/2024 13:30 9/11/2024 14:00 0.50 COMPZN, RPCOMP CIRC T Circulate hi-vis sweep SxS 1,026.0 1,026.0 9/11/2024 14:00 9/11/2024 14:30 0.50 COMPZN, RPCOMP TRIP T Confirm entry into top of stump // 10 K set downs then work into pipe 1,026.0 1,026.0 9/11/2024 14:30 9/11/2024 15:15 0.75 COMPZN, RPCOMP TRIP T TOOH for cutter with mule shoe F/1,026' T/BHA 1,026.0 242.7 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 7/40 1D-05 Report Printed: 11/11/2024 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) 9/11/2024 15:15 9/11/2024 15:45 0.50 COMPZN, RPCOMP BHAH T At surface, LD drift assembly BHA #23 242.7 0.0 9/11/2024 15:45 9/11/2024 16:15 0.50 COMPZN, RPCOMP BHAH T MU Baker MSC, 0.0 4.8 9/11/2024 16:15 9/11/2024 16:45 0.50 COMPZN, RPCOMP BHAH T MU Baker MSC TIH w/BHA #24 4.8 987.0 9/11/2024 16:45 9/11/2024 17:15 0.50 COMPZN, RPCOMP TRIP T Work bullnose into stump @ 987', unable to get cutting through TOF @ 987'. 987.0 987.0 9/11/2024 17:15 9/11/2024 18:00 0.75 COMPZN, RPCOMP TRIP T TOOH, to inspect BHA 987.0 4.8 9/11/2024 18:00 9/11/2024 18:30 0.50 COMPZN, RPCOMP BHAH T At surface LD and inspect cutter, found cement debris inside of tool, flush and replace 1 cutter. 4.8 0.0 9/11/2024 18:30 9/11/2024 19:00 0.50 COMPZN, RPCOMP BHAH T MU Baker MSC 0.0 6.8 9/11/2024 19:00 9/11/2024 19:30 0.50 COMPZN, RPCOMP TRIP T TIH, w/BHA #25 6.8 9/11/2024 19:30 9/11/2024 22:30 3.00 COMPZN, RPCOMP SLPC T Slip and cut drill line +/- 1,500' 945.0 945.0 9/11/2024 22:30 9/11/2024 23:00 0.50 COMPZN, RPCOMP SVRG T Service Rig 945.0 945.0 9/11/2024 23:00 9/11/2024 23:30 0.50 COMPZN, RPCOMP TRIP T Continue IH 945.0 980.0 9/11/2024 23:30 9/12/2024 00:00 0.50 COMPZN, RPCOMP CUTP T Work past top of fish @ 987', set down 10k pop through, continue IH F/987' T/1,200', bring pump online @ 3 bpm 440 psi, locate collar @ 1,213', continue IH T/1,221', Make cut, rotate 80 rpm/Free TQ=1,019 ft/lbs, increase pump pressure to 72 spm/4 bpm/800 psi, increase TQ=2,780 ft/lbs, 1,221.0 1,221.0 9/12/2024 00:00 9/12/2024 00:15 0.25 COMPZN, RPCOMP CUTP T Continue cut @ 1,221', pressure fell of indicating successful cut, PUH/PUW=55k, PUW=55k, SOW=50k 1,221.0 1,221.0 9/12/2024 00:15 9/12/2024 01:00 0.75 COMPZN, RPCOMP TRIP T TOOH for spear. F/1,221' T/BHA 1,221.0 6.8 9/12/2024 01:00 9/12/2024 01:30 0.50 COMPZN, RPCOMP BHAH T LD Baker MSC 6.8 0.0 9/12/2024 01:30 9/12/2024 02:30 1.00 COMPZN, RPCOMP BHAH T Pick up BHA# 26 7" fishing spear // RH release spear with packoff 227.7' OAL 0.0 227.7 9/12/2024 02:30 9/12/2024 03:00 0.50 COMPZN, RPCOMP TRIP T TIH w/BHA #26 PUW & SOW 55k 227.7 987.0 9/12/2024 03:00 9/12/2024 03:45 0.75 COMPZN, RPCOMP FISH T Attempt to fish 7", Tag up @ 987' work spear into fish, Jar 250K straight pull 400K, Hit fish 20 times no movement PUW & SOW=55k Release Spear 987.0 963.0 9/12/2024 03:45 9/12/2024 04:15 0.50 COMPZN, RPCOMP SVRG T Perform Derrick Inspection while circulating BU 963.0 963.0 9/12/2024 04:15 9/12/2024 05:15 1.00 COMPZN, RPCOMP TRIP T TOOH w/BHA #26 F/987' T/BHA 963.0 227.7 9/12/2024 05:15 9/12/2024 06:00 0.75 COMPZN, RPCOMP BHAH T LD BHA and inspect tools 227.7 0.0 9/12/2024 06:00 9/12/2024 06:30 0.50 COMPZN, RPCOMP BHAH T MU Baker MSC 0.0 6.8 9/12/2024 06:30 9/12/2024 07:15 0.75 COMPZN, RPCOMP TRIP T TIH w/cutter BHA #27 6.8 1,070.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 8/40 1D-05 Report Printed: 11/11/2024 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) 9/12/2024 07:15 9/12/2024 07:30 0.25 COMPZN, RPCOMP CPBO T Perform cut in 7" w/ MSC @ 1070' PUWT= 55 SOWT= 50 Locate collar @ 1,060', Pump 4.5 bpm @ 840psi Rot 85rpm @ 1100 ft/lbs PP after cut 200 psi good indication of cut 1,070.0 1,070.0 9/12/2024 07:30 9/12/2024 08:15 0.75 COMPZN, RPCOMP TRIP T OWFF, no flow, TOOH for fishing spear 1,070.0 6.8 9/12/2024 08:15 9/12/2024 08:45 0.50 COMPZN, RPCOMP BHAH T Lay down and inspect casing cutter, found damaged to screw, cutters look good with little wear 6.8 0.0 9/12/2024 08:45 9/12/2024 09:15 0.50 COMPZN, RPCOMP BHAH T Pick up fishing spear BHA# 28 0.0 227.0 9/12/2024 09:15 9/12/2024 10:30 1.25 COMPZN, RPCOMP TRIP T Engage fish @ 987' NG @ 995' PUWT= 59K SOWT= 55K 2bpm @ 57psi 227.0 995.0 9/12/2024 10:30 9/12/2024 11:15 0.75 COMPZN, RPCOMP FISH T Jar on fish 225K straight pull 400K 25 jar hits no movement 995.0 995.0 9/12/2024 11:15 9/12/2024 12:00 0.75 COMPZN, RPCOMP SFTY T Perform Derrick inspection post jarring operations 995.0 995.0 9/12/2024 12:00 9/12/2024 13:30 1.50 COMPZN, RPCOMP TRIP T Trip out of hole with fishing BHA 995.0 227.0 9/12/2024 13:30 9/12/2024 14:00 0.50 COMPZN, RPCOMP BHAH T Rack back collars, lay down jars 227.0 0.0 9/12/2024 14:00 9/12/2024 14:30 0.50 COMPZN, RPCOMP SVRG T Service iron roughneck 0.0 0.0 9/12/2024 14:30 9/12/2024 16:30 2.00 COMPZN, RPCOMP RGRP T Remove lower jaw on roughneck to repair hose 0.0 0.0 9/12/2024 16:30 9/12/2024 17:30 1.00 COMPZN, RPCOMP BHAH T PU BHA #29, found improper XO for mule shoe, call for replacement. Onsite Baker hand meeting Baker Deadhorse 1/2 way. Dress cutter with new blades. 0.0 6.4 9/12/2024 17:30 9/12/2024 18:30 1.00 COMPZN, RPCOMP BHAH T Improper XO for mule shoe. Dress cutter with new blades. Addtional fishing tools on location, unload and load into pipeshed, tally and bring 6-5/8" lifting Sub to shed. 6.4 6.4 9/12/2024 18:30 9/12/2024 19:00 0.50 COMPZN, RPCOMP BHAH T Continue MU Baker MSC BHA #29 6.4 7.6 9/12/2024 19:00 9/12/2024 20:00 1.00 COMPZN, RPCOMP TRIP T TIH, w/Baker MSC BHA #29 Past through TOF @ 987' w/10k bobble 7.6 1,028.0 9/12/2024 20:00 9/12/2024 20:45 0.75 COMPZN, RPCOMP CUTP T Locate collars w/ CSG cutter. Make cut @ 1,028'. PUW=50k, SOW=50k 4 BPM / 85 gpm @ 835 PSI. 80 RPM @ 680-1,300- Ft/lbs TQ. 1,028.0 1,028.0 9/12/2024 20:45 9/12/2024 21:15 0.50 COMPZN, RPCOMP OWFF T Check well for flow, grease TOP Drive Rail 1,028.0 1,028.0 9/12/2024 21:15 9/12/2024 21:45 0.50 COMPZN, RPCOMP TRIP T TOOH F/1,028' T/BHA 1,028.0 7.4 9/12/2024 21:45 9/12/2024 22:00 0.25 COMPZN, RPCOMP BHAH T LD and Inspect MSC/BHA (good), 7.4 0.0 9/12/2024 22:00 9/13/2024 00:00 2.00 COMPZN, RPCOMP BHAH T MU Spear BHA #30 w/7-3/4" jars 0.0 180.0 9/13/2024 00:00 9/13/2024 01:00 1.00 COMPZN, RPCOMP BHAH P MU Spear BHA #30 w/7-3/4" jars 180.0 240.5 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 9/40 1D-05 Report Printed: 11/11/2024 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) 9/13/2024 01:00 9/13/2024 01:30 0.50 COMPZN, RPCOMP TRIP P TIH, w/Baker ITCO spear and 7-3/4" Jars PUW=55, SOW=50k 240.5 987.0 9/13/2024 01:30 9/13/2024 01:45 0.25 COMPZN, RPCOMP FISH P Engage TOF @ 987', straight pull 185k, continue PUH dragging F/987' T/924', fish pulling freely. stop pulling 987.0 924.0 9/13/2024 01:45 9/13/2024 02:15 0.50 COMPZN, RPCOMP OWFF P Check well for flow, straighten up rig floor 924.0 924.0 9/13/2024 02:15 9/13/2024 02:45 0.50 COMPZN, RPCOMP TRIP P TOOH w/BHA #30 924.0 240.5 9/13/2024 02:45 9/13/2024 03:30 0.75 COMPZN, RPCOMP BHAH P Stand back BHA in Derrick Fish OAL=40.74' Cut Jt OAL=8.14' 7" collar is deformed 7.125" x 8.25" Cut look machined 240.5 0.0 9/13/2024 03:30 9/13/2024 04:00 0.50 COMPZN, RPCOMP SVRG P Rig Service 0.0 0.0 9/13/2024 04:00 9/13/2024 05:30 1.50 COMPZN, RPCOMP BHAH P PJSM, MU Cleanout/Drift assembly 0.0 266.6 9/13/2024 05:30 9/13/2024 06:15 0.75 COMPZN, RPCOMP TRIP P TIH w/cleanout assembly BHA #31 266.6 987.0 9/13/2024 06:15 9/13/2024 06:45 0.50 COMPZN, RPCOMP REAM P Clean out to top of fish @ 1,028' 987.0 1,028.0 9/13/2024 06:45 9/13/2024 07:00 0.25 COMPZN, RPCOMP CIRC P Circulate sweep SxS 1,028.0 1,028.0 9/13/2024 07:00 9/13/2024 08:15 1.25 COMPZN, RPCOMP TRIP P TOOH for spear 1,028.0 225.0 9/13/2024 08:15 9/13/2024 09:00 0.75 COMPZN, RPCOMP BHAH P Lay down BHA# 31 and inspect, boot baskets had cement debris in them 225.0 0.0 9/13/2024 09:00 9/13/2024 09:45 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 32, jarring bha w/ 7-3/4" jars 0.0 220.0 9/13/2024 09:45 9/13/2024 11:15 1.50 COMPZN, RPCOMP TRIP P TIH w/ spear and 7-3/4" jars // Engage fish @ 1,028' 225.0 1,028.0 9/13/2024 11:15 9/13/2024 11:45 0.50 COMPZN, RPCOMP FISH P Jar on fish 300 K jar hits w/ 400 K straight pull // Fish moved 3' on the 4th hit, moving up hole on 5th w/ 225' PUW, Start moving freely @ 960' top of fish 1,028.0 960.0 9/13/2024 11:45 9/13/2024 12:00 0.25 COMPZN, RPCOMP OTHR P Post jarring inspections 960.0 960.0 9/13/2024 12:00 9/13/2024 13:15 1.25 COMPZN, RPCOMP TRIP P TOOH to lay down fish 960.0 225.0 9/13/2024 13:15 9/13/2024 14:30 1.25 COMPZN, RPCOMP BHAH P Rack collars and lay down spear and fish 225.0 0.0 9/13/2024 14:30 9/13/2024 15:30 1.00 COMPZN, RPCOMP BHAH P Pick up cleanout BHA 0.0 266.0 9/13/2024 15:30 9/13/2024 16:30 1.00 COMPZN, RPCOMP TRIP P Trip in hole for clean out run to top of fish @ 1070' 266.0 1,030.0 9/13/2024 16:30 9/13/2024 17:30 1.00 COMPZN, RPCOMP REAM P Perform clean out down to top of fish @ 1,070 // Cement in returns // Rot 50 rpm 800 ft/lbs torque // Pump 10 bpm @ 550 psi // PUWT 59 SOWT 54 1,030.0 1,070.0 9/13/2024 17:30 9/13/2024 18:00 0.50 COMPZN, RPCOMP TRIP P TOOH w/Cleanout BHA #33 1,070.0 240.0 9/13/2024 18:00 9/13/2024 19:00 1.00 COMPZN, RPCOMP BHAH P LD BHA #33 240.0 0.0 9/13/2024 19:00 9/13/2024 20:00 1.00 COMPZN, RPCOMP BHAH P MU, Baker ITCO spear w/7-3/4" jars BHA #34 0.0 246.6 9/13/2024 20:00 9/13/2024 21:00 1.00 COMPZN, RPCOMP TRIP P TIH w/fishing BHA #34 w/Baker ITCO Spear and 7-3/4" Jars. 246.6 1,070.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 10/40 1D-05 Report Printed: 11/11/2024 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) 9/13/2024 21:00 9/13/2024 21:30 0.50 COMPZN, RPCOMP FISH P PUW=60k, SOW=60 @ 1,027' Wash down 1.5 bpm @ 60 psi F/1,027' T/1,068.5' notice 100 psi increase as spear entered TOF Engage fish set down 1,077' w/20k down. Bleed jars @ 125k, fish free @ 255k, continue pulling dragging 55k-400k T/904', 1,070.0 904.0 9/13/2024 21:30 9/13/2024 22:00 0.50 COMPZN, RPCOMP CIRC P Circulate BU 904.0 9/13/2024 22:00 9/13/2024 22:30 0.50 COMPZN, RPCOMP OWFF P Check well for flow, Service Rig 904.0 904.0 9/13/2024 22:30 9/13/2024 23:00 0.50 COMPZN, RPCOMP TRIP P Continue TOOH w/fish F/904' T/BHA PUW=65k, SOW=50k 904.0 246.6 9/13/2024 23:00 9/13/2024 23:30 0.50 COMPZN, RPCOMP BHAH P Stand back collars, grapple at surface, observe 7" collars deformed. Dis-engage graple after sercuring 7" casing in elevators. 246.6 0.0 9/13/2024 23:30 9/14/2024 00:00 0.50 COMPZN, RPCOMP BHAH P Load pneumatic sal-zaw tools onto rig floor and prep to cut 7" casing. PJSM with rig crew and BOT. 0.0 0.0 9/14/2024 00:00 9/14/2024 00:30 0.50 COMPZN, RPCOMP BHAH P Secure and Cut 7" casing in stump with pnematic sal-zaw tool, LD 7" casing joint to pipeshed *** Note: Centralizer missing the top half. as well as one lock ring and bow springs. 0.0 0.0 9/14/2024 00:30 9/14/2024 01:00 0.50 COMPZN, RPCOMP BHAH P Lower Baker ITCO Spear to RF, inspect, lay down to pipe shed. 0.0 0.0 9/14/2024 01:00 9/14/2024 01:30 0.50 COMPZN, RPCOMP BHAH P Swap out elevators, latch onto remaining fish, pull up and secure with dog collar, RU GBR, back out connection. continue LD fish OAL=153.36' 0.0 0.0 9/14/2024 01:30 9/14/2024 02:00 0.50 COMPZN, RPCOMP OTHR P RD GBR, Empty pipeshed, load cleanout assembly into pipeshed 0.0 0.0 9/14/2024 02:00 9/14/2024 04:00 2.00 COMPZN, RPCOMP BHAH P MU cleanout/drift assembly, w/9.5" OD Washover shoe 0.0 273.4 9/14/2024 04:00 9/14/2024 04:30 0.50 COMPZN, RPCOMP TRIP P TIH w/Cleanout BHA #35 273.4 1,089.0 9/14/2024 04:30 9/14/2024 04:45 0.25 COMPZN, RPCOMP REAM P Perform clean out down F/1,089' T/1,089 Rot 20 rpm 800 ft/lbs torque, PUW=65k SOW=63k, unable to make forward progress. 1,089.0 1,089.0 9/14/2024 04:45 9/14/2024 05:15 0.50 COMPZN, RPCOMP TRIP P TOOH, w/BHA #35 1,089.0 273.4 9/14/2024 05:15 9/14/2024 06:00 0.75 COMPZN, RPCOMP BHAH P Stand back collars, LD BHA 273.4 0.0 9/14/2024 06:00 9/14/2024 06:45 0.75 COMPZN, RPCOMP BHAH P MU Cleanout assembly BHA #36 0.0 226.0 9/14/2024 06:45 9/14/2024 08:15 1.50 COMPZN, RPCOMP TRIP P TIH with ventrui assembly // 8-1/8" RCJB w/ 8.5" string mills 226.0 1,000.0 9/14/2024 08:15 9/14/2024 10:15 2.00 COMPZN, RPCOMP REAM P Ream down to top of fish @ 1218' 1,000.0 1,218.0 9/14/2024 10:15 9/14/2024 11:15 1.00 COMPZN, RPCOMP CIRC P Circulate 2 sweeps and B/U 1,218.0 1,215.0 9/14/2024 11:15 9/14/2024 12:30 1.25 COMPZN, RPCOMP TRIP P TOOH for RCJB 2.0 1,215.0 225.0 9/14/2024 12:30 9/14/2024 13:45 1.25 COMPZN, RPCOMP BHAH P Lay down and inspect BHA# 36 // 225.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 11/40 1D-05 Report Printed: 11/11/2024 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) 9/14/2024 13:45 9/14/2024 14:30 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 37 0.0 226.0 9/14/2024 14:30 9/14/2024 15:30 1.00 COMPZN, RPCOMP TRIP P Trip in hole with RCJB 226.0 1,000.0 9/14/2024 15:30 9/14/2024 16:15 0.75 COMPZN, RPCOMP WASH P Wash down with RCJB T/ 1219 // Pump 5.5 bpm @ 2290 psi // PUWT 68 SOWT 65 // Top of stump 1217' rot down to 1219' // Circulate Sweeps to clean hole 1,000.0 1,219.0 9/14/2024 16:15 9/14/2024 18:15 2.00 COMPZN, RPCOMP TRIP P TOOH, LD cleanout assembly inspect junk baskets (clean) 1,219.0 0.0 9/14/2024 18:15 9/14/2024 19:30 1.25 COMPZN, RPCOMP BHAH P MU spear assembly 0.0 246.6 9/14/2024 19:30 9/14/2024 20:15 0.75 COMPZN, RPCOMP TRIP P TIH w/Baker ITCO Spear BHA #38 246.6 1,220.0 9/14/2024 20:15 9/14/2024 22:45 2.50 COMPZN, RPCOMP FISH P Bring pump online 10 bpm/580 psi, observe graple doing into top of fish, bleed jar, hit x 50 @ 265k, straight pull to 400k, pulled fish free @ 290k, to 1,196.71', stop making forward progress, Confer with TT, release from fish. 1,220.0 1,196.7 9/14/2024 22:45 9/14/2024 23:00 0.25 COMPZN, RPCOMP SFTY P Inspect derrick 1,196.7 9/14/2024 23:00 9/14/2024 23:30 0.50 COMPZN, RPCOMP CIRC P Circulate BU 1,196.7 1,196.7 9/14/2024 23:30 9/15/2024 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF 1,196.7 1,196.7 9/15/2024 00:00 9/15/2024 00:45 0.75 COMPZN, RPCOMP TRIP P TOOH w/Spear BHA #38 1,196.7 246.6 9/15/2024 00:45 9/15/2024 01:15 0.50 COMPZN, RPCOMP BHAH P At surface, LD Spear BHA #38 246.6 0.0 9/15/2024 01:15 9/15/2024 01:45 0.50 COMPZN, RPCOMP BHAH P MU Baker MSC 0.0 7.6 9/15/2024 01:45 9/15/2024 02:15 0.50 COMPZN, RPCOMP TRIP P TIH, w/Baker MSC, BHA #39 7.6 1,242.0 9/15/2024 02:15 9/15/2024 02:45 0.50 COMPZN, RPCOMP CUTP P Bring pump online, locatlor @ 1,231', Cut 7" casing @ 1,239', PUW=50k, SOW=50k 1,242.0 1,242.0 9/15/2024 02:45 9/15/2024 03:15 0.50 COMPZN, RPCOMP TRIP P TOOH w/Baker MSC BHA #39 1,242.0 7.6 9/15/2024 03:15 9/15/2024 03:45 0.50 COMPZN, RPCOMP BHAH P LD BHA #39 7.6 0.0 9/15/2024 03:45 9/15/2024 04:15 0.50 COMPZN, RPCOMP BHAH P MU Baker ITCO spear w/6.220" grapple 0.0 246.6 9/15/2024 04:15 9/15/2024 05:15 1.00 COMPZN, RPCOMP TRIP P TIH w/Spear BHA #40 246.6 1,200.0 9/15/2024 05:15 9/15/2024 06:15 1.00 COMPZN, RPCOMP TRIP P TOOH lay down fish 1,200.0 200.0 9/15/2024 06:15 9/15/2024 07:00 0.75 COMPZN, RPCOMP BHAH P Lay down 40' fish and spear BHA 0.0 0.0 9/15/2024 07:00 9/15/2024 07:45 0.75 COMPZN, RPCOMP BHAH P Make up clean out BHA# 41 0.0 225.0 9/15/2024 07:45 9/15/2024 08:45 1.00 COMPZN, RPCOMP TRIP P Trip in the hole to 1000' // 225.0 1,000.0 9/15/2024 08:45 9/15/2024 10:15 1.50 COMPZN, RPCOMP WASH P Pump 6 bpm @ 2100 psi wash down to 1237 1,000.0 1,234.0 9/15/2024 10:15 9/15/2024 11:15 1.00 COMPZN, RPCOMP CIRC P Circulate sweeps SxS 1,234.0 1,234.0 9/15/2024 11:15 9/15/2024 12:15 1.00 COMPZN, RPCOMP TRIP P TOOH for cutter 1,234.0 226.0 9/15/2024 12:15 9/15/2024 13:15 1.00 COMPZN, RPCOMP BHAH P Lay down BHA# 41 clean out // few chunks of cement in basket 226.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 12/40 1D-05 Report Printed: 11/11/2024 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) 9/15/2024 13:15 9/15/2024 13:45 0.50 COMPZN, RPCOMP BHAH P Make up BAH# 42 cutter 0.0 8.0 9/15/2024 13:45 9/15/2024 14:45 1.00 COMPZN, RPCOMP TRIP P Trip in hole with cutter, tag top of fish @ 1235' // Rot 1/4" turn work into 7" // Continue in hole T/1457' stack out, pick up hole to locate collar 1430 225.0 1,430.0 9/15/2024 14:45 9/15/2024 15:15 0.50 COMPZN, RPCOMP CPBO P Pump 90 spm @ 1000 psi // Locate collar @ 1434' // Shut down pump run in hole 1444' // Pump 90 spm @ 1000 psi Rot 80 rpm ( 690 tq free ) perform cut w/ up to 2000 tq and 1300 psi // PP drop to 750 psi 1,430.0 1,444.0 9/15/2024 15:15 9/15/2024 16:00 0.75 COMPZN, RPCOMP TRIP P Trip out of hole with cutter to pick up spear // lay down cutter 1,444.0 0.0 9/15/2024 16:00 9/15/2024 16:30 0.50 COMPZN, RPCOMP SVRG P Rig service 0.0 9/15/2024 16:30 9/15/2024 17:15 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 43 fishing spear w/ 7-3/4" Jars 0.0 225.0 9/15/2024 17:15 9/15/2024 18:15 1.00 COMPZN, RPCOMP TRIP P TIH w/Spear BHA #43 225.0 1,239.0 9/15/2024 18:15 9/15/2024 18:45 0.50 COMPZN, RPCOMP FISH P Work pipe to engage fish @ 1,239', jar @ 320k, fish moving up hole F/1,239' T/1,197', allow breaks to cool, continue jarring, 36 hit total, 1,239.0 1,197.0 9/15/2024 18:45 9/15/2024 22:15 3.50 COMPZN, RPCOMP TRIP P Continue pulling fish to surface dragging weight 100k-250k F/1,239' T/180' 1,197.0 205.0 9/15/2024 22:15 9/15/2024 22:45 0.50 COMPZN, RPCOMP BHAH P Fish at surface, PJSM, LD BHA, trouble getting spear released, move forward in LD BHA, send spear into pipe shed to be cut out. 205.0 205.0 9/15/2024 22:45 9/16/2024 00:00 1.25 COMPZN, RPCOMP BHAH P RU GBR, LD fish 205.0 43.0 9/16/2024 00:00 9/16/2024 00:30 0.50 COMPZN, RPCOMP BHAH P Continue LD 7" casing 43.0 0.0 9/16/2024 00:30 9/16/2024 01:00 0.50 COMPZN, RPCOMP OTHR P RD GBR, Clean RF 0.0 0.0 9/16/2024 01:00 9/16/2024 01:30 0.50 COMPZN, RPCOMP SVRG P Perform Derrick inspection, Service top drive and Iron Roughnecks 0.0 0.0 9/16/2024 01:30 9/16/2024 02:00 0.50 COMPZN, RPCOMP OTHR P Move DC out of line of fire 0.0 0.0 9/16/2024 02:00 9/16/2024 02:30 0.50 COMPZN, RPCOMP BHAH P MU Cleanout BHA #44 0.0 271.6 9/16/2024 02:30 9/16/2024 03:30 1.00 COMPZN, RPCOMP TRIP P TIH, F/surface T/1,444', tight spot @ 1,175' 271.6 1,444.0 9/16/2024 03:30 9/16/2024 05:30 2.00 COMPZN, RPCOMP CIRC P Circulate BU with sweeps, cement in returnxs. 1,444.0 1,443.0 9/16/2024 05:30 9/16/2024 06:30 1.00 COMPZN, RPCOMP TRIP P Trip out of hole to pick up fishing BHA 1,443.0 0.0 9/16/2024 06:30 9/16/2024 07:30 1.00 COMPZN, RPCOMP BHAH P Break down BHA and inspect RCJB found some cement in basket 0.0 0.0 9/16/2024 07:30 9/16/2024 08:30 1.00 COMPZN, RPCOMP BHAH P Pick up fishing spear BHA # 45 0.0 226.0 9/16/2024 08:30 9/16/2024 09:30 1.00 COMPZN, RPCOMP TRIP P Trip in hole Tight spot 1175' // Trip in T/1282 226.0 1,282.0 9/16/2024 09:30 9/16/2024 13:00 3.50 COMPZN, RPCOMP SLPC P Cut and slip drill line // change saver sub due to wear from Jarring 1,282.0 1,282.0 9/16/2024 13:00 9/16/2024 13:45 0.75 COMPZN, RPCOMP TRIP P Trip in hole engage fish @ 1453' 1,282.0 1,453.0 9/16/2024 13:45 9/16/2024 14:00 0.25 COMPZN, RPCOMP FISH P Pull on fish 90K bleed jars // Popped free @ 150K // Drag 150 - 200 up for 60' then pulled freely @ 65K PUWT 1,453.0 1,390.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 13/40 1D-05 Report Printed: 11/11/2024 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) 9/16/2024 14:00 9/16/2024 15:00 1.00 COMPZN, RPCOMP TRIP P Trip to surface pulling 65K up wt 1,390.0 225.0 9/16/2024 15:00 9/16/2024 15:45 0.75 COMPZN, RPCOMP BHAH P Rack collars, no fish on grapple 225.0 0.0 9/16/2024 15:45 9/16/2024 16:30 0.75 COMPZN, RPCOMP BHAH P Make up new grapple and run in BHA# 45 fishing spear 0.0 225.0 9/16/2024 16:30 9/16/2024 18:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole to top of fish 1452' // Wash into top of fish 225.0 1,452.0 9/16/2024 18:00 9/16/2024 19:00 1.00 COMPZN, RPCOMP CIRC P Circulate sweep prior to engaging fish 1,452.0 1,450.0 9/16/2024 19:00 9/16/2024 21:00 2.00 COMPZN, RPCOMP FISH P Attempt to engage fish // unable to verrify fish caught 1,450.0 1,463.0 9/16/2024 21:00 9/16/2024 21:45 0.75 COMPZN, RPCOMP TRIP P TOOH to inspect fishing tools 1,463.0 225.0 9/16/2024 21:45 9/16/2024 22:30 0.75 COMPZN, RPCOMP BHAH P Rack collars // Lay down and inspect BHA, found packoff damaged re- configure spear 225.0 0.0 9/16/2024 22:30 9/16/2024 23:00 0.50 COMPZN, RPCOMP BHAH P Make up spear w/o packoff // Pick up collars 0.0 223.0 9/16/2024 23:00 9/16/2024 23:30 0.50 COMPZN, RPCOMP TRIP P TIH 223.0 1,455.0 9/16/2024 23:30 9/17/2024 00:00 0.50 COMPZN, RPCOMP CIRC P Circulate BU @ 10 bpm/607 psi 1,455.0 9/17/2024 00:00 9/17/2024 00:30 0.50 COMPZN, RPCOMP CIRC P Continue circulating BU @ 10 bpm/607 psi 1,455.0 1,462.0 9/17/2024 00:30 9/17/2024 01:00 0.50 COMPZN, RPCOMP FISH P Work pipe, attempt to engage fish, with no success. Circulate second BU, attempt to engage fish, no success 1,462.0 1,462.0 9/17/2024 01:00 9/17/2024 01:30 0.50 COMPZN, RPCOMP TRIP P TOOH w/BHA #47 1,462.0 271.6 9/17/2024 01:30 9/17/2024 02:00 0.50 COMPZN, RPCOMP BHAH P LD and inspect BHA 271.6 0.0 9/17/2024 02:00 9/17/2024 04:30 2.50 COMPZN, RPCOMP BHAH P MU Baker RCJB BHA #48 w/6.0" burn shoe and 6.125" string mills 0.0 274.1 9/17/2024 04:30 9/17/2024 05:00 0.50 COMPZN, RPCOMP TRIP P TIH with BHA #48 274.1 1,409.0 9/17/2024 05:00 9/17/2024 07:00 2.00 COMPZN, RPCOMP OTHR P Bring pump on line 10 bpm/2,250 psi F/1,459', ROT=40 rpm, TQWT=54k, TQ=1,000 fl/lbs T/1,469' 1,409.0 1,471.0 9/17/2024 07:00 9/17/2024 08:00 1.00 COMPZN, RPCOMP TRIP P TOOH, w/RCJB BHA #48 1,471.0 274.1 9/17/2024 08:00 9/17/2024 09:00 1.00 COMPZN, RPCOMP BHAH P LD and inspect BHA, recovered 3 full bow springs and cement chunks 2"x3". 274.1 0.0 9/17/2024 09:00 9/17/2024 10:30 1.50 COMPZN, RPCOMP BHAH P MU BHA #49 Baker ITCO spear 6.220" grapple, with out packoff, 0.0 245.8 9/17/2024 10:30 9/17/2024 11:00 0.50 COMPZN, RPCOMP TRIP P TIH w/Spear, BHA #49 245.8 1,468.0 9/17/2024 11:00 9/17/2024 11:30 0.50 COMPZN, RPCOMP FISH P Bring pump online @ 4 bpm/663 psi, Engage fish 1,468.0 1,468.0 9/17/2024 11:30 9/17/2024 13:30 2.00 COMPZN, RPCOMP FISH P Jar on fish 325k straight pull to 400k.31 jar hits, moved fish up hole F/1,468' T/1,374' 1,468.0 1,374.0 9/17/2024 13:30 9/17/2024 14:00 0.50 COMPZN, RPCOMP SVRG P Perform Derrick inspecion, Rig Service 1,374.0 1,374.0 9/17/2024 14:00 9/17/2024 18:00 4.00 COMPZN, RPCOMP FISH P Continue POOH, dragging 100k-220k, Circulate 2.6% lube pill and spot around fish Continue POOH @ 1270' No movement Jarred for 2 .50 hrs pulled free or pulled off of fish 1,374.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 14/40 1D-05 Report Printed: 11/11/2024 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) 9/17/2024 18:00 9/17/2024 20:00 2.00 COMPZN, RPCOMP JAR P Service rig,derrick inspection 1,270.0 9/17/2024 20:00 9/17/2024 21:00 1.00 COMPZN, RPCOMP TRIP P Continue POOH F/ 1265' 9/17/2024 21:00 9/17/2024 22:00 1.00 COMPZN, RPCOMP BHAH P L/D 4.8' of 7" casing C/O grapple M/U BHA 9/17/2024 22:00 9/17/2024 23:00 1.00 COMPZN, RPCOMP FISH P RIH latch up on Fish @ 1275' 1,275.0 9/17/2024 23:00 9/18/2024 00:00 1.00 COMPZN, RPCOMP TRIP P POOH w/ Fish Continue jarring as needed 9/18/2024 00:00 9/18/2024 01:30 1.50 COMPZN, RPCOMP FISH P Continue jarring 325k straight pull 400k F/1,178' T/1,150' 1,178.0 1,150.0 9/18/2024 01:30 9/18/2024 02:30 1.00 COMPZN, RPCOMP FISH P Continue jarring, fish moving up hole w/200k up weight F/1,150' T/800' 1,150.0 800.0 9/18/2024 02:30 9/18/2024 03:00 0.50 COMPZN, RPCOMP TRIP P TOOH, F/800' T/BHA 800.0 243.0 9/18/2024 03:00 9/18/2024 04:00 1.00 COMPZN, RPCOMP BHAH P At surface, LD BHA #50, unable to release spear, LD cut joint and spear to shed. load out to shop to be cut out., 243.0 0.0 9/18/2024 04:00 9/18/2024 05:30 1.50 COMPZN, RPCOMP BHAH P LD fish OAL=285.23' 0.0 0.0 9/18/2024 05:30 9/18/2024 06:00 0.50 COMPZN, RPCOMP RURD P RD GBR, clean and clear rig floor 0.0 0.0 9/18/2024 06:00 9/18/2024 06:30 0.50 COMPZN, RPCOMP BHAH P Derrick inspection, drawworks and Top Drive. 0.0 0.0 9/18/2024 06:30 9/18/2024 07:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #51 w/8.125" cut lip guide, RCJB, and boot baskets. 0.0 271.6 9/18/2024 07:30 9/18/2024 08:30 1.00 COMPZN, RPCOMP TRIP P TIH, w/BHA #51 F/surface T/1,405', PUW=68k, SOW=68k, LD stand 11, repalse joints, update DP tally. 271.6 1,405.0 9/18/2024 08:30 9/18/2024 11:30 3.00 COMPZN, RPCOMP OTHR P Wash down F/1,405' T/1,678', PUW=68k, SOW=68k, bring pump online 6 bpm/2,200 psi, 30 RPM/800 TQ off bottum, running 2-3k WOB, rotating 60 rpm 1,405.0 9/18/2024 11:30 9/18/2024 12:00 0.50 COMPZN, RPCOMP CIRC P Ciculate sweep around 1,678.0 1,678.0 9/18/2024 12:00 9/18/2024 13:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/RCJB BHA #51. F/1,678' T/surface 1,678.0 271.6 9/18/2024 13:00 9/18/2024 14:00 1.00 COMPZN, RPCOMP BHAH P At surface, LD BHA, inspect boot baskets and RCJB, packed off with cement and metal centrailzers. Take pictures and place on morning update slide; 271.6 0.0 9/18/2024 14:00 9/18/2024 14:30 0.50 COMPZN, RPCOMP OTHR P Clean RF 0.0 0.0 9/18/2024 14:30 9/18/2024 15:00 0.50 COMPZN, RPCOMP BHAH P MU Cleanout BHA #52, RR RCJB 0.0 271.6 9/18/2024 15:00 9/18/2024 16:30 1.50 COMPZN, RPCOMP TRIP P TIH w/Cleanout BHA # 52, strapping DP as we run IH. 271.6 9/18/2024 16:30 9/18/2024 18:00 1.50 COMPZN, RPCOMP WASH P Clean out f/ 1500' T/ 1684' W/ RCJB 1,684.0 9/18/2024 18:00 9/18/2024 19:00 1.00 COMPZN, RPCOMP CIRC P Circulate and pump 42 bblsHi vis Sweep Around 9/18/2024 19:00 9/18/2024 20:00 1.00 COMPZN, RPCOMP TRIP P POOH 9/18/2024 20:00 9/18/2024 21:30 1.50 COMPZN, RPCOMP BHAH P Clean out RCJB w/ lots of cement and metal 9/18/2024 21:30 9/18/2024 22:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA # 52 RR W/RCJB 9/18/2024 22:00 9/18/2024 23:00 1.00 COMPZN, RPCOMP TRIP P RIH T/ 1650' 1,650.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 15/40 1D-05 Report Printed: 11/11/2024 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) 9/18/2024 23:00 9/18/2024 23:45 0.75 COMPZN, RPCOMP WASH P Start Washing @ 1650' T/1688' 9/18/2024 23:45 9/19/2024 00:00 0.25 COMPZN, RPCOMP CIRC P Pump 38 BBLs hi vis sweep @ 6 bbls min w/2500 PSI 9/19/2024 00:00 9/19/2024 00:30 0.50 COMPZN, RPCOMP CIRC P Continue Circ out Sweep 1,680.0 1,682.0 9/19/2024 00:30 9/19/2024 02:00 1.50 COMPZN, RPCOMP TRIP P POOH F/1684' 1,682.0 271.6 9/19/2024 02:00 9/19/2024 03:30 1.50 COMPZN, RPCOMP BHAH P Clean out RCJB and Stand Back BHA 271.6 0.0 9/19/2024 03:30 9/19/2024 05:30 2.00 COMPZN, RPCOMP OTHR P Flush out BOP stack prep for BOP test and pull W.R. install test plug 0.0 0.0 9/19/2024 05:30 9/19/2024 07:30 2.00 COMPZN, RPCOMP OTHR P Grease all valves on mud manifold and stack, MU Test Joints, string out test lines, Flood stack, 0.0 0.0 9/19/2024 07:30 9/19/2024 13:00 5.50 COMPZN, RPCOMP BOPE P Test BOPS 3,000 psi high/2,500 psi low, 7" 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=28 Blind=5sec HCR Kill=1sec HCR Choke=1sec 200 psi Recovery=14sec Full System Recovery=102sec 5 Koomey Bottles @ 2,100 psi 0.0 0.0 9/19/2024 13:00 9/19/2024 15:00 2.00 COMPZN, RPCOMP RURD P RD testing equipment, blow down test pump, RD pressure lines. 0.0 0.0 9/19/2024 15:00 9/19/2024 17:30 2.50 COMPZN, RPCOMP BHAH T MU Cleanout BHA #53 @ 16:15 had a figer incident w/ pipe elevators on the rig floor All proper notifications were made. Secured Well 0.0 52.8 9/19/2024 17:30 9/19/2024 17:30 COMPZN, RPCOMP SFTY T Held stand down w/crew and safety team 52.8 52.8 9/19/2024 17:30 9/19/2024 19:00 1.50 COMPZN, RPCOMP BHAH P Continue M/U #53 RR 52.8 277.3 9/19/2024 19:00 9/19/2024 20:00 1.00 COMPZN, RPCOMP TRIP P RIH T/ 1632' PUW/SOW=65k 277.3 1,632.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 16/40 1D-05 Report Printed: 11/11/2024 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) 9/19/2024 20:00 9/19/2024 22:00 2.00 COMPZN, RPCOMP WASH P Wash Down F/ 1632' T/ 1694' @ 120 sk min w/ 3400 psi Tq 1200 RPM 30 WOB 1-2 K Pump a sweep around 1,632.0 1,694.0 9/19/2024 22:00 9/19/2024 23:00 1.00 COMPZN, RPCOMP TRIP P POOH F/1694' T/BHA 1,694.0 277.3 9/19/2024 23:00 9/20/2024 00:00 1.00 COMPZN, RPCOMP BHAH P Stand back BHA and clean out J.B & RCJB 277.3 277.3 9/20/2024 00:00 9/20/2024 01:00 1.00 COMPZN, RPCOMP BHAH P Contune to LD Clean out J.B & RCJB BHA #54 277.3 0.0 9/20/2024 01:00 9/20/2024 01:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #55 0.0 277.3 9/20/2024 01:30 9/20/2024 02:30 1.00 COMPZN, RPCOMP TRIP P RIH T/ 1635' 277.3 1,635.0 9/20/2024 02:30 9/20/2024 04:00 1.50 COMPZN, RPCOMP WASH P Wash Down F/ 1635' T/ 1703' @ 120 sk min w/ 3600 psi Tq 1100 RPM 30 WOB 1-2 K Pump a sweep around 1,635.0 1,703.0 9/20/2024 04:00 9/20/2024 05:30 1.50 COMPZN, RPCOMP TRIP P POOH 1,703.0 277.3 9/20/2024 05:30 9/20/2024 06:00 0.50 COMPZN, RPCOMP BHAH P Contune to LD, Clean out J.B & RCJB 277.3 0.0 9/20/2024 06:00 9/20/2024 06:30 0.50 COMPZN, RPCOMP BHAH P MU Cleanout BHA #56 0.0 277.3 9/20/2024 06:30 9/20/2024 07:30 1.00 COMPZN, RPCOMP TRIP P TIH T/ 1,640' PUW/SOW=70k 277.3 1,640.0 9/20/2024 07:30 9/20/2024 09:00 1.50 COMPZN, RPCOMP WASH P 1,640', Wash down F/1,640' T/1,709', 6 bpm/2,300 psi ROT=40 rpm, ROTW=69k, TQ off=800, TQ=2-3k, circulate sweep 40 bbls 1,640.0 1,709.0 9/20/2024 09:00 9/20/2024 10:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/1,709' T/BHA 1,709.0 277.3 9/20/2024 10:00 9/20/2024 11:00 1.00 COMPZN, RPCOMP BHAH P LD, BHA #56 Cement and minor metal peices., 277.3 0.0 9/20/2024 11:00 9/20/2024 11:45 0.75 COMPZN, RPCOMP BHAH P MU, BHA #57 0.0 277.3 9/20/2024 11:45 9/20/2024 12:45 1.00 COMPZN, RPCOMP TRIP P TIH, F/surface T/1,680' 277.3 1,680.0 9/20/2024 12:45 9/20/2024 14:15 1.50 COMPZN, RPCOMP WASH P 1,680', Wash down F/1,680' T/1,714', 6 bpm/2,300 psi ROT=40 rpm, ROTW=69k, TQ off=800, TQ=2-3k, circulate sweep 40 bbls 1,680.0 1,714.0 9/20/2024 14:15 9/20/2024 14:45 0.50 COMPZN, RPCOMP TRIP P TOOH, F/1,714' T/BHA 1,714.0 277.3 9/20/2024 14:45 9/20/2024 16:15 1.50 COMPZN, RPCOMP BHAH P LD, BHA #57 Cement and minor metal peices., 277.3 0.0 9/20/2024 16:15 9/20/2024 17:15 1.00 COMPZN, RPCOMP BHAH P M/U BHA # 58 0.0 277.3 9/20/2024 17:15 9/20/2024 18:15 1.00 COMPZN, RPCOMP TRIP P RIH T/ 1700' 277.3 1,714.0 9/20/2024 18:15 9/20/2024 20:15 2.00 COMPZN, RPCOMP WASH P Wash down F/1714' T/1718', 6 bpm/2,300 psi ROT=40 rpm, ROTW=69k, TQ off=800, TQ=2-3k, circulate sweep 40 bbls 1,714.0 1,718.0 9/20/2024 20:15 9/20/2024 20:45 0.50 COMPZN, RPCOMP TRIP P POOH 1,718.0 277.3 9/20/2024 20:45 9/20/2024 22:15 1.50 COMPZN, RPCOMP BHAH P L/D and Clean out BHA # 58 L/D chunks of cement 4 to5" inches long. 277.3 0.0 9/20/2024 22:15 9/20/2024 22:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #59 0.0 277.0 9/20/2024 22:45 9/20/2024 23:30 0.75 COMPZN, RPCOMP TRIP P RIH t/ 1700' and Service Rig 277.3 1,695.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 17/40 1D-05 Report Printed: 11/11/2024 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) 9/20/2024 23:30 9/21/2024 00:00 0.50 COMPZN, RPCOMP WASH P Wash down F/1714' T/1718', 6 bpm/2,300 psi ROT=40 rpm, ROTW=69k, TQ off=800, TQ=2-3k, circulate sweep 40 bbls 1,695.0 1,700.0 9/21/2024 00:00 9/21/2024 00:30 0.50 COMPZN, RPCOMP TRIP P POOH /w BHA #59 1,728.0 277.3 9/21/2024 00:30 9/21/2024 02:30 2.00 COMPZN, RPCOMP BHAH P Contune to LD, Clean out BHA # 59 J.B & RCJB 277.3 0.0 9/21/2024 02:30 9/21/2024 03:30 1.00 COMPZN, RPCOMP BHAH P M/U cleanout assembly 0.0 277.3 9/21/2024 03:30 9/21/2024 04:30 1.00 COMPZN, RPCOMP TRIP P TIH, BHA #60 277.3 1,695.0 9/21/2024 04:30 9/21/2024 06:00 1.50 COMPZN, RPCOMP WASH P Wash down F/1,695'' T/ 1,736', 6 bpm/2,300 / 3200 psi ROT=40 rpm, ROTW=69k, TQ off=850, TQ=1-2k, circulate sweep 40 bbls, blow down top drive 1,695.0 1,736.0 9/21/2024 06:00 9/21/2024 07:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/BHA #60 1,736.0 277.0 9/21/2024 07:00 9/21/2024 07:30 0.50 COMPZN, RPCOMP BHAH P LD BHA, Cement in baskets small chunks of metal bands. 277.0 0.0 9/21/2024 07:30 9/21/2024 08:00 0.50 COMPZN, RPCOMP BHAH P M/U cleanout assembly w/8.125" cut lip guide shoe 0.0 277.3 9/21/2024 08:00 9/21/2024 09:30 1.50 COMPZN, RPCOMP TRIP P TIH, with BHA #61 277.3 1,681.0 9/21/2024 09:30 9/21/2024 10:30 1.00 COMPZN, RPCOMP WASH P Wash down F/1,681'' T/ 1,743.7', 6 bpm/2,300 / 3700 psi ROT=40 rpm, ROTW=69k, TQ off=1,080, TQ=1-2k, circulate sweep 40 bbls, blow down top drive 1,681.0 1,743.7 9/21/2024 10:30 9/21/2024 11:30 1.00 COMPZN, RPCOMP TRIP P TOOH, w/BHA #61 PUW=68, SOW=65k 1,743.7 277.3 9/21/2024 11:30 9/21/2024 12:30 1.00 COMPZN, RPCOMP BHAH P LD, BHA #61, Cement in baskets with large chucks cement and small striips x 4 bow springs. 277.3 0.0 9/21/2024 12:30 9/21/2024 13:00 0.50 COMPZN, RPCOMP BHAH P MU Cleanout BHA 0.0 277.3 9/21/2024 13:00 9/21/2024 14:00 1.00 COMPZN, RPCOMP TRIP P TIH, with cleanout BHA #62 277.3 1,700.0 9/21/2024 14:00 9/21/2024 17:30 3.50 COMPZN, RPCOMP WASH P Wash down F/1,700'' T/ 1,750', 6 bpm/2,300 / 3700 psi ROT=40 rpm, ROTW=69k, TQ off=1,080, TQ=1-2-3-5k, circulate sweep 40 bbls, blow down top drive 1,700.0 1,750.0 9/21/2024 17:30 9/21/2024 19:00 1.50 COMPZN, RPCOMP TRIP P POOH 1,750.0 277.3 9/21/2024 19:00 9/21/2024 21:00 2.00 COMPZN, RPCOMP BHAH P LD, BHA #62, Cement in baskets with large chucks cement and small striips x 3 bow springs. M/U BHA # 63 277.3 0.0 9/21/2024 21:00 9/21/2024 21:30 0.50 COMPZN, RPCOMP BHAH P M/U cleanout assembly w/8.125" cut lip guide shoe 0.0 277.3 9/21/2024 21:30 9/21/2024 23:00 1.50 COMPZN, RPCOMP TRIP P RIH / Rig Service@ 277' Contune RIH 277.3 1,740.0 9/21/2024 23:00 9/22/2024 00:00 1.00 COMPZN, RPCOMP WASH P Wash down F/1,750'' T/ 1751', 6 bpm/2,300 / 3700 psi ROT=40 rpm, ROTW=69k, TQ off=1,080, TQ (1100-3800 Stalled out) , circulate sweep 40 bbls, blow down top drive 1,740.0 1,751.0 9/22/2024 00:00 9/22/2024 01:30 1.50 COMPZN, RPCOMP TRIP P POOH 1,751.0 277.3 9/22/2024 01:30 9/22/2024 03:00 1.50 COMPZN, RPCOMP BHAH P LD, BHA #63, Cement in baskets with large chucks cement and small striips. 277.3 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 18/40 1D-05 Report Printed: 11/11/2024 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) 9/22/2024 03:00 9/22/2024 03:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA # 64 0.0 277.3 9/22/2024 03:45 9/22/2024 04:45 1.00 COMPZN, RPCOMP TRIP P RIH 277.3 1,700.0 9/22/2024 04:45 9/22/2024 06:15 1.50 COMPZN, RPCOMP SLPC P Cut and Slip Drilling line @1700' 1,700.0 1,700.0 9/22/2024 06:15 9/22/2024 06:45 0.50 COMPZN, RPCOMP TRIP P Continue RIH T/ 1750' 1,700.0 1,749.0 9/22/2024 06:45 9/22/2024 08:45 2.00 COMPZN, RPCOMP WASH P Wash down F/1,749'' T/ 1751', 3 bpm / 3700 psi ROT=45 rpm, ROTW=70k, TQ off=1,080, TQ (1100-3800k) Continue rotating ahead , circulate sweep 40 bbls, blow down top drive 1,749.0 1,753.7 9/22/2024 08:45 9/22/2024 09:45 1.00 COMPZN, RPCOMP TRIP P TOOH, w/BHA #64 1,753.7 277.3 9/22/2024 09:45 9/22/2024 11:15 1.50 COMPZN, RPCOMP BHAH P LD/Inspect BHA, large cement chunks, 1.15' 7" casing inside cut lip guide. cut lip is cracked and bent. 277.3 0.0 9/22/2024 11:15 9/22/2024 12:30 1.25 COMPZN, RPCOMP OTHR P Load out cut lip guide to shop, cut new cut liip. 0.0 0.0 9/22/2024 12:30 9/22/2024 13:00 0.50 COMPZN, RPCOMP SVRG P Service Rig Found broken weld on top drive foot post jarring operations. 0.0 0.0 9/22/2024 13:00 9/22/2024 17:30 4.50 COMPZN, RPCOMP SVRG T Swap out top drive foot 0.0 0.0 9/22/2024 17:30 9/22/2024 18:45 1.25 COMPZN, RPCOMP BHAH P M/U BHA # 65 0.0 277.3 9/22/2024 18:45 9/22/2024 20:00 1.25 COMPZN, RPCOMP TRIP P RIH T/ 1750" 277.3 1,750.0 9/22/2024 20:00 9/22/2024 22:00 2.00 COMPZN, RPCOMP WASH P Start Washing F/ 1750' W/ RCJB T/ 1756' 1,750.0 1,756.0 9/22/2024 22:00 9/22/2024 23:00 1.00 COMPZN, RPCOMP TRIP P POOH 1,756.0 277.3 9/22/2024 23:00 9/23/2024 00:00 1.00 COMPZN, RPCOMP BHAH P LD, BHA #65, Cement in baskets with large chunks cement and redress cutlip guide,M/U BHA # 66 277.3 0.0 9/23/2024 00:00 9/23/2024 01:00 1.00 COMPZN, RPCOMP BHAH P ContinueW/ M/U BHA # 66 0.0 277.0 9/23/2024 01:00 9/23/2024 01:30 0.50 COMPZN, RPCOMP SVRG P RIH,Service Top Drive @ 400' 277.3 400.0 9/23/2024 01:30 9/23/2024 02:30 1.00 COMPZN, RPCOMP TRIP P Continue RIH 400.0 1,745.0 9/23/2024 02:30 9/23/2024 04:00 1.50 COMPZN, RPCOMP WASH P Wash down F/1,745'' T/ 1752', 3 bpm / 3700 psi ROT=45 rpm, ROTW=70k, TQ off=1,080, TQ (1100-3200k) Continue rotating ahead Slow No GO @ 1752' 1,745.0 1,756.0 9/23/2024 04:00 9/23/2024 05:00 1.00 COMPZN, RPCOMP TRIP P POOH 1,756.0 277.3 9/23/2024 05:00 9/23/2024 06:45 1.75 COMPZN, RPCOMP BHAH P L/D BHA # 66, Load out to pipe shed 277.3 0.0 9/23/2024 06:45 9/23/2024 08:30 1.75 COMPZN, RPCOMP BHAH P MU cleanout BHA w/5-3/4" cut lip guide shoe. 0.0 275.8 9/23/2024 08:30 9/23/2024 09:30 1.00 COMPZN, RPCOMP TRIP P TIH w/BHA #67 275.8 1,756.0 9/23/2024 09:30 9/23/2024 12:30 3.00 COMPZN, RPCOMP WASH P Wash down F/1,756'' T/ 1,820', 3 bpm / 3700 psi ROT=45 rpm, ROTW=70k, TQ off=1,080, TQ (1100-3200k) Continue rotating ahead Slow No GO @ 1752' 1,756.0 1,820.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 19/40 1D-05 Report Printed: 11/11/2024 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) 9/23/2024 12:30 9/23/2024 13:30 1.00 COMPZN, RPCOMP CIRC P Circulate SXS with sweep 1,820.0 1,820.0 9/23/2024 13:30 9/23/2024 15:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/5-3/4" Cleanout assembly BHA #67 1,820.0 9/23/2024 15:00 9/23/2024 20:00 5.00 COMPZN, RPCOMP BHAH P Discuss/ town engineers about what type of shoe that we should run. Baker build the tape of shoe w/ no cutters in side 9/23/2024 20:00 9/23/2024 21:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA # 68 9/23/2024 21:00 9/23/2024 22:00 1.00 COMPZN, RPCOMP TRIP P RIH 9/23/2024 22:00 9/24/2024 00:00 2.00 COMPZN, RPCOMP MILL P Tag up @ 1756' Start Washing and milling top of 7"stub F/ 1755' T 1756' 1,756.0 9/24/2024 00:00 9/24/2024 04:30 4.50 COMPZN, RPCOMP MILL P Continue Washing and milling top of 7"stub F/ 1756' T 1760.17'' WOB 2-5 RPM w/40 pump 155 PSI w/4 bbls min 1,756.0 1,760.2 9/24/2024 04:30 9/24/2024 05:00 0.50 COMPZN, RPCOMP OWFF P OWFF: Static. Blow down top drive. 1,760.2 1,760.0 9/24/2024 05:00 9/24/2024 05:30 0.50 COMPZN, RPCOMP SVRG P Rig service. Service, travelling blocks, crown, and top drive. 1,760.0 1,760.0 9/24/2024 05:30 9/24/2024 06:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1760' to 64'. 1,760.0 64.2 9/24/2024 06:00 9/24/2024 07:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA # 68. Inspect dress off mills. Little to no wear on mills. 64.2 0.0 9/24/2024 07:30 9/24/2024 08:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 9/24/2024 08:00 9/24/2024 09:30 1.50 COMPZN, RPCOMP BHAH P P/U and M/U BHA # 69. 5.75" RCJB, boot baskets, 6 1/8" string mill. 0.0 272.0 9/24/2024 09:30 9/24/2024 10:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 272' to 1754'. 272.0 1,754.0 9/24/2024 10:30 9/24/2024 12:00 1.50 COMPZN, RPCOMP REAM P Attempt to wash and ream down into top of 7" @ 1756'. Unable to enter 7". Observed TQ stall multiple times. 1,754.0 1,756.0 9/24/2024 12:00 9/24/2024 12:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1756' to 272' 1,756.0 272.0 9/24/2024 12:30 9/24/2024 13:30 1.00 COMPZN, RPCOMP BHAH P Rack back drill collars, and rack back 4.75" DC. B/O and L/D RCJB. M/U mule shoe to bottom of 6.125" string mill. RIH W/ DC. 272.0 264.0 9/24/2024 13:30 9/24/2024 14:00 0.50 COMPZN, RPCOMP TRIP P RIH F/ 264' to 1700' 0.0 1,700.0 9/24/2024 14:00 9/24/2024 14:30 0.50 COMPZN, RPCOMP REAM P Slack off and set down weight @ 1760'. Pick up, and orient string, slack off again and set down 5K @ 1760'. P/U and start pumping @ 172 GPM @ 200 PSI. Start rotary @ 60 RPM @ 800 Ft/lbs free torque. Ream down. Torque increase to 950 Ft/lbs to 1050 ft/lbs @ 1760' Ream down to 1765'. Observe torque drop off to 780 ft/lbs. Ream back up to 1759'. Stop rotary, and shut off pumps. Drift f/ 1758' to 1765'. Clean pass. 1,700.0 1,765.0 9/24/2024 14:30 9/24/2024 15:00 0.50 COMPZN, RPCOMP TRIP P Cont. to RIH F/ 1765 to 1853'. Tag sand @ 1853' Set down 5K to confirm tag. 1,765.0 1,853.0 9/24/2024 15:00 9/24/2024 15:30 0.50 COMPZN, RPCOMP OWFF P OWFF: Static. Blow down top drive. 1,853.0 1,853.0 9/24/2024 15:30 9/24/2024 16:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1853' to 264' 1,853.0 264.0 9/24/2024 16:30 9/24/2024 17:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #70 Mule shoe drift run. Clear and clean rig floor. 264.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 20/40 1D-05 Report Printed: 11/11/2024 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) 9/24/2024 17:30 9/24/2024 18:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA #71 7" dress off 0.0 64.2 9/24/2024 18:30 9/24/2024 20:00 1.50 COMPZN, RPCOMP TRIP P RIH 64' to 1671', KU, Obtain parameters PUW=55K, SOW=55K, 3 BPM =100 PSI. 20 RPM @ 515 Ft/Lbs 64.2 1,671.0 9/24/2024 20:00 9/24/2024 20:12 0.20 COMPZN, RPCOMP MILL P Shut down pump and rotary, Dry tag 7" stub @ 1758. Ratty getting on top of stub 1,671.0 1,758.0 9/24/2024 20:12 9/24/2024 21:42 1.50 COMPZN, RPCOMP MILL P PUH to 1740, Bring pump and rotary online, Start milling from 1758.4 to 1760.5 1,758.0 1,760.5 9/24/2024 21:42 9/24/2024 22:12 0.50 COMPZN, RPCOMP CIRC P Pump 25 BBl sweep while recip 20' interval. Still ratty. Got sand back in first sweep. Pump second 25 BBl sweep @ 5 BPM. Dry tag @ 1760.7 1,760.5 1,760.0 9/24/2024 22:12 9/24/2024 23:30 1.30 COMPZN, RPCOMP TRIP P Trip out of well, PUW=55K 1,760.0 64.0 9/24/2024 23:30 9/25/2024 00:00 0.50 COMPZN, RPCOMP BHAH P Breal down BHA #71 7" dress off mill 64.0 0.0 9/25/2024 00:00 9/25/2024 01:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #72, 6.125" drift 0.0 264.0 9/25/2024 01:00 9/25/2024 02:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole 264.0 1,690.0 9/25/2024 02:00 9/25/2024 03:00 1.00 COMPZN, RPCOMP REAM P Kelley up. Continue in well. Set down @ 1756'. PUH. Index 180°. slide through clean to 1765'. Bring rotary online 50 RPM. Ream 1756' area keeping muleshoe in 7". No torque build up. Make 3 cycles. PUH to 1750. Index to original mark. RBIH. Set down 1756. PUH index 180° pass right through. Continue in to top of sand @ 1853 1,690.0 1,853.0 9/25/2024 03:00 9/25/2024 04:00 1.00 COMPZN, RPCOMP TRIP P Trip out of hole, PUW=60K 1,853.0 264.0 9/25/2024 04:00 9/25/2024 05:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #72 264.0 0.0 9/25/2024 05:00 9/25/2024 05:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #73 Test packer and G plug 0.0 68.3 9/25/2024 05:30 9/25/2024 07:30 2.00 COMPZN, RPCOMP TRIP P RIH F/ 63' to 1830'. 68.3 1,830.0 9/25/2024 07:30 9/25/2024 07:45 0.25 COMPZN, RPCOMP MPSP P Set RBP per Baker rep. 1,830.0 1,830.0 9/25/2024 07:45 9/25/2024 08:00 0.25 COMPZN, RPCOMP MPSP P POOH F/ 1830 to 1777'. Set test packer per Baker rep. Rig up to test G-Plug. 1,830.0 1,794.0 9/25/2024 08:00 9/25/2024 08:30 0.50 COMPZN, RPCOMP MPSP P Attempt to pressure test G-Plug. Unable to get good test. 1,794.0 1,794.0 9/25/2024 08:30 9/25/2024 09:00 0.50 COMPZN, RPCOMP MPSP P Release test packer. Go down, and J onto G-Plug, and set down 30K to verify isolation sleeve is closed. Pick back up and set test packer COE 1794' 1,794.0 1,794.0 9/25/2024 09:00 9/25/2024 10:30 1.50 COMPZN, RPCOMP MPSP P Pressure test G-Plug to 3500 PSI for 15 min: GOOD. 1,794.0 1,794.0 9/25/2024 10:30 9/25/2024 14:30 4.00 COMPZN, RPCOMP MPSP P Unset and relax test packer. Dump 35' (12 sacks) of sand on top of G-Plug. Allow sand to fall for 30 min. 1,794.0 1,794.0 9/25/2024 14:30 9/25/2024 15:00 0.50 COMPZN, RPCOMP MPSP P RIH and tag top of sand @ 1804'. 1,794.0 1,804.0 9/25/2024 15:00 9/25/2024 16:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1804' to 59'. 1,804.0 59.0 9/25/2024 16:00 9/25/2024 16:30 0.50 COMPZN, RPCOMP BHAH P L/D G-plug running tool, and test packer (BHA # 73). 59.0 0.0 9/25/2024 16:30 9/25/2024 18:00 1.50 COMPZN, RPCOMP BHAH P L/D 6 1/8" DC from the derrick. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 21/40 1D-05 Report Printed: 11/11/2024 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) 9/25/2024 18:00 9/25/2024 20:00 2.00 COMPZN, RPCOMP BHAH P R/U GBR, and change handling equipment on rig floor to run 7". Verify pipe count and completion jewelry. Pull wear ring Measure elevators 0.0 0.0 9/25/2024 20:00 9/25/2024 20:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/GBR, BOT , and HES to pick up 7" casing patch, HES ES cement valve, and 7" completion 0.0 0.0 9/25/2024 20:30 9/26/2024 00:00 3.50 COMPZN, RPCOMP PUTB P M/U 7" Hyd 563 tie back, Cementralizers every other joint. 1685' PUW=68K, RIW=65K, P/U joint #42. RIH see go over stub @ 1760. PUH no latch. Add XO. reset elevators. Set down 8K @ 1762.8. Pull up 15K over, latched up 0.0 1,762.8 9/26/2024 00:00 9/26/2024 00:30 0.50 COMPZN, RPCOMP RURD P Rig up PT equipment to test 7" tie back 1,762.8 1,762.8 9/26/2024 00:30 9/26/2024 01:30 1.00 COMPZN, RPCOMP PRTS P Fluid pack surface lines. IA open to atmosphere. Unable to get more then 55 PSI SPP. Shut in at head pin. Pressure up on SPP. We are moving fluid. Getting fluid out IA as stack filling up. Set down 15K on casing patch. Attempt test. Fluid out IA at pump rate. Never able to generate more then 50 PSI SPP pumping down 7" 1,762.8 1,762.8 9/26/2024 01:30 9/26/2024 02:00 0.50 COMPZN, RPCOMP CIRC P Consult on call engineer. Attempt higher flow rate to energies packing. 4 BPM @ 120 PSI. No good. Full returns 1,762.8 1,762.8 9/26/2024 02:00 9/26/2024 02:30 0.50 COMPZN, RPCOMP RURD P R/D PT equipment. Prep to recover 7" casing patch 1,762.8 1,762.8 9/26/2024 02:30 9/26/2024 03:00 0.50 COMPZN, RPCOMP PUTB P Release CSG patch from Stump 1,762.8 1,762.0 9/26/2024 03:00 9/26/2024 07:00 4.00 COMPZN, RPCOMP PUTB P POOH L/D 7" CSG. 1,762.0 0.0 9/26/2024 07:00 9/26/2024 07:30 0.50 COMPZN, RPCOMP BHAH P Break shoe off of casing patch. Inspect seals, light scaring on the seals. Pick up ES cementer, and inspect. Put thread protector on the bottom and fill ES cementer with water to verify ES cementer not leaking. 0.0 0.0 9/26/2024 07:30 9/26/2024 08:30 1.00 COMPZN, RPCOMP RURD P R/D GBR equipment. Clean and clear rig floor. 0.0 0.0 9/26/2024 08:30 9/26/2024 09:00 0.50 COMPZN, RPCOMP OTHR P Install wear bushing. 0.0 0.0 9/26/2024 09:00 9/26/2024 09:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 75. (Casing cutter). 0.0 45.0 9/26/2024 09:30 9/26/2024 10:00 0.50 COMPZN, RPCOMP TRIP P RIH W/ BHA #75 F/ 45' to 1747'. PUWT 65K SOWT 65K 45.0 1,747.0 9/26/2024 10:00 9/26/2024 11:00 1.00 COMPZN, RPCOMP CPBO P Bring pumps up to 160 GPM @ 600 PSI. Slack off and locate collar on the bottom of previously cut joint @ 1789.49.49'. P/U 20' to 1768.49'. Increase flow rate to 240 GPM @ 1300 PSI. Start rotary @ 90 RPM @ 1300 FT/LBS TQ. Observe pressure drop to 600 PSI, and TQ decrease to 100 Ft/lbs. 1,747.0 1,769.5 9/26/2024 11:00 9/26/2024 11:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1769.49' to 45'. 1,769.5 45.0 9/26/2024 11:30 9/26/2024 12:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 45. Inspect knives on cutter. Indications of ware observed. 45.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 22/40 1D-05 Report Printed: 11/11/2024 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) 9/26/2024 12:00 9/26/2024 12:30 0.50 COMPZN, RPCOMP SVRG P Rig service/ top drive inspection. 0.0 0.0 9/26/2024 12:30 9/26/2024 15:00 2.50 COMPZN, RPCOMP BHAH P P/U BHA # 76. Spear, 6 1/4" Jars, bumper sub, accelerator, and 6 1/4" DC. 0.0 226.0 9/26/2024 15:00 9/26/2024 15:15 0.25 COMPZN, RPCOMP OTHR P Function test BOP. 226.0 226.0 9/26/2024 15:15 9/26/2024 15:45 0.50 COMPZN, RPCOMP TRIP P RIH F/ 226' to 1750' PUWT 70K SOWT 65 K 226.0 1,750.0 9/26/2024 15:45 9/26/2024 16:00 0.25 COMPZN, RPCOMP FISH P S/O and no go out on top of 7" Fish @ 1766.14' (top of fish @ 1757.46'). Set down 30K. P/U 5'. No observerable increase in drag or overpull. Set back down Rotate string to the left @ 7 RPM @ 1200 RPM to verify grapple in the catch position. Stop rotary. Set down 30K. P/U 1-2K initial drag observed. 1,750.0 1,766.1 9/26/2024 16:00 9/26/2024 17:30 1.50 COMPZN, RPCOMP TRIP P POOH racking back drill pipe F/ 1766.14' to 226'. 1,766.1 226.0 9/26/2024 17:30 9/26/2024 21:00 3.50 COMPZN, RPCOMP BHAH P L/D BHA.. Recovered 12.88' of 7". Appears string mills ran down between 7" and 10 3/4 annulas. 3.9' of external milling on 7" Work fish out of overshot 226.0 0.0 9/26/2024 21:00 9/26/2024 22:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #77 dress off assembly 0.0 227.0 9/26/2024 22:00 9/26/2024 23:30 1.50 COMPZN, RPCOMP TRIP P Trip in hole to 1755 227.0 1,755.0 9/26/2024 23:30 9/27/2024 00:00 0.50 COMPZN, RPCOMP CIRC P KU on stand 19 1,755.0 1,755.0 9/27/2024 00:00 9/27/2024 01:18 1.30 COMPZN, RPCOMP MILL P PUW=53K, SOW=53K, 3 BPM @ 105PSI. 40 RPM @ 800 Ft/Lbs FT. Shut down rotary. Ease in hole to initial set down @ 1768' on top of stump with no pressure increase. PUH. go to 10 RPM. Walk cutlip guide over top of stump down to 1774.5 with torque up and PSI increase to 140 PSI. PUH to 1772', Rotary @ 40 RPM. ease to stump @1775'. Mill down to 1776.5 Pump 25 BBL Hi Vis sweep. 1,755.0 1,776.5 9/27/2024 01:18 9/27/2024 01:30 0.20 COMPZN, RPCOMP MILL P Come off stump up to 1766'. Shut down rotary, RIH to setdown @ 1770. . PUH to 1766 rotate 10 RPM go clean over top of stump down to 1776.5 1,776.5 1,776.5 9/27/2024 01:30 9/27/2024 02:00 0.50 COMPZN, RPCOMP CIRC P Circulate sweep to surface 1,776.5 1,752.0 9/27/2024 02:00 9/27/2024 02:30 0.50 COMPZN, RPCOMP TRIP P Blow down top drive. Trip out for overshot with type A packoff 1,752.0 227.0 9/27/2024 02:30 9/27/2024 04:00 1.50 COMPZN, RPCOMP BHAH P Break down BHA #77 227.0 0.0 9/27/2024 04:00 9/27/2024 04:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #78 Overshot with type A packoff 0.0 28.0 9/27/2024 04:30 9/27/2024 05:00 0.50 COMPZN, RPCOMP TRIP P RIH BHA #78 Sealing overshot to PT 7" 28.0 1,770.2 9/27/2024 05:00 9/27/2024 05:30 0.50 COMPZN, RPCOMP FISH P Engage top of 7" stump w/ over shot. 1,770.2 1,773.0 9/27/2024 05:30 9/27/2024 06:15 0.75 COMPZN, RPCOMP PRTS P Rig up and pressure test 7" to 500 PSI. Increase pressure to 1300 PSI, pressure dropped to 1000 PSI. Release over shot. 1,773.0 1,773.0 9/27/2024 06:15 9/27/2024 07:00 0.75 COMPZN, RPCOMP TRIP P POOH w/ BHA # 78. 1,773.0 28.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 23/40 1D-05 Report Printed: 11/11/2024 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) 9/27/2024 07:00 9/27/2024 08:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 78. Observed damage on seals. 28.0 0.0 9/27/2024 08:00 9/27/2024 08:30 0.50 COMPZN, RPCOMP OTHR P Pull wear bushing. 0.0 0.0 9/27/2024 08:30 9/27/2024 10:00 1.50 COMPZN, RPCOMP RURD P R/U GBR, and prepare rig floor to run 7". 0.0 0.0 9/27/2024 10:00 9/27/2024 13:30 3.50 COMPZN, RPCOMP PUTB P P/U and RIH w/ 7" 26# L-80 tie back string. RIH F/ Surface to 1750 0.0 1,750.0 9/27/2024 13:30 9/27/2024 14:00 0.50 COMPZN, RPCOMP PUTB P Latch Casing patch on to stump. S/O to 1773'. Set down 25K. P/U and overpull 20K. 1,750.0 1,773.0 9/27/2024 14:00 9/27/2024 14:30 0.50 COMPZN, RPCOMP PRTS P R/U and pressure test 7" Casing. Pressure up to 500 PSI and hold 5 min. Increase pressure to 1000 For 5 min. Increase pressure to 2500 PSI, and hold for 10 min: GOOD. Attempt to increase pressure slowly to 3000 PSI. ES cementer opened @ 2800 PSI. 1,773.0 1,773.0 9/27/2024 14:30 9/27/2024 15:00 0.50 COMPZN, RPCOMP CIRC P CBU @ 4 BBL/ Min. @ 135 PSI. 1,773.0 1,773.0 9/27/2024 15:00 9/27/2024 15:30 0.50 COMPZN, RPCOMP PRTS P Pressure test Halliburton equipment. 1,773.0 1,773.0 9/27/2024 15:30 9/27/2024 17:00 1.50 COMPZN, RPCOMP CMNT P Rig up and pump 10 BBLS spacer with red die 130 BBLS 15.3 PPG Class G cement Chase wtih 10 BBLS of water. Chase with rig pumps @ 4 BBL/min. ICP 130 PSI. FCP 425 PSI. Slow down for final 10 BBLS to 2 BBL/min. Bumped plug @ 54.6 BBLS (56 BBLS calculated). Increase pressure to 1750 PIS, Observe ES cementer shift closed. Hold pressure for 10 min. Bleed pressure and check for flow @ flow line: No flow. Cement in place @ 1645 hours. 1,773.0 1,773.0 9/27/2024 17:00 9/27/2024 18:00 1.00 COMPZN, RPCOMP RURD P Flush rig and surface lines with contam pill. R/D cement head, R/D HES cementers. Blow down rig and lines to tank. 1,773.0 1,773.0 9/27/2024 18:00 9/28/2024 00:00 6.00 COMPZN, RPCOMP WOC P Suck out BOP stack and 7" joint, Clean pits. Load and process 3 1/2" completion 1,773.0 1,773.0 9/28/2024 00:00 9/28/2024 05:00 5.00 COMPZN, RPCOMP WOC P Wait on Cement to reach 100 PSI compressive strength. Continue to load and process 3 1/2" completion. Service equipment through out the rig. 0.0 0.0 9/28/2024 05:00 9/28/2024 06:00 1.00 COMPZN, RPCOMP NUND P PJSM, Rig up to lift stack. Split stack, and raise off of Casing spool. 0.0 0.0 9/28/2024 06:00 9/28/2024 07:00 1.00 COMPZN, RPCOMP NUND P Pull 50 K tension. Cameron Rep set slips, and cut 7". 0.0 0.0 9/28/2024 07:00 9/28/2024 11:30 4.50 COMPZN, RPCOMP NUND P Cameron rep dress top of 7". Install pack off. N/U tubing spool. Inject packing into well head. Test pack off to 3000 PSI: GOOD. 0.0 0.0 9/28/2024 11:30 9/28/2024 12:00 0.50 COMPZN, RPCOMP NUND P N/U BOP. 0.0 0.0 9/28/2024 12:00 9/28/2024 12:30 0.50 COMPZN, RPCOMP SEQP P Install test plug and test breaks to 250, 3000 PSI high: GOOD test. 0.0 0.0 9/28/2024 12:30 9/28/2024 13:00 0.50 COMPZN, RPCOMP OTHR P Pull test plug. Set wear ring. 0.0 0.0 9/28/2024 13:00 9/28/2024 14:30 1.50 COMPZN, RPCOMP ELNE P PJSM. R/U SLB E-line. 0.0 0.0 9/28/2024 14:30 9/28/2024 15:30 1.00 COMPZN, RPCOMP ELOG P RIH F/ Surface to 1687' w/ CBL. Tag at 1767'. 0.0 1,687.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 24/40 1D-05 Report Printed: 11/11/2024 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) 9/28/2024 15:30 9/28/2024 16:00 0.50 COMPZN, RPCOMP ELOG P POOH Logging up F/ 1687' to surface w/ CBL. Top of cement is @ 600'. Offline: R/U to pressure test OA. 1,687.0 0.0 9/28/2024 16:00 9/28/2024 16:45 0.75 COMPZN, RPCOMP ELNE P R/D SLB E-Line. 0.0 0.0 9/28/2024 16:45 9/28/2024 18:00 1.25 COMPZN, RPCOMP PRTS P Pressure test OA to 1800 PSI. 0.0 0.0 9/28/2024 18:00 9/28/2024 20:00 2.00 COMPZN, RPCOMP PRTS P Rig up to retest OA. Min 1800 PSI 30 Min charted. Pumped up 3 times to get air compressed 0.0 0.0 9/28/2024 20:00 9/28/2024 20:30 0.50 COMPZN, RPCOMP RURD P R/D test equipment 0.0 0.0 9/28/2024 20:30 9/28/2024 22:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA #80 to mill out cement 0.0 224.0 9/28/2024 22:00 9/28/2024 23:45 1.75 COMPZN, RPCOMP PUTB P Single in hole 224.0 1,643.0 9/28/2024 23:45 9/29/2024 00:00 0.25 COMPZN, RPCOMP MILL P 1643', Obtain paramerters, PUW=60K, SOW=60K, 4 BPM @ 260 PSI, 60 RPM @ 870 Ft/Lbs free torque. S/D pump and top drive. Dry tag @ 1684 1,643.0 1,684.0 9/29/2024 00:00 9/29/2024 06:00 6.00 COMPZN, RPCOMP DRLG P PUH, bring pump online 5 BPM @ 420 psi, 80 RPM @ 920 Ft/Lbs free torque. Mill cement 1684 to ES cement valve wiper dart @ 1718' PUWT: 60K SOWT: 60K ROTWT: 60 K 1-5K WOB 210 GPM @ 400 PSI 80 RPM @ 1050 Ft/Lbs torque. 1,684.0 1,804.0 9/29/2024 06:00 9/29/2024 06:30 0.50 COMPZN, RPCOMP CIRC P Pump 20 BBL High vis sweep. @ 210 GPM @ 400 PSI. Sand and cement debris back to surface. 1,804.0 1,804.0 9/29/2024 06:30 9/29/2024 07:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1718' to 224'. 1,804.0 224.0 9/29/2024 07:00 9/29/2024 07:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 80 F/ 224' to surface. 224.0 0.0 9/29/2024 07:30 9/29/2024 08:30 1.00 COMPZN, RPCOMP PRTS P R/U and pressure test 7" to 1804'. 250 low, 3000 PSI high 10 min: GOOD. Bleed down pressure, blow down/ rig down test equipment. 0.0 0.0 9/29/2024 08:30 9/29/2024 09:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA # 81 (RCJB). 0.0 272.0 9/29/2024 09:30 9/29/2024 11:00 1.50 COMPZN, RPCOMP PULD P RIH picking up singles F/ 272' to 1800'. PUWT: 60K SOWT: 60K 272.0 1,800.0 9/29/2024 11:00 9/29/2024 12:00 1.00 COMPZN, RPCOMP CIRC P Drop ball and wash down F/ surface to 1815'. Pump high vis sweep. 1,800.0 1,815.0 9/29/2024 12:00 9/29/2024 12:30 0.50 COMPZN, RPCOMP OWFF P Blow down top drive. Flow check well10 min: Static. 1,815.0 1,815.0 9/29/2024 12:30 9/29/2024 13:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1815' to 272'. 1,815.0 272.0 9/29/2024 13:00 9/29/2024 14:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA 81 F/ 272' to surface. Clean RCJB. Aluminum, brass flakes, and Casing material found in RCJB. 272.0 0.0 9/29/2024 14:30 9/29/2024 15:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA # 82 (RCJB run #2). 0.0 272.0 9/29/2024 15:00 9/29/2024 15:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 272' to 1650'. PUWT: 60 K SOWT: 60 K 272.0 1,650.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 25/40 1D-05 Report Printed: 11/11/2024 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) 9/29/2024 15:30 9/29/2024 15:30 COMPZN, RPCOMP WASH P Wash down f/ 1650' to 1784' @ 220 GPM @ 563 PSI. Drop ball for RCJB. Increase flow to 250 GPM @ 3000 PSI once ball on seat. 1,750.0 1,784.0 9/29/2024 15:30 9/29/2024 16:30 1.00 COMPZN, RPCOMP WASH P Wash down F/ 1784' to 1824'. Pump 20 BBL high vis sweep. 1,784.0 1,824.0 9/29/2024 16:30 9/29/2024 17:00 0.50 COMPZN, RPCOMP CIRC P Circulate and condition 45 BBl sweep 1,824.0 1,824.0 9/29/2024 17:00 9/29/2024 17:30 0.50 COMPZN, RPCOMP TRIP P Trip out of well 1,824.0 272.9 9/29/2024 17:30 9/29/2024 19:00 1.50 COMPZN, RPCOMP BHAH P Lay down BHA #82, RCJB. Very minimal amout in basket 272.9 0.0 9/29/2024 19:00 9/29/2024 19:30 0.50 COMPZN, RPCOMP SVRG P Service rig, Iron roughneck and draw works 0.0 0.0 9/29/2024 19:30 9/29/2024 20:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #83 G plug retrival tool 0.0 44.4 9/29/2024 20:00 9/29/2024 21:30 1.50 COMPZN, RPCOMP PULD P RIH on singles to 1826 44.4 1,826.0 9/29/2024 21:30 9/29/2024 22:30 1.00 COMPZN, RPCOMP FISH P KU on stand, PUW=59K, SOW=59K, 4 1/2 BPM @ 210PSI. Pump Hi Vis sweep @ 8 BPM 620 PSI, S/D pump Go over G plug. set down 10 K. PUH no latch. RBIH set down -15K. PUH 10K over. Latched up. Rotate right @ 5 RPM. Get G plug unlocked. RBIH from 1820 to 1835 clean. Circ BU @ 4 BPM 1,826.0 1,830.0 9/29/2024 22:30 9/29/2024 23:30 1.00 COMPZN, RPCOMP TRIP P Trip out of hole to BHA 1,830.0 44.0 9/29/2024 23:30 9/30/2024 00:00 0.50 COMPZN, RPCOMP BHAH P At surface. Recover G plug 44.0 0.0 9/30/2024 00:00 9/30/2024 01:30 1.50 COMPZN, RPCOMP BHAH P M/U BHA #84 RCJB 0.0 272.9 9/30/2024 01:30 9/30/2024 04:00 2.50 COMPZN, RPCOMP PULD P Single in hole 272.9 1,787.0 9/30/2024 04:00 9/30/2024 04:30 0.50 COMPZN, RPCOMP OTHR P KU, Bring pumps on 3 BPM @1646 PSI. Ball on seat in RFJB. Shut down pump. Lightly tag top of sand @ 1853, PUH 10', PUW=60, SOW=60. Pumps on line. RPM=10 Recip 1840 to 1853 three cycles at different speed. Extend cycles to 1855 where hard set down was encountered @ 1855. Recip 3 times at different speed. Acting like hard bottom not sand. Could be grapple, Top of IBP??. Unscrew, Blow down top drive 1,787.0 1,855.0 9/30/2024 04:30 9/30/2024 05:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1855' to 272.9' 1,855.0 272.9 9/30/2024 05:30 9/30/2024 06:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 84. Metal shavings, and small debris in RCJB. 272.9 0.0 9/30/2024 06:30 9/30/2024 08:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA # 85. RCJB BHA F/ Surface to 272.9' 0.0 272.9 9/30/2024 08:00 9/30/2024 09:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 272.9' to 1753' PUWT: 60K SOWT: 60K 272.9 1,753.0 9/30/2024 09:00 9/30/2024 09:15 0.25 COMPZN, RPCOMP TRIP P Slack off F/ 1753' to 1855'. Set down 5K. P/U 20'. Observe 10K over pull. S/O and tag again @ 5K. P/U and observe over pull. 1,753.0 1,753.0 9/30/2024 09:15 9/30/2024 09:45 0.50 COMPZN, RPCOMP CIRC P Start circulating @ 420 GPM @ 1600 PSI. Pump around high vis sweep. Very little sand returned to surface. 1,753.0 1,753.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 26/40 1D-05 Report Printed: 11/11/2024 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) 9/30/2024 09:45 9/30/2024 10:45 1.00 COMPZN, RPCOMP CIRC P Shut down pumps. Break connection at floor, and drop ball. Pump ball on seat in RCJB. Circulate and wash down and tag @ 1853'. Pumping 220 GPM @ 1600 PSI. Pump high vis sweep. Little to no sand returned to surface. 1,753.0 1,753.0 9/30/2024 10:45 9/30/2024 11:00 0.25 COMPZN, RPCOMP OTHR P Blow down top drive. 1,753.0 1,753.0 9/30/2024 11:00 9/30/2024 12:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1753 to 272.9. 1,753.0 272.9 9/30/2024 12:00 9/30/2024 13:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA F/ 272.9' to surface. 272.9 0.0 9/30/2024 13:30 9/30/2024 14:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 9/30/2024 14:00 9/30/2024 14:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 86 0.0 20.0 9/30/2024 14:30 9/30/2024 15:00 0.50 COMPZN, RPCOMP SFTY P PJSM discuss potential for trapped gas underneat of IBP. 0.0 0.0 9/30/2024 15:00 9/30/2024 15:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Change out pin on spinner assy of iron roughnec. 0.0 0.0 9/30/2024 15:30 9/30/2024 16:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 86. IBP retrieval tool. 0.0 20.0 9/30/2024 16:00 9/30/2024 16:30 0.50 COMPZN, RPCOMP TRIP P RIH w/ BHA 86 to recover IBP 20.0 1,813.0 9/30/2024 16:30 9/30/2024 17:30 1.00 COMPZN, RPCOMP FISH P KU, PUW=50K, SOW=50K, 2 BPM @ 80 psi, RIH to initial setdown @ 1857. PUH 10 K over. Latched up. Saw tool shear, Pull back into it 5 K. Shut bag. Circ BU X2 1,813.0 1,857.0 9/30/2024 17:30 9/30/2024 18:00 0.50 COMPZN, RPCOMP OWFF P Observe well for flow. 1,857.0 1,850.0 9/30/2024 18:00 9/30/2024 19:00 1.00 COMPZN, RPCOMP TRIP P Work IBP up. Pull 10 K over then break free, PUW=55K 1,850.0 20.0 9/30/2024 19:00 9/30/2024 19:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHA # 86. Recover IBP 20.0 0.0 9/30/2024 19:30 9/30/2024 20:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA #87 spear to recover balance of 3 1/2" completion Grapple 2.7 to 2.832 0.0 232.4 9/30/2024 20:30 9/30/2024 22:00 1.50 COMPZN, RPCOMP TRIP P Trip in hole BHA #87 232.4 1,800.0 9/30/2024 22:00 9/30/2024 22:30 0.50 COMPZN, RPCOMP FISH P KU PUW=60K, SOW=55K, Pump 1.5 BPM @ 1300PSI. RIH see taking weight @ 1861' Get pressure increase @ 1863. Work down to 1868.6. PU with friction bite. Slip off. Set back down. Rotate left. Pick up and slip off. Repeat. Rotate left Getting friction bite 1,800.0 1,868.7 9/30/2024 22:30 9/30/2024 23:30 1.00 COMPZN, RPCOMP TRIP P Unscrew, Blow down top drive. Trip to resize grapple 1,867.0 232.0 9/30/2024 23:30 10/1/2024 00:00 0.50 COMPZN, RPCOMP BHAH P Rack back 2 stands 4 3/4 DC, Jar and bumper sub 232.0 0.0 10/1/2024 00:00 10/1/2024 01:00 1.00 COMPZN, RPCOMP BHAH P P/U BHA #88 resize grapple to 2.372 to 3.692 0.0 233.0 10/1/2024 01:00 10/1/2024 02:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole BHA #88 233.0 1,841.0 10/1/2024 02:00 10/1/2024 03:00 1.00 COMPZN, RPCOMP FISH P KU. PUW=60K, SOW=60K, 1.5 BPM 1170 PS, RIH to initial setdown @ 1168 with 25K down. No latch. Try multiple speeds and pump rates. Rotate left trying to get latch. Try indexing 90°. Some friction bites. One 25K overpull with slip off 1,841.0 1,868.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 27/40 1D-05 Report Printed: 11/11/2024 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) 10/1/2024 03:00 10/1/2024 04:00 1.00 COMPZN, RPCOMP TRIP P Blow down top drive, TOOH, PUW=60K 1,868.0 233.0 10/1/2024 04:00 10/1/2024 04:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 89 233.0 0.0 10/1/2024 04:30 10/1/2024 05:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 90. RIH 0.0 233.0 10/1/2024 05:00 10/1/2024 06:30 1.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #90 F/ 233' to 1841'. PUWT: 60 K SOWT: 60 K 233.0 1,841.0 10/1/2024 06:30 10/1/2024 07:30 1.00 COMPZN, RPCOMP FISH P Attempt to spear fish w/ 2.372" Grapple. Observed 50-100 PSI differential, no over pul. 1,841.0 1,869.0 10/1/2024 07:30 10/1/2024 08:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1869 to 232' 1,869.0 232.0 10/1/2024 08:00 10/1/2024 08:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #90. Change to 2.922" grapple. RIH w/ BHA. 232.0 232.0 10/1/2024 08:30 10/1/2024 09:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 232' to to 1841'. 232.0 1,841.0 10/1/2024 09:30 10/1/2024 10:00 0.50 COMPZN, RPCOMP FISH P Attempt to engauge fish. Observed 50 to 100 PSI differential. "Bobble" on weight indicator appeared to be drag from grapple entering fish. Attempt to engage fish. P/U no over pull. 1,841.0 1,869.0 10/1/2024 10:00 10/1/2024 11:00 1.00 COMPZN, RPCOMP TRIP P Pull out of the hole F/1869' to 233' 1,869.0 233.0 10/1/2024 11:00 10/1/2024 11:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 90. P/U BHA # 91. 233.0 26.0 10/1/2024 11:30 10/1/2024 12:15 0.75 COMPZN, RPCOMP TRIP P RIH w/ fishing magnet BHA. Tag @ 1869'. 26.0 1,869.0 10/1/2024 12:15 10/1/2024 13:00 0.75 COMPZN, RPCOMP TRIP P POOH F/ 1869' to 26'. 1,869.0 26.0 10/1/2024 13:00 10/1/2024 13:30 0.50 COMPZN, RPCOMP BHAH P L/D Magnet BHA. Metal shavings on magnet. No large pieces. 26.0 0.0 10/1/2024 13:30 10/1/2024 14:00 0.50 COMPZN, RPCOMP SFTY P PJSM to rig up slick line. 0.0 0.0 10/1/2024 14:00 10/1/2024 15:00 1.00 COMPZN, RPCOMP SLKL P Rig up HAL slick line. 0.0 0.0 10/1/2024 15:00 10/1/2024 15:15 0.25 COMPZN, RPCOMP SLKL P HAL P/U tools string and RIH w/ LIB F/ surface to 1869' 0.0 1,869.0 10/1/2024 15:15 10/1/2024 15:30 0.25 COMPZN, RPCOMP SLKL P HAL slick line POOH. Little to no markings on LIB. 1,869.0 0.0 10/1/2024 15:30 10/1/2024 16:00 0.50 COMPZN, RPCOMP SLKL P Re Run HAL LIB to 1869'. 0.0 1,869.0 10/1/2024 16:00 10/1/2024 16:30 0.50 COMPZN, RPCOMP SLKL P HAL slick line POOH w/ LIB F/ 1869' to surface. 1,869.0 0.0 10/1/2024 16:30 10/1/2024 17:30 1.00 COMPZN, RPCOMP SLKL P R/D HAL slick line. 0.0 0.0 10/1/2024 17:30 10/1/2024 18:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #92 Over shot grapple 0.0 224.9 10/1/2024 18:30 10/1/2024 19:15 0.75 COMPZN, RPCOMP TRIP P TIH F/224.94' T/ 1868' PUW=60K SOW=55K 224.9 1,868.0 10/1/2024 19:15 10/1/2024 20:00 0.75 COMPZN, RPCOMP FISH P Engage fish PR 3 BPM work weight down up to 30K Engage fish dry Rot=10 RPM Tq=6k Broke back 3 times set dow 20 K at 1869' PU Weight erratic PU weight swings 10K BD top drive and surface lines. 1,868.0 1,869.0 10/1/2024 20:00 10/1/2024 20:45 0.75 COMPZN, RPCOMP TRIP P TOOH F/1869 T/224.94' 1,869.0 224.9 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 28/40 1D-05 Report Printed: 11/11/2024 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) 10/1/2024 20:45 10/1/2024 21:30 0.75 COMPZN, RPCOMP BHAH P LD BHA and inspect for fish. No fish recovered. Fresh scarring inside overshot 3" inside cut lip. 224.9 0.0 10/1/2024 21:30 10/1/2024 22:15 0.75 COMPZN, RPCOMP BHAH P MU BHA #93 RCJB 5" ID. T/217.53' Dress shoe and paint white for tattle tale. 0.0 217.5 10/1/2024 22:15 10/1/2024 23:30 1.25 COMPZN, RPCOMP TRIP P TIH F/217.53' T/1869' 217.5 1,869.0 10/1/2024 23:30 10/2/2024 00:00 0.50 COMPZN, RPCOMP FISH P Wash over top of fish F/1868' Tag, T/1870' W/RCJB 5BPM 2500 PSI Rot 20 RPM Tq swings F/1800-3200 Ft/Lbs. Shut down Rot PUH 10' shut down rotary set down 20K stacked out at 1869' Blow down top drive. 1,869.0 1,869.0 10/2/2024 00:00 10/2/2024 01:30 1.50 COMPZN, RPCOMP TRIP P TOOH F/1869'T/217' 1,869.0 217.0 10/2/2024 01:30 10/2/2024 02:30 1.00 COMPZN, RPCOMP BHAH P LD BHA #93 RCJB Recovered 2 segments of grapple that were lost in hole. 4' of control line and small metal parts. MU BHA #94 RCJB. 217.0 217.0 10/2/2024 02:30 10/2/2024 04:30 2.00 COMPZN, RPCOMP TRIP P TIH F/217' T/1869' PUW 60K SOW 60K 217.0 1,869.0 10/2/2024 04:30 10/2/2024 05:00 0.50 COMPZN, RPCOMP FISH P PR=5BPM 2000 PSI ROT 20 RPM Tag top of fish at 1864' work down to 1869'. Increase PR 7 BPM 3600 PSI. ROT 40 RPM set down 20K unable to pass 1869. 1,869.0 1,869.0 10/2/2024 05:00 10/2/2024 05:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1869' to 217'. 1,869.0 217.0 10/2/2024 05:30 10/2/2024 06:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA. No large pieces or debris in RCJB. Some notable wear on RCJB. 217.0 0.0 10/2/2024 06:00 10/2/2024 07:30 1.50 COMPZN, RPCOMP BHAH P P/U BHA # 92. RCJB w/ magnets, and boot baskets. 0.0 227.0 10/2/2024 07:30 10/2/2024 08:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 227' to 1860' 227.0 1,860.0 10/2/2024 08:30 10/2/2024 11:00 2.50 COMPZN, RPCOMP FISH P Drop ball, and kelly up to string. Wash down F/ 1860' to 1868'. Flow rate @ 250 GPM @ 3000 PSI. Attempt to work past 1868'. P/U and rotate @ 20, 30, 40 RPM 1500 Ft/lbs to 3000 ft lbs. While rotating P/U to 1860' and tag @ 1865'. Continue to work down to 1868'. Pump high vis sweep. 1,860.0 1,868.0 10/2/2024 11:00 10/2/2024 11:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1868' to 227'. 1,868.0 227.0 10/2/2024 11:30 10/2/2024 13:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA 92. Pieces of control line, and thin metal in RCJB. Newer cement, scale, and small metal fragments in boot baskets. Cement had LCM fibers resembling bridgemaker II pumped during 7" tie back cement job. 227.0 0.0 10/2/2024 13:00 10/2/2024 13:30 0.50 COMPZN, RPCOMP PRTS P R/U and pressure test 7" to 1500 PSI 15 min: GOOD TEST. 0.0 0.0 10/2/2024 13:30 10/2/2024 14:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA # 93. RCJB. Change cut lip shoe to crown shoe, no cutting structure on the outside of shoe. 0.0 227.0 10/2/2024 14:30 10/2/2024 14:45 0.25 COMPZN, RPCOMP TRIP P RIH Tag @ 500'. 5-7K bobbles. 227.0 500.0 10/2/2024 14:45 10/2/2024 15:15 0.50 COMPZN, RPCOMP FISH P Drop ball and circ @ 210 GPM @ 2200 PSI. Work down to 700'. Did not see any more bobbles. 500.0 700.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 29/40 1D-05 Report Printed: 11/11/2024 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) 10/2/2024 15:15 10/2/2024 15:30 0.25 COMPZN, RPCOMP TRIP P POOH to check RCJB. 700.0 227.0 10/2/2024 15:30 10/2/2024 16:00 0.50 COMPZN, RPCOMP BHAH P POOH Inspect BHA. Drain stack after collars out of the hole, and watch down hole to check for junk riding on BHA. RIH W/ BHA 227.0 227.0 10/2/2024 16:00 10/2/2024 17:15 1.25 COMPZN, RPCOMP TRIP P RIH F/227' to 1860' PUW=60K SOW= 60K. 227.0 1,860.0 10/2/2024 17:15 10/2/2024 18:30 1.25 COMPZN, RPCOMP FISH P Rot 40 RPM PR=5BPM 2600 PSI TQ- 950 Ft/Lbs. Engage TOF at 1869 work down to 1869.93' 1,860.0 1,869.9 10/2/2024 18:30 10/2/2024 22:00 3.50 COMPZN, RPCOMP TRIP P TOOH pulled 178K weight broke back to 75K. LD single. continued TOOH pulling 8K-10K over constant with 30K weight swings. Performed Derrick inspection. 30 minutes. 1,869.9 251.6 10/2/2024 22:00 10/2/2024 23:30 1.50 COMPZN, RPCOMP BHAH P LD BHA #96 Recovered approx. 4' portion of SSSV flow tube and spring jammed in bottom of crown shoe. 2' of control line, metal shrapnel from 7" and spring portions above fingers in RCJB. MU BHA #97 Box tap and RCJB. 251.6 262.6 10/2/2024 23:30 10/3/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Sercve rig. 0.0 10/3/2024 00:00 10/3/2024 01:00 1.00 COMPZN, RPCOMP TRIP P TIH F/262.59 T/1655' 262.6 1,655.0 10/3/2024 01:00 10/3/2024 03:00 2.00 COMPZN, RPCOMP SLPC P Slip and cut drilling line 1,655.0 1,655.0 10/3/2024 03:00 10/3/2024 03:30 0.50 COMPZN, RPCOMP TRIP P TIH F/1655' T/1833 Tag. PU. PUW=60K SOW=60K 1,655.0 1,833.0 10/3/2024 03:30 10/3/2024 04:00 0.50 COMPZN, RPCOMP FISH P 6 BPM at 3400 PSI, ROT= 20 RPM, Free Tq= 1000 Ft/Lbs Rot Wt=65K, Worked down to 1834' Torque 6500 Ft/Lbs. Set dow 30K. Blow down top drive LD single. 1,833.0 1,834.0 10/3/2024 04:00 10/3/2024 05:30 1.50 COMPZN, RPCOMP TRIP P Start TOOH F/1800' T/262.6 1,834.0 262.6 10/3/2024 05:30 10/3/2024 06:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA. Sections of SSSV spring, Metal fragments, and pieces of control line recovered F/ RCJB and boot baskets. 262.6 0.0 10/3/2024 06:30 10/3/2024 07:00 0.50 COMPZN, RPCOMP OTHR P Pull wear busing, install test plug. R/U test equipment. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 30/40 1D-05 Report Printed: 11/11/2024 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) 10/3/2024 07:00 10/3/2024 12:00 5.00 COMPZN, RPCOMP BOPE P Test BOP's. 1) Blind Rams, CMV 1-2-3-16, 2 Demco Kill, OTSV, UPPER IBOP, 2) Blind Rams, CMV 4-5-6, HCR Kill, ITSV, Saver Sub (TD) Open CMV 2, 2 Demco Kill, UPPER IBOP Remove Blind sub and MU to HT38 Dart / RU test hose, BD TD into rotary TABLE 3) Blind Rams, CMV 7-8-9, Manual Kill, HT-38 DART Open CMV 4-5-6, HCR Kill, Saver Sub (TD) 4) Super & Manual Bean choke (1500 PSI) - Open CMV 7-9 5), CMV 10-11, HT38 TIW Valve (8), Manual Kill Open Super & Manual Bean Choke 6) CMV 12-13-15 (8), Manual Kill Open, CMV 10, 11 7) (3000 psi) Annular, CMV 14, HT-38 TIW Open 8-12-13 8) HCR choke, UPR, HCR Kill Open CMV 14, manual kill 9) UPR, manual choke, HCR Kill 0.0 0.0 10/3/2024 12:00 10/3/2024 12:30 0.50 COMPZN, RPCOMP OTHR P Blow down lines, and R/D Test equipment. Pull test plug, and wear ring. 0.0 0.0 10/3/2024 12:30 10/3/2024 14:30 2.00 COMPZN, RPCOMP BHAH P P/U BHA # 98 RCJB w/ Crown shoe, boot baskets, magnets, and collars. 0.0 250.0 10/3/2024 14:30 10/3/2024 15:15 0.75 COMPZN, RPCOMP TRIP P RIH F/ 250' to 1860' PUWT: 60 K SOWT: 60 K 250.0 1,860.0 10/3/2024 15:15 10/3/2024 16:00 0.75 COMPZN, RPCOMP FISH P P/U single. Drop ball for RCJB. Wash and rotate down F/ 1870' to 1871.89'. 20 RPM @ 1000 Ft/lbs free torqhe, set down 10,20,30 K @ 4 K, 5K, 6K toruqe. Pumping 230 GPM @ 2600 PSI. P/U and cut pumps, and go over stump w/o rotation. tag @ 1865'. P/U start rotary @ 20 RPM rotate over stump and set down 20 K @ 1817.89'. Cut rotary release torque, P/U to 90K (30K overpull). Allow jars to bleed. Continue to P/U to 120K. Weight fell off to 60K. 1,860.0 1,871.9 10/3/2024 16:00 10/3/2024 17:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1871.89' to 250' 1,871.9 250.0 10/3/2024 17:00 10/3/2024 18:30 1.50 COMPZN, RPCOMP BHAH P LD BHA, 98 MU BHA 99 Rope spear. 250.0 297.5 10/3/2024 18:30 10/3/2024 20:15 1.75 COMPZN, RPCOMP TRIP P TIH F/297.48 T/1869' PUW=65K SOW=65K 297.5 1,869.0 10/3/2024 20:15 10/3/2024 20:45 0.50 COMPZN, RPCOMP FISH P Work spear down to 1873.38' set down 12K slight weight gains fell off when PUH, Continue to work rope spear 1/4 rotatins rotating at 10 RPM attempted pumping at 3 BPM 160 PSI. Dry poked. unable to get any indication that we were pulling anything up hole. Blow down top drive. 1,869.0 1,874.0 10/3/2024 20:45 10/3/2024 21:15 0.50 COMPZN, RPCOMP TRIP P TOOH F/1874.38' T/297.5 1,874.0 297.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 31/40 1D-05 Report Printed: 11/11/2024 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) 10/3/2024 21:15 10/3/2024 23:15 2.00 COMPZN, RPCOMP BHAH P LD BHA 99 MU BHA 100 off set rope spear 297.0 302.3 10/3/2024 23:15 10/4/2024 00:00 0.75 COMPZN, RPCOMP TRIP P TIH F/302.03 T/1777' tagged obstruction in casing, Set down 15K PUH. PUW=64K SOW=61K Continue to RIH to 1874' 302.3 10/4/2024 00:00 10/4/2024 00:45 0.75 COMPZN, RPCOMP FISH P Work rope spear down to 1875' Rotate 8 RPM 800 Free Tq. Employ multiple techniques and weights. work up to 30K down 2K over pull. 1,875.0 1,875.0 10/4/2024 00:45 10/4/2024 02:00 1.25 COMPZN, RPCOMP TRIP P TOOH F/1875' T/302' 1,875.0 302.0 10/4/2024 02:00 10/4/2024 03:15 1.25 COMPZN, RPCOMP BHAH P LD BHA 100 MU BHA 101 302.0 297.6 10/4/2024 03:15 10/4/2024 04:15 1.00 COMPZN, RPCOMP TRIP P TIH F/297.6' T/1869' PUW=65K SOW=62K 297.6 1,869.0 10/4/2024 04:15 10/4/2024 05:00 0.75 COMPZN, RPCOMP FISH P Tagged at 1869 PR=6 BPM 3200 PSI, Rot at 20 RPM Free Tq=1000 Work over spring and attempt to get a bind on spring over pulled 10K 2 times unable to maintain any excess weight. attempted to drive over spring W/O rotation no success. Attempted to rotate over several more timed worked up to 8.5K torque varied RPM's no success. 1,869.0 1,869.0 10/4/2024 05:00 10/4/2024 05:30 0.50 COMPZN, RPCOMP TRIP P TOOH F/1869' T/297.6' 1,869.0 297.6 10/4/2024 05:30 10/4/2024 06:30 1.00 COMPZN, RPCOMP BHAH P LD BHA 101 MU BHA 102 Modified rope spear. 297.6 0.0 10/4/2024 06:30 10/4/2024 07:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA 102. Rope spear with offset tines. 0.0 255.0 10/4/2024 07:00 10/4/2024 08:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 255' to 1864'. PUWT: 60 K SOWT: 60 K 255.0 1,864.0 10/4/2024 08:00 10/4/2024 08:30 0.50 COMPZN, RPCOMP FISH P P/U single from the pipe shed. S/O F/ 1864' to 1873' observed 5-10K Bobble. Continue to S/O to 1876' set down 25K. P/U to 1872' Rotated string 1/2 turn. S/O observed 5-10K Bobble F/ 1873'. S/O to 1876' set down 30K. P/U to 1873' observed 5K over pull wait 3 min. 1,864.0 1,876.0 10/4/2024 08:30 10/4/2024 09:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1876' to 255'. 1,876.0 255.0 10/4/2024 09:30 10/4/2024 10:00 0.50 COMPZN, RPCOMP TRIP P POOH Break down and lay down BHA F/ 255' to surface. Wear observed on rope spear, and bent tines indicating it possibly entered flow tube. 255.0 0.0 10/4/2024 10:00 10/4/2024 11:00 1.00 COMPZN, RPCOMP BHAH P P/U BHA # 103, Spear BHA F/ Surface to 292'. 0.0 292.0 10/4/2024 11:00 10/4/2024 12:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 292' to 1868'. PUWT: 60 K SOWT: 60 K 292.0 1,868.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 32/40 1D-05 Report Printed: 11/11/2024 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) 10/4/2024 12:00 10/4/2024 13:00 1.00 COMPZN, RPCOMP FISH P P/U single. Start pumps @ 1 BBL/MIN @ 260 PSI. Slack off to 1871' observe 150 PSI pressure spike. Cut pumps. Cont. to S/O to 1876', 5-10 K Bobbles observed F/ 1872' to 1876'. Set down 20K. Weight fell off to 15K, Slack of .27' to 20K. P/U to 15K over pull @ 1875'. Weight 3 min for jars to bleed. Cont. to P/U @ 1872' weight fell off. P/U to 1865'. S/O F/ 1865' to 1874' set down 3K. Turn string 1/4" turn. S/O 1877' Set down 25K. P/U to 30K over (90K). Wait 3 min for jars to bleed off. Cont. to P/U to 100K over (160K). Cont to P/U to 250K. Weight fell off to 180K. Cont to pick up, weight pull up to 200-225K breaking over to 160K @ 1834' weight fell off to 116K. 1,868.0 10/4/2024 13:00 10/4/2024 14:00 1.00 COMPZN, RPCOMP CIRC P Attempt to break circulation. Unable to circulate. 1,834.0 1,834.0 10/4/2024 14:00 10/4/2024 15:30 1.50 COMPZN, RPCOMP TRIP P POOH F/ 1834' to 292' 1,834.0 292.0 10/4/2024 15:30 10/4/2024 16:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA. SSSV on spear. Grapple segment found bellow SSSV in first joint of tubing w/ spring segments, and metal fragments. 292.0 6,300.0 10/4/2024 16:30 10/4/2024 17:00 0.50 COMPZN, RPCOMP OTHR P R/U to L/D 3.5" Tubing. 6,300.0 6,300.0 10/4/2024 17:00 10/5/2024 00:00 7.00 COMPZN, RPCOMP PULL P L/D 3.5" 9.3# EUE tubing F/ 6300' to surface 6,300.0 0.0 10/5/2024 00:00 10/5/2024 00:30 0.50 COMPZN, RPCOMP CLEN P Clear rig floor, Change elevators empty pipe shed. Prep to TIH with dress off assembly. 0.0 0.0 10/5/2024 00:30 10/5/2024 01:00 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment 0.0 0.0 10/5/2024 01:00 10/5/2024 04:00 3.00 COMPZN, RPCOMP BHAH P MU BHA 104 dress off assembly 0.0 253.4 10/5/2024 04:00 10/5/2024 07:15 3.25 COMPZN, RPCOMP TRIP P TIH W/DP F/253.4 T/1424' tagged obstruction in tubing, set down 10K ' PUW=53K Pulled to 64K 10K over string weight. Continued to RIH F/1424' T/8101' PUWT: 170 K SOWT: 95 K 253.4 8,101.0 10/5/2024 07:15 10/5/2024 07:30 0.25 COMPZN, RPCOMP TRIP P Slack off and tag stump @ 1876'. ( 53' Deeper than last recorded when stump was cut.) 8,101.0 8,176.0 10/5/2024 07:30 10/5/2024 08:00 0.50 COMPZN, RPCOMP RURD P Count Pipe in the derrick, and yard. Count Tubing that was laid down. 8,176.0 8,176.0 10/5/2024 08:00 10/5/2024 13:00 5.00 COMPZN, RPCOMP TRIP P POOH strapping pipe in the derrick. No descrepency found between original pipe tally and tally measured coming out of the hole. 8,176.0 253.0 10/5/2024 13:00 10/5/2024 13:30 0.50 COMPZN, RPCOMP WAIT T Discuss plan forward with town. 253.0 253.0 10/5/2024 13:30 10/5/2024 16:00 2.50 COMPZN, RPCOMP TRIP P TIH w/ Dress off BHA.F/253.4' T/8176' PUW=170K SOW=96K 253.0 8,108.0 10/5/2024 16:00 10/5/2024 17:30 1.50 COMPZN, RPCOMP MILL P Establish milling parameters. 15 RPM Free Tq. = 7900'/lbs. 4BPM 860 PSI Push down hole to 8202' No torque gain or DP seen PUH erratic Wt. PUW=185K - 210K 8,108.0 8,202.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 33/40 1D-05 Report Printed: 11/11/2024 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) 10/5/2024 17:30 10/5/2024 18:00 0.50 COMPZN, RPCOMP OWFF P OWFF 8,172.0 8,172.0 10/5/2024 18:00 10/5/2024 20:00 2.00 COMPZN, RPCOMP CIRC P Circ SxS 5100 STKS 3 BPM 530 PSI. Slight gas cut at BUS continued till clean. 8,172.0 8,172.0 10/5/2024 20:00 10/5/2024 20:30 0.50 COMPZN, RPCOMP OWFF P OWFF. 30 minutes. No Flow. 8,172.0 8,172.0 10/5/2024 20:30 10/5/2024 20:45 0.25 COMPZN, RPCOMP TRIP P Rack back 5 stands Weight erratic PUW=150K - 185K 7,711.0 7,711.0 10/5/2024 20:45 10/5/2024 21:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes 7,711.0 7,711.0 10/5/2024 21:15 10/5/2024 23:30 2.25 COMPZN, RPCOMP TRIP P TOOH F/7711' T/2713' 7,711.0 2,713.0 10/5/2024 23:30 10/6/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment 2,713.0 2,713.0 10/6/2024 00:00 10/6/2024 01:15 1.25 COMPZN, RPCOMP TRIP P Cont TOOH F/2713' T/ 253.4' 2,713.0 253.4 10/6/2024 01:15 10/6/2024 03:00 1.75 COMPZN, RPCOMP BHAH P LD BHA 104, Empty boot baskets, metal and sand in boot baskets. MU BHA 105, 253.4 253.5 10/6/2024 03:00 10/6/2024 05:30 2.50 COMPZN, RPCOMP TRIP P TIH F/253.48' T/8186' PUW=150K SOW=105K 253.5 8,186.0 10/6/2024 05:30 10/6/2024 06:00 0.50 COMPZN, RPCOMP FISH P 30K down rotate over fish at 10 RPM Tq=5300 work down to 8189'. PU pulled 10K over PU WT=180K weight broke back attempted to engage fish 5 times unable to get more than 10K over pull and weight broke back 8,186.0 8,189.0 10/6/2024 06:00 10/6/2024 06:15 0.25 COMPZN, RPCOMP TRIP P Rack 5 back 8,189.0 7,689.0 10/6/2024 06:15 10/6/2024 07:00 0.75 COMPZN, RPCOMP CIRC P Circ BUS Sheared Circ sub at 1400 PSI. 7,689.0 7,689.0 10/6/2024 07:00 10/6/2024 07:30 0.50 COMPZN, RPCOMP OWFF P OWFF 7,689.0 7,689.0 10/6/2024 07:30 10/6/2024 10:00 2.50 COMPZN, RPCOMP TRIP P TOOH F/7689' T/253.5' PUW of bottom 150K 7,689.0 253.5 10/6/2024 10:00 10/6/2024 12:00 2.00 COMPZN, RPCOMP BHAH P LD BHA 105, Overshot packed off with fines ffrom well. Cleaned and emptied shoe and grapple. MU BHA 106, 253.5 267.6 10/6/2024 12:00 10/6/2024 14:30 2.50 COMPZN, RPCOMP TRIP P TIH F/267.58' T/8175' 267.6 8,175.0 10/6/2024 14:30 10/6/2024 17:30 3.00 COMPZN, RPCOMP REAM P Wash and ream F/8175' T/8210' Hard tag at 8210' Unable to get any deeper with cut lip on shoe after multiple attempts. 8,175.0 8,210.0 10/6/2024 17:30 10/6/2024 19:30 2.00 COMPZN, RPCOMP CIRC P Circulate 5.3BPM 1200 PSI alternate vis sweeps till clean returns at shakers. 7,900.0 7,900.0 10/6/2024 19:30 10/6/2024 20:00 0.50 COMPZN, RPCOMP OWFF P OWFF 7,900.0 7,900.0 10/6/2024 20:00 10/6/2024 21:45 1.75 COMPZN, RPCOMP SLPC P Slip and cut drill line. 7,900.0 7,900.0 10/6/2024 21:45 10/6/2024 23:30 1.75 COMPZN, RPCOMP TRIP P TOOH F/7900' T/2500' 7,900.0 2,500.0 10/6/2024 23:30 10/7/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service Crown. 2,500.0 2,500.0 10/7/2024 00:00 10/7/2024 01:00 1.00 COMPZN, RPCOMP TRIP P Continue to TOOH F/2500' T/267.6' 2,500.0 267.6 10/7/2024 01:00 10/7/2024 03:00 2.00 COMPZN, RPCOMP BHAH P LD BHA 106 MU BHA 107 267.6 279.3 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 34/40 1D-05 Report Printed: 11/11/2024 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) 10/7/2024 03:00 10/7/2024 06:30 3.50 COMPZN, RPCOMP TRIP P TIH F/279.29' T/ 8216' PUWT: 145K SOWT: 110K 279.3 8,216.0 10/7/2024 06:30 10/7/2024 11:00 4.50 COMPZN, RPCOMP WASH P Wash ream over top of fish F/8216' RPM= 50 280 GPM @ 2050 PSI Free Tq= 5 K Wash and ream down to 8243'. Pumping sweeps back to back. Observed metal cuttings come back F/ 8240' to 8243' in sweeps. Injection debris/sand cleaned up. Torque 6-9K 1-5K set down 8,216.0 8,243.0 10/7/2024 11:00 10/7/2024 12:00 1.00 COMPZN, RPCOMP CIRC P Circulate around high vis sweep. More cuttings indicating mills where on tubing brought out with sweep. 280 GPM 2050 PSI. 8,243.0 8,243.0 10/7/2024 12:00 10/7/2024 12:30 0.50 COMPZN, RPCOMP OWFF P OWFF: Static. Blow down top drive. 8,243.0 8,243.0 10/7/2024 12:30 10/7/2024 14:30 2.00 COMPZN, RPCOMP TRIP P POOH F/ 8243 to 279.3 8,243.0 279.3 10/7/2024 14:30 10/7/2024 15:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 107. Carbides worn off of bottom of wavy bottom shoe. Inside mill indicates 3.5" Tubing stump was dressed off. 279.3 0.0 10/7/2024 15:30 10/7/2024 16:00 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment. 0.0 0.0 10/7/2024 16:00 10/7/2024 16:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 108. Over shot BHA. 0.0 261.3 10/7/2024 16:30 10/7/2024 19:15 2.75 COMPZN, RPCOMP TRIP P TIH F/261.3 T/8230' PUW=150K SOW=105K 261.3 8,230.0 10/7/2024 19:15 10/7/2024 19:45 0.50 COMPZN, RPCOMP FISH P Wash down to to fish top at 8230' set down 10K PR=4 BPM 680 PSI, 2 BPM=400 PSI, Engage top of fish set down 10 work up to 20K down. Bleed jars Establish circulation. 2 BPM=270 PSI Pressure incresed to 800 PSI built to 920 PSI continue Increase PR 2.7 BPM=1200 PSI. 8,230.0 8,230.0 10/7/2024 19:45 10/7/2024 22:45 3.00 COMPZN, RPCOMP CIRC P Establish circulation. 2 BPM=270 PSI Pressure incresed to 800 PSI built to 920 PSI continue Increase PR 2.7 BPM=1200 PSI. Continue to increase PR up to 5 BPM 1500 PSI Pressure remained constant. SxS 1.8 times Shakers clean. 8,230.0 8,230.0 10/7/2024 22:45 10/8/2024 00:00 1.25 COMPZN, RPCOMP FISH P Start working fish. PU to 250K straight pull 4 times no movement Start jarring on fish working PU WT to 255K, Fish started moving uphole. Pulling 200K 25K over. PUH to 8176' 8,230.0 8,176.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 35/40 1D-05 Report Printed: 11/11/2024 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) 10/8/2024 00:00 10/8/2024 00:30 0.50 COMPZN, RPCOMP FISH P Continue to fish tail pipe packer and tubing out of well. Fish top at 8140'. Packer approximately at previous set depth. Jar on fish and work DP W/O success. Appears there is trash above GLM or packer. Start circulating at 3BPM 455 PSI 8,176.0 8,140.0 10/8/2024 00:30 10/8/2024 01:45 1.25 COMPZN, RPCOMP CIRC P Circulate SxS with 100 vis sweep. 8,140.0 8,140.0 10/8/2024 01:45 10/8/2024 06:00 4.25 COMPZN, RPCOMP FISH P Fish tubing string. Fish will move down freely. attempt to pull past 8136' Pull 240K fire jars and attempt to jar fish free. Continue jarring on fish. beat down on fish several times without movement. 80 jar hits up total. Release fish Rack back 1 stand 8,140.0 8,050.0 10/8/2024 06:00 10/8/2024 06:30 0.50 COMPZN, RPCOMP OWFF P OWFF No flow 8,050.0 8,050.0 10/8/2024 06:30 10/8/2024 07:00 0.50 COMPZN, RPCOMP SVRG P Service rig 8,050.0 8,050.0 10/8/2024 07:00 10/8/2024 10:00 3.00 COMPZN, RPCOMP TRIP P TOOH F/8050' T/261.3 8,050.0 261.3 10/8/2024 10:00 10/8/2024 11:30 1.50 COMPZN, RPCOMP BHAH P LD BHA reconfigue to allow access to tubing with slickline and E-Line. 261.3 0.0 10/8/2024 11:30 10/8/2024 14:00 2.50 COMPZN, RPCOMP TRIP P TIH w/Fishing BHA #109 (5.06' swallow) 0.0 166.6 10/8/2024 14:00 10/8/2024 14:30 0.50 COMPZN, RPCOMP FISH P PUW=150k, SOW=105k Tag TOF @ 8,137', space out with 5' DP pup, set in slips 20k over pickup weight. 166.6 8,142.0 10/8/2024 14:30 10/8/2024 15:00 0.50 COMPZN, RPCOMP SFTY P PJSM with Rig and SL crew 8,142.0 8,142.0 10/8/2024 15:00 10/8/2024 16:00 1.00 COMPZN, RPCOMP SLKL P Spot in equipment, RU SL 8,142.0 8,142.0 10/8/2024 16:00 10/9/2024 00:00 8.00 COMPZN, RPCOMP SLKL P RIH W/1.875" TS 1.75" DD bailer. SD @ 8178' work bailer. Small amount of fines recovered in bailer. RIH W/2" DD bailer work down to 8178' Small amount of metal and fines in bailer. RIH W/2" Pump bailer work bailer 8,142.0 8,142.0 10/9/2024 00:00 10/9/2024 06:00 6.00 COMPZN, RPCOMP SLKL P Slick line continue bailing fill from tubing. 8,142.0 8,142.0 10/9/2024 06:00 10/9/2024 19:00 13.00 COMPZN, RPCOMP SLKL P Continue bailing fill from tubing T/8,199' MU/Run 2.125" brush T/8,197' MU/Run 2" bailer T/8,197' MU/Run Memory CCL on SL RD Slickline 8,142.0 10/9/2024 19:00 10/9/2024 19:15 0.25 COMPZN, RPCOMP SFTY P PJSM with E-line Etc. Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 36/40 1D-05 Report Printed: 11/11/2024 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) 10/9/2024 19:15 10/10/2024 00:00 4.75 COMPZN, RPCOMP ELNE P RU Eline verify TS to proposed shot depth. RIH W/Eline at 21:45 Tagged bottom at 8153' Bottom ot TS. Logged up from tag depth Correlated to tubing tally from 1990' Anchor would be across GLM unable to get any deeper Logged 2 more passes with same result. Consulted with engineer and superintendent to bail more fill with Slick line before proceding. POOH W/E-line 10/10/2024 00:00 10/10/2024 01:30 1.50 COMPZN, RPCOMP ELNE P Continue POOH w/e-line to surface. RD E-line. 8,140.0 8,140.0 10/10/2024 01:30 10/10/2024 02:00 0.50 COMPZN, RPCOMP SVRG P Service top drive. 8,140.0 8,140.0 10/10/2024 02:00 10/10/2024 06:00 4.00 COMPZN, RPCOMP SLKL P Spot in slick line unit, move tools to floor, RU to RIH with slick line and bail fill from tubing. 8,140.0 8,140.0 10/10/2024 06:00 10/10/2024 09:00 3.00 COMPZN, RPCOMP SLKL P Slickline depth 8,222', POOH, PU 2" brush, RIH, work brush F/8,222' SLMD T/8,224' SLMD, fell through bridge T/8,237.6' SLMD, tag x 3 same depth 8,237.6', POOH, LD Brush, PU 2" bailer, RIH, tag up on depth 8,237.6', POOH, RD Slickline 8,140.0 8,140.0 10/10/2024 09:00 10/10/2024 14:00 5.00 COMPZN, RPCOMP ELNE P Spot in, RU Yellow Jacket E-line Arm cutter @ 10:45am, RIH, correlate CCL, on depth, set anchors, cut @ 8,160' Hung up after cut work string free, pull tight again in accelerator free, Continue OOH, LD cutter ( tool appears complete ) Stand back E-line. 8,140.0 8,140.0 10/10/2024 14:00 10/10/2024 14:30 0.50 COMPZN, RPCOMP FISH P Latch up, screw into DP, PUH 145k, pull up 1 stand *** Note: 1430 hrs release YJ E-line 8,140.0 8,111.0 10/10/2024 14:30 10/10/2024 15:00 0.50 COMPZN, RPCOMP CIRC P CBU @ 231 gpm/1,200 psi At BU send returns over board @ 3,700 stks away, 4,122 stks sway bring returns back inside 8,111.0 8,111.0 10/10/2024 15:00 10/10/2024 15:30 0.50 COMPZN, RPCOMP OWFF P Check well for flow 8,111.0 8,111.0 10/10/2024 15:30 10/10/2024 19:15 3.75 COMPZN, RPCOMP TRIP P TOOH F/8,111' T/166.6' 8,111.0 166.0 10/10/2024 19:15 10/10/2024 20:00 0.75 COMPZN, RPCOMP BHAH P LD BHA 166.0 0.0 10/10/2024 20:00 10/10/2024 20:30 0.50 COMPZN, RPCOMP PULL P LD fish, recoverd cut section to 8160' cut joint, pup joint mandrel, pu joint and XX' of joint. 0.0 0.0 10/10/2024 20:30 10/10/2024 21:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor after laying down BHA. 0.0 0.0 10/10/2024 21:00 10/10/2024 21:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 10/10/2024 21:30 10/10/2024 22:00 0.50 COMPZN, RPCOMP SFTY P Safety meeting for MU BHA. 0.0 0.0 10/10/2024 22:00 10/10/2024 23:00 1.00 COMPZN, RPCOMP BHAH P MU BHA 110. Burn shoe and wash pipe. 0.0 307.8 10/10/2024 23:00 10/11/2024 00:00 1.00 COMPZN, RPCOMP TRIP P TIH W/Burn shoe wash pipe BHA F/307.8' T/2100' 307.8 2,100.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 37/40 1D-05 Report Printed: 11/11/2024 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) 10/11/2024 00:00 10/11/2024 02:15 2.25 COMPZN, RPCOMP TRIP P Con't TIH F/2100' T/8152' PUW = 148K SOW = 108K 2,100.0 8,152.0 10/11/2024 02:15 10/11/2024 02:45 0.50 COMPZN, RPCOMP MILL P Establish milling parameters. Rot 22 RPM, Free Tq.=4K Ft/Lbs Engage top of fish at 8181' RIH down to top of PBR at 8200' PR= 5 BPM = 1126 PSI. Increase RPM to 60 5BPM 110 PSI Establish milling pattern on PBR. WOB=1K 8,152.0 8,200.0 10/11/2024 02:45 10/11/2024 06:00 3.25 COMPZN, RPCOMP MILL P Burn over PBR WOB= 1k 60 RPM, 5BPM 11 PSI 6500 Ft/Lbs. 8,200.0 8,205.3 10/11/2024 06:00 10/11/2024 10:00 4.00 COMPZN, RPCOMP MILL P Continue burning over PBR WOB=3k, PUW=150k, SOW=105k Rot=66 RPM, Rot Wt.=115k, Rot TQ.=8,600 ft/lbs, 8,205.3 8,213.0 10/11/2024 10:00 10/11/2024 12:00 2.00 COMPZN, RPCOMP MILL P Burning over packer, F/8,213' T/8,215.7', WOB=8.8k, PUW=155k, SOW=105k Rot=66 RPM, Rot Wt.=115k, Rot TQ.=8,100 ft/lbs, Stall out, PU, tight hole off bottom, assuming its rubber. Work pipe, shed rubber off BHA Circulate sweep around 20 bbl 8,213.0 8,215.7 10/11/2024 12:00 10/11/2024 15:30 3.50 COMPZN, RPCOMP MILL P Continue burning over Packer F/8,215.7' T/8,217' with 22k down WOB=22k, PUW=155k, SOW=105k Rot=61 RPM, Rot Wt.=98k, Rot TQ.=7,400 ft/lbs, Send second 20 bbl sweep around 8,215.7 8,217.0 10/11/2024 15:30 10/11/2024 16:00 0.50 COMPZN, RPCOMP OWFF P OWFF no flow. 8,217.0 8,217.0 10/11/2024 16:00 10/11/2024 17:30 1.50 COMPZN, RPCOMP TRIP P TOOH F/8217' T/5278' lost 4BBl's last 5 stands. 8,217.0 5,278.0 10/11/2024 17:30 10/11/2024 18:00 0.50 COMPZN, RPCOMP OWFF P Establish loss rate 24 BBL's/hour. 10 minute fill volume=4BBL 5,278.0 5,278.0 10/11/2024 18:00 10/11/2024 19:45 1.75 COMPZN, RPCOMP TRIP P TOOH 5 stands F/5278' T/4900' fill hole 5BBl's Continue TOOH W/DP F/4900' T/307.79' 5,279.0 307.8 10/11/2024 19:45 10/11/2024 21:00 1.25 COMPZN, RPCOMP BHAH P LD BHA 110' Shoe had wear on face and several chipped buttons. MU BHA 111' 307.8 307.0 10/11/2024 21:00 10/11/2024 21:30 0.50 COMPZN, RPCOMP SVRG P Service Iron rough neck 307.0 307.0 10/11/2024 21:30 10/12/2024 00:00 2.50 COMPZN, RPCOMP TRIP P TIH W/BHA 111 F/307.3' T/7500' 95K 307.0 10/12/2024 00:00 10/12/2024 00:30 0.50 COMPZN, RPCOMP TRIP P Continue TIH F/7500' T/8212' PUW=145K SOW=110K 7,500.0 8,212.0 10/12/2024 00:30 10/12/2024 01:00 0.50 COMPZN, RPCOMP SVRG P Service top drive 8,212.0 8,212.0 10/12/2024 01:00 10/12/2024 02:45 1.75 COMPZN, RPCOMP MILL P Establish milling parameters. PR=5BPM 1075 PSI PUH off tag. 65 RPM 4.1-4.4 Ft/Lbs. Rotate down to tag at 8216.82' WOB = 7K 6-7K Torque 2 BPM 260 PSI. Continue to burn over packer. Packer started moving down hole. Pushed fish down to 8225' 8,212.0 8,221.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 38/40 1D-05 Report Printed: 11/11/2024 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) 10/12/2024 02:45 10/12/2024 05:45 3.00 COMPZN, RPCOMP CIRC P Close in annular line up to circulate through gas buster. Circulate 2 BPM SxS. 8,221.0 8,221.0 10/12/2024 05:45 10/12/2024 06:15 0.50 COMPZN, RPCOMP OWFF P Check well for flow 8,221.0 8,221.0 10/12/2024 06:15 10/12/2024 08:30 2.25 COMPZN, RPCOMP CIRC P Discuss with town team, plan to push packer below C-sand perfs, Static loss rate = 24 bph Condition fluid F/10.4 ppg T/10.3 ppg Static loss rate = 12 bph 8,221.0 8,221.0 10/12/2024 08:30 10/12/2024 08:45 0.25 COMPZN, RPCOMP FISH P Push packer F/8,221' T/stackout @ 8,300', work pipe, unable to move move fish, confer w/town, Pumping 3.0 bpm/1,200 psi, PUW=145k, SOW=115k Rot=40 rpm, Rot Free TQ=4,800 ft/lbs 8,221.0 8,300.0 10/12/2024 08:45 10/12/2024 09:15 0.50 COMPZN, RPCOMP CIRC P Pull up hole F/8,300' T/8,278', circulate BU 8,300.0 8,278.0 10/12/2024 09:15 10/12/2024 09:45 0.50 COMPZN, RPCOMP OWFF P Check well for flow 8,278.0 8,278.0 10/12/2024 09:45 10/12/2024 12:15 2.50 COMPZN, RPCOMP TRIP P TOOH F/8278' T/surface *** Note: TOF @ 8,262' 8,278.0 307.0 10/12/2024 12:15 10/12/2024 13:15 1.00 COMPZN, RPCOMP BHAH P Stand back collars, LD BHA, inspect Junk Baskets, full of metal/black shmoo. 307.0 0.0 10/12/2024 13:15 10/12/2024 13:45 0.50 COMPZN, RPCOMP CLEN P CLean RF/Prep to pickup BHA *** Note: Static loss rate 10 bph 0.0 0.0 10/12/2024 13:45 10/12/2024 14:45 1.00 COMPZN, RPCOMP BHAH P MU, 5.75" over shot cut lip guide, 3.5" grapple, upper extention, top sub, bumper sub, jars, collars x 3, and accelerator 0.0 166.0 10/12/2024 14:45 10/12/2024 17:45 3.00 COMPZN, RPCOMP TRIP P TIH, w/fishing assembly BHA #112 F/166.57' T/8210 Kelly up Establish circulation rates and pressures. 5 BPM 970 PSI. PUW = 145K SOW = 110K 166.0 8,210.0 10/12/2024 17:45 10/12/2024 18:15 0.50 COMPZN, RPCOMP FISH P Wash over down to 8267'' 1 BPM 80 PSI off fish, 100 PSI when we washed over. Set down 20K. Verfiy we are latched up to fish. Pulled 185K, 40K over. 8,210.0 8,260.0 10/12/2024 18:15 10/12/2024 18:30 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 8,267.0 8,267.0 10/12/2024 18:30 10/12/2024 23:30 5.00 COMPZN, RPCOMP TRIP P Start TOOH F/8267 T/166 PUW off bottom = 165K Racked back 4 stands. Screw into DP and pump out F/7800' T/6695'. Worked through restrictsions pulled up to 230K Continue to TOOH F/6695' T/166.57' 8,267.0 166.6 10/12/2024 23:30 10/13/2024 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF before laying down BHA, Fill stack and monitor for 30 minutes. 166.6 166.6 10/13/2024 00:00 10/13/2024 00:30 0.50 COMPZN, RPCOMP BHAH P LD BHA 166.6 0.0 10/13/2024 00:30 10/13/2024 01:00 0.50 COMPZN, RPCOMP PULL P LD cut joint Seal assembly, PBR, packer and tail pipe section When unscrewing packer from string trapped pressure was released. Crew members were assessed. Work was stopped. Floor hands all left the floor to change and clean up. 0.0 0.0 10/13/2024 01:00 10/13/2024 02:00 1.00 COMPZN, RPCOMP CLEN P Clean rig floor. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 39/40 1D-05 Report Printed: 11/11/2024 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) 10/13/2024 02:00 10/13/2024 02:30 0.50 COMPZN, RPCOMP SFTY P Safety stand down was held with crew. 0.0 0.0 10/13/2024 02:30 10/13/2024 03:00 0.50 COMPZN, RPCOMP SFTY P Pre job safety meeting for PU BHA. 0.0 0.0 10/13/2024 03:00 10/13/2024 04:30 1.50 COMPZN, RPCOMP BHAH P PU Clean out BHA. 0.0 309.8 10/13/2024 04:30 10/13/2024 07:30 3.00 COMPZN, RPCOMP TRIP P TIH w/cleanout assembly BHA #13 309.8 7,972.0 10/13/2024 07:30 10/13/2024 08:15 0.75 COMPZN, RPCOMP CIRC P Circulate BU 7,972.0 7,972.0 10/13/2024 08:15 10/13/2024 10:15 2.00 COMPZN, RPCOMP SLPC P Slip and cut drill line. 7,972.0 7,972.0 10/13/2024 10:15 10/13/2024 11:45 1.50 COMPZN, RPCOMP WASH P Wash down F/7,972' T/8,200' PUW=142k SOW=110, Rot=56 rpm Rot TQ=6,100 ft/lbs Pumping 5 bpm/1,291 psi 7,972.0 8,200.0 10/13/2024 11:45 10/13/2024 13:00 1.25 COMPZN, RPCOMP WASH P Washed down F/8,200' T/8,414' Rot=56 rpm Rot TQ=6,100 ft/lbs Pumping 5 bpm/1,291 psi PUW=142k SOW=110, Stall out, PUW=185k, Continue washing down F/8,414' T/8,420' Rot=67 rpm Rot TQ=7,100 ft/lbs Pumping 8 bpm/2,700 psi PUW=142k SOW=110, 8,200.0 8,420.0 10/13/2024 13:00 10/13/2024 14:00 1.00 COMPZN, RPCOMP TRIP P PUH, F/8,420' T/8,381', confer with TT 8,420.0 8,381.0 10/13/2024 14:00 10/13/2024 14:30 0.50 COMPZN, RPCOMP CIRC P Circulate BU, 8 bpm/2,500 psi Rot=20 rpm, Rot TQ=5,200 ft/lbs, Rot W=116k 8,381.0 8,381.0 10/13/2024 14:30 10/13/2024 17:30 3.00 COMPZN, RPCOMP TRIP P TOOH, w/cleanout assmebly 8,381.0 307.0 10/13/2024 17:30 10/13/2024 18:00 0.50 COMPZN, RPCOMP OWFF P OWFF 307.0 307.0 10/13/2024 18:00 10/13/2024 20:30 2.50 COMPZN, RPCOMP BHAH P LD BHA #114 L/D collars 307.0 0.0 10/13/2024 20:30 10/13/2024 21:00 0.50 COMPZN, RPCOMP BHAH P Unload BHA from pipe shed move collars out. Load BHA #115 in shed . Sim-ops cleaning floor. PU BHA #115 G-lock and TST-3 packer 0.0 37.0 10/13/2024 21:00 10/14/2024 00:00 3.00 COMPZN, RPCOMP TRIP P TIH F/37.03' T/5338' PUW=80K 10/14/2024 00:00 10/14/2024 01:15 1.25 COMPZN, RPCOMP TRIP P TIH F/5338' T/8299' PUW = 150K SOW=110K 5,338.0 8,299.0 10/14/2024 01:15 10/14/2024 01:30 0.25 COMPZN, RPCOMP MPSP P Set G-Lock RBP at 8299' 8,299.0 8,299.0 10/14/2024 01:30 10/14/2024 02:45 1.25 COMPZN, RPCOMP CIRC P Circulate SxS strokes 8,299.0 8,299.0 10/14/2024 02:45 10/14/2024 04:45 2.00 COMPZN, RPCOMP PRTS P Attempt to test casing at 8299' Closed in UPR's. Tested casing to 2500 PSI for 30 minutes. Tested good 8,299.0 8,299.0 10/14/2024 04:45 10/14/2024 05:30 0.75 COMPZN, RPCOMP CIRC P Circulate BU 8,299.0 8,299.0 10/14/2024 05:30 10/14/2024 06:00 0.50 COMPZN, RPCOMP OWFF P Check well for flow 8,299.0 8,299.0 10/14/2024 06:00 10/14/2024 14:30 8.50 COMPZN, RPCOMP TRIP P Trip OOH PUW=148k 8,299.0 37.0 10/14/2024 14:30 10/14/2024 15:30 1.00 COMPZN, RPCOMP BHAH P LD Packer and G-lock 37.0 0.0 10/14/2024 15:30 10/14/2024 16:00 0.50 COMPZN, RPCOMP PULL P Pull wear ring 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Page 40/40 1D-05 Report Printed: 11/11/2024 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) 10/14/2024 16:00 10/14/2024 16:30 0.50 COMPZN, RPCOMP CLEN P Clean rig floor 0.0 0.0 10/14/2024 16:30 10/14/2024 17:15 0.75 COMPZN, RPCOMP PUTB P Load 3.5" completion jewelry into pipe shed. Verify and confirm jewelry and tubing 0.0 0.0 10/14/2024 17:15 10/15/2024 00:00 6.75 COMPZN, RPCOMP PUTB P Run 3.5" HYD563 Completion as per tally F/surface T/5870' SOW=64K 0.0 5,870.0 10/15/2024 00:00 10/15/2024 03:00 3.00 COMPZN, RPCOMP TRIP P Con't TIH W/ 3-1/2" 9.3# L-80 Hyd 563 Comletion F/5870 T/8235' 90K=PUW 70K=SOW. 5,870.0 8,235.0 10/15/2024 03:00 10/15/2024 04:00 1.00 COMPZN, RPCOMP THGR P PU Tubing hanger and MU landing joint to string. MU hardline to landing joint. Land hanger RILDS. Sim Ops rigging truck to pumps. 8,235.0 8,274.8 10/15/2024 04:00 10/15/2024 04:15 0.25 COMPZN, WHDBOP SFTY P PJSM W/Nabors, ASRC, Cameron, SLB, discussed plan forward hazards and mitigations. Everyone has an obligation to stop the job. 8,274.8 8,274.0 10/15/2024 04:15 10/15/2024 04:30 0.25 COMPZN, WHDBOP RURD P Line up vac trucks and build pressure. purge line to pump. 0.0 0.0 10/15/2024 04:30 10/15/2024 07:00 2.50 COMPZN, WHDBOP CIRC P Line up and circulate down the IA taking returns up the tubing. 3 BPM 230 PSI. 0.0 0.0 10/15/2024 07:00 10/15/2024 08:45 1.75 COMPZN, WHDBOP PRTS P Pressure test tubing to 3,500 PSI for 30 minutes. bled pressure back to 2,200 PSI. Pressured up on IA to 3,000 PSI for 30 minutes. Dumped TBG pressure sheared SOV. 0.0 0.0 10/15/2024 08:45 10/15/2024 09:15 0.50 COMPZN, WHDBOP RURD P RD testing equipment Back out Landing Joint, Drain stack 0.0 0.0 10/15/2024 09:15 10/15/2024 09:30 0.25 COMPZN, WHDBOP MPSP P Set BPV 0.0 0.0 10/15/2024 09:30 10/15/2024 10:00 0.50 COMPZN, WHDBOP PRTS P PT down the IA against BPV to 1,000 psi for 10 mins 0.0 0.0 10/15/2024 10:00 10/15/2024 10:30 0.50 COMPZN, WHDBOP RURD P RU Jet stack 0.0 0.0 10/15/2024 10:30 10/15/2024 16:00 5.50 COMPZN, WHDBOP SVRG P Between wells maintenance. 0.0 0.0 10/15/2024 16:00 10/15/2024 17:00 1.00 COMPZN, WHDBOP NUND P ND BOP stack and set back on pedestal. Remove DSA. 0.0 0.0 10/15/2024 17:00 10/15/2024 19:30 2.50 COMPZN, WHDBOP NUND P Install tree test dart, NU tree, TQ bolts, PT void to 5K/ 15 min, good test. RU circ lines for FP. 0.0 0.0 10/15/2024 19:30 10/15/2024 20:30 1.00 COMPZN, WHDBOP PRTS P RU LRS and PT tree T/5000 psi, No leaks. Pull BPV. 0.0 0.0 10/15/2024 20:30 10/15/2024 22:00 1.50 COMPZN, WHDBOP FRZP P Freeze protect the well with 80 bbls diesel. Pumped 2 BPM at 550 psi taking returns to tiger tank. Line up Tubing to IA and allow to U-tube. 0.0 0.0 10/15/2024 22:00 10/16/2024 00:00 2.00 DEMOB, MOVE OTHR P BD circ lines and get final pressures OA=0/IA=400 psi/TBG=0 Prep rig for rig move to 1D-39. Rig release at midnight. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/16/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,600.0 1D-05 11/7/2024 claytg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post Rig well work 1D-05 11/7/2024 claytg Notes: General & Safety Annotation End Date Last Mod By NOTE: 2024 RWO replaced entire tubing string. Attempted to cement OA but didn't get cmt to surface. 10/23/2024 spilch NOTE: Waivered for OA x Formation Communication. SC leak @ ~876' 3/12/2020 duffyp 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 Insulated 24" 16 15.06 32.0 80.0 80.0 62.58 H-40 WELDED SURFACE 10 3/4 9.95 31.0 3,076.8 2,709.2 45.50 K-55 BTC Tie-Back String 7 6.28 29.9 1,775.4 1,739.6 26.00 L-80 HYD 563 Production 7 6.28 1,770.5 8,917.0 6,895.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.2 Set Depth 8,274.8 String Max No 3 1/2 Set Depth 6,341.9 Tubing Description Tubing Production 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) 29.8 29.8 0.09 Hanger 7.010 CameronTubing Hanger CXS 7- 1/16" x 3-1/2" EUE Top x 3-1/2"EUE Mod Bottom Prepped for 1/4"(2) Control Line SN: 122191255-1 Camero n Gen 4 2.950 8,043.8 6,147.4 34.01 Mandrel GAS LIFT 5.873 3.5" x 1.5" MMG, GLM SLB MMG P#21131 -01 2.920 8,103.5 6,197.0 33.80 Packer 6.276 7" x 3 1/2" Bluepack Packer, VAMTOP, SN#:C24P-1208 SLB Bluepac k P#10305 8459 2.894 8,190.6 6,270.2 31.88 Nipple - X 4.281 3 1/2" x 2.813 X Nipple HES X Nipple 2.813 8,274.3 6,341.5 31.34 Wireline Guide 5.980 WLEG 3.5 Inno WLEG 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) 8,043.8 6,147.4 34.01 1 GAS LIFT DMY RK 1 1/2 11/7/2024 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) 29.9 29.9 0.09 1,708.9 1,681.7 28.14 Collar - Stage 8.000 HES Cementer 7" HAL ES II 6.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,402.0 8,499.0 6,450.9 6,534.2 C-4, C-3, C-2, 1D-05 2/10/1980 4.0 IPERF 2 1/8" Enerjet Guns 8,654.0 8,672.0 6,668.0 6,683.5 A-5, 1D-05 6/10/1981 4.0 IPERF 2 1/8" Enerjet Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 600.0 1,773.0 600.0 1,737.5 Intermediate String 1 Cement Lost returns estimated top of cement at 600' 9/27/2024 1D-05, 11/11/2024 12:11:28 PM Vertical schematic (actual) Production; 1,770.5-8,917.0 PRODUCTION; 30.9-8,917.0 IPERF; 8,654.0-8,672.0 IPERF; 8,402.0-8,499.0 Nipple - X; 8,190.6 Packer; 8,103.5 Mandrel GAS LIFT; 8,043.8 SURFACE; 31.0-3,076.8 Tie-Back String; 29.9-1,775.4 Intermediate String 1 Cement; 600.0 ftKB CONDUCTOR Insulated 24"; 32.0-80.0 Hanger; 29.8 KUP INJ KB-Grd (ft) 38.99 RR Date 3/4/1980 Other Elev 1D-05 ... TD Act Btm (ftKB) 8,925.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292041700 Wellbore Status INJ Max Angle & MD Incl (°) 51.23 MD (ftKB) 4,700.00 WELLNAME WELLBORE1D-05 Annotation Last WO: End Date 10/15/2024 H2S (ppm) DateComment SSSV: Originated: Delivered to:10-Oct-24 Alaska Oil & Gas Conservation Commiss 10Oct24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3T-621 50-103-20882-00-00 224-022 Kuparuk River WL FMI-MSIP-PEX-ZAIT-XPT FINAL FIELD 11-Mar-24 3S-722 50-103-20886-00-00 224-066 Kuparuk River WL HSD FINAL FIELD 18-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL TTiX-IPROF FINAL FIELD 22-Sep-24 1J-154 50-029-23254-00-00 205-035 Kuparuk River WL TTiX-WFL FINAL FIELD 25-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL IPROF FINAL FIELD 27-Sep-24 1D-05 50-029-20417-00-00 179-095 Kuparuk River WL SCMT FINAL FIELD 28-Sep-24 2K-07 50-029-21351-00-00 189-071 Kuparuk River WL PPROF FINAL FIELD 1-Oct-24 1R-08 50-029-21333-00-00 185-073 Kuparuk River WL IPROF FINAL FIELD 5-Oct-24 1R-10 50-029-21351-00-00 185-096 Kuparuk River WL IPROF FINAL FIELD 6-Oct-24 3S-722 50-103-20886-00-00 224-066 Kuparuk River WL TTiX-Perf FINAL FIELD 9-Oct-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39651 T39652 T39652 T39653 T39653 T39654 T39655 T39656 T39657 T39658 1D-05 50-029-20417-00-00 179-095 Kuparuk River WL SCMT FINAL FIELD 28-Sep-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.11 08:44:58 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1D-05 JBR 10/16/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 3-1/2" & 7" TJ used, FP on UPR VBR on 3-1/2' cycled and passed. Accumulator bottles 11 @ 1086 psi Precharge Avg. Test Results TEST DATA Rig Rep:Morales/KellyOperator:ConocoPhillips Alaska, Inc.Operator Rep:Ronnie Dalton/Seth Burson Rig Owner/Rig No.:Nabors 7ES PTD#:1790950 DATE:9/5/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopKPS240907104236 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2442 Sundry No: 324-434 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 3-12" X 5-1/2 FP #2 Rams 1 Blinds P #3 Rams 1 7" Fixed P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 2 3-1/8", 2' De P Check Valve 0 NA BOP Misc 2 2-1/16" gate P System Pressure P3100 Pressure After Closure P1625 200 PSI Attained P17 Full Pressure Attained P125 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5 @2100 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9999 9 9 9 FP FP on UPR VBR ORIGINATED TRANSMITTAL DATE: 8/13/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4998 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4998 1D-05 500292041700 Hoist (with logs) 12-Aug-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 179-095 T39451 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 10:03:20 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 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): 8925' 6902' 8249' 6320' 2442 8249' 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: 907-263-4597 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 1D-05 8402-8499' 8654-8672' 8886' 6451-6534' 6668-6684' 8/22/2024 3-1/2" Baker HB SSSV: Camco TRDP-1A-ENC 3046' 8917' Perforation Depth MD (ft): 80' 3077' 6895'7" 16" 10-3/4" 48' Burst 8282' MD 80' 2709' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 179-095 P.O. Box 100360, Anchorage, AK 99510 50-029-20417-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8211'MD/6288'TVD 1783'MD/1746'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 Shane Germann shane.germann@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 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.07.25 15:09:38-08'00' Foxit PDF Editor Version: 13.0.0 324-434 By Grace Christianson at 4:25 pm, Jul 25, 2024 X 10-404 A variance to 20 AAC 25.412(b) is granted to allow the packer to be placed ~350' above the top of the top Ugnu perforation. VTL 8/5/2024 X X SFD 7/29/2024 DSR-7/31/24 BOP test to 3000 psig Annular preventer test to 3000 psig *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.05 15:21:28 -08'00'08/05/24 RBDMS JSB 080624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 25, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 1D-05 (PTD# 179-095). Well 1D-05 was drilled and completed 1980 as a Kuparuk A/C sand injector. The well was worked over in 1990 to replace the 3.5" tubing. In 2019, a leak in the surface casing was discovered at 876' RKB. In 2020, the well was shut-in due to TxIA communication suspected at the packer/PBR depth. Remediation efforts to patch/plug the leak were unsuccessful (including BiSN beads). If you have any questions or require any further information, please contact me at +1-406-670-1939. In order to bring the well back online we request approval to proceed with a RWO to replace the tubing with new and stack a production packer. A subsidence repair will be performed on the 7" production casing and cemented to surface in order to remedy the SC leak. We also request approval for the stacked packer depth to be greater than 200' MD from the top perforations. The packer will be approximately 300'-400' above the top perforation, but well below the 7" TOC identified from the CBL ran in 1980 (TOC approximately ~6400' MD). Anticipated packer set depth will be approximately 8040' RKB. Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.07.25 15:10:00-08'00' Foxit PDF Editor Version: 13.0.0 ϭͲϬϱZtKWƌŽĐĞĚƵƌĞ <ƵƉĂƌƵŬ/ŶũĞĐƚŽƌ WΘZdƵďŝŶŐǁͬ^ƵďƐŝĚĞŶĐĞ WdηϭϳϵͲϬϵϱ WĂŐĞϭŽĨϯ WƌĞͲZŝŐtŽƌŬ ϭ͘ dͲWWWKd͕dͲWKd͕/ͲWWWKd͕ĂŶĚ/ͲWKdƚĞƐƚƐ͘ Ϯ͘ ^ĞƚƉůƵŐŝŶͲŶŝƉƉůĞĂƚϴϮϰϵ͛Z<͘ ϯ͘ D/dͲddž/ƚŽϯϬϬϬƉƐŝŐ͘ ϰ͘ dͲddž/ ϱ͘ >ĞĂǀĞůŽǁĞƐƚ'>DŽƉĞŶĨŽƌĐŝƌĐƵůĂƚŝŽŶƉŽŝŶƚ͘ ϲ͘ ƵƚƚƵďŝŶŐĂƚΕϴϭϮϱ͛Z<͘ ϳ͘ WƌĞƉĂƌĞǁĞůůǁŝƚŚŝŶϰϴͲϵϲŚƌƐŽĨƌŝŐĂƌƌŝǀĂů͘ŽŶĨŝƌŵŶŽŐĂƐŝŶK͕/͕ŽƌƚƵďŝŶŐ͘ ZŝŐtŽƌŬ D/Zh ϭ͘ D/ZhEĂďŽƌƐϳ ^ŽŶϭͲϬϱ͘ Ϯ͘ ZĞĐŽƌĚƐŚƵƚͲŝŶƉƌĞƐƐƵƌĞƐŽŶƚŚĞdΘ/͘/ĨƚŚĞƌĞŝƐƉƌĞƐƐƵƌĞ͕ďůĞĞĚŽĨĨ/ĂŶĚͬŽƌƚƵďŝŶŐƉƌĞƐƐƵƌĞĂŶĚĐŽŵƉůĞƚĞ ϯϬͲŵŝŶƵƚĞE&d͘sĞƌŝĨLJǁĞůůŝƐĚĞĂĚ͘ŝƌĐƵůĂƚĞ<t&ĂƐŶĞĞĚĞĚ͘ ϯ͘ ^ĞƚWsĂŶĚĐŽŶĨŝƌŵĂƐďĂƌƌŝĞƌŝĨŶĞĞĚĞĚ͕EdƌĞĞ͕EhKW ĂŶĚƚĞƐƚƚŽϮϱϬͬϯ͕ϬϬϬƉƐŝ͘dĞƐƚĂŶŶƵůĂƌϮϱϬͬϯ͕ϬϬϬ ƉƐŝ͘ ZĞƚƌŝĞǀĞϯͲϭͬϮ͟dƵďŝŶŐ ϰ͘ WƵůůWs͕DhůĂŶĚŝŶŐũŽŝŶƚĂŶĚK>^͘ ϱ͘ WƵůůϯͲϭͬϮ͟ƚƵďŝŶŐĚŽǁŶƚŽƉƌĞͲƌŝŐĐƵƚĂƚΕϴϭϮϱ͛Z< Ă͘ /ĨƵŶĂďůĞƚŽƉƵůůƚƵďŝŶŐƚŽƐƵƌĨĂĐĞ͗ ŝ͘ Zh ůŝŶĞ͘ ŝŝ͘ Z/,ĂŶĚƐĞƚ/WŝŶϳ͟ĐĂƐŝŶŐďĞƚǁĞĞŶƚƵďŝŶŐƐĞĐƚŝŽŶƐ͘ ŝŝŝ͘ WdĨƌŽŵĂďŽǀĞƚŽĐŽŶĨŝƌŵĂƐďĂƌƌŝĞƌ͘ ŝǀ͘ ƵŵƉƐĂŶĚŽŶ/WƚŚƌŽƵŐŚƚƵďŝŶŐ͘ ǀ͘ ^ĞƚƌĞŵĂŝŶŝŶŐƚƵďŝŶŐďĂĐŬĚŽǁŶŽŶ/WƐĂŶĚ͘ ǀŝ͘ WƌŽĐĞĞĚƚŽĨƵůůƐƵďƐŝĚĞŶĐĞƌĞƉĂŝƌ ϳ͟ĂƐŝŶŐ^ƵďƐŝĚĞŶĐĞͲ^ƚLJůĞZĞƉĂŝƌ ϲ͘ ^ĞƚƐƚŽƌŵƉĂĐŬĞƌŽƌƉůƵŐŝŶϳ͟ĐĂƐŝŶŐĂŶĚWdƚŽĐŽŶĨŝƌŵĂƐĂďĂƌƌŝĞƌ ϳ͘ EKW ĂŶĚEƚƵďŝŶŐŚĞĂĚ͘ZĞŵŽǀĞƉĂĐŬŽĨĨƐ͘EhKW ƚŽƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐŚĞĂĚ͘ Ă͘ hŶĂďůĞƚŽƚĞƐƚKW ĨůĂŶŐĞďƌĞĂŬĂƚƚŚŝƐƉŽŝŶƚĚƵĞƚŽƌĞŵŽǀĂůŽĨƉĂĐŬŽĨĨƐ͕ǁŝůůƚĞƐƚĂĨƚĞƌϳ͟ŚĂƐďĞĞŶ ƌĞƚƌŝĞǀĞĚ͘ ď͘ /ĨŶĞĞĚĞĚ͕ZhŚLJĚƌĂƚŝŐŚƚĂŶĚĐƵƚĞdžĐĞƐƐĐĂƐŝŶŐ͘'ƌŽǁͬƐƚƌĞƚĐŚϳ͟ĐĂƐŝŶŐĂƐŶĞĞĚĞĚ͘^Ğƚϳ͟ĐĂƐŝŶŐŽŶ ƐůŝƉƐ͘ ϴ͘ Zh ͲůŝŶĞ͗ZƵŶ>ĂŶĚůŽŐϳ͟ĐĂƐŝŶŐĨŽƌKĐĞŵĞŶƚĨƌŽŵƌĐƚŝĐWĂĐŬũŽď͘ ϵ͘ Ƶƚϳ͟ĐĂƐŝŶŐĂďŽǀĞKĐĞŵĞŶƚŽďƐĞƌǀĞĚĨƌŽŵ>͕dKK,ĂŶĚƐƚĂŶĚďĂĐŬW ϭϬ͘ ^ƉĞĂƌƚŚĞĐĂƐŝŶŐĂŶĚĐŝƌĐƵůĂƚĞŽƵƚƚŚĞKƵŶƚŝůĐůĞĂŶ͘ ϭϭ͘ WKK,ĂŶĚůĂLJĚŽǁŶƚŚĞϳ͟ĐĂƐŝŶŐ͘ Ă͘ DĂŬĞĂĚĚŝƚŝŽŶĂůĐƵƚƐͬƌƵŶƐĂƐĚĞƚĞƌŵŝŶĞĚŶĞĐĞƐƐĂƌLJ ď͘ /ĨĂŶLJϯͲϭͬϮ͟ƚƵďŝŶŐƌĞŵĂŝŶƐŝŶƚŚĞǁĞůů͕ƌĞŵŽǀĞƚŽĐůĞĂƌǁĞůůďŽƌĞĨŽƌƌƵŶŶŝŶŐŽĨϳ͟ƚŝĞďĂĐŬ͘ ϭϮ͘ /ŶƐƚĂůůƚĞƐƚƉůƵŐĂŶĚƚĞƐƚĨůĂŶŐĞďƌĞĂŬƚŽϮϱϬͬϯϬϬϬƉƐŝ͘ZĞŵŽǀĞƚĞƐƚƉůƵŐ͘ ϭϯ͘ Z/,ǁͬƚĂŶĚĞŵƐƚƌŝŶŐŵŝůůƐƚŽŐĂƵŐĞƚŚĞϭϬͲϯͬϰ͟ĐĂƐŝŶŐĂƐŶĞĐĞƐƐĂƌLJƚŽŽďƚĂŝŶĚƌŝĨƚ͘ ϭϰ͘ Z/,ĂŶĚĚƌĞƐƐŽĨĨϳ͟ĐĂƐŝŶŐƐƚƵŵƉ͘ ϭϱ͘ ZhĐĂƐŝŶŐĐƌĞǁĂŶĚZ/,ǁͬŶĞǁϳ͟ĐĂƐŝŶŐ͕ ^ĞŵĞŶƚĞƌĂŶĚƐĞĂůŝŶŐŽǀĞƌƐŚŽƚ͘WdĐĂƐŝŶŐƚŽϮϱϬϬƉƐŝ͘ ϭϲ͘ ZhĐĞŵĞŶƚĞƌĂŶĚĐĞŵĞŶƚϳ͟džϭϬͲϯͬϰ͟ĂŶŶƵůƵƐƚŽƐƵƌĨĂĐĞ ϭϳ͘ WĞƌĨŽƌŵϯϬŵŝŶE&d͘EKW ͕ƉƵůůϳ͟ĐĂƐŝŶŐŝŶƚĞŶƐŝŽŶĂŶĚůĂŶĚŝŶƚŚĞƐůŝƉƐ͘ƵƚĞdžĐĞƐƐϳ͟ĐĂƐŝŶŐǁŝƚŚtĂĐŚƐ ĐƵƚƚĞƌĂŶĚŝŶƐƚĂůů/ƉĂĐŬŽĨĨƐ͘ ϭϴ͘ EhŶĞǁƚƵďŝŶŐŚĞĂĚĂŶĚKWƐƚĂĐŬ͘dĞƐƚĨůĂŶŐĞďƌĞĂŬƚŽϮϱϬͬϯϬϬϬƉƐŝ͘ ϭͲϬϱZtKWƌŽĐĞĚƵƌĞ <ƵƉĂƌƵŬ/ŶũĞĐƚŽƌ WΘZdƵďŝŶŐǁͬ^ƵďƐŝĚĞŶĐĞ WdηϭϳϵͲϬϵϱ WĂŐĞϮŽĨϯ ϭϵ͘ DŝůůĐĞŵĞŶƚͬƉůƵŐƐŝŶĐĞŵĞŶƚĞƌ͘WKK,ƐƚĂŶĚŝŶŐďĂĐŬĚƌŝůůƉŝƉĞ͘ ϮϬ͘ WƌĞƐƐƵƌĞƚĞƐƚƚŚĞĐĂƐŝŶŐƚŽϮϱϬϬƉƐŝ͕ĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϭ͘ Z/,ǁͬǁĂƐŚƐƚƌŝŶŐĂƐƐĞŵďůLJĂŶĚĐŝƌĐƵůĂƚĞŽƵƚƐĂŶĚŽŶƚŽƉŽĨZW͘WKK,ƐƚĂŶĚŝŶŐďĂĐŬĚƌŝůůƉŝƉĞ͘ ϮϮ͘ ZĞŵŽǀĞĂŶLJƌĞŵĂŝŶŝŶŐƉůƵŐƐŝŶϳ͟ĐĂƐŝŶŐ Ϯϯ͘ WĞƌĨŽƌŵĐůĞĂŶŽƵƚƌƵŶŝĨŶĞĐĞƐƐĂƌLJ /ŶƐƚĂůůϯͲЪ͟dƵďŝŶŐǁŝƚŚ^ƚĂĐŬĞĚWĂĐŬĞƌ Ϯϰ͘ DhϯͲϭͬϮ͟ĐŽŵƉůĞƚŝŽŶǁŝƚŚƉŽŽƌďŽLJŽǀĞƌƐŚŽƚ͕ƉĂĐŬĞƌ͕ŶŝƉƉůĞƐ͕ĂŶĚ'>DƐ͘Z/,ƚŽƚƵďŝŶŐƐƚƵď͘ Ϯϱ͘ KŶĐĞŽŶĚĞƉƚŚ͕ĐŝƌĐƵůĂƚĞ/ďƌŝŶĞ͕ƐƉĂĐĞŽƵƚĂƐŶĞĞĚĞĚ͕ůĂŶĚŚĂŶŐĞƌ͕Z/>^͕ĚƌŽƉΘZ͕ĂŶĚƐĞƚƉĂĐŬĞƌ͘ Ϯϲ͘ WƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚŽϯ͕ϱϬϬƉƐŝŐĨŽƌϯϬŵŝŶƵƚĞƐĂŶĚĐŚĂƌƚ͘ Ϯϳ͘ WƌĞƐƐƵƌĞƚĞƐƚŝŶŶĞƌĂŶŶƵůƵƐƚŽϯ͕ϬϬϬƉƐŝŐĨŽƌϯϬŵŝŶƵƚĞƐĂŶĚĐŚĂƌƚ͘ EKW͕EhdƌĞĞ Ϯϴ͘ ŽŶĨŝƌŵƉƌĞƐƐƵƌĞƚĞƐƚƐ͕ƚŚĞŶƐŚĞĂƌŽƵƚ^KsǁŝƚŚƉƌĞƐƐƵƌĞĚŝĨĨĞƌĞŶƚŝĂů͘ Ϯϵ͘ /ŶƐƚĂůůWs͘ ϯϬ͘ EKW ͘EhƚƌĞĞ͘ ϯϭ͘ WƵůůWsĂŶĚĨƌĞĞnjĞƉƌŽƚĞĐƚǁĞůů ϯϮ͘ ZDK͘ WŽƐƚͲZŝŐtŽƌŬ ϯϯ͘ ZƵŶ'>͘ ϯϰ͘ WƵůůĂŶLJƉůƵŐƐŽƌďĂůůͬƌŽĚƵƐĞĚĨŽƌƐĞƚƚŝŶŐƉĂĐŬĞƌ͘ ϯϱ͘ dƵƌŶŽǀĞƌƚŽŽƉĞƌĂƚŝŽŶƐ͘ ϭͲϬϱZtKWƌŽĐĞĚƵƌĞ <ƵƉĂƌƵŬ/ŶũĞĐƚŽƌ WΘZdƵďŝŶŐǁͬ^ƵďƐŝĚĞŶĐĞ WdηϭϳϵͲϬϵϱ WĂŐĞϯŽĨϯ General Well info: Wellhead type/pressure rating: Cameron Gen IV, 5M psi top flange x 3M bottom flange Production Engineer: Banabas Dogah Reservoir Development Engineer: Cody Keith Estimated Start Date: 8/22/2024 Workover Engineer: Shane Germann (406-670-1939 / shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above the bottom GLM, perform subsidence repair on 7” production casing, and install a new 3-1/2” completion and stacked packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CMIT-TxIA: Passed (3000 psig, 9/1/2023) MIT-OA: Failed (9/14/2019, leak at ~876’ RKB) IC POT & PPPOT – TBD TBG POT & PPPOT – TBD MPSP: 2442 psi using 0.1 psi/ft gradient Static BHP: 3108 psi / 6665’ TVD measured on 6/17/2023 (9.0 ppg EMW) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,588.0 1D-05 11/26/2021 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull stuck Slickline tools ooh 1D-05 8/21/2023 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for OA x Formation Communication. SC leak @ ~876' 3/12/2020 duffyp 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 Insulated 24" 16 15.06 32.0 80.0 80.0 62.58 H-40 WELDED SURFACE 10 3/4 9.95 31.0 3,076.8 2,709.2 45.50 K-55 BTC PRODUCTION 7 6.28 30.9 8,917.0 6,895.2 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 29.6 Set Depth … 8,281.8 Set Depth … 6,347.9 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD 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) 29.6 29.6 0.09 HANGER 8.000 CAMERON GEN IV TUBING HANGER 3.500 1,783.1 1,746.2 30.96 SAFETY VLV 5.937 CAMCO TRDP-IA-ENC SAFETY VALVE 2.812 8,156.2 6,241.1 32.64 GAS LIFT 5.793 CAMCO MMG-2 2.920 8,197.7 6,276.2 31.72 PBR 5.125 BAKER 80-40 PBR w/ 10' STROKE 3.000 8,211.4 6,287.9 31.62 PACKER 6.078 BAKER HB RETRIEVABLE PACKER 3.000 8,248.6 6,319.6 31.45 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 8,281.1 6,347.3 31.31 SOS 4.570 BAKER SHEAR OUT SUB 2.992 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) 8,156.0 6,240.9 32.64 OTHER 575 kg BiSN beads pumped into the IA (SCMT/GR found some above GLM at 8156' and some may be above packer) 11/13/2021 3.500 8,240.6 6,312.7 31.49 CATCHER Set 2.71" x 8' junk catcher on top of CA plug. 9/1/2023 0.000 8,248.6 6,319.6 31.45 TUBING PLUG Set 2.75" CA-2 Plug 9/1/2023 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) 8,156.2 6,241.1 32.64 1 GAS LIFT DMY RK 1 1/2 0.0 6/23/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,402.0 8,499.0 6,450.9 6,534.2 C-4, C-3, C-2, 1D-05 2/10/1980 4.0 IPERF 2 1/8" Enerjet Guns 8,654.0 8,672.0 6,668.0 6,683.5 A-5, 1D-05 6/10/1981 4.0 IPERF 2 1/8" Enerjet Guns 1D-05, 9/2/2023 2:51:18 PM Vertical schematic (actual) PRODUCTION; 30.9-8,917.0 IPERF; 8,654.0-8,672.0 IPERF; 8,402.0-8,499.0 TUBING PLUG; 8,248.6 CATCHER; 8,240.6 PACKER; 8,211.4 OTHER; 8,156.0 GAS LIFT; 8,156.2 SURFACE; 31.0-3,076.8 SAFETY VLV; 1,783.1 CONDUCTOR Insulated 24"; 32.0-80.0 KUP INJ KB-Grd (ft) 38.99 RR Date 3/4/1980 Other Elev… 1D-05 ... TD Act Btm (ftKB) 8,925.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292041700 Wellbore Status INJ Max Angle & MD Incl (°) 51.23 MD (ftKB) 4,700.00 WELLNAME WELLBORE1D-05 Annotation Last WO: End Date 6/19/1990 H2S (ppm) DateComment SSSV: TRDP 1D-05 Proposed Completion COMPLETION INFO OD (in) Nom. ID (in) MD (ft RKB) TVD (ft RKB) Weight (lb/ft)Grade Thread Conductor 16"15.06 80 80 62.58 H-40 Welded Surface 10-3/4"9.95 3077 2079 45.5 K-55 BTC Production 7"6.28 8917 6895 26 K-55 BTC Liner N/A Tubing 3-1/2"2.99 8125 6215 9.3 L-80 HYD563 PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface 3-1/2" Camco (1.5") MMG-2 GLM @ XXXX' RKB 3-1/2" x 7" SLB cut-to-release packer @ ~8040' RKB 3-1/2" X-nipple @ ~8104' RKB (2.813" ID) Poorboy Overshot over cut stub @ ~8125' RKB REMAINING COMPLETION LEFT IN HOLE 3-1/2" Camco (1.5") MMG-2 GLM @ 8156' RKB Baker 80-40 PBR @ 8198' RKB (4.00" sealbore) Baker HB Retrievable Packer @ 8211' RKB (3.00" ID) Camco D-nipple @ 8249' RKB (2.75" ID) Baker SOS @ 8281' RKB Surface Casing Production/Intermediate Casing Conductor A-5 sand perfs 8654' - 8672' RKB C-sand Perfs 8402-8499' MD SC leak @ 876' Possible PBR leak BiSN bead fill up to GLM JLC 3/15/2023 RBDMS JSB 032023 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϳϵϬϵϱϬ Ͳ^Ğƚ͗ϯϲϭϲϮJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct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y Meredith Guhl at 7:22 am, Sep 16, 2021 321-477 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.09.15 16:49:42 -08'00' 10-404X DSR-9/27/21 X DLB 09/16/2021 X VTL 9/28/21 dts 9/28/2021 JLC 9/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.28 13:33:56 -08'00' RBDMS HEW 9/28/2021 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner, Please find the enclosed 10-403 from ConocoPhillips Alaska, Inc. for KRU well 1D-05 (PTD# 179-095) proposing a Bismuth patch formed in the well’s inner annulus to remediate a seal assembly and packer leak. Please contact Stefan Weingarth at (907) 265-6038 if you have any questions. Sincerely, Stefan Weingarth Sr. Wells Engineer ConocoPhillips Alaska, Inc. 1D-05 SUMMARY OF PROPOSAL Bismuth patch for KRU 1D-05: KRU well 1D-05 (PTD# 179-095) is an Kuparuk injector with known TxIA communication through a leaking seal assembly and production packer. CPAI proposes the following scope below: 1. Pump Bismuth beads into the IA of 1D-05 above the production packer and seal assembly. 2. Run CBL to survey for Bismuth beads settling. 3. Hoist BiSN’s PRT toolstring to melt the beads into a solid patch. 4. Run CBL to log Bismuth patch. 5. Normal up 1D-05 for injection service. 6. Complete MITIA and IA-DDT. 7. Return 1D-05 to injection. CPAI proposes a 30-day monitor period on injection after the patch is formed. If no communication is observed on injection, we propose to return 1D-05 to normal WAG injection service. VTL 9/22/21 State witnessed MIT-IA required after stabilized injection. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,464.0 10/26/2014 1D-05 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Patch Assembly 1/23/2021 1D-05 fergusp Casing Strings Casing Description CONDUCTOR Insulated 24" OD (in) 16 ID (in) 15.06 Top (ftKB) 32.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.0 Set Depth (ftKB) 3,076.8 Set Depth (TVD) … 2,709.2 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 30.9 Set Depth (ftKB) 8,917.0 Set Depth (TVD) … 6,895.2 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 29.6 Set Depth (ft… 8,281.8 Set Depth (TVD) (… 6,347.9 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 29.6 29.6 0.09 HANGER CAMERON GEN IV TUBING HANGER 3.500 1,783.1 1,746.2 30.96 SAFETY VLV CAMCO TRDP-IA-ENC SAFETY VALVE 2.812 8,197.7 6,276.2 31.72 PBR BAKER 80-40 PBR w/ 10' STROKE 3.000 8,211.4 6,287.9 31.62 PACKER BAKER HB RETRIEVABLE PACKER 3.000 8,248.6 6,319.6 31.45 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,281.1 6,347.3 31.31 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,402.0 8,499.0 6,450.9 6,534.2 C-4, C-3, C-2, 1D-05 2/10/1980 4.0 IPERF 2 1/8" Enerjet Guns 8,654.0 8,672.0 6,668.0 6,683.5 A-5, 1D-05 6/10/1981 4.0 IPERF 2 1/8" Enerjet Guns Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 8,156.2 6,241.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/24/2020 Ext. Freud enbur g packin g Notes: General & Safety End Date Annotation 3/12/2020 NOTE: Waivered for OA x Formation Communication. SC leak @ ~876' 11/9/2014 NOTE: CLEANOUT TO 8645' RKB 8/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1D-05, 1/24/2021 6:47:35 AM Vertical schematic (actual) PRODUCTION; 30.9-8,917.0 IPERF; 8,654.0-8,672.0 IPERF; 8,402.0-8,499.0 SOS; 8,281.1 NIPPLE; 8,248.6 PACKER; 8,211.4 PBR; 8,197.7 GAS LIFT; 8,156.2 SURFACE; 31.0-3,076.8 SAFETY VLV; 1,783.1 CONDUCTOR Insulated 24"; 32.0-80.0 HANGER; 29.6 KUP INJ KB-Grd (ft) 38.99 Rig Release Date 3/4/1980 1D-05 ... TD Act Btm (ftKB) 8,925.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292041700 Wellbore Status INJ Max Angle & MD Incl (°) 51.23 MD (ftKB) 4,700.00 WELLNAME WELLBORE1D-05 Annotation Last WO: End Date 6/19/1990 H2S (ppm) DateComment SSSV: TRDP Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-20 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 1790950 E-Set: 34409 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: Tubing Patch 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 Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8925 N/A N/A Casing Collapse Conductor N/A Surface N/A Production N/A Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:9/11/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7224 Baker HB Camco TRDP-1A-ENC 8211 / 6288 1783 / 1746 Size Authorized Signature: 10/1/2020 3.5 Perforation Depth MD (ft): J-55 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 6451 - 6684 Perforation Depth TVD (ft):Tubing Size: 8402 - 8672 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 179-095 P.O. Box 100630, Anchorage, Alaska 99508 50029204170000' ConocoPhillips Alaska, Inc. KRU 1D-05 Kuparuk River / Kuparuk River Oil 6902 8464 PRESENT WELL CONDITION SUMMARY 6504 N/A Length TVD Burst 8282 MD N/A N/A N/A 2709 6895 3077 8886 80 80 8917 48 16 10.75 7 3046 Well Integrity & Compliance Specialist Jan Byrne / Dusty Freeborn n1617@conocophillips.com m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:56 pm, Sep 11, 2020 320-377 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨 宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰 宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷 宏宲宦室宷宬宲宱孽季安季宺宬宱宪孯季宎宒宆孯季宎宸害室宵宸宮 宇室宷宨孽季孵孳孵孳孰孳孼孰孴孴季孴學孽孷孹孽孵孺 安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne X X 10-404 DLB 09/16/2020 X VTL 9/17/20 DSR-9/15/2020Comm. 9/18/2020 dts 9/18/2020 JLC 9/18/2020 RBDMS HEW 9/21/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 11 September 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1D-05 (PTD 179-095) to set a retrievable tubing patch over a suspected tubing leak. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨 宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季 守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰 宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷 宏宲宦室宷宬宲宱孽季安季宺宬宱宪孯季宎宒宆孯季宎宸害室宵宸宮 宇室宷宨孽季孵孳孵孳孰孳孼孰孴孴季孴學孽孷孹孽孳孺 安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne Proposal Summary KRU 1D-05 (PTD 179-095) (AIO 2C.078) was reported to the AOGCC on 7/5/2020 for exhibiting TxIA communication. The well was secured with a downhole plug and passed a MITT, CMIT TxIA , and IA DDT. The well was brought on injection and shortly after started to exhibit slow IAP build up. While online the well passed an MITIA, but fails an IA DDT. With this information the most likely leak source is the PBR which is being affected by injection fluid temperature only while on injection. CPAI intends to set a 3.5”, Paragon 2 Packer, ~34’ OAL, retrievable patch with expansion joint over the PBR and production packer. Below is the planned work, the work may change slightly as wellbore conditions dictate. Well Work Justification & Objectives (and date required if appropriate): 1D-05 appears to have TxIA communication only when the well is online. While shut in the well passed MITs and DDTS. While online the well passed an MITIA, but the IAP continues to build up slowly. The IAP increase is too slow to detect by logging. The most likely leak source is the PBR which is being affected by injection fluid temps. This procedure requests to set a tubing patch with expansion joint across the PBR in attempt to eliminate the TxIA communication observed while online. Risk/Job Concerns: Well appears to have TxIA communication only while online Well has known subsidence issues. SC leak at 876'. IPC joints around PBR and Packer, refrence in tubing tally. DO NOT PERFORM WORK UNTIL 10-403 HAS BEEN APPROVED Steps: Relay 1. RIH to brush and flush tubing down to below packer at 8211'. 2. RIH to drift dummy patch 2.72" OD and 34' OAL (2 sections, 4' and 30'). 3. RIH to set lower P2P at 8222'. 4. RIH with test tool to sting into lower P2P and perform MITT to 3000 psi. Record TIOs. 5. RIH with upper P2P/Expansion joint assembly to sting into lower P2P. Sheer expansion joint and pull up 2' and set upper P2P. Patch should be 30' element to element after sheering expansion joint which will set the upper P2P at 8192'. 6. Perform MITIA to 3000 psi. Record TIOs. 7. RDMO, turn well over to Operations, will require state witnessed MITIA once BOI and stabilized (notify DHD supervisor). require state witnessed MITIA o Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,464.0 10/26/2014 1D-05 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Catcher & Plug 8/25/2020 1D-05 zembaej Casing Strings Casing Description CONDUCTOR Insulated 24" OD (in) 16 ID (in) 15.06 Top (ftKB) 32.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.0 Set Depth (ftKB) 3,076.8 Set Depth (TVD) … 2,709.2 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 30.9 Set Depth (ftKB) 8,917.0 Set Depth (TVD) … 6,895.2 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 29.6 Set Depth (ft… 8,281.8 Set Depth (TVD) (… 6,347.9 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 29.6 29.6 0.09 HANGER CAMERON GEN IV TUBING HANGER 3.500 1,783.1 1,746.2 30.96 SAFETY VLV CAMCO TRDP-IA-ENC SAFETY VALVE 2.812 8,197.7 6,276.2 31.72 PBR BAKER 80-40 PBR w/ 10' STROKE 3.000 8,211.4 6,287.9 31.62 PACKER BAKER HB RETRIEVABLE PACKER 3.000 8,248.6 6,319.6 31.45 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,281.1 6,347.3 31.31 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,402.0 8,499.0 6,450.9 6,534.2 C-4, C-3, C-2, 1D-05 2/10/1980 4.0 IPERF 2 1/8" Enerjet Guns 8,654.0 8,672.0 6,668.0 6,683.5 A-5, 1D-05 6/10/1981 4.0 IPERF 2 1/8" Enerjet Guns Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 8,156.2 6,241.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/12/2020 Notes: General & Safety End Date Annotation 3/12/2020 NOTE: Waivered for OA x Formation Communication. SC leak @ ~876' 11/9/2014 NOTE: CLEANOUT TO 8645' RKB 8/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1D-05, 8/26/2020 8:28:44 AM Vertical schematic (actual) PRODUCTION; 30.9-8,917.0 IPERF; 8,654.0-8,672.0 IPERF; 8,402.0-8,499.0 SOS; 8,281.1 NIPPLE; 8,248.6 PACKER; 8,211.4 PBR; 8,197.7 GAS LIFT; 8,156.2 SURFACE; 31.0-3,076.8 SAFETY VLV; 1,783.1 CONDUCTOR Insulated 24"; 32.0-80.0 HANGER; 29.6 KUP INJ KB-Grd (ft) 38.99 Rig Release Date 3/4/1980 1D-05 ... TD Act Btm (ftKB) 8,925.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292041700 Wellbore Status INJ Max Angle & MD Incl (°) 51.23 MD (ftKB) 4,700.00 WELLNAME WELLBORE1D-05 Annotation Last WO: End Date 6/19/1990 H2S (ppm) DateComment SSSV: TRDP Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Monday, August 31, 2020 10:28 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1 D-05 (PTD 179_-095) Report of suspect TxIA communication Attachments: 1 D-05 90 day TIO plot 8-30-20.pdf, 1 D-05 schematic.pdf Chris, KRU 1D-05 (PTD 179-095) was brought online post diagnostics & exhibiting suspect TxIA communication. CPAI intends to leave the well online until we can complete a new round of diagnostic, the diagnostics will be conducted as soon as work load allows. Once the diagnostics have been completed the well will be shut in & secured. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the current 90 day TIO plot and well bore schematic. Matt Miller Filling in for Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 354-5520 WELLS TEAM Coroc(`'NNgx Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, August 22, 2020 5:45 PM To: Wallace, Chris D (CED) Cc: Well Integrity Compliance Specialist CPF1 & 2; CPA Wells Supt Subject: RE: 1 D-05 (PTD#179-095) Update of initial diagnostics Attachments: 1 D-05 Diagnostic Tests Aug 20.xlsx Chris - 1D -05 (PTD# 179-095) diagnostics have been completed. The well was secured and passed a MIT -T, CMIT-TxIA and IA DDT. An MIT -IA was performed but deemed inconclusive due to pressure building in the tubing string. It is suspected that the pressure gain was not coming from the IA because during the IA DDT the tubing pressure had a continual pressure increase with the IA pressure lower than the tubing pressure. It is suspected that the plug has potentially lost integrity so it is CPAI's intention to remove the plug and return the well to injection. Once online and stabilized an AOGCC witnessed MIT -IA will be performed. Attached is a 10-426 form with the diagnostics tests for your reference. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Cor"CZONd+ps Fro Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tue , July 7, 2020 7:03 PM To: Wallace, Ch ' (CED) <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <ni030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com Subject: 1D-05 (PTD#179-095) Update of initial diagnostics �a. Chris - 1D -05 (PTD# 179-095) initial diagnostics were completed yesterday. The results of the test yielded an inconclusive MIT - IA due to abnormal pressure swings during the test and a Bailing IA DDT. The pack off testing all passed and showed no signs of communication during the tests. The well was shut in` tthat time and it is CPAI's intention to secure the well with a down hole plug and re -perform the MIT -IA and IA DDT with ^the tubing in static conditions to attempt to obtain accurate MIT-IA/DDT data. Depending on the results of the MIT -IA and'1A IDDT, the proper notifications for continued injection or repair will be submitted at that time. Attached is the 10-426 for the �onclusive diagnostics MIT -IA. Please let me know if you have any questions or disagree with the plan. .. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Conoco` lips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, July 7, 2020 7:03 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 1D-05 (PTD#179-09_5) Update of initial diagnostics Attachments: 1D-05 Diagnostic MIT -IA 6 July 20.xlsx Chris - 1D -05 (PTD# 179-095) initial diagnostics were completed yesterday. The results of the test yielded an inconclusive MIT - IA due to abnormal pressure swings during the test and a failing IA DDT. The pack off testing all passed and showed no signs of communication during the tests. The well was shut in at that time and it is CPAI's intention to secure the well with a down hole plug and re -perform the MIT -IA and IA DDT with the tubing in static conditions to attempt to obtain accurate MIT-IA/DDT data. Depending on the results of the MIT -IA and IA DDT, the proper notifications for continued injection or repair will be submitted at that time. Attached is the 10-426 for the inconclusive diagnostics MIT -IA. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM From: Well Integrity mpliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, July 5, 202154:57 PM To: Wallace, Chris D (CED) <cs.wa[lace@alaska.gov> Cc: CPA Wells Supt <n1030@conobQ1 hi lips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> \\\ Subject: 1D-05 90 Day TIO 5 July 20.xism \, Chris- \� 1D-05 was reported by operations with suspected T%IA mmunication. Initially the operator bled the IA several time in response to a thermal increase in injection fluids. However,'the IA has continued to build beyond what CPAI would believe to be a realistic thermal increase in pressure. DHD will be s eduled to conduct the initial diagnostics while the well is still online. Depending on the results of the diagnostics the prop notifications for continued injection or repair will be submitted at that time. Attached is a copy of the 90 day TIO plot you have any questions or disagree with the plans. Cheers, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 schematic. Please let me know if Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Sunday, July 5, 2020 4:57 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 1 D-05 90 Day TIO 5 July 20.xlsm Attachments: 1 D-05.pdf; 1 D-05 90 Day TIO 5 July 20.pdf Chris - 1D -05 was reported by operations with suspected TxIA communication. Initially the operator bled the IA several time in response to a thermal increase in injection fluids. However, the IA has continued to build beyond what CPAI would believe to be a realistic thermal increase in pressure. DHD will be scheduled to conduct the initial diagnostics while the well is still online. Depending on the results of the diagnostics the proper notifications for continued injection or repair will be submitted at that time. Attached is a copy of the 90 day TIO plot and wellbore schematic. Please let me know if you have any questions or disagree with the plans. Cheers, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, February 25, 2020 11:35 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPH & 2 Subject: RE: KRU 1 D-05 (PTD 179-095) Report of failed MITOA Attachments: —TD -05 90 Day TIO plot .JPG Chris, Kuparuk injector 1D-05 (PTD# 179-095) has completed the 30 -day monitor period. The surface casing leak at 876' did not display any indications that it effects the tubing or inner casing as barriers. The OA pressure has stabilized around the 200 -psi mark. CPAI intends to apply for administrative approval for continued water injection only due to a deep surface casing leak. The well was shut in for -10 hours for pigging operations but has since been returned to injection and will remain on water injection only during the administrative approval application process. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the current 90 day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM ca,aoRan�� From: Well Integrity Compliance Specialist CPFI & 2 Sent. unday, September 15, 2019 10:38 AM To:'chnallace@alaska.gov' <chris.wallace@alaska.gov> Cc: CPA We Supt <nl030@conocophillips.com> Subject: KRU 11DD-O,�(PTD 179-095) Report of failed MITOA Chris, KRU injector 1D-05 (PTD 179-095) fa d an MITOA yesterday. A Surface Casing Leak Detect was performed and confirmed a surface casing leak depth o 76'. A passing MITIA and passing pack off tests were achieved. The well has been shut in since June 29, 2019. The plan i's -to wait for a Water Line Upgrade expected to be completed in a few months, then the well will be brought on water i 'ecticn for a 30 day monitor period. The proper paperwork for continued injection or corrective action will be subm' eonce the monitor period has been completed. A wellbore schematic, TIO trend, and 10-426 are attached. Please let us know if you disagree or have any questions with this n. Regards, A Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, September 15, 2019 10:38 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 11D-05 (PTD 179-095) Report of failed MITOA Attachments: MIT KRU 1 D-05 Diagnostic ggnostic MITIA 09-14-19.xlsx; 1 D-05.pdf; 1 D-05 90 day TIO trend 9.15.19.pdf Chris, KRU injector 1D-05 (PTD 179-095) failed an MITOA yesterday. A Surface Casing Leak Detect was performed and confirmed a surface casing leak depth of 876'. A passing MITIA and passing pack off tests were achieved. The well has been shut in since lune 29, 2019. The plan is to wait for a Water Line Upgrade expected to be completed in a few months, then the well will be brought on water injection for a 30 day monitor period. The proper paperwork for continued injection or corrective action will be submitted once the monitor period has been completed. A wellbore schematic, TIO trend, and 10-426 are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 VVF� TEAM [ o`Nips MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, August 27, 2018 Jim Re P.I. Supgrvisor ' `� 3� I� SUBJECT: Mechanical Integrity Tests 1 CONOCOPFULLIPS ALASKA, INC. 1D-05 FROM: Brian Bixby KUPARUK RIV UNIT 1D-05 Petroleum Inspector Src: Inspector Reviewed Bx: P.I. Sup"Y'1- NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1D-05 API Well Number 50-029-20417-00-00 Inspector Name: Brian Bixby Permit Number: 179-095-0 Inspection Date: 8/26/2018 Insp Num: mitBDB180827073008 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ID -05 Type Inj W -'TVD 6288 j Tubing 2576 2578 2578 2578 ' PTD 1790950 Type Test SPT Test psi 1572 IA j 1530 2050 2020 2010 ' BBL Pumped: 0.8 BBL Returned: 0.8 pA 252 252 252 252 - Interval axRTST p/F P Notes: SES11+MV N c) v 0 8 Zola Monday, August 27, 2018 Page I of 1 0 Keit l b - c 5 Pm 179 o% -o Regg, James B (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> -7/16 (cg Sent: Sunday, July 15, 2018 1:18 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk MITs Attachments: MIT KRU 1 D Pad Non -Injecting 7-13-18.xlsx; MIT KRU 1 D PAD 7-13-18.xlsx; MIT KRU 2K-32 07-13-18.xlsx Attached are the MIT forms for the tests performed in Kuparuk on 7-13-18. Please let me know if there are any questions. Kelly Lyons / Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SCANNED AUG 0 6 1018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reco0alaska.00v: AOGCC.InsoectorsCcaalaska.aow phoebe.brooks0alaska.00v OPERATOR: ConoccPhillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk/ KRU / 1 D Pad DATE: 07/13/18 OPERATOR REP: VanCamp/Richwine AOGCC REP: Non -Witnessed chns.wallaceCctialaska. oov Well 1D-06 - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1790950 Type Inj N Tubing 225 225 225, - Type Test P Packer TVD 6288 BBL Pump 2.7 IA 110 1820 1700 • Interval 4 Test psi 1572 BBL Return 0 OA 200 200 200 Result F Notes: test #1 No bleed back volume. Re -Pressured IA for second test. - Well 1D -O6 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1790950 Type Inj N Tubing 225 - 225 _ 225 - 225 - Type Test P Packer TVD 6288 BBL Pump 0.2 IA 1700 1820 - 1790 - 1780 - Interval 4 Test psi 1572 - BBL Return 2.7 - OA 200 - 200 - 200 - 200 Result P Notes: test #2 Re -pressurized IA for second test. Well 1D-107 pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD 2001770 Type Inj N Tubing 2250 2250 1875 Type Test P Packer TVD 3675 BBL Pump 3.4 IA 15 2300 180 Interval 4 Test psi 1500 BBL Return 1 0.9 OA Result F Notes: Single casing well. Established LLR of 1.7 gallons per min at 2300 psi Well 1D-07 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1791120 Type Inj N Tubing 550 550 550 550 Type Test P Packer TVD 5928 BBLPump 1.7 IA 25 1815 1730 1720 Interval 4 Test psi 1500 BBL Return 1.7 OA 350 505 513 513 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes W = Water G = Gas S = Slurry I = Industrial Wastewater N = Not Injecting TYPE TEST Codes INTERVAL Cotler P = Pressure Test I = Initial Test O = Other (describe in Notes) 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Form 10-426 (Revised 01/2017) MIT KRU I Pad Non -Injecting 7-13-18 Result Codes P = Pass F = Fail I = Inconclusive 1�' MEMORANDUM TO: Jim Regg "j'lo 14 P.I. Supervisor G( FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 04, 2014 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID -05 KUPARUK RIV UNIT ID -05 Src: Inspector Reviewed By: P.I. Supr `-)S ---- NON -CONFIDENTIAL Comm Well Name KUPARUKRIV UNIT 1D-05 API Well Number 50-029-20417-00-00 Permit Number: 179-005-0 Insp Num: mitJJ140715163224 Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 7/13/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell ID os Type Inj w - TVD 6288 Tubing j 2185 2153 - 2168. 2148 PTD 1790950 Type Test SPT Test psi - - --- — — 4YRTST 1572 - IA 657 2800 - I 2720 2700 - ---- — — --- 323 - 323 - 323 Interval �P/FP 0-322 Notes: I well inspected, no exceptions noted. SCAt4NED OCT 3 02014 Monday, August 04, 2014 Page I of 1 i ConocoPhillips Aaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7t' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: inH'vg5 C: Ei 2 3 2010 t !' & jw cv&n Anchow 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 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 August 16 and September 9, 2010. The corrosion inhibitor/sealant was pumped September 10 thru September 14, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field n�+o o14014n 1C. 1D. 1E. 1G & 1L PAD Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of Cement top off cement date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1A-07 50029206580000 1811370 21" NA 21" NA 1.7 9/14/2010 1A=10 - *00 7 0 0 1,4811600 22" NA 22" NA 2 9/14/2010 1C-05 5002 , 0 500000 1810050 34'8" 4.12 17" 8/16/2010 1.7 9/10/2010 1C-12 50029227190000 1961770 SF NA 18" NA 2.5 9/10/2010 1C-104 50029230760000 2020610 50" NA 50" NA 7.6 9/10/2010 1C-109 50029230470000 2012030 5" NA 5" NA 4.25 9/10/2010 ID -01 50029203930000 1790590 45" 0.48 13" 8/16/2010 2.5 9/10/2010 1D-02 50029204290000 1791110 12" NA 12" NA 2.5 9/10/2010 1 D -04A 50029204160100 2080840 2" NA 2" NA 1.4 9/10/2010 1 D-05 50029204170000 1790950 3" NA 3" NA 1.7 911112010 1D-112 50029229190000 1981830 12" NA 12" NA 11.9 9/11/2010 1D-114 50029229080000 1981590 8' 1.07 14" 8/16/2010 8.6 9/11/2010 1D-118 50029228390000 1972290 23" NA 23" NA 4.5 9/11/2010 1D-124 50029228330000 1972170 22' 4.75 42" 8/16/2010 13.6 9/11/2010 1D-135 50029228160000 1971840 22" NA 22" NA 4.1 9/11/2010 1E-12 50029207360000 1820600 33'3" 4.35 25" 9/8/2010 5.1 9/14/2010 IE -14 50029207510000 1820790 6'8" 1.00 4" 9/8/2010 1.7 9/14/2010 1E-18 50029209040000 1830160 27'9" 3.00 24" 9/8/2010 5.1 9/14/2010 1 E-20 50029208950000 1830050 16'9" 4.00 26" 9/8/2010 5.95 9/14/2010 IE -26 50029208400000 1821660 5'9" 0.50 12" 9/8/2010 2.5 9/14/2010 1 E-27 50029208370000 1821630 13'4" 2.50 7" 9/8/2010 1.7 9/14/2010 1G-01 50029208050000 1821300 12'5" 1.50 22" 9/8/2010 4.25 9/12/2010 1G-02 50029208130000 1821380 21" NA 8" NA 1.7 9/12/2010 1G-03 50029208240000 1821490 11'10" 3.25 14" 9/8/2010 2.5 9/13/2010 1 G-04 50029208350000 1821610 76' 9.50 49" 9/8/2010 15.3 9/13/2010 1G-05 50029209080000 1830200 37" NA 37" NA 7.65 9/13/2010 1G-06 50029208900000 1822200 23" NA 23" NA 1.7 9/13/2010 1G-07 50029208720000 1822010 37.6 4.25 21" 9/8/2010 4.25 9/13/2010 1 G -08A 50029208490100 2041010 227" 2.25 15" 9/8/2010 2.5 9/13/2010 1G-09 50029210010000 1831240 31" NA 31" NA 2.5 9/12/2010 1G -10A 50029210030100 1961400 31" NA 31" NA 6.8 9/12/2010 1G-11 50029210080000 1831310 21" NA 21" NA 2.5 9/12/2010 1G-12 50029210090000 1831320 25" NA 25" NA 1.7 9/12/2010 1G-14 50029210170000 1831410 10'3" 2.00 19" 9/8/2010 3.4 9/12/2010 1G-15 50029210240000 1831480 43'3" 5.25 41" 9/8/2010 10.2 9/12/2010 IG -16 50029210310000 1831550 9'6" 1.00 6" 9/8/2010 1.7 9/12/2010 1 L -03A 50029211820100 1990370 44'8" 6.00 15" 9/8/2010 6.8 9/11/2010 1L-07 50029211710000 1841450 7' 1.50 12" 9/8/2010 3.4 9/11/2010 1L-10 50029220260000 1900350 11' 1.50 16" 9/8/2010 5.1 9/11/2010 1L-14 50029221320000 1910100 14'4" 3.00 14" 9/8/2010 5.1 9/11/2010 1L -20A 50029220270100 2000360 17" NA 17" NA 1.7 9/11/2010 1L-22 50029221140000 1901640 13" NA 13" NA 11.9 9/11/2010 1 L -25A 50029221740100 2051750 32" NA 32" NA 15.3 9/11/2010 MEMORANDUM TO: Jim Regg ~ P.I. Supervisor h~~ ~ 7~2~'1 FROM: $ob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 D-OS KUPARUK RIV iJNIT 1D-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~S~ Comm Well Name: KUPARUK RIV UNIT 1D-OS API Well Number: 50-029-20417-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100718150849 Permit Number: 179-095-0 Inspection Date: 7/16/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We117 1D-os' Type In j W TVD I 6288 ~. IA 861 1744 1695 1685 P.T.DI 1790950 ypeTest I SPT ~ Test psi 1744 it QA 306 ~ 306 306 307 Interval axxTST p~F P Tubing ]o7z lo7a ]071 ]068 Notes: i µ~~ : r~ecl ~ ~~- rs~Z Ps Thursday, July 22, 2010 Page 1 of 1 ConocoPhillips November 13, 2008 Robert Christensen Production Engineering Specialist. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 Tom Maunder, P.E. Senior Petroleum Engineer ~f~"~~` ~~~ ~~~$ State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 C~' Anchorage, AK 99501 } 1 V~~ Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has begun Gas Injection is association with the Kuparuk River Oil Pool 1D FOR Expansion. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for Wells 1D-O5, 1D-06, 1D-10, 1D-11, 1D-11L1, and 1D-11L2. This report records the commencement ofwater-alternating-gas injection service. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, Robert D. Christensen Attachments ~a ,,,, ~.~\ ~ s ~~~.a~ ~ v~ ~C-~ ~, ~~~~C s y s~c~ ~`~~ v ~~}~ ~~~'rt Li•~~s n®~r 'CQ ~~ ` i • ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS - 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^. 1D EORX Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ f,ri~~C~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillipS Alaska, InC. Development ^ Exploratory ^ 179-095 ~ 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20417-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' 1 D-05 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Unit / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8930' feet true vertical 6906' feet Plugs (measured) Effective Depth measured 8872 feet Junk (measured) true vertical 6856 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" ao' 80' SURFACE 2972' 10-3/4" 3077' 2709' PRODUCTION 8812' 7" 8917' 6895' Perforation depth: Measured depth: 8402' - 8499'; 8654' - 8672' true vertical depth: 6451' - 6534'; 6668' - 6684' Tubing (size, grade, and measured depth) 3-1/2", J-55, 8281' MD. q .. .-..-. ~. Packers & SSSV (type & measured depth) Packer = Baker'HB' Packer = 8211' i ` `.._ ' ~~ ~ `~~ ~~r'°~` SSV = Camco TRDP-1A-ENC SSV = 1783 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 3628 ~ 943 1884 Subsequent to operation 5350 415 1799 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAGQ ' GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact Bob Christensen/Vacant Printed Name Rob D. hr' sen ,~ Title Production Engineering Technician Signature - Phone: 659-7535 Date ~ ~ / 2 Form 10-404 Revised 04/2004 OR161NAL ~l.. r~' Submit Ori ' n~~~l~~ ~- • 1 D-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/01/08 Commenced 1D EORX WAGIN Injection 07/10/06 1 D- 05, State witnessed (Jeff Jones), 4-year MITIA -passed. Initial T/I/0= 2025/900/480, Pressured up the IA to 2590 psi. Start MITIA T/I/0= 2080/2590/480, 15 min. reading T/I/0= 2100/2560/480, 30 min. reading T/I/0= 2090/2540/480 • ConocoPhillips Alaska, Inc. KRU 1 D-05 1 D-05 API: 500292041700 WeII Type: INJ An le TS: 31 deg @ 8402 _ SSSV Type: TRDP __ Orig _ _ __ __ 3/4/1980 Angle @ TD: 30 deg @ 8930 Com letion: Annular Fluid: Last WJO: 6/19/1990 Rev Reason: TAG SLM Reference Lo Ref Lo Date: Last U date: 10/2/2007 sssv Last Ta : 8487 SLM TD: 8930 ftKB (1783-17ea' OD:3 500) Last Ta Date: 9/28/2007 Max Hole An le: 51 de 4700 . ruewc Casin Strin -ALL STRINGS ~: (o-x261, Descrl tlon Size To ___ Boriom ND Wt Grade Thread oo:3.soo, ID:2.992) CONDUCTOR - 16.000 0 - 80 80 - ------ 62.58 - H-40 - - P O SUR. CASING 10.750 0 3077 2709 45.50 K-55 R D. cnsiNG -- PROD. CASING 7.000 0 _ - 8917 6895 26.00 K-55 (0-8917' T bi St i TUBING Wt26.oo) u n r n Size__ Top Bottom TVD Wt Grade_ Thread 3.500 0 8281 6347 9.30 J-55 EUE-MOD Perforations Summa ---- Interval -- --- TVD ~ _ Zone Status Ft SPF Date_ - TYee _ __ __Comment Gas LiR andrel/Dummy 8402 - 8499 6451 - 6534 C 4,C-3,C-2 97 _ 4 _2/10/1980 IPERF 2 1/8" Enerjet Guns _ valee 1 8654 - 8672 6668 - 6684 A-5 18 4 6/10/1981 IPERF 2 1/8" Ener'et Guns (615s-a157' Gas Lift Mandrels/Valves OD:5.7s7) St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO `Date Run Vlv __ _ __ _ _ Cmnt _ __ 1 8156 6241 Camco MMG-2 DMY 1.5 TG 0.000 0 6/27/1990 Other lu s, a ui etc JEWELRY ,Z- De th ND T e _ __ Descrlptlon ID PaR -- 1783 1746 SSSV Camco TRDP-IA-ENC 2.813 (stsa-ales' OD:3 500) 8198 6276 PBR Baker 3.000 . 8211 6288 PKR Baker'HB' RETR. 3.000 8248 6319 NIP Camco'D' Ni le NO GO 2.750 8281 6347 SOS Baker 2.992 8282 6348 TTL 2.992 PKR (8211-8212, OD:6.156) NIP (8248-8249, OD:3.500) SOS (8281282, • OD:3.500) TTL (8282283, OD:3.500) Perf (8402499) _ PeA (8654-8872) 12/06/06 Schlumbel'gel' NO. 4061 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth t~ ....': ; ¡ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U1-~ tiC) -Ögb Field: Kuparuk . Well Job# Log Description Date BL Color CD 1G-16 11486083 INJECTION PROFILE 11/26/06 1 1C-133 11486084 INJECTION PROFILE 11/27/06 1 1R-20 11486085 LDL 11/28/06 1 10-05 11486086 INJECTION PROFILE 11/29/06 1 10-03 N/A SBHP 11/25/06 1 1 0-09 N/A SBHP 11/25/06 1 2T-18 11477636 INJECTION PROFILE 12/01/06 1 1 R-03A 11483497 INJECTION PROFILE 11/30/06 1 2X-03 11483499 INJECTION PROFILE 12/02/06 1 1E-04 11477639 INJECTION PROFILE 12/04/06 1 I . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: J. R ,~ ~I 1m egO" / ;;~ I "7~í~ '" \<---. (:/1-1 '! (..;0 {ei("., P.I. Supervisor . '. DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA lNC 10-05 KUPARUK RIV UNIT 10-05 11 ~-Dq5 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv SBì2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-05 API Well Number 50-029-20417-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ0607II181420 Permit Number: 179-095-0 Inspection Date: 7/10/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 10-05 !Type Inj. ! w I TVD I I 6288 i IA 900 2590 2560 2540 I P.T. I 1790950 !TypeTest i SPT i Test psi I 1572 ¡ OA I 480 480 480 480 V T b' I 2025 2080 2100 2090 Interval 4YRTST PIF P U mg' , Notes 4.8 bbls diesel pumped. I welI house inspected; no exceptions noted. '~.... .. ..... . ~ ~ :h,~,,""\,'!Jj\1.¡';;;t . ~1 Wednesday, July 12,2006 Page I of I SSSV (1783-1784. 00:3.500) TUBING (0-8281, 00:3.500, 10:2.992) PROD. CASING (0-8917, 00:7.000, WI: 26. 00) Gas Lift mdrellDummy Valve 1 (8156-8157, 00:5.797) PBR (8198-8199. OD:3.500) PKR (8211-8212, 00:6.156) NIP (8248-8249, OD:3.500) SOS (8281-8282, 00:3.500) m (8282-8283, 00:3.500) Perf (8402-8499) Perf (8654-8672) e ConocoPhiUipsAlaska, inc. 10-05 e KRU 1 D-05 API: 500292041700 SSSV Type: TRDP Cameo TRDP-1 A-ENC Baker Baker 'HB' RETR. Cameo '0' Ni Ie NO GO I Baker STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Op~alJ~:~s performed- Operat~ shutdown_ Stimubte_ Plugging_ Perlorate _ ~ tul~ng _ Alter casing ~ Repair wel~ _ Other _:X TPROD to WAG lf~ecflon 2. Name of Operator Phillips Alaska, Inc. 3 Address P. O. Box 100360 Anchorage, AK 99510-0360 4 Locabon of well at surface 239' FNL, 601' FEL, Sec. 23, T11 N, R10E, UM 5 Type of Well- Development _ Exploratory _ Strat~jraph~c _ Servlce__X (asp' s 560488, 5959424) 6. Datum elevabon (DF or KB feet) RKB 105 feet 7 Unmt or Property name Kuparuk Umt 8 Well number 1D-05 At top of producbve ~nterval 1256' FNL, 1180' FEL, Sec. 24, T11N, R10E, UM At effecbve depth At total depth 1312' FNL, 919' FEL, Sec. 24, T11N, R10E, UM (asp's 565457, 5958392) 9 Permit number / approval number 179-095 / 300-276 10 APl number 50-029-20417 11 F~eld / Pool Kuparuk Oil Pool 12 Present well cond~bon summary Total depth measured true verbcal Effective depth measured true vertical Casing Length Size CONDUCTOR 80' 16" SUR CASING 2972' 10-3/4" PROD CASING 8812' 7" 8930 feet Plugs (measured) 6906 feet feet Junk (measured) feet Cemented Measured Depth 240 sx AS II 80' 800 sx Fondu & 1500 sx AS II 3077' 2800 sx se~ stress 8917' True vertical Depth 80' 2709' 6895' Perforabon depth measured 6402-8499; 8654-8672 true vertical 64,51-6534; 6668-6684 Tubing (s~ze, grade, and measured depth) 3-1,~', 9.:~f, J-55 TI3g ~ 828t" MD. RECEIVED NOV 6 2001 Packers & SSSV (type & measured depth) BAKER 'HB' RETR @ 8211"MD CAMCOTRDP'-IA-ENC @ 1'783' MD. 13 St~mulatJon or cement squeeze summary Intervals treated (measured) N/A Treatment descrmpbon including volumes used and hnal pressure 14 Representabve Dady Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Pnor to well operabon 40 2714 4330 550 200 Subsequent to operation .............................. 2472 ~: 575 ............ _ ~4 15 Attachments Copras of Logs and Surveys run _ Dady Report of Well Operabons ._X O~t__ Gas m Suspended __ Service _X WAG Injecbon 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gned ~ T~tle Production Eng~neenng Supervmor Jeff A Spe Questions? Call Jeff Spencer 659-7226 Date / ~ ~)/~/ Prepared by Robert Chflst~nsen 6~9-753~ Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 1 D-05 (~ DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/311001Converted from temporary oil production to EOR Injection I I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Alter casing __ Change approved program _X_ Suspend __ Repair well __ Pull tubing __ Operal]on Shutdown __ Reenter suspended well __ Plugging __ Time extension __ Vanance __ Perforate __ Sbmulate __ Olher __ 2. Name of Operator:. ARCO Alaska, Inc. 3. Address: P.O Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 243' FNL, 600' FEL, Sec 23, T11N, R10E, UM At top of productive interval: 1256' FNL, 1180' FEL, Sec 24, T11N, R10E, UM At effective depth: 1308' FNL, 919' FEL, Sec 24, T11N, R10E, UM At total depth: 1315' FNL, 919' FEL, Sec 24, T11N, R10E, UM 5. Type of Well: Development __ Expk>r=*o~/__ Stratagrap~c __ Service X..~=. 6. Datum of alavation (DF or KB) 10S' RKB 7. Unit or Property: Kuparuk RNer Unit 8. Well number: 1 D-05 9. Pen~ilv~umber: 79:95/9O-353 10. APl number: 50-029-20417-00 :11. Field/Poot: Kuparuk R~ver Reid/Od Pool feet 12. Present well condition summary Total Depth: measured true vertical 8930 feet Plugs (measured) none 6906 feet Effective Depth: measured 8872 feet Junk (measured) none true vertical 6856 feet Casing Length S~ze Conductor 72' 16" Su trace 3043' 10 -3/4" Production 8881' 7" Liner Cemented Measured depth True vertical depth 240 Sx AS II 72' 72' 800 Sx Fondu & 1500Sx AS Il 6077' 2710' 2800 Sx Self Stress 8916' 6894' Perforation Depth measured 8402'-8499', 8654'-8672' true vertical 6421'-6504', 6638'-6654' Tub,ng (size, grade, and measured depth) 3-1/2', #, K-55, EUE Mod tub,ng @~7 Packers and SSSV (type and measured depth) Pkr Baker'HB" @ 8211', SSSV Camco TRDP-1A-ENC @ 1763' 13. Attachments Descnpbon summary of proposal _X Detaded operabons program __ BOP sketch _ 14 Estimated date for commencing operation Convert temporary Od well to MWAG Inlect~on - October 2000 16. If proposal was verbally approved Blair Wondzell Name of appmver 15. Status of well classdicatlon as: t Od __ Gas __ 10/30/00I Date approved~ Service X Suspended__ 17. I hereby certify that the forgoing ~s true and correct to the best of my knowledge. T~tle Producbon Eng~neenng Superwsor FOR COMMISSION USE ONLY Conditions of approval Not~fy Com~ss~on so representmve may witness Plug ~ntegrety __ BOP test __ Location clearance __ Mechanical ~ntegrety test__ Subsequent form required 10- Date IAppr°v~°~ ~4~ 7~1~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner SUBMIf IN TRIPLICATE Attachment 1 Description of Proposal Kuparuk Well 1D-05 Phillips Alaska, Inc. is hereby requesting Commission approval for convert Well 1D-05 from temporary oil production to MWAG injection. Well 1D-05 was classified as a Gas injector on the Form 10-407 Well Completion Report. The well has been pre-producing since 1/1/00 and is now ready to retum to injection service. Injection will commence in October 2000. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water and gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6421' and 6654' TVD. This interval correlates with the strata found in Phillip's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule I of this injection order. A Mechanical Integrity Test will be performed before injecbon is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. PHILLIP, Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY October 30, 2000 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Maunder: Attached in triplicate is an Applicaton for Sundry Approvals (Form 10-403) and in duplicate is a Report of Sundry Well Operations (Form 10-404) on the following Kuparuk wells. Form Well Action 10-404 1 D-05 10-403 1D-05 Other(Change Approved Program) Change Approved Program If you require any additional information or clarification, please call me at (907) 659- 7535. Sincerely, Robert D. Christensen Kuparuk Production Engineering Attachments Well Fdes (attach only) Fde: FTR 050701 (w/o attach) STATE OF ALASKA (r ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator. ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage. AK 99510-0360 4. Localion of well at surface: 243' FNL, 600' FEL. Sec 23, T11N, R10E, UM At top of productive interval: 1256' FNL, 1180' FEL, Sec 24, T11N, R10E, UM At effective depth' 1308' FNL, 919' FEL, Sec 24, T11N, R10E, UM At total depth: 1315' FNL, 919' FEL, Sec 24, T11N, R10E, UM Operation Shutdown _ Stimulate_ Pull tubing _ Alter casincj _ 5. Type of Well: Development Exploratory _~ Stratagrapic __ Service __~ 12. Present well condition summary Plugging _ Perforate__ Repair well _ Other _X 6. Datum of elavation (DF or KB feet): 105' RKE .7. Unit or Properly: Kuparuk River Unit 8. Well number:. 1D-05 9. Permit number/approval number:. 179-95 10. APl number: 50-029-20417-00 11. Field/Pool: Kuparuk River Field / Oil Pool Total Depth' measured 8930 feet Plugs (measured) None true vertical 6906 feet Effective Depti measured 8872 feet Junk (measured) None true vertical 6856 feet Casing Length Size Cemented Conductor 80' 16" 240 Sx AS II Surface 6043' 10-3/4" 800 Sx Fondu & 1500 Sx AS Ii Production 8881' 7" 2800 Sx Self Stress 8402'-8499',8654'-8672' 6421'-6504',6638'-6654' Liner Perforation Depth measured true vertical Measured depth True vertical depth 121' 121' 6077' 2710' 8916' 6894' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, J-55 @ 8917' Packers and SSSV (type and measured depth) Packer: Baker HB @ 8211', SSSV Camco TRDP-1A-ENC @ 1783' 13. Stimulation or cement squeeze summary N/A Intervals ffeated (measured) N/A Treatment description including volumes used and final pressure Temporary production from Gas Injector from 01/01/00 to 02/28/00. 14. Representit,ve Daily Average Production or Injection Data Od-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 2150 0 Subsequent to operation 41 4023 2915 0 300 15. Attachments MIT form 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _ ©~1 _ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S, gned .~.~~~~.~ Title Produchon Eng,neer, ng Superv,sor Date 7 0/~O//~:~) E~ SUBMIT IN DUPLICAT Form 10-404 Rev 06/15/88 ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Ron Marquez Production Engineering Supervisor Kuparuk River Unit NSK 69 Phone 659-7226 Fax 659-7314 October 5, 1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Christenson' Attached in triplicate is an Application for Sundry Approval (Form 10-403) on the following Kuparuk Well. Well Action 1 D-05 Change Approved Program If you have any questions, please call me at 276-1215, ext. 7226. Sincerely, Kuparuk Production fingineering Supervisor ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany bcc: Central Files NSK Well Files ATO-320 NSK-69 (w/o cover) STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend __ Opembon Shutdown __ Reenter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing __ Vanance __ Pedomte _ Other __ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB) ARCO Alaska, Inc Development __ 105' RKB feat 3. Address: Exploratory__ 7. Unit or Property: P O Box 100360 Stratagral~c__ Anchorage. AK 99510-0360 Service ~ Kuparuk R~ver Umt 4. Location of well at surface: 8. Well number: 243' FNL, 600' FEL, Sec 23, T11N, R10E, UM ~"),m.. 1D-05 At top of product,ye ,nterval:~ 9. Pe,~.it~_.~lztber: 1256' FNL, 1180' FEL, Sec 24, T11N, R10E, UM I~~-~--w.~.~4~,,~,~90.353 At effective depth: 10. APl number: 1308' FNL, 919' FEL, Sec 24, T11N, R10E, UM 50-029-20417-00 At total depth. 11 Field/Pool: 1315' FNL, 919' FEL, Sec 24, T11N, R10E, UM Kuparuk R~ver Reid/Od Pool 12. Present well condition summary Total Depth: measured 8930 feet Plugs (measured) none true vertical 6906 feet Effective Depth: measured 8872 feet Junk (measured) none true vertical 6856 feet Casing Length Size Cemented Measured depth True verhcal depth Conductor 72' 16" 240 Sx AS II 72' 72' Surface 3043' 10-3/4" 800 Sx Fondu & 1500Sx AS II 6077' 2710' Production 8881' 7" 2800 Sx Self Stress 8916' 6894' Liner Perforation Depth measured 8402'-8499', 8654'-8672' ORIGINAL true vertical 6421'-6504', 6638'-6654' Tubing (size, grade, and m.sured depth) R~- 3-1/2", #, K-55, EUE Mod tubing @ 8917' Packers and SSSV (type and measured depth) Pkr Baker 'HB" @ 8211', SSSV Camco TRDP-1A-ENC @ 1783' ii & GaS ConS. C0~t~tS~0t~--'"' 13. Attachments Descnptlon summary of proposal _X Detailed operations program__ BOP sketch _'' 14. Estimated date for commencing opemt,on 15. Status of well classification as: Convert well to temporary producer - October 1999 Oil__ Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service X 17. I hereby certify that the fo~loing is true and correct to the best of my knowledge. S,gned ~L~ ~-'"-'-~ ~ T, tle Product,on Eng,neer, ng Superv, sor Date · l l l,r FO. CO..,ss.o. U EO., IApprova, Conditions o~f/~:ll~a~' I~ot~ [y Com~ss~on so represenht~ve may w~tness ~qO(~ ~"~ Plug integrety BOP test Location clearance ~,~)~)L~.~ .~I~~ Mechanical integrety test Subsequent form required 10- ~.~ ~'~ 1~ ~"-~'e~ . .- -- -- :3RiG~ALIN SI ' - _ Approved by order of the Comm,ss,o, GNED BY Comm,ss,oner Date -- Robert N Chdstenson SUBMIT IN TRIPLICATE Attachment 1 Description of Proposal Kuparuk Well 1 D-05 ARCO Alaska, Inc. is hereby requesting Commission approval for temporary production from injection well 1D-05. Well 1D-05 was classified as an injector on the Form 10-407 Well Completion Report, and has been on injection service since start-up. The well has been shut-in since 5/26/97. Production will commence in mid-October 1999, and will continue throughout the Winter, assuming liquids are produced from the well. If the well produces only gas, it will be shut-in and converted back to injection. Either way, once the production test on 1D-05 is complete, it will be returned to produced water injection service. 1D-05 will be produced through a new riser that will eventually be converted to water injection. R ECEiVED OCT ? 1999 STATE OF ALASKA ALASKA OIL AND GAS ~RVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown m Pull tubing X Alter casing Stimulate __ Plugging . Perforate Repair well X Other__ 0 R I G I N/V i - feet True vertical depth 115' tvd 22710' tvd 6894' tvd Tubing Pressure Serv, ce X l I N,3' 2. Name of Operator :ARCO Alaska. Inc. 13. Address !P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 411' FSL, 224' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1979' FSL, 1273' FEL, Sec. 15, T11N, R10E, UM At effective depth 2146' FSL, 934' FEL, Sec. 15, T11N, R10E, UM At total depth 2175' FSL, 871' FEL, Sec. 15, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 8930' true vertical 6906' feet feet 6. Datum elevation (DF or KB) 105' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-5 9. Permit number/approval number 79-95/90-353 ,, 10. APl number 50-029-20417 . 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8872' feet true vertical 6856' feet Junk (measured) None Casing Length Size Cemented Structural 80' 1 6" 290 Sx AS II Conductor Surface 3043' 1 0-3/4" 800 sx AS I Intermediate 1500 sx AS II Production 8881' 7" 2800 sx Class G Liner Perforation depth: measured 8654'- 8677', 8402' - 8499' Measured depth 115' md 3078' md 8916' md true vertical 6668' - 6688', 6451' 6531' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 TBG W/ TAIL @ 8282' MD Packers and SSSV (type and measured depth) Baker "HB" Pkr ~ 8211' MD, Camco "TRDP-1AENC" SSSV ~ 1783' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or In!ection D{tta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 16. Status of well classification as: Water Injector__ Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rely 05/17/89 Title Area Drilling Engineer Date 4~/~ .~ ~~~) SUI~IVII'F IN DUPLICATE ARCO Oil = Gas Company <) Well History - Initial Report - Daily Iltlt~tlctlonl Prepare and submit the "lltitial RaiN, ri" on the first Wednesday after a well ~s spudded or workover operations are started Daily work prior to sPudding should be summarized on the form giving inclusive dates only D~stnct IC°unty pansl~ or borough I State ARCO ALASKA INC. I NORTH SLOPE BOROUGH I AK Field ~1 Lease or Umt ]Well no KUPARUK RIVER FIELD I ALK: 25650 I 1D-5 Auth or W 0 no ITM WORKOVER AK4818 Operator ARCO J ARCOW, 55. 8533 IHour 09 00 iP , fawo ..... ..... I Date 1/29/80 : Spudded or WO begun SPUD Date and depth aaof 800 am 06/14/90 (1) TD: 8930 PB: 8872 SUPV:DEB 06/15/90 (2) TD: 8930 PB: 8872 SUPV:DEB 06/16/90 ( TD: 8930 PB: 8872 SUPV:DEB 06/17/90 ( TD: 8930 PB: 8872 SUPV:DEB 06/18/90 ( TD: 8930 PB: 8872 The above ia correct Signature 3) 5) For form preparation and d~atnbution, see Procedures Manual, Section 10, Drllhng, Pages 86 and 87 Complete record for each day reporled NORDIC 1 RIG ACCEPTED AT 0:600 MW: 0.0 MOVE RIG FROM 1Y PAD TO 1D PAD - 7 MILES W/ DERRICK UP, SET MATS, REMOVE 7" STACK FROM RIG CELLAR, MOVE RIG OVER WELL AND LEVEL RIG, RIG ACCEPTED AT 0:600 6/14/90 DAILY:S23,100 CUM:$23,100 ETD:S23,100 EFC:$270,000 NU BOPE MW:12.5 WBM ATTEMPT TO BLEED PRES. OFF TREE, MU LUBRICATOR, RU OTIS S-LINE, RIH AND PULL DV FROM GLM AT 8128', RIH AND SET A2 BLANKING PLUG IN D NIPPLE AT 8207', POH, RD AND STAND OTIS S-LINE ASIDE, WEIGHT UP MUD, 3250 PSI SITP, 2700 PSI SICP, BLEED GAS OFF ANNULUS, SHUT IN AND MONITOR, PLUG HOLDING, LOAD TBG AND ANNULUS W/ H20, PT-PA-0 PSI, RU OTIS S-LINE, RIH AND PULL EQUALIZING PRONG, RIH AND PULL A2 PLUG, RD OTIS S-LINE, WEIGHT UP MUD TO 12.5 PPG, CIRCULATE MUD AND AND KILL TBG, SHUT IN AND CHECK WELL WHEN FILLED, PT=0 PSI, PA=1300 PSI, INJECT 25 BBL MUD INTO PERFS, CONT. PUMPING AND KILL WELL, RD LINES, SET BPV, ND MCEVOY 3.125, 5KSI TREE, NU 11" 5KSI BOPE DAILY:S46,178 CUM:$69,278 ETD:$69,278 EFC:$270,000 LAND 3-1/2" DP IN SHED MW:12.4 WBM FINISH NU BOP, TST BOP, PULL BPV, MU LNDG JT, BOLDS, UNSEAT TBG HNGR, MAX PULL 85K#, STRING WEIGHT 65K#, SAW SOME DRAG BUT NO SHEAR, PUT 8 TURNS INTO STRING TO FULLY RELAX FHL PKR IN CASE WE HAVE IT, CIRC. I HOLE VOLUME, BREAKOUT AND LD MCEVOY GEN I RETROFIT TBG HNGR, UPPER AND LOWER PAKOFF SEALS TORN UP, POH, STAND BACK AND TALLY 3-1/2" COMP., CHG SEAL RINGS, DAILY:S30,834 CUM:$100,112 ETD:S100,112 EFC:$270,000 POH W/ FHL PKR ON 3-1/2" HW:12.5 WBM SERVICE RIG, FUNCTION TST BOP, TALLY AND MU FTA#I, RIH, TAG PKR AT 8181', LATCH J-TOOL ONTO EXPANDA JT SLICK STICK/FHL PKR, HOLD 5-10K# UPSTRAIN, ROTATE AND RELEASE FHL PKR, WAIT 30 MINUTES, LD SINGLE, WORK PKR THRU CASING COLLAR, CIRC. HOLE VOKUME TO CLEAR OUT GAS BEHIND TAILPIPE, RD CIRC. HD. POH DAILY:S28,627 CUM:$128,739 ETD:S128,739 EFC:$270,000 TST 7"X10-3/4" PACKOFFS MW: 12.5 WBM SERVICE RIG, FINISH POH W/ FHL PKR AND TAILPIPE, MU HALIBURTON RBP, RIH 5 STDS 4-3/4" DC, TRY TO SET RBP AT 8200', DiT. N' - OVERSHOT FROM RBP, TST CSG TO 2500 PSI, LOST 25 PSI IN 15 MIN, PU AND MU HOWCO 7" RTTS AND STORM VALVE, RIH AND SET WITH STORM VALVE AT 26', BLEED 725 PSI GAS ON 7"X10-3/4" ANNULUS, ND MCEVOY GEN I RETROFIT TUBG HEAD, INSTALL CAMERON D~ILY: $28,59~ CUM: $157,32~ ETD: $1_57~ 329 RFC: ~270, 0OO AR3B-459-1-D Ia Number all dally well h~story forms conaecuhvely they are prepared for each well iPage no ARCO Oil a Gas Company Daily Well History--Interim Inetmctlona This form is used during drilling or workover operations If testing coring or perforahng show formation name ~n describing work performed Number all drill stem testa sequenbally Attach description of all cores Work performed by Producing Sectton will be reported on ' Interim' sheets until final completion Report ofhc~al or representative test on "Final" form 1) Submit 'leterlle ' sheets when filled out but not less frequently than every 30 days or (2) on Wednesday of the week in which oll string is set Submit weekly for workovers and following setting of oil satin§ until completion F~eld Itease or Unit Data and ~'d~l~ ............. ~;o~np'~et--e--~cord for aach day while dr~lhng or workover m progress as of 800 am 06/19/90 (6) TD: 8930 PB: 8872 SUPV:DEB NORDIC 1 RUNNING 3-1/2" COMP.ASSY MW:12.5 WBM TST CIW 7"X10-3/4" PACKOFFS, PU SINGLE, RIH AND STAB-IN AND OPEN STORM VALVE, RELEASE RTTS, POH AND LD STORM VALVE AND RTTS, RIH 2 STDS, LATCH AND RELEASE RBP AT 8230', LD 2 SINGLES, RU CIRC HEAD AND CBU, POH, PD DP AND RBP, RUN 3-1/2" COMP ASSY, PREPARE TO DROP BALL AND MU TBG HNGR DAILY:S50,987 CUM:$208,316 ETD:S208,316 EFC:$270,000 A~ lWetl no The above Is correct DrHhng, Pages 86 and 87 AR3B-459-2-B Number all dally well h~story forms as they are prepared for each well consecutively IPage no ARCO ~i .~nd Gas Company Daily Well History-Final Report Instruchona Prepare and submit the "Final Rep~t" on the hrst Wednesday after allowable has been assigned or well ~s Plugged Abandoned or Sold "Final Report' should be submdted also when operations are suspended for an mdeflmte or appreciable length of hme On workovers when an official test ~s not required upon completion, report completion and representative test data ~n blocks prowded The "Final Rapoll" form may be used for reporting the entire operanon d space ~s available I AccounUng Cost center code D~stnct I State ARCO ALASKA INC. I AK Field County or Parish NORTH SLOPE BOROUGH Lease or Unit T,tle AT'K: 25650 WORKOV~R KUPARUK RIVER FIELD Well no 1D-5 Auth or W O no AK4818 Operator ARCO Spudded or W O begun SPUD Date and depth as of 8 00 a m 06/20/90 ( TD: 8930 PB: 8872 SUPV:DEB ARCo WI Oate 1/29/80 Complete record for each day reported NORDIC 1 Iotal number of wells (achve or mact~ve) on th~sI Dst center prior to plugging and / bandonment of th~s well 55.8~533 our IPrlor status if a WO I 09:00 RIG RELEASED MW: 0.0 Diesel CONT RIH W/ 3-1/2" COMP ASSY, MU CAMERON GEN IV 3-1/2" TBG HNGR, DROP BALL, MU AND TST CNTL LINE, LAND TBG, RILDS, SET PKR, BOLDS, SHEAR PBR, RILDS, CLOSE SSSV, TST AT 500 PSI FOR 15 MIN, OK, ND STACK, NU 3-1/8" MCEVOY 5KSI TREE, SHEAR SOS AT 3800 PSI, DESPLACE WELL W/ CLEAN DIESEL, PUMPED 290 BBLS FRESS WATER AHEAD OF 300 BBLS DIESEL, RD AND BLOW DOWN LINES, SET BPV, SECURE WELL, RELEASE RIG AT 1800 HRS DAILY:S72,751 CUM:$281,067 ETD:S281,067 EFC:$270,000 Old TD Released ng Class~hcahons (OH, gas, etc ) INew TD I PB Depth Date K~nd of ng Type completion (s~ngle, dual, etc ) Producing method Official reservmr name(s) Potenhal test data Well no Date Reservoir Producing Interval Od or gas Test t~me Produchon Oil on test I Gas per day Pump s~ze, SPM X length Choke, s~z~t T P C P Water % GOR Grawty AIlewable Effec,*~e date corrected The above is correct "' Date Slgnature~ ~ ] ~J/FO IT~ For form preparation a~ dls'~rlbu~lon, ~ ~) ~-~- see Procedures Manual, Section 10, Dnthng, Pages 86 and 87 AR3B-459-3-C JNumber all dady well h~story forms consecutively j Page no as they are prepared for each well I Olvl~on of AtlantlcRIchfleldCompsoy 0 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator feet Plugs (measured) feet _ Suspend _ Operation Shutdown Alter casing _ Repair well ~ Plugging _ Change approved program_ Pull tubing ~ Variance _ 5. Type of Well: Development ARCO Alaska. In{;. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchora~le, AK 99510 Service _ 4. Location of well at surface 243' FNL, 600' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 1256' FNL, 1180' FEL, Sec. 24, T11N, R10E, UM At effective depth 1308' FNL, 948' FEL, Sec. 24, T11N, R10E, UM At total depth 1315' FNL~ 919' FEL~ Sec. 24~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 9 3 0' true vertical 6 9 0 6' _ Re-enter suspended well _ Time extension Stimulate Perforate Other 6. Datum elevation (DF or KB) RKB 105 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-05 f~et g. Permit number 79-95 10. APl number 5o-029-2041 7 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8 872' feet Junk (measured) true vertical 6 8 5 6' feet None Casing Length Size Structural Conductor 72' 1 6" Surface 3 0 4 3' 10 3/4" Intermediate Production 8 8 81' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 240 Sx AS II 72' 72' 800 Sx Fondu & 3 0 7 8' 2 71 0° 1500 Sx ASII 2800 Sx Self Stress 891 6' 6 8 94' 8654'-8677', 8402'-8495' at 4 SFP true vertical 6668'-6688', 6451'-6531' TVD Tubing (size, grade, and measured depth 3-1/2" J-55 set at 8222' Packers and SSSV (type and measured depth) Baker FHL ~ 8189'~ Camco TRDP-1A ~ 1980' 13. Attachments Description summary of proposal _ Repair seals in wellhead and replace retrievable packer 14. Estimated date for commencing operation June 5, 1 16. If proposal was verbally approved Date approved Name of approver 90° phasing RECEIVED MAY 1 4 199 A/aska Oil & Gas Cons, Commisslor~ ~choral~ Detailed operation program X BOP sketch 15. Status of well classification as: Oil __ Gas _ Suspended Service _Gas I n!ect0r 17. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed /~,~^~--~/~--c~//~ ~'~-~(~~ Title .,/ ~'C~),<~ ~)~ ~ COMMISSION USE ONLY Conditions of ~pproval: ~iotify Commission ~epresentative may witness Plug integrity_ ~ Test_ Location clearance__ Mechanical Integrity Test Subsequent form require 10-g~/~- Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY : n~.,- r, e~:'ru Commissioner Approved Copy eturned, _ / Date ~'-~'~'- ~'O / / Date 5 -- I ~ --C~,0 SUBMIT IN TRIPLICATE Kuparuk River Unit Well 1 D-5 Preliminary Workover Procedure Pre-Rig Operations 1. Shut-in well and obtain downhole BHP. (Est BHP is 4000 psi at 6450" TVD or 11.9 EMW) Rig Operations 1. MIRU Nordic #1. 2. Displace tubing with seawater. 3. Pull dummy valve at 8073'. 4. Circulate 12.2 ppg mud to displace tubing and annulus. 5. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. 6. Pull 3-1/2" EUE AB mod tubing. (Baker "Expanda Jt" was pinned for 40,000# shear but was not sheared on initial completion, FHL packer was pinned for 75,000# release.) 7. RIH with drill pipe and retrieving tool. Retrieve FHL packer and tailpipe. 8. Rerun 3-1/2" EUE 8rd AB mod single completion with new HB retrievable packer. 9. ND BOPs, NU tree. 1 0. Reverse circulate mud from annulus and tubing with diesel. Set BPV. 1 1. RD, release rig. Pull BPV. RECEIVEL ,~,laska Oil & Gas Cons. Commission Anchorage 5000 PSI BOP S3(ACK ,,,J 6 1. 9 5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" - 5000 PSI CROSS~:3VER SPOOL 4. 11" - 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 · CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. 2. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINTAND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, 14. SIGN AND SEND TO DRILUNG SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORE~C SRE 9/89 / / 0r~11 Site lA Well No. '" 1A-4 "'"1A-5 '~1A-7 ~lA-g ~1A-11 '~1A-12 %1A-14 %1A-15 "~lA-16A ATTACHMENT II KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~ m 5/7/82/~ 1/25/82-~'-~ 3/23/83 / ~ . 1/19/83") ~-' 3/21/83/ 3/8/82 4/1/82 6/5/82 5/11/82~ Drill Site Well No. Log Date __ 18 "~18-1 12/26/81 '~18-3 11/1~;18/81"~, '~ 12/82/ ~-18-6 11/18/81k, "~ 9/10/82/ ~ ~18-7 11/23/81 ~18-8 12/28/81'-,~ '~ 8~4/82/ ~!B-g ~ 6/24/82,..-,~,° '% 8/3/84" Drill Site lC Wel 1 No. '"'"lC-1 ",-zc-e '"1C-3 ",ulC-4 '"~,~ ~lC- 5, '"'"1C-6 '~1C-7 '~- 1C-8 Log Date 5/9/81 5/8/81 7/13/81 11/8/81"~ 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date_ "~1D-1 1/80'"> ~. ~- 5/23/83/ "'"1D-3 8/5/80 1D-4 ~7/30/80'% ~ ~ 8/13/80/ - '~ '~lD-5 6/11/81 ~1D-6 6/9/81 .-. '~lD-7 6/8/81 . X'~lD-8 {WS-8) 5/10/78 ' - - - - RECEIVED_ -: -:--tT:-- FEB 2 1 1988 .....- ;t::-_ - ..- -~?_- _. _ _. ~q~.~ ~_- Almskm 011 & Gas Cons. C, onunlssl.on. · --'----e ~ ARCO Alaska, Inc. Post Office( ~' 60 AnchorJge, ~laska 99510 Telephone 907 277 5637 RETURN TO: ~CO ALAS~, INC. ATTN: Records Clerk ATO-1115B Box 100360 , /~chorage, ~ 99510 Transmitted herewith are the following it.s. and retu~ one signed copy of this tra~mittal. Date: 2/05/85 Transmittal No: 4824 Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 Gearhart --~2Z-6/ 9/03/84 Otis 2X-6~ 8/16/84 Gearhart - -- 2X-4/ 8/16/84 Camco ~--2X-lv 8/16,19/84 Camco --2V-5/ 8/16,19/84 Dresser ~2V-2~ 9/07/84 Otis ~2F-9/ 8/28/84 Otis / --'2F-SW~ 10/08/84 Camco --2F-7~ 10/07/84 Otis --2B-l~~ 9/03/84 Otis --2C-5 / 8/17/84 Otis -1Y-!3/ 8/16/84 Dresser ~lY-9~z 9/07/84 Camco --1Y-5/ 9/14/84 Camco 1Y-5~ 9/06/84 Otis ~lG-6.' '8/25/84 Otis ~lH-4~ 9/04/84 Otis --1F-12¥ 9/09/84 Otis ~lF-9 Z 8/17,18/84 Camco ~-lF-8Z~ 8/16,17/84 Camco · --1E-8~ 10/12/84 Otis ~lD-5~ 10/07/84 Camco ~lA-4wz 9/02/84 Otis ~--1A--3~ 9/02/84 Otis Receipt Acknowledged: "HP 232" "HP 233" 9/06/84 "SBHP" 9/05/84 8/17/84 8/16/84 10/1.3/84 ].0/07/84 "Static BHP" "PBU"" "PBU" "SBHP" "E Line" "Pressure Falloff" DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips 0il Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska. If r--. C': z: f: c,)~ 36C A:-,chcrag,.. Ala,.,ka 99~,10 -e %~,hone 907 277 5637 Date: 9/11/84 Transmittal No: 4719 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 "~~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/PRESSURE ANALYSIS 2Z-7 /8/17/84 Run 1 Lynes 2B_7/8/17/84 " Lynes ~ 2B-9 8/17/84 Lynes 1C-9GI~'7/07/84 Camco i ~2~ ~7/12-14/84 Camco lB-5~' 12/15/84 Otis SEQUENCE OF EVENTS 8/18,19/84 ~PBu 8/17-19/84 ~ " 8/17-19/84 ~_2'- ' 7/08/84 Falloff Test 7/12/84 " " 12/16/84 Static BHP lC-4-~-' 12/17/84 Otis lC-6 12/29/84 Otis 12/17/84 " " 12/29/84 " " 1D_7/"~ 12/19/84 Otis 12/19/84 " " 1D-4'" 12/18/84 Otis 12/18/84 " " /cat Receipt Acknowledged: B. Adams D & M F.G. Baker Drilling P. Baxter Geology BPAE Mobil Chevron DISTRIBUTION W.V. Pasher Alaska 0~1 & Gas Ancl~or~c~ C. R. Smith G. Phillips Phillips Oil J.J. Rathmell 5tat~'- o~ Alaska Sohio Union NSK Operations R&D Well Files ARCO Alaska. Inc ~r ~ ,c-,.. 5;- ;_77 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 8/16/84 Transmittal No: 4686 nsmitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 4/12/84 Camco lC-5 " " 4/13/84 " lC-6 Gas Disp. 5/16/84 Otis lC-7 PBU 4/20-21 Camco 1C-9~alloff Test 4/29/84 " lC-l~" " 5/06/84 " ID-1 Static BHP 4/19/84 " ID-5 Falloff Test 4/29/84 Otis lE-12 Flow BHP/GLV 7/01/8484 Camco 1E-17 Static BHP 1/8-11/84 Otis 1E-18 " " 1/03/84 " 1E-24 Injectivity 6/21-22/84 " 2F-8 T Log PBU 5/06/84 Otis 2F-11 Initial PBU 5/22/84 Camco 2F-12 Initial Well 5/15/84 " 2F-13 " " 5/14/84 Otis 2F-14 PBU 5/03/84 " 2F-15 PBU State 4/26/84 /cat Receipt Acknowledged: B. Adams Camco DISTRIBUTION W.V. Pasher C.R. Smith'O~S7'~ ~ F.G. Baker P. Baxter BPAE Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska · Sohio Union Chevron NSK Operations R&D Well Files ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 4, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1D-5 Dear Mr. Chatterton- Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG' tw GRU5/L99 Enclosure If RECEIVED AlaSka 0il & Gas Cons ~,m lmm~m~ ARCO Alaska, Inc Es a Subsidiary of AtlanhcR,chfleldCompany STATE OF ALASKA ALASK~ IL AND GAS CONSERVATION (3( IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL gJX OTHER [] 2 Name of Operator 7 Permit No ARCO Alaska, Inc. 79-95 3 Address 8 APl Number P. O. BOX 100360, Anchorage, AK 99510 50- 029-20q17 4 Location of Well Surface: 2~3' FNL, 600' FEL, Sec.23, T11N, R10E, UM 5 Elevatmon in feet (indicate KB, DF, etc ) 105' RKB 12 I 6 Lease Deslgnatmon and Serial No ADL 25650 9 Unit or Lease Name Kuparuk River Unit 10 Well Number 1D-5 11 F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indmate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit m Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casmg [] Perforations [] Altermg Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well I'-J Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing J~ (Note Report multmple completmons on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, ~ncludlng estimated date of startmg any proposed work, for Abandonment see 20 AAC 25 105-170) Accepted rig ~ 1800 hrs, 11/03/83. Pulled BPV. Killed well. Set BPV. ND tree. NU BOPE & tstd - ok. Sheared 5BR. POH w/3-1/2' tbg, gas-lift mandrels, & 5BR. Circ bridge-sal pill; bull head 22 bbls to bottom perfs ~ 8q02' - 8q99'. POH w/pkr. TIH w/retrievable bridge plug & set ~ 1183'. ND BOPE. ND 11" 3M psi tbg head & NU 11" 5M psi tbg head & tstd to 5000 psi - ok. NU BOPE & tstd - ok. Retrieved bridge plug & POH. Ran new 3-1/2" completion assembly w/tail @ 8207', pkr @ 8189', & SSSV ~ 1980'. Tstd packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well to Kuparuk crude & 30 bbls diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig ~ 2130 hrs, 11/09/83. RECEIVED JAN Naska Oil & Gas Cons. bommmslon Anchor~e t~f Signed T~tle ~~__~dn use- Condition f any 14 I hereby cert y that the foregoing ~s true and correct to the best of my knowledge Area Drilling Engineer Date By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev 7-1~80 GRUS/SN52 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate AI~CO Alaska, Inc ( Post Office Bc~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 4, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1D-5 Dear Mr. Chatterton' Enclosed is a Completion Report for the subject well. have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG'tw GRU5/LIO0 Enclosure If you ARCO Alaska, Inc ~s a Subsidiary of AtlanhcR~chfleldCompany e STATE OF ALASKA ALASKA~ L AND GAS CONSERVATION C~ .... MISSION ~a~ WELL COMPLETION OR RECOMPLETION REPORT AND LOO I Status of Well Classification of Serwce Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ Gas Tnjection 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 79-95 3 Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20417 4 Location of well at surface 9 Unit or Lease Name 243' FNL, 600' FEL, Sec.23, T11N, R10E~ UM Kuparuk River Unit At TopProduclng Interval 10 Well Number 1256' FNL~ 1180' FEL, Sec.24, T11N, R10E~ UM 1D-5 At Total Depth 11 Fmeld and Pool 1315' FNL~ 919' FEL, Sec.24, T11N, R10E, UM Kuparuk River Field , 5 Elevatmon ~n feet (red,cate KB, DF, etc ) 6 Lease Des~gnatmon and Sermal No Kuparuk River 0i 1 Pool 105' RK8 ADL 25650 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband / 15 Water Depth, mf offshore 116 No of Completions 01/29/80 02/24/80 Ol/04/80(Conversion to Gl 11/9/83) N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 D~rect~onal Survey I 20 Depth where SSSV set 21 Thickness of Permafrost 8930'ND~6906'TVD 8872'ND~6856'TVD YES IX1 NO []I 1980 feet MD 1400' (Approx) 22 Type Electric or Other Logs Run D i L/BHCS/SP/GR ~ FDC/CNL/GR ~ Epi the rma l/Neut ron/Soni c ~ DLL/NSFL/GR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOT_.~I HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf~ 24" 240 sx AS II 10-3/4" 45.5# K-55 Surf 3078' 13-3/4" 800 sx Fondu & 1500 sx AS II 7" 26.0# K-55 Surf 8916' 9-7/8" 2800 sx Dowel1 Self-Stress cmt 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8654' - 8677' 3-1/2" 8207 ' 8189' 8469' - 8495' w/4 spf 8444' - 8469' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC 8402' - 8444' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED All perforated 3000 9al - 7-1/2% HCL & intervals 9000 gal - 12-3 Hud Acid 2000 aa1 WF40J-347 Pad & 22.000 aa1 Stratafrac w/76.000# sar 27 N/A PRODUCTION TEST Date F~rst Production I Method of Operation (Flowing, gas lift, etc ) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 24-HOUR RATE ~ 28 COP E DATA Brief description of I~thology, porosity, fractures, apparent d~ps and presence of od, gas or water Submit core ch~ps See core description attached to original completion report. Form 10-407 GRUS/~C11 Submit ~n 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 TRUEVERT DEPTH GOR, and t.me of each phase __ Top Upper Sand 8z~02' 6z~51' Base Upper Sand 8514' 6547' See original compleX, ion report; for results. Top Lower Sand 8639' 6655' Base Lower Sand 8734' 6737' 31 LIST OF ATTACHMENTS Workover Hi st:ory 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gned L · T~tle Ar~,,:~ rtr411{n~ I'n.. Date / ................ 7 ;/ , ..... INSTRUCTIONS General: Th~s 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 ~njection, water injection, steam injection, air ~nject~on, salt water d~sposal, water supply for ~nject~on, observation, ~nject~on for in-situ combustion. Item 5: Indicate which elevation ~s used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and ~n 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 ~n ~tem 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 th~s 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 1D-5 WORKOVER HISTORY Accepted rig @ 1800 hrs, 11/03/83. Pulled BPV. Killed well. Set BPV. ND tree. NU BOPE & tstd - ok. Sheared SBR. POH w/3-1/2" tbg, gas-lift mandrels, & SBR. Circ bridge-sal pill; bull head 22 bbls to bottom perfs @ 8402' - 8499'. POH w/pkr. TIH w/retrievable bridge plug & set @ 1183' iND BOPE. ND 11" 3M psi tbg head & NU 11" 5M psi tbg head & tstd to 5000 ~s - ok. NU BOPE & tstd - ok. Retrieved bridge plug & POH. Ran new 3-1/2" completion assembly w/tail @ 8207', pkr @ 8189', & SSSV @ 1980' Tstd packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok'. Disp well to Kuparuk crude & 30 bbls diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 2130 hrs, 11/09/83. GRU5/WH04' tw ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 21, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1D-5 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1D-5 to gas injection. Since we expect to start this work on October 30, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG' tw GRU4/L117 Encl osures cc: B. J. LaForce, ATO 1490 Well File ARCO Alaska, Inc ~s a Subsidiary of Atlant~cR~chfleldCompany A(r'~j STATE OF ALASKA ~ ALASK IL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator ARCO Alaska~ Inc. 3 Address P,0, Box 100360, Anchoraqe~ Alaska 4 Location of Well 99510 Surface Loc: 2~3' FNL, 600' FEL, Sec. 23, T11N, RIOE, UN Bottom Hole Loc: 13~3' FNL, 9~4' FEL, Sec. 24, T11N, RI~E, UM 5. Elevation ~n feet (~nd~cate KB, DF, etc.) I 6 Lease Designation and Serial No 105' RK~ I ~DL 9~6~N 12 7 Permit No 79-95 8 APl Number 50-- 029-20417 9 Umt or Lease Name Kuparuk River Unit 10 Well Number 1D-5 11 F~eld and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF (Submit m Tnplmate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altenng Casing [] Stimulate [] Abandon [] St~mulauon [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [~ Other [] Pulling Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, ~nclud~ng estimated date of starung any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska~ Inc,~ proposes to convert well 1D-5 to gas injection, The procedure will be as follows; (1) The tubing will be perforated at 8150' and 9.1 ppg kill weight brine will be circulated. (2) The tubing and packer will be pulled. (3) A bridge plug will be run and set. (4) The 3000 psi tubing head will be replaced with a 5000 psi wellhead. (5) The bridge plug will be pulled ~ new AB Modified tubing and completion assembly/~/ The tubing will be tested to 4000 psi. ~ A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 30, 1983 Subsequent Wm'k Reported 7%~ OCT 14 I hereby cer.t~ that the foregoing ~s true and correct to the best of my knowledge S~gned T~tle Area Dri 11 i ng Engineer m~ss~on L~O Cond~t~o , ~f any Date ORIGINAL SIG~IEg BY B,~,RRY W. KIJGLEil B¥Orderof Approved by COMMISSIONER the Commission Approved Copy Returned _ Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duplicate Forms/Sundry09 ARCO Alaska, Inc./' Post OfficeI~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton: Enclosed are revised well completion reports and gyroscopic surveys for the following wells: 1D-1 1D-2 1D-4 1D-5 1D-6 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG:tw GRU4/L110 Enclosures ARCO Alaska Inc Js a Subsidiary of AtlanhcR~chheldCompany ! STATE OF ALASKA ~ ' ALASKAI ~AND GAS CONSERVATION C~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class,hcatlon of Serv,ce Well REV I SE D oILX~(-] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 79-95 3 Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20417 4 Location of well at surface 9 Unit or Lease Name 243' FNL, 600' FEL, Sec.23, TllN, R10E, UN Kuparuk River Unit At Top Producing Interval 10 Well Number 1256' FNL, 1180' FEL, Sec.24, TllN, R10E, UM 1D-5 At Total Depth 11 F~eld and Pool 1315' FNL, 919' FEL, Sec.24, TllN, R10E, UM Kuparuk River Field 5 Elevation ~n feet (mdmate KB, DF, etc ) 6 Lease Designation and Serial No Kuparuk River 0i 1 Pool 105' RKB ADL 25650 12 Date Spudded 13 Date T D Reached 14 Date Comp , Susp or Aband 115 Water Depth, ~f offshore 116 No of Completions 01/29/80 02/24/80 03/04/80I N/A feet MS LI 1 17 TotaIDepth(MD+TVD) 18 Plug Back Depth (MD+'rVD) 19 Directional Survey I 20 Depth where SSSV set I 21 Thickness of Permafrost 8930'HD,6906'TVD 8872'MD,6856'TVD YES~[~ NO [] 1977 feet MD 1400' (Approx) 22 Type Electrm or Other Logs Run D I L/BHCS/SP/CR, FDC/CNL/GR, Epithermal/Neutron/Sonic, DLL/MSFL/GR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 72' 24" 240 sx AS II 10-3/4" 45.5# K-55 Surf 3078' 13-3/4" 800 sx Fondu & 1500 sx A,~ II 7" 26.0# K-55 Surf 8916' 9-7/8" 2800 sx Dowell Self-Stre,~s cmt 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD ~nterval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8654' - 8677 ' 3-1/2" 7670' 7633' 8469' - 8495' w/4 spf 8444' - 8469' 26 ACID, FRACTURE, CEMENT SOUEEZE, ETC 8402' - 8444' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED All perforated 3000 gal - 7-1/2% HCL & intervals 9000 gal - 12-3 Mud Acid 2000 gal WF40J-347 Pad & 22,000 gal Stroicafra¢ W/76;000# san, 27 N/A PRODUCTION TEST ,, Date F~rst Production I Method of Operation (Flowing, gas I~ft, etc ) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of I~thology, porosity, fractures, apparent d~ps and presence of oil, gas or water Submit core chips See core description attached to original completion report. OCT 2 1983 Form 10-407 GRU4/WC18 Submit ~n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 t £ " ' 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include .nterval tested, pressure data, all flu.ds recovered and gravity, MEAS DEPTH TRUEVERT DEPTH GOR, and t~rne of each phase Top Upper Sand 8402' 6451' Base Upper Sand 8514' 6547' See original completion report for results. Top Lower Sand 8639' 6655' Base Lower Sand 8734' 6737' 31 LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gned T~tle Area Drilling Engr. Date INSTRUCTIONS General Th~s 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 ~nject~on, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for ~n-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements g~ven 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 ~n item 16, and in ~tem 24 show the producing intervals for only the interval reported in ~tem 27 Submit a separate form for each additional ~nterval 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- ~ng and the location of the cementing tool. Item 27 Method of Operation. Flowing, Gas L~ft, 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 KUPA, ,RUK B'IG I NEER ! DATE: Transmitted herewith are the fol lowing- ~: D.W. Bose/Shelby J. Matthews' ' -. . LEASE P, ERJP, N RECEIPT TO: ATTO3 ALASKA, ! l',,t3. ATTN: SHEI~Y J. M~TI'} 15t, S - ATO/111 5-B P. O. BOX 100360 AN(]-tORtGE, AK, 99510 KLJP~ E]'~ I NEERII',~ Transmitted herewith are the fol lowing: PLEASE FEYFE: BL- BLUELINE, S- SEPIA, F- FILM, T- TAPE, ~_,~-~ LIPT ~'/I FP'Z3ED: PLEASE ~ RECE ! PT TO: AFCO ALASKA, INt3. ATTN: SHELBY J. MATTH~.¥S - ATOI 1115-B. P. O. BOX 100360 ~E, /~{. 9951O ARCO Alaska, Inc. Post Oflice 13 Anchorage, Al,:,=,~(a 99510 Telephone 907 277 5637 July 21, 1982 C. V. Chatterton State of Alaska Oil and Gas Conservation Cc~n. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Enclosed are subsequent reports for Kuparuk Wells LA-5, lA-6, 1D-2, 1D-3, 1D-4, and ~ 1D-5 covering acid stimulations. Sincerely, JE. A. Simbnsen FAS/er cc: L. K. Blacker -AFA 330 w/o Attachment L. B. Kelly -AST 306 w/Attachment L. M. Sellers - ANO 332 w/Attachment H. C. Vickers -AFA 326 w/o Attac~t ARCO Ala'~ka Inc ~s a ~;ubs~ary of Atlant~cRtchf,eldCompany STATE OF ALASKA C(~ ALASK OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL E~( OTHER [] 2 Name of Operator 7 Perm,t No ARCO Alaska, Inc. 79-95 3 Address 8. APl Number P.0.Box 360, ^nchorage, AK 99510 50- 029-20417 4 Location of Well SL: 243' FNL, 601' FEL, Sec. 23, TllN, RIOE, UM 9 Umt or Lease Name Kuparuk River Unzt 10 Well Number 1D-5 5 Elevation ~n feet (~ndlcate KB, DF, etc ) I 6 Lease Designation and Serial No K u p a r u k KB=105' IADL 25650 12 Check Appropriate Box To Indmate Nature of Notme, Report, or Other Data 11 F~eld and Pool Kuparuk River Field River Oil NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation E~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Poo 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Begin acid procedure May 18, 1982. RU CTU and pumping equipment. Tested to 4000 psi. RIH to 8592' MD circulating diesel. Squeezed 12,% HC1 acid with additives into perforations 8402-8499' MD. Maxzmum TP=600 psz. Total aczd pumped = 88 bbls. Circulate nitrogen and diesel alternately to cleanup. POOH with CT while pumping diesel. Flowed well for 2.5 hours to clean up. Put well zn test line to CPF. Test showed production of 1246 BOPD with wellhead pressure at 106 psi. B-2 14 I hereby cert~ that the foregoing is true and correct to the best of my knowledge ~j~, '~ (~ ~~% Regional Signed , · T~tle The space b~w for Comm,sslon/~ Conditions of Approval, ~f any ~ Operations Engineer ?/'Z /~ Date / ~ Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev 7-1-80 IX/ A/~ P Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate KUPARUK ENGINEERING TO: DATE: ~~/~ WELL NA~IE: ~ T~~ran~mitted herewith are the following: TRANSMITTAL ~. ~~ FROM: D.W. Bose/Lorie m. Johnson PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED~.- ,..~-'~ ATE: .-"PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. q!~s~ab..,~.~ ATTN: LORIE L. JOHNSON - P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Olhce Be .~0 Anchorage, Alaska 99510 Telephone 907 277 5637 April 21, 1982 Mr. C. V. Chatterton State of Alaska 0il 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 1B-gGI 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, bl Attachments ( STATE OF ALASKA Ct ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL EX OTHER [] 2 Name of Operator 7 Permit No ARCO Alaska, Inc. 79-95 3 Address P.O.Box 360, Anchorage, AK 99510 4 Location of Well S.L. 243'FNL, 601'FEL, Sec 23, T11N, RIOE, UM B.H.L. 1343'FNL, 944'FEL, Sec ~ T11N, RIOE, UM 8 APl Number 50- 029-~ 9 Umt or Lease Name Kuparuk 25650 10 Well Number 1D-5 5 Elevatmon mn feet (mnd~cate KB, DF, etc ) 6 Lease Desmgnatmon and Serial No 105' RKR ADL 25650 12 Check Appropriate Box To Indmate Nature of Notice, Report, or Other Data 11 F~eld and Pool Kuparuk River Field Kuparuk River Oil NOTICE OF INTENTION TO (Submit m Tnphcate) Perforate [] Alter Casing [] Perforations Stimulate X[] Abandon [] Stimulation Repa,r Well [] Change Plans [] Repairs Made Pull Tubmng [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) SUBSEQUENT REPORT OF (Submit m Duplmate) [] Altenng Casing [] Abandonment [] Other Poo] 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc. proposes to stimulate this well using a 12% HCI plus additives treatment. Acid will be spotted across and squeezed into the perforated interval using a coiled tubing unit. Ail circulated and flowed fluids will be diverted to on site tankage. After clean up, the well will be turned into the CPF test separator for rate determination. This work is scheduled for the later part of April, 1982, and will take one day to complete. 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Area Operations T~tle Signed cT:: ~ ~t::: s bo f~A~pfpOr ro vC-a~ ,m~ 7: ,nS;O n Approved by Form 10-403 Rev 7-1-80 Engineer Date Approved Copy Returned By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class,flcatlon of Serwce Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 79-95 3 Address 8 APl Number P.0.Box 360, Ancho['age, AK 99510 50- 029-20417 4 Locat,on of well at surface 243'FNL, 600'FEL, Sec 2), T11N, R10E, UM 9 Umt or Lease Name Kupacuk 25650 AtTopProduc,nglnterval 1283'FNL, 1162'FEL, Sec 2~, T11N, R10E, UM 10WellUumber 1D-5 At Total Depth 1351'FNL, ~18'FEL, Sec 2~, T11N, R10E, UH ~ F ,eld and Pool Kupa~uk R[ve~ Field 5 Elevation m feet (red,cate KB, DF, etc ) 6 Lease Designation and Serial No 105' RKB ADL 25650 Kuparuk River 0il Pool 12 Date Spudded 13 Date T D Reached 14 Date Comp , SuMp or Aband ~ 15 Water Depth, if offshore m 16 No of Completions 1/29/80 2/24/80 3/4/80~ __ feetMSL~ 1 I 17 Total Depth (MD+TVD) 18 Plug Back Depth(M~D) 19 D~rect~onal Survey 20 Depth where SSSV set 21 Thickness of Permafrost 8930' 6883' 8264' 6301 YES ~ NO D 1977 ~tMD 1650' (appcox.) 22 Type Electr,c or Other Logs Run DIL/BHCS/SP/GR. FDC/CNL/GR. EDithe~mal/neut~on/sonie. DLL/MSFL/GR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" AE~ w~ld~d H-~ ~,,r¢_ R~' ~" ~0 SX ~rcticset T F cmt 7" 2~RTC K-55 R~rf R91~' D 7/R ~800 S~ DO~e~] $e~' Rfr~ nm~ .... 24 Perforat,ons open to Production (MD+TVD of Top and Bottom and 25. , interval, s,ze and number) SIZE DE'P~H'~~ "PA~ SET (MD) ,~ 820~'-8~¢¢' w/~ 5PF / '8&5~' -8~72 ' 2~ ACID, FRACTURE, CEMENT SQUEEZE, ETC ~~,,~ ~EPTH INTERVAL(MD} AMOUNT& KINDOF MATERIAL USED ~eiow PINg ~ 82~' N/A - 27 , PRODUCTION TEST Date F~rst Production ~ Method of Operation (Flowing, gas hft, etc 12/1~/R1I Finwlnn Date of'Test' Hours Tested PRO.DU~T~'~'~ I OIL-BBL GAS-MCF WATER-EEL CHOKE SIZE GAS-OIL RATIO ~/!2/8! 9 ~ TESTPE~OD ~ ~5 ~ ~/~" ~ ,, Flow Tub,rig ~a~g Pressure CALCULATED OIL-EEL G~MCF wA~R-BBL O~VITY-API ~) Pres, 2~5 24-HOUR RATE ~ !!87 ~n __ ~.0 28 CORE D~T~ Br~efdescr~pnonofl,thology, poros~ty, fractures, apparent dlps and presence of od, gasorwater Submit corech~ps Form 10-407 Submit in duphcate 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 t~me of each phase ,,~ Top Kuparuk 8402r Form. 6419' 6461 ' Base Kuparuk 8734' 6706' River Form. 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge ~111 i i !MAR 1 O' 198 S,gned- I~V .~. ~. ~l~rQIl~l T,tle Area 0ps. Enqr. Date , , , , i ii .... INSTRUCTIONS General Th~s 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 d~sposai, water supply for injection, observation, injection for in-sltu combustion. Item 5' Indicate which elevation is used as reference iwhere not otherwise shown) for depth measurements given ~n other spaces on th~s form and in any attachments. Item 16 and 24 If th~s well IS completed for separate production from more than one interval (multiple completion), so state ~n ~tem 16, and in item 24 show the producing intervals for only the interval reported in ~tem 27 Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such ~nterval. 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- ~ng 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 ilORTH SLG['E E~GI~IEERI~:G FROM: J.J. Pa,.:eleK/Ann Simonsen CATE' ~- 2.~- ~/ WELL Transmitted herewith are the follcwing' PLEASE HOTE' BL - BLUELI;iE, S - SEPIA, F - FILM, T - TAPE / RE CE I PT AC,, :0:: [' "E ' ~_~_... ~, [...~.~/./.~¢ ~ ~F---~Z.-,, TE ~, , r~ .' '] ~ x/PLE;.~- RE-U?'I P. ECEi2T TO: ARCC ALAS:S~, I~C. At~s~flfl&GasCons Commission ~ ' Anchm age ,d ATT~' A;;;~ SIFO;~SE:i - AFA/311 P.O. BOX 360 A;;C}:['2ACZ, AK 99-10 STATE OF ALASKA O(' ALASKA ,L AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] X OTHER [] 2 Name of Operator ARCO Alaska, Inc. 3 Address P.O.Box 360, Anchoraqe, AK 99510 4 Location of Well Surface Location: 363' FNL, 600' FEL, Sec. 23, TllN, R10E 7 PermIt No 79-95 8 APl Number 50- 029-20417 9 Umt or Lease Name Kuoaruk 25650 -- 10 Well Number D-5 11 F~eld and Pool 5 Elevataon~nfeet(~nd~cateKB, DF, etc.) 16 LeaseDes~gnat~onandSer~alNo Kuparuk River Field KB=105' J ADL _95650 RJ,nar~ Riv~r Oil PC) 12 Check Appropriate Box To Ind,cate Nature of Not,ce, Report, or Oth~-D~al~,~ ........... NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforauons I~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] RepaIrs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Report muluple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Began perf operations on 6/11/81. RU, tested lub to 3000 psi. Perf'd intervals 8469'-8495' & 8444'-8469' w/Schlumberger 2 1/8" Enerjet w/4 SPF. RIH with HP, Spinner, Gradio & Temp Tools. Flowed well @ rate of 1378 BOPD. GOR=386, FTP=285 psi, FBHP=1999. Ran production logs. SI well f/BHPBU. Final SI BHP=3226 psi. POH with PL string. Secured well on 6/12/81. NOTE: HP Tool set at 6271'ss RECEIVED SEP ? 9 ! Alaska. Oil & Gas Cons. COiTIITIJSS Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gned _ T~tle The space be(~ for Comm,sslon u~' Condmons of Approval, if any Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Tr~pl,cate and "Subsequent Reports" m Duplicate i~ORTIt SLOPE Ei~GINEERI~IG TRA~;S:!ITTAL -- I, J. J. Pa'.:ele:./Ann S]monsen DATE' c~ _.// -~ ! WELL NAME' Transmitted herewith are tile following' PLEA.,r_ HOTE' BL BLUELIilE S SEPIA, F FILM T TAPE RECEIPT ACr,,:O.',LEDu _~:' · .. ~.-.._ DLE,~ RECEI?T TO' AP, CO ALAS!gA, I!~C. ATTII: A;~:I SI:'O~!SE~I - AFA/31 1 P.O. BO'< 3GO ,F,,m ~ r ,- ,, Cc1510 A;,Ci,u,,,~uu, Ar STATE OF ALASKA ALASK/~ IL AND GAS CONSERVATION C~ ,'1MISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] 2. Name of Operator ARCO Alaska Inc. 3 Address B, 360 Anchoraqe, Alaska 99510 4. Location of Well COMPLETED WELL)[] Surface Location: 363' FNL, 600' FEL, Sec 23, TllN, R10E 5. Elevation ~n feet hnd~cate KB, DF, et~: ) 12 6 Lease Designation and Serial No OTHER [] 7 Permit No 79-95 8 APl Number 50- 029-20417 9 Unit or Lease Name Kuparuk 25650 10 Well Number D-5 11 Field and Pool Kuparuk River Field Ku_~uk River Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data - NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit ~n Triplicate) Perforate ~{~ Alter Casing F-] Stimulate [] Abandon [] Repair Well [] Change Plans [] (Submit ~n Duplicate) Perforations [] Altering Casing I-'l Stimulation [] Abandonment l-ti Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng 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 detads and g~ve pertinent dates, ~ncludlng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska Inc. proposes to extend perforations of inter~al 8402-8444 to 8402-8495 of the upper Kuparuk Sands. The extended interval will be flow tested. All wireline work will be done through a 3000 psi lubrica- tor which will be pressure tested after being installed on the wellhead. Expected start date 6-11-81 0ii & Gas Cons. Commission k~cborage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed £~'L-/-&_~W ~ ~ I/~ The space below for Commission use I ~ Condmons of Approval, ~f any Title Kuparuk Startup Director Date 6/10/81 Approved by~ Form 10-403 By Order of COMMISSIONER the Commission Date Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" m IDuphcate , ARCO Oil and Gearr'! f ~ny North Slop[ , .ct Post Ofhce Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 15-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 Kuparuk E-7 Permit #80-80 D-6 Permit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir: Enclosed please find: 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17-4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9,.E-8 & D-7. Very truly yours~f , P. ^. YanDusen D~str~ct Dr~ll~n~ [n~ineer ?A¥:sp Inclosures ARCO 0~1 and Gas Company ~s a D~ws~on of AtlanticR~chfleldCompany Form R[FV. 1-10-73 Submit '1 ntentions" in Triplicate & "Sul~equent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for prol)osal$ to drill or to deepen Use "APPLICATION FOR PERMIT--~' for ~Jch proposals.) ~' OIL I;-I GAS ~ WELLI~ ! WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20417 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuparuk 25650 3. ADDRESS OF OPERATOR '9.WELL NO. P.O. Box 360, Anchorage, AK 99510 Kuparuk D-5 4. LOCATION OF WELL At surface 243' FNL, 601' FEL, Sec 23, Tl lN, RIOE, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' RKB 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Kuparuk River Oil ].1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 'Pool Sec 24, TllN, RIOE, UM 12. PERMIT NO. 79-95 ].4. Check Appropriate Box To Indicate Nature of Notice, Repo~or..~ther Data NOTICE OF INTENTION TO: ~_. _S.~BSEQU~,~REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTINGt OR AClDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Perforate (Other) (MOTEl Report results of multiple completion on Well ComPletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. (See attached perforating history) Alaska 0il e: ~: Co/:~ 16. I hereby certify that the fojIl~gol~is true and correct · (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE District Drilling EngineerDATE November 25, 1980 T IT LE PAT E See Instructions On Reverse Side DRILLING HISTORY KUPARUK D-5 API #50-029-20417 Permit #79-95 Began perf operations 7/25/80. Bled tbg press to 0 psi. Instl lubricator ~ tst same to 2000 psi. Run 2-1/8"-perf gun & perf 8654' - 8677'. Run press rec & flow well to tank, avg 72 bpd. Run 2-1/8" perf gun, perf 8664' - 8672'. Flow well 95% H20. Run bottom hole sampler to 8310', recover clear water sample tst lubricator. RIH w/2-1/8" perf gun & perf 8402' - 8444'. Run press, temp, & flow recorders. Flow well thru separator, 747 bopd & 462 bwpd. SI well. Run fluid sample catcher and take bottom hole samples. Run bailer & set cmt plug @ 8622' - 8600', WOC. Flow tst well. FBHP @ 1555 psi, FTP 280 psi. SI for press build-up. Pull tst tools. Shut & tst SSSV. RD lubricator. Instl & tst tree cap. Released well to operations group 8/22/80. Alaska Od & Gss Cons. Comrrlissiori Anchorag~ Transmitted herewith are DATE ( NORTH SLOPE DISTRICT ENGINEERING k-~_~ TRANSMITTAL # '//~5~- ~No_~L'J-! eNQ , ~ O~Ot~ WELL NAME: the follow~n~ for the subject ~ell' BL SCALE XEROX SEPIA L[NE F[LH BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.)- Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log ..... Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR' LEASE RETURN DATE- RECEIPT TO' · ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 ARCO O~1 and Ga~ ','~pany 'iC;e[~,Lp ',.,[_,- , , September 24, 1980 Mr. Hoyle Hamilton State of Alaska D~vis~on of Oil & Gas 3001 Porcupine Dr~ve Anchorage, Alaska 99501 Subject' As-Built Survey Plats f ,' _.~ ,- ,'., ~__._] 2 ~ GEOL 3 GEOL~ '~ STAI, TEC STAT l'EC C~NFrR: Dear Sir' In an effort to insure that your files are complete, we ed copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those ~ncluded in our original drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments i ( iii <:fF=.. WELLS GOI' I I I I ,.9 D'I~, '~CAL E.. I"'- 200' · 14 23 ~RIOE~IJM.) 24 WI~LL =I Y = 5,959,904.19 X 60 484.14 LAT : 70~18103.F~72'' LONG = 149°30'36.426" WELL :2 Y = 5,959,784.20 X = ~60 485.20 LAT 70 18~O2.492'' LONG = 149°30'36.424", WELL :3 Y = 5,959,664.22 X = ~)60 486.26 LAT = 70 18;O1.312'' LONG = 149°30'36.42 WELL qY = 5,959,544.23 X = ~60,487.32 LAT = 70~'18'OO.131" LONG 149°30' 36'418¢ WELL 5 Y = 5,959,424.25 X = ~60,488.38 LAT 70 17'58.951" LONG = 149°30'36.415· WELL ~6 Y = 5,959,304.26 x = ~60 489.44 LAT = 70 17157. 771" LONG = 149°30'36.413" WELL -7 Y = 5,959,184.28 X = ~60,490.51 LAT = 70 17'~6.591" LONG = 149°30,36.409. WELL Y = 5,959, O64.29 X = ~60,491.56 LAT = 7OVI7,55.411,, LONG = 149°30,36.407, *1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE BY ME, AND Ti{AT ALL DIMENSIONS AND OTIIER DETAILS ARE CORRECT,AS OF : DATE q/7/'7c~ I I L I iii i i i i ii1,11 ii II D? WELLeJ 1,2,5.,4.,5,6.,7,&8 LOCATION5 AG-gUILT I I IIII II I I ! I1'11 I II IIII I I II IIII , AtlanticRichfieldCompany {) iDATE: }DRAWING NO: NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT., KUPARUK ARCO Oil and Gas[~ ~any North Slope~ .... Ict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 2, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Kuparuk Wells D-4 & D-5 Dear Sir' Enclosed please find Sundry Notices detailing work planned for the above-mentioned wel 1 s. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/ms Enclosures ARCO Oil and Gas Company is a Division of AtlanhcRichfleldCompany Form 10-403 REV. 1-10-73 · Submit "1 ntentlons" In Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--J' for such prol3osals.} O,L F~I GAS [-] WELL'"' WELL OT.ER NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P, 0... Box. 360 Anchor0ge, LOCATION OF WELL At surface AK. 99510 243~ FNL and 601~ FEL Sec.. 23, TllN~ R10E, UM 13. ELEVATIONS {Show whether DF, RT, GR, etc.) 14. lOSt RKB 5. APl NUMERICAL CODE 50-029-20417 6. LEASE DESIGNATION AND SERIAL NO. ADL - 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuoaruk, 2_~6Sll 9. WELL IqO: Kuoaruk. D-5 10. FIEL[~ AND ~OL, OR WILDCAT Prudhne Bay. Kunar,~ RivP~ fli! ,P001 ~. sic., T., R., ~ mOY~OM HO~[ Oa~ECT,V~} Sec. 24.. TllN R1-F IIM 12. PERM IT-NO. ~ 79-95 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-- PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS {Other)_ Perfnrato, to~t and SUBSEQUENT REPORT OF; WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent ¢letall~ and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate, test, acidize, test, fracture and test selected intervals within the Upper Kuparuk Sands, Selected intervals within the Lower Kuparuk Sands will be perforated and tested. A 3000 psi wireline BOP/Lubricator will be utilized wi'th all wireline work. All perforated intervals, treatment volumes, and test volumes will be reported in a subsequent report, Expected Start Date~ JUly, 1~ 1980 Subsequent Work Reportecl on Form No. ~ Dated//_/~~ 16. I hereby certify that the fore and correct SIGNED -~~'. ..~- ,This space for State o~se) CONDITIONS OF A~ROVAL. IF T,TLEDiStrict Drilling Engineer DATE. May 30, 1980 COMMISSIONER DATE Approved Copy Returned See Instructions On Reverse Side -- J ."~_ I COMM~ NORTH SLOPE DISTRICT ENGINEERI_ TRANSMITTAL # ~(~') "J ~2~NO I ~ ~ GEO~ FROM' Jerry . PaweleE/~eo Lash WELL NAME' P~mL ~.. ~ ~TATTEC-- Transmitted herewith are the following for the subject well: DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log - Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL ~/~./~-/~ Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log SCALE XEROX ,,, SEPIA .., .. , / ,, BL LINE FILM RECEIPT ACKNOWLEDGED FOR: DATE: //~PL~ASE RETURN RECEIPT TO- ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL # h__t 3 GEO.- FROM: Jerry J. Pawele~/~eo Lash Transmitted herewith are the following for the subject well' DATE SCALE XEROX BL SEPIA LINE FILM ~.~%-~o BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og ,~'" TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log ~'~ Carbon-Oxygen Log ! ! / ,/ / RECEIPT ACKNOWLEDGED FOR' DATE' PLEASE RETURN RECEIPT TO' ARCo 0il and Gas Company Attn- Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 TO- ~q~L ( ! I co_J~_~ i _ICO_~' 1 NORTH SLOPE DISTRICT ENGINEERING ~] ENG~ _ ! t 3 EN~~ TRANSMITTAL ~1 ~E~_ ~ ~~ FROM' Jerr~ J. Pawelek/Leo Lash J3GE~/- DATE' ~- /-~O WELL I J CONFER, J Transmitted herewith are ~he following fo~ ~he subjec~ well' JFI~,_'_'__' BL DATE SCALE XEROX SEPIA LINE FILM .,, BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: P~~LEAS DATE- E RETURN RECEIPT TO- J~ III ~ ARCo 0~1 and Gas Company A~n' Hr. Leo Lash P.O. Box 360- Rm. ~311-FAB Anchorage, AK 99510 -- COMM ~ _ --- -CORM ~-'-~ EN._Cl~~ '~ EN~RAF 1 _.__ J STAT TEC I ¢ON~m~ ~l I I ~ICT EIIG I I~EE,'!, I ~iG SM ITTAL ~//~ ~ FROM- Jerry J. Pawel ',~ete Woodring~' NELL IiAME- /</F~/P,x~A~d/<' .~-,S' Transmitted herewith are the following for the subject well- DATE SCALE XEROX SEPIA BL LINE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. · Directional Survey- Gyro ' -- Single Shot Multi-shot Drill Stem Test- Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log SpinNer 'Survey Fluid Density Casi~"Collar Log Perfb.?~ting Record Nuclear F1 o-log S, ......... RECEIPT ACKNOWLEDGED FOR~ , ~ ~, :F,) ~g~ BY- // ~ Al' ~:(~ L][~ ~, ~ ~- ~' "'" "' PLEASE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn' Hr. Pete Woodring P.0. Box 360 --Rm. ~:449 Anchorage, AK 99510 1 Il P/P,F/ TO' ~ ~T hO~, H I~" ErlGI[IEERI[~G FROM' I I ,~T'T TF.C -1 WELL NAME' /<"6/P/~d~ ~-- ~ Transmit:ed herewith are the foll~~e~r-t~ subject well' [FILF: -I DATE SCALE XEROX SEPIA BL LINE ,,, Jerry J. Pa:vel e Woodring ~HC Sonic/Gamma Ray Log ~y~_~ Cement Bond Lo§/VDL Compensated Formation Density Log Compensated Neutron-Formation Density · . - ~- CoF...pensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey-- Gyro Single Shot Mul ti-shot"~ Drill Stem Test- Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL j-~,,~o Differential Temperature Log Spinner Survey Fluid Density j~,/.~,m~ Casing Collar Log Perforating Record Nuclear Flo-log RECEIPT ACKNOWLEDGED FOR- DATE' PLEASE RETURi; RECEIPT TO- ARCo Oil and Gas Company Attn' Mr. Pete Woodring P.O. Box 360 - Rm. Anchorage, AK 99510 ]/]O/gO HORTH Sl OPE 1 RES ENO I I ~ ~N~ I I I 3 ~NQ ! , DATE' ~~ ~0 [ Pawel /Pete BL LINE ,~.-~,/,~.~-~BHC Sonic/Gamma Ray Log ~ / ~ ~ Cement Bond Log/VDL ~.~a~Compensated Formation Density Log /~ ~'~ ~.~/~.~Compensa ted Neutron-Formation Density ~ . Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot Multi-shot Drill Stem Test - Test No. ~.~~~oDual Induction Laterolog-~ ~ ~ Formation Density Log ., , Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log / ___/ / / RECEIPT ACKi~OWLEDGED FOR' DATE' ~PI EASE RETURN RECEIPT TO' RECEIVED An¢l~ora[,~ ARCo Oil and Gas Company Attn' Mr. Pete Woodring P.O. Box 360 - Rm. z:449 Anchorage, AK 99510 'i/lO/8O ARCO Oil and Gas~' ~pany North Alask~_ otnct Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 17, 1980 Mr. Hoyl e Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk Well D-5 Dear Sir- Enclosed please find the Completion Report and Gyroscopic Survey for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosures ARCO Oii and Gas Company Is a Division of AtlanhcRichfmeldCompany Form SUBMIT IN Du rE* STATE OF ALASKA (se~ other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* Other WELLI I DRYO b TYPE OF COMPLETION NEW WORK DEEP- I~I PLUG DIFF WELL[X'] OVER['-'] EN I I BACK[--] RESER [--] Other 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4 LOCATION OF WELL (Report location clearly and ~n accordance with any State requirements)* At surface 243'FNL & 600'FEL, Sec 23, TllN, RIOE, UM At top prod interval reported below 1283'FNL & l162'FEL, Sec 24, TllN, RIOE, UM At total depth 1351'~NL & 918'FEL, Sec 24, TllN, R10E, UM 13 DATE SPUDDED 4 DATETD REACHED 15 DATECOMP, SUSP, ORABAND 1/29/80 2/25/80 3/4/80 1S TOTAL DEPTH, MD&TVD 119 PLUG BACK MD&TVDIZO IF MULTIPLECOMPL, I DEPTH I HOW MANY* 8930'MD 6883'TVD 18872'MD 6831'TVD Sinqle 22 PRODUCING INTERVAL(S), OF THIS COMPLETION -TOP, BOTTOM, NAME (MD & TVD)* Top Upper Sand 8402'MD 6420'TVD Top Lower Sand Base Upper Sand 8513'MD 6516'TVD Base Lower Sand 5 APl NUMERICAL CODE 50-029-20417 6 LEASE DESIGNATION AND SERIAL NO ADL 25650 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT, FARM OR LEASE NAME Kunaruk ?.~EO I 9 WE'LL NO D-5 (43-24-11-10) 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River 11 SEC,T,R,M,(BOTTOMHOLE OBJECTIVE) Sec 24, T11N, RIOE, UM 12 PERMIT NO 79-95 16 ELEVATIONS (DF, RKB, RT, GR, ETC)* 117 ELEV CASINGHEAD I 105' RKB 21 ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS All 23 WAS DIRECTIONAL 8639'MD 6625'TVD SURVEYMADE 8676'MD 6657'TVD Yes Oil Pool 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHCS/SP/GR, FDC/CNL/GR, Epithermal/Neutron/Sonic, DLL/MSFL/GR 25 CASING SIZE16. i z0-3/74:;45 Buttl K-55l 26 LINER RECORD CASING RECORD (Report all strings set in well) WE,GHT, LB/Ft I GRADE / DEPTH SET (MD) [ HOLES,ZE 65# Weldedl H-40 ['/2 below GlI 24" 3078' J13-3/4" 8915' 19-718" 28 PERFORATIONS OPEN TO PRODUCTION SACKS CEMENT* N/A CEMENTING RECORD 240 sx Arcticset II cmt 1500 sx Arcticset II cmt 2800 sx Dowel l self stres 273 SIZE -1/2" TUBING RECORD AMOUNT PULLED s cmt (Interval, size and number) SCREEN (MD) DEPTH SET (MD) PACKER SET (MD) 29 8305' ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC R234' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED u/A DATE FIRST PRODUCTION PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) WELL STATUS (Producing or shut-In) DATE OF TEST IHOURSTESTED ICHOKE SIZE IPROD'N FOR TEST PERIOD PRESS 24-HOUR RA~_TE 31 DISPOSITION OF GAS (Sold, used for fuel, vented, otc ) OIL-BBL GAS--MCF 32 LIST OF ATTACHMENTS Drilling History & Gyroscopic Survey 33 I hereby cer, l fy~oregol~ ~1~ attac~ln for m~atlon is complete and correct as determined from all available records SIGNED 7~ ~ _~_~ TITLE District Drilling Engineer GAS-MCF WATER-BBL J GAS--OI L RATIO WATER-BBL . ' lO.iT- GRA¥1TyT~PI (CORR.) TEST V)/I1;NF~SED ~BY ~.r DATE 3/]4/R~ *(See ~nstructlons and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General Th~s form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska Item 16' Indicate which elevation ~s used as reference (where not otherwise shown) for depth measurementsg~ven ~n other spaces on th~s form and ~n any attachments Items 20, and 22 If th~s well ~s completed for separate production from more than one ~nterval zone (multiple com- plet~on), so state ~n ~tem 20, and ~n ~tem 22 show the producing ~nterval, or ~ntervals, top(s), bottom(s) and name(s) (~f any) for only the ~nterval reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately~dent~fled, for each additional ~nterval to be separately produced, showing the additional data pertinent to such Interval Item 26. "Sacks Cement" Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 28' Submit a separate completion report on th~s form for each ~nterval to be separately produced (See ~nstruct~on for ~tems 20 and 22 above). 34 SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35 GEOLOGIC MARKERS WATER AND MUD NAME , Conducted cased hole drill stem test on perforations 2298'-2319' and 2339'- MEAS DEPTH rTRUEVERT. DEPT 2360'. Cumulative production was 2 bbls of mostly CaC1. mud or mud/cement filtrate. The zone was flowed for 25 hours. One wirel~ne sample was taken Top Upper Sand 8402 near the perforations recovered mud w/30 mg/liter concentration of oil. A small amount of oil was recovered off of the test assembly when it was Base Upper Sand 8513 pulled out of the hole. No pressure build up data was acquired. Top Lower Sand 8639 Base Lower Sand 8676 ,- 36 CORE DATA, ATTACH BRIEF DESCRIPTIONS OF L'ITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER Core data sent under separate cover letter by our Geology Department, 2/21/80. Drilling Hi story D-5 (43-24-11-10) API 50-029-20417, ADL 25650, Permit No. 79-95 Spudd, ed well @ 0900 hrs 1/29/80. Drld 13-3/4" hole to 2275'. Cored from 2275'- 2335 w/3 core trips. ~ to 3076' Ran DIL/BHCS/SP/GR, FDC/CNL/GR and epi- thermal/neutron/sonic logs. Ran 10-~/4", 45.5# K-55 csg w/shoe @ 3078' Cmtd csg w/200 sx Fondu cmt followed by 1500 sx Arcticset II cmt. NU BOPE & tst~ to 3000 psi. Changed over from mud to water to CaC12. Tstd 10-3/4" csg to 2500 psi. Ran CCL/CBL/GR & temp sur. RIH w/DST tools. Set pkr @ 2256' w/tail @ 2268' RI w/perf gun, could not get thru tools. Circ & warmed hole. POOH DST too~s. Perf'd from 2339'-2360' & from 2298'-2319' RIH w/DST tools w/1372' diesel cushion. Ran HP press tool to top of diesel. Open ~ST valve for initial flow of 8 min @ ave rate of 169 bpd. SI I hr. Flowed well 7 hrs. 190' cumulative rise. Took wireline sample @ 2335'. Reversed out diesel from tst. Set RTTS @ 2237'. Pump dwn DP @ 850 psi, 6 bbls/min. POH w/ret. RIH w/stinger stabbed into retainer. Cmtd w/450 sx Arcticset I cmt. Drld thru cmt 30' to top of retainer. Changed over to KC1 mud. Pushed ret dwn to 2900' Drld out ret, shoe & 10' new form. Tstd form to 12.5 ppg EMW. Drld 9-7/8" h~le to 8925'. Ran DLL/MSFL/GR, FDC/ CNL/GR & BHCS/GR logs. Ran 7~6# K-55 csg w/sH6-6-~ 8915'. Cmtd csg w/2800 sx Dowell self stress cmt. Set Lynes pkr. Arctic Packed 7" x 10-3/4" ann. Squeezed 300 sx cmt thru FO. Drld cmt to FC @ 8872'. Ran spectralog, neutron lifetime log, gyro,.~_ & CO logs Changed over to 'oil base mud. Ran 3½" tbg set @ 8305'. Set & tst pkof~ to 3000 ~si. Displ mud to'diesel. Set pkr & tstd log to 3000 psi. ND BOPE. NU tree. Released rig @ 2100 hrs 3/4/80. · r- ."/ Eastman / ~' *~ Whipstock l )~ A PETROLANE COM~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY Arco Oil & Gas COMPANY D.-5 WELL NAME ,,~uparu-k, F,,,iel,d,, 1North ,S,lqpe, Alaska LOCATION JOB NUMBER TYPE OF SURVEY A18OD0210 Directional Single Shot SURVEY BY Don LeJuene Alcska 0~ & . ,, OFFICE Alaska DATE 2-4-80 ARCO OIL & GAS F'AI.; D, WELL NO; 5 EUPARUK FIELD, NORTH SLOPE, ALASKA HHS, 0-3074HD, SURVEYOR; B KISER, DATE RUN; 4-FEB-80 DSS, 3192-8875HD, SURVEYOR; D LEJUENE J/N; A180D0210 VERTICAL SECTION CALCULATED IN PLANE OF PROPOSAL DIRECTION; S 76 DEGo 43 HIN, E RECORD OF SURVEY RADIUS OF CURVATURE METHOD ARCO OIL ~ GAS F'AD D, WELL NO; 5 KUF'ARUK FIELD, NORTH SLOPE, ALASKA COHPUTATION TIt~E DATE 14:42:26 22-FEB-80 PAGE NO. · I TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG DEPI'H ANGLE DIRECTION LENGTH DEPTH SECTION C 0 0 R ~; I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D FEET FEET FEET FEET FEET D ~i DG/100FT O, 0 0 0 O, 0,00 0,00 0,00 0,00 0,00 0 0 0,00 171. 0 30 N 68 E 171, 171,00 0,61 0,28 N 0,69 E 0.75 N 68 0 E 0,2? 265. 0 30 N 54 E 94, 264,99 1,21 0,68 N 1,41 E 1.56 N 64 20 E 0.13 360. 0 30 S 90 E 95, 359,99 1.91 0.93 N 2,18 E 2.57 N 66 58 E 0,33 454, 0 45 N 70 E 94, 453,99 2,85 1,11 N 3,19 E 3,37 N 70 52 E 0.35 ~-"548, 0 45 N 67 E 94. 547.98 3.86 1,56 N 4.33 E 4.60 N 70 14 E 0.04 642. 0 30 N 45 E 94, 641.97 4,55 2.13 N 5,18 E 5.60 N 67 40 E 0.36 736. 0 0 0 94. 735.97 4,76 2,42 N 5,47 E 5,98 N 66 ? E 0,53 830, 0 0 0 94, 829.97 4,76 2.42 N 5.47 E 5,98 N 66 9 E 0,00 924, 0 45 S 78 E 94, 92~.97 5,38 2.29 N 6,07 E 6,48 N 69 20 E 0.80 1018. 3 0 S 76 E 94, 1017,91 8,46 1,60 N 9,06 E 9,20 N 80 i E 2.39 1112, 6 30 S 85 E 94, 1111,57 .16,21 0,31 N 16,73 E 16,74 N 88 56 E 3,80. 1206, 10 0 S 87 E 94, 1204,59 29,52 0.63 $ 30,19 E 30,19 S 88 49 E 3,74 1301, 13 45 S 85 E 95, 1297,54 48,81 1,99 S 49.68 E 49,72 S 87 42 E 3,97 1395, 17 30 S 90 E 94, 1388,05 73,67 3,09 S 74,96 E 75,03 S 87 38 E 4,24 1489, 21 45 N 89 E 94. 1476.57 104.32 2,82 S 106.53 E 1583, 25 30 S 86 E 94, 1562,67 141,18 3,81 S 144,16 E 1677, 28 30 S 81 E 94, 1646.42 183,54 8,63 S 186.55 E 1771. 32 0 S 79 E 94. 1727.61 250,81 16,86 $ 233,17 E ~,~1865. 36 0 S 77 E 94, 1805,52 283,34 27.78 S 284,58 E 1959, 36 0 S 77 E 94. 1881.57 338,60 40,21S 338.41E 2053. 40 0 S 78 E 94, 1955,62 3?6,45 52~73 8 3?4,90 E 2147. 41 0 S 80 E 94, 2027,10 457,45 64.38 S 454,82 E 2241, 40 45 S 85 E 94, 2098,18 518,63 72,41S 515,79 E 2335, 42 0 S 8? E 94. 2168.71 579,75 75~66 S 577,83 E 106.56 S 88 29 E 144,21 S 88 29 E 186,75 S 87 21 E 233,78 S 85 52 E 285.93 S 84 25 E 340~79 S 83 13 E 398,40 S 82 24 E 459.36 S 81 57 E 520,85 S 82 1E 582,76 $ 82 32 E 4.54 4,52 4.00 3,87 4,42 0.00 4.31 1.74 3.49 3.11 2430. 45 0 S 87 E 95, 2237.62 64~.87 77.94 S 643.17 E 2524. 45 30 S 84 E 94, 2303.79 709.84 8~,18 $ 709.71E 2618. 45 0 S 82 E 94, 2369,97 776.19 91.~1 $ 775.97 E 2712. 44 0 S 81E 94. 2437,02 841.85 101.05 S 841,13 E '2806, 43 15 S 81E 94, 2505°06 906,52 111,20 $ 905,18 E 647,88 S 83 5 E 714,57 S 83 19 E 781,33 S 83 17 E 847,18 S 8~ 9 E 911,99 $ 83 0 E 3.47 2.33 1,60 1.30 0.80 ARCO OIL ~ GAS I:'Arl D, WELL NOI 5 t<UF'ARUK FIELD, NORTH SLOPE, ALASKA COMPUTATION TIHE DATE 14;42~2& 22-FEB-80 PAGE NO. TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'I')I ANGLE DIRECTION LENGTH DEF'TH SECTION C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITI FEEl' D H D FEET FEET FEET FEET FEET D M DG/iOOFI 2899. 43 0 S 81 E 93. 2572.94 969.92 121,14 S 967,98 E 975.53 S 82 52 E 0.27 2994. 42 0 S 82 E 95, 2642,98 1033.87 130,63 S 1031.45 E 1039.69 S 82 47 E 1o27 3074. 42 0 S 82 E 80. 2702.43 1087.17 138,08 S 1084,46 E 1093.22 S 82 45 E 0.00 DSS TIED ON TO PREVIOUS E/W MHS SURVEY ~,,<J192. 42 0 S 80 E 118. 2790.12 1165.91 150.43 S 1162.44 E 1172.14 S 82 38 E 1.13 3347. 46 0 S 79 E 155. 2901.59 1273.43 170.05 S 1268.29 E 1279.64 S 82 22 E 2.62 $581o 49 0 S 80 E 234. 3059.66 1445.72 201.48 S 1437.90 E 1451.95 S 82 i E 1.32 4081. 50 0 S 78 E 500. 3384,39 1825.60 274,02 S 1811.09 E 1831.70 S 81 24 E 0°36 4550. 50 0 S 74 E 469. 3685.85 2184.77 360.92 S 2159.62 E 2189.57 S 80 31E 0.65 4986. 51 0 S 74 E 436. 3963,18 2520,82 453,66 S 2483,02 E 2524.12 S 79 39 E 0.23 5265, 51 0 S 74 E 279, 4138,76 2737.40 513,42 S 269~,44 E 2739,98 S 79 12 E 5735, 49 0 S 75 E 470, 4440.85 3097.15 609,63 S 3038.37 E 3098,92 S 78 39 E 0,46 6231. 47 0 S 76 E 496, 4772.73 3465.65 701.92 S 3395.21E 3467.00 S 78 19 E 0.43 6575. 44 0 S 75 E 344, 5013,81 3710,92 763,34 S 3632,72 E 3712.06 S 78 8 E 0.90 7071. 42 0 S 77 E 496. 5376,54 4049,13 845,17 S 3960,91E 4050,08 S 77 57 E 0,49 7571. 37 45 S 76 E 500, 5760.18 4369,61 919,98 S 4272,54 E 4370.46 S 77 51E 0,86 7898, 35 0 S 75 E 327, 6023,44 4563,48 968,53 S 4460,27 E 4564,22 S 77 45 E 0,86 8241. 32 30 S 78 E 343. 6308,61 4754,00 1013.01 S 4645,53 E 4754,70 S 77 42 E 0,88 8736, 28 30 S 76 E 495. 6735.03 5005.17 1069,51 S 4890.26 E 5005.85 S 77 40 E 0,83 8875, 27 0 S 74 E 139. 6858,04 5069,85 1086.26 S 4952,77 E 5070,50 S 77 38 E 1,27 FINAL CLOSURE - DIRECTION: DISTANCE; S 77 DEGS 38 HINS E 5070,50 FEET ,. 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HtCKMAN .............. COHF'UTATION TIHE DATE 00:01:35 00--00 PAGE NO · 2 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH "'DEPTH -SECTION TVD C 0'0 R-D I--N A-T-"~-'S-DISTANCE DIRECTION SEVERIT' FEET D H D FEET FEET FEET FEET FEET FEET D H DG/iOOF' 2~00+ 45 30 S 85 E 2700. 44 0 S 86 E 2800. 43 15 S 8~ E 2~00. 42 15 S 88 E 3000. 41 30 S 82 E '-~00, .... 2354.62 742.~1 224~.62 100. 2425.63 812.48 2320.63 100. 24~8.02 880,57 23~3.02 100, 2571.45 947.36 2466+45 100, 2645.~1 1013,38 2540.~1 42.36 S 753.;33 E-- 754.52 S 86 47 E 47+8~ S 823.51 E 824,~0 S 86 40 E 52.70 S 8~2+;33 E 8~;3.8~ S 86 ;37 E 56,25~S .... ~60712-E- ~61.77 S 8& 3~ E &2.06 S 1026.58 E 1028.46 S 86 ;32 E 1.52 1.66 0+75 1~'~ 3100+ 40 15 S 81E 3200. 43 15 S 80 E 3300. 46 ~5 S 80 E 3400. 48 45 S'79~E 3500. 49 45 S 80 E 3600. 50 0 S 80 E 3700. 50 0 S 79 E 3800. 50 15 S 79 E 3900+ 47 45 S 7~ E 4000+ 50 15 S 80 E 100, 2721.52 1078.5~ 2616.52 100, 2796,12 1145.0;3 2691.12 100, 2867.13 1215.30 2762.13 100. 2~34.68 1288.~4 2829.68 100,---~,-2~,~6' 1364.60 2894.96 71.74-S -'1091.30 E 1093.66 S 86 14 E 82.73 S 1156.~7 E 115~.93 S 85 55 E 94.95 S 1226.30 E 1229.97 S 85 34 E 108.;38 S -1298+78 E 1J0;3.;30 S 85 14 E 122,19 S 1;375.27 E 1;378.6~ S 84 55 E 100. , ;3064,40 1440.94 2959,40 135.47 ~ i'4~8,56 E 1454.89 S 84 ~9 E 100+ ;3128+68 1517.45 ;3023.68 ' 149+4;3~'S 1523.89 E 15;31.19 S 84 24 E 100. ;319'~ ~ E 1607.6° S 84 9 E ~.79 1594.13 ;3087.79 164.07 S 1599.~ ~ 100. 3'257.07 1670.68 3152.07 178.69 S 1674.42 E 1683.92 S 8;3 55 E 100+ ;3;321.;35 1747.1~ ;3216.~5 "1~2,&5'S 174~.74 E 1760.Sl S 8;3 4~ E 1.41 3.07 3.00 2.61 1.25 0.25 0.77 0.25 0.50 0.91 4].00. 50 30 S'77 E '100, 3385.13 1824.17 3280.13 4200. 50 15 S 76 E 100+ 3448.~1 1~01.1~ 3;343.~1 4300~ 50 15 S 76 E 100. ~512.85 1~78.07 ;3407.85 4400+ 50 0 S'74-E ............ £00~-'~3576,9& .... 20540'78 -3471.96 4500. 50 45 S 75 E 100+ ;3640.74 21;31.74 3535.74 208.00 S 1825.21 E 1837.02 S 8;3 ;30 E ~. 98 S 1900.11 E 1~1;3.50 S 8;3 1;3 E 244,58 S 1974.71 E 198~.80 S 8~ 56 E 264-7,'~5--S ..... 2048'J-83 -E "' 2065.83 S 82 -;3<2- E 285.0;3 S 212;3.05 E 2142.10 S 82 21 E 2.32 -- 1.56 1.08 4600. 51 0 S 74 E 4700. 51 45 S 74 E 4800+ 52 0 S 74 E 4900, 51 30 S 74 E 5000, 51 15 S 74 E '-lO0-J '3703.84 2209.2& 3598.84 --305.76 S 2197.81 E 2218.98 S 82 5 E 100. ;3766,26 2287,30 ;3661.26 ;327,29 S 2272.~1 E ~96.35 S 81 48 E 100+ ;3828.00 2;3~5.87 ;372;3.00 ;348,98 S 2;348.52 E 2~74.31 S 81 ;3;3E 100, ;3889,91 2444.;32 ;3784.91 ;370.&2~S 2424,01 E 2452.18 S 81 18 E 100. 3952.33 ~.~'°.36 3847.33 392.16 S 2499,11 E ~-~-.°~°~ 69 S 81 5 E 0.82 0.75 0.25 0.50 0.25 5100+ 51-'30' S 74 E ...... 100. 4014~75 '2600.39--'3909.75 ..... 413'~6¢"S---2574-J21-"E .... 2607.24 8-80' 52 E 0+25 ARCO OIL g GAS COMPUTATION PAGE NO, KUPARUK FIELD WELL D-5 TIME DATE GYRO MULTI-SHOT RUN.ON.~Z80_B~.A, HIOKHAN 00;01;35 00--00 TRUE MEASURED DRIFT DRIFT .... 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C: 1 1855.82 3? }. 62 1.9'--n3.47 426. 35 1 S./3 l. 14. 45':,. 03 1 S/68.85 30.28 S 3.3c).-,'5 E 331.63 S 84 46 E 4.50 ~-'~',_,_. 92 S '::/,2_.. .26 E :-:64.03 41. 10 '.S 3'-:, 4.75 E Z: '-.? /_-, . :B8 'S E: 4 :-: E I. E: _:: 4_~. 7? c- .... 427 '-"-' E~,:, . .cf'--/ .... 50 13 S 4._- :33 E 4/,2. ~'9 S :_:3 47 E ~ :--:0 4.',"-' 1. 'P4 2006.27 ._ .~ _, 18 2 (') 4 :z:. ~.j 559. 17 207'2.4 E: 574.]6 2114,75 6~9.8'7 2149.4~ ARCCI AI_AC,}A, INC. F'AD 10, WCLI_ NFJ: 5 SIOMA-GYRO t'I_IF-'AFa.I~ FI EL[I, NCIIR fl-i SLOPE, AI_A'BI-'.A ,_lOB NA: AOS/:::3Z 07.'C)5 C OMPI.ITAT I ON T I ME DATE ] 3: 54: ()/-, 07 - 0 C T - 8 :' F'AAE NO. " TRUE MLA'=.,URI.][~ I~RIF] DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S LI R E [IOGLE~, DEF' Fit ANbl. E DIREC TII:IN LENGTH DEPTH '].;CC f ION TVD C 0 0 R D I N A T E S DISTANCE DIREC l ION '.SI.=-VERI I FEE T I* M D M FEET FEET FEE'F FEET FEET FEET 2500. 45 42 S 82 18 E 260C). 45 0 ',E, L::O 54 E Z'700. 43 48 '~, 80 18 E ~'800. 4:: 18 '._--, 7o 12 E 2':/n0. 42 24 '=, 7'--/ =:/=, E (-) .::,.-.,,:,,=y. 1 (') 0. ':'~ ':',.,._.S g .4 :: 100. 243A. 88 100 -'=;o~: ":,~ 100. 2576.67 665.58 2184.16 736 46, ~'~'~ 43 . ~_4. 806.26 2325.88 875.06 239r:.35 942.9? 2471.67 68.86 S 667.65 E 671. 19 S 84 7 E 3.20 79 -'~: c 7'::8.02 E 742 =" o ~-,:, . .,:.7 c 3 E: :{ "" # ~ _1 ._1 _, i., _ . 9C).68 'S 807. C) 5 E-: :312. J.3 '3 8 3 ::,5 E-: 1.2/ 102.94 '._:, 874.84 E 880,88 F, 83 17 E. ().'-:,""~ 115.45 S 941.69 E ':/48.74 $ .'::'3i E 0.' -:C) C)('). 41 1:3 ::, 7 '=/ 6. E 3100. 40 '::0 S 79 24 E: -:200. 42 3(.) S 79 0 E 33(.)0,, 45 .36 S 77 24 E :4~.)0. 48 30 '_:, 77 36 E 100 '-' F '=' ....... . ..:. :,._, 1 16 1 (')¢)'9.64 '"~146 16 1 (')0 '-'- -' ' . . . ..: 7~ ¢.. 74 1 C)75. C)5 2621 74 100. 280 ] . 6 :',' i 141.25 2696.63 100. 2873.50 1210.74 2768.50 1C)0~ 2':/41.6._:: 1283.9 :: 28:36.6 3 127.78 S 1007.1'6 E 1015.:33 S, 82 46 E lC:'=~.'~'=/ S 1071.5c/ E 1080. /.,'-? S 82 .-:3 E ,:' ~ ':-: :~ 1.~'=',..,.. 41 ._,'= I I _::6 ./:,7 E 114~ ..... . '-', ,_,. 2'2 E 166.62 ,.E, 1204.72 E 1216. 19 S 82 8 E 182.47 S 127/_-,. 18 E 128'./. 16 ,E: 81 52 ~ 1.15 0.82 ". ::. 29 2. ':~0 ::500. 4':/ 0 'S 78 1'-' E :6.0(). 48 54 E, 78 1::.: E ":7C)0. 4':/ 42 S 7'-' 994 E ::E:OO. .4c/ 4::: S 79 42 E ::') 0 F,. '-,C) 0 'E, 7':~ 0 E 10'0 qA(")7 56 1359 0':./ '-' ' ...... ~90~. 56 1 O0. :-::07'-=:. z3 1434.47 '--'¢/6, 100. 31 ':":'_, ,.,. 441510 · 21 :,0..:,..'.',-' - '-"-'. 44 1 (")('). '-' ':'~ -' .. ~0.:,, 05 1586.42 30'=./8.05 :' -' . ,:, 100. .,.-'67.47 16,62 ~"--' /,-' 47 198.2:3 8 1349.69 E 1364.17 S 81 39 E 213.58 S 1423.51 E 1439.45 E, 81 28 E, 227.9! $ 1497.96 E 1515.20 S :~:1 21 E 241.4~ S 1573.07 E 1591.49 S :--:1 1/_-, E 255.57 S 1648.24 E 1667.'-74 S 81 ~ i E 0.67 (). 13 0. 1 C: ('). 57 .1000,, 4c/ 4::: ':; 77 42 E 410(). 4'/ 54 ':, 77 6 E /IS'O('). 5(') 6 S 7E. 54 E 4 .:C) C). 5 C) 6, ':_, 7 7 0 E 4,100. L,O 6, '..i', 7% 3,') k' 10C). "c: -::._-:~ 1 . ,:,:=:'-' "' 1739..--'~"o 3226 . 8,=,"-' ] ~.)0. 3 _=:o6.36 1815.71 3291.36, 100. ..::460.64 1892.32 3]:55.64 100. .35'."4.78 1969.02 341 'F/. 78 100. ._::588.93 2045.73 _::483.93 271.01 S 1723. 15 E 1744· 33 S 81 4 E 2:37.68 S 1797.75 E 182C).6-.=' S :BO ~95 E 304.92. ':._, 1:=.:7'2.-:::'-.?. E 1897 .05 ':, ~:(")_. 45 E: :322.25 $ 1947. 11 E 1'.-:/73. 60 S 80 .'-:6 E 340.48 S 2021.62: E 2050. 10 'B 80 26 E 1.01 0.4 / 0/"~, (.). 1.J5 45,0C). 50 "'=: E, 75 42 E /I6C)(). t,O 41 S 74 18 E 47o0. 51 14 'E, 75 54 E 4:::00. 50 54 % 74 18 E 490,3. 5l 3 'E, 74 30 E 0C). '::65 ='. :::'.-.-/ 212.--'- -'. =19_ .:,._,47'-"=. 8'-:/ 0C). .3716.45 21 'P':,. 7'q .3611.45 00. B77':/. 44 2277.39 3674.44 (')(') 384 .'. 28 .... "=, = - -. =: ....,. 15 37:37.28 00. ~"' ' = . 3800 · =, .'./( )., 24 24.~:L-''. 7,'_=: . '>4 359.6 ('). ._,': 2 ('). ':/,/-._. 08 E 2126 .70 S :i:(-)_ 16 E :379..'=,o .. _ · _ ,:., :=;2170.65 E 2203.5':/ ¢, :::0 ~, E '::".-,":/ "l'=, S '-"-' '-- . ...... :~.4._,. 71 E-: 22:q0 97 S 79 55 E 419.55. -'=.., ".320. ':' :.A,,_, ,_ E ..-,.:,.~o.,._ ,_, · 5C) ._,c 7':~ ~5 E 44.0.44 '_:, 23'.:/5.71 E 24 35. :F:/=, S 7'-/ '35 E 0. 32 1.12 1. 36 1 . 2..? C). -' "' L.,0o0. 51 11 5, 7J 4:' E ':lJoO. 50 5'=,' ':, 74 42 E ',2C)(). '90 5:: S, -/:: 6 E 5 _:0(.). 5C) 1 '.:, :':, 74- 4,?: E ~-~,10c). 4° 4:3 ':, 7,-1 4F' E 1 (JO. _=:':.~68.01 2510.54 :3863.01 I 00 ,, 4() 3('). 8 3 2588.1:7 3925.83 10A. 409 3.85 2665.83 3988.85 100. 4157..37 2742.97 405~. 3:7 100. 422'l .62 28] S/. 56 4116.6.--.' 46,1.76 :=-, 2470.58 E 2513.36 '.::, 79 25 E 482.95 S 2545.44 E 2590.:~:5 '_:, 7',-) 15 E 5C)4.48 S 262O.05 E 2668.17 :E, 7¢/ 6 E ,525.90 S 26'P4.25 E 2745.10 '.E, 78 57 E '=' ':' 2821 .'=;-' c 78 50 E 546. 1'-'~ c._, ~.76 .... . 17 E .... ~ ._, 0.6.4 1, -25 1. 39 0.4 5 ARt_O ALA'",I A, II',IC. F"'~D lB, WELL N i~: 5 E, ltSMA"GYRO ~.I_IF'AIRLII' I:'] F~LD, NURTH 'SLOPE-., ALA'_:;I A ,J(~B NO: AOg::-:3Z0205 COMPIJ TAT I ON 'r t ML" DA1 E I 3: 54:06 07-0CT-83 PAGE NO. 'f RUE MEA':,UF(t-D DF(LFT DRIFT COURSE VERTICAL VERTICAL 'E, UBE, EA R E C T A N O U L A R C L 0 ':.-, U R E DOGLEg. L~EF'I'H ANGLE DIRECTION LENGI'H DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION '=,EVEIRI I FEET il M D M FEE [ FEEl FEET FEET FEET FEET [~ M DG/1001 100. 4286.01 2:~ 96.02 4181.01 100. 4 35( } 81 2972. 12 4 ~ 4 ....:, 1 100. 4416.21 3047.72 4311. ;71 100. 4481.97 '3 ~ 23,, 05 4376.97 100. 4548.24 3177.93 4443.24 566.44 L=, 2841.93 E 28'P7.83 E, 7:_: 44 E ?~_ 87 . O..~].. S ~.? 91 ._.~. 26 E .;, o 73 .78 c_, 78 -E: 7 E 606.88 S 2o88.25 E E:049.'25 ,E, ?8 ::1 E 624.9. 1 '.E, :::_ 0 A. 1 . 40 E .E: 124· S_ :E: ,=_, 7:3 .~-',:,"' E 642.08 S 3134.28 E 3t'o'g..37 S 7:3 25 E 0..T,:E: 0. o0 t. 04, 100. 4 615.07 .'_--:272.32 4 510.07 ~ 00. 4682.77 3345. ':.' 1 4577.77 200. 4820.0::: 3491.31 4715.08 10U. 4890. 15 ..-:562.65 4785. 15 100. 4961.41 3632'. 80 4856.41 6...:z.6:3 c.., 3206.57 E 2:.273.72 S 78 23 E 677.'::1 '=': 327:~.0'2 E 3347.26 E, 7:3 20 E 712.12 E, 341w.1':" E :"4492. ~._ /-_, 'b 78 14 E 729.14 .S 3"~88.47 E 3563.86 S 7:_: 12 E 745·51. S 355/=,.6° E 31:.33.98 'E, 78 10 F 0.77 U. ,A · 1.54 0.4 '"' 100. 5033.25 3702.36 4928.25 100. 510=,. 71 3771.28 50o0.71 100. F, 178.82 38:39.50 507:3.82 1 oo. 5252.28 3'-?07.36 .5147.28 10,'~. ~326.0'2 3974.90 5221.02 761.52 $ 3624. 38 E 37C)3.52 S 78 C-: E 776.~6 S 3691.55 E 3772.4] E, 78 7 E 7o2.60 S 3757.'-75 E 3840.63 S 78 5 E 807.92 S 3824.06 E '3'=~0:]:. 48 E=. 78 4 E 822.60 S 3890.0A E 3976.02 S 78 4 E 0.55 o. 67 I . 0':~ 1.16 <'). 7 3 /10o. 42 ~> ':, 77 0 k. /:"0~}. 41 17 '_.:, 76 18 E /-_-:t~(),, 4r~ 6 5, 77 0 E 7400. ::,o 0 '_:, 75 6 E /~.,,)c~,, 37 25 ':, 7': 12 E 100. 5400.20 4041.96 5295. =.:'0 100. 5474. o 3 4108.4 0 5369.9:.:: 1AO. 555o. 7/:. 4173.60 5445.76 100. ~,'-,27 86 42 37 27 =,,~;£' .-' '::/- 100. 5706.44 42'9~>. 06 5601.44 837.63 S 3955.35 E 4043.07 E. 7::: =: E 85.'.97 S 4020.00 E 4109.50 S 7:.:,' 1 E E,/-,:' 'r-, . . .. 78 0 E ....... t~. S 408'2:44 E. 4174 67 ,:,,:,.=.: ,:. :- -,.-.,, :: 4 .' .,,: '31 ':; 77 $::: o,-.,._..:.:7 .., 414 _,. .._:'-~, E · . _ E 900.27 S 4204.72 E 47::00.02 E, 77 55 E 0. -' 3 r). :_::5 1."~7 1 .o7 7/,o~,. :.:6 4'0 'S 75 6 E /7cn~. 37 -: ':., 71-, }:6 E] 7:-:A~).. .:,-'":_, .:4 '" 7/ 42 .F 7'-~C) 0. ::4 '-:7 ':, 77 ::0 E :::,}(~0. _::(~ 7 '5 7:E: 3<) E 100. 57::':6. 18 4359. 34 56::: 1. 18 10~. 5066. 11 4419.4'2 5761. 11 ~ 00. S':~46.69 447:::. 63 5841.6o 100. /_.028.5 l 4536. I I 5923.51 1 00. 6111.06 45':~2.54 6006.06 '716.75 :F., 4262.77 E 4360.23 E, 77 5-' E o31.43 :=-, 4321.04 E 4420.2° E, 77 50 F 944.60 S 4.::78.76 E 4479.4':* '5 77 50 E 956.95 E, 44 34.91 E 4536.98 E, 77 4'P E 968.68 S 4490.1.2: E 459.=:. 4_--: S 77 "50 E 1 · 2'° 0. '-' 3 0 · '9/_, A. 100. 61'-T¢3. '96. 4./:.48.42 6088.'°/.. 979.31 c_. 4545.02: E 4649.34 'E, 77 '-,0_ E 100. 6278.04 4702.~1 617.3.04 98'9.73 .'_:, 45'P8.15 E 4703.46 S 77 51 E 6 ..-._ ,:,. 1000 :-::-: S 4649 10 E 47.=,.'-i. 62 c 7 7 .""; 1 [--. 10(') 6"::63 75_, _ 47._M 4 /-./:, '-'M"" :'N - - ._, lC)O. /...',44':,. 02 ,q::;,n,~,. 24 6.=:44 02 ;I Ol...-' '"'-' 5- 4/-.':'° 40 E 4:::07 2o :~., 77 51 E ..... ~ . t.I ,.~ - · · ~ - · 1~0, 6~,']-:4~Ol 4857,,46 64 2'-?.,¢~ 1023.61 S 4749.36 E 4858.42 S 77 50 E 0.66 2. 34 0.7'7-: u. 2'4 O. 1 :=: AlZrU ALASKA, 1NL. I'AD lB, WEI.L NF~: 5 'BIGMA-GYRO I ~ II"AI~ ~1-' F] L-I D, Ixl~]RTlt '],LOPE, ALASI-'A dOB NO: Ac)':~83Z02O5 COMPI. ITAT I ON T I ME [,ATE 1 3: 54: (')6 07--Fu] T-8 3 PAE, E Nil. ' ] RUIF MEA'-],I~RLD l~l~I["l I IRIFI PF~LIR':,E VERTICAl_ VERIII. AL SUBSEA R E C T A N G LI L A R C L O S, U R E I IOC, LE~, DEPTI~ ANGI E DIRE-CTION LENGTH DEPTH SECTION TVD E 0 0 R D I N A T E S DISTANCE DIREL'TION SEVERll F EFT I"l bi D bi FEET FEET FEEl FEET FEET FEET D ~1 [u'.,/l 0( ~F :_--:553. ]:0 13 S 77 12 E 53. 6580.59 4884.7:4 6475.57~ 1029.52 S 4775.5:3 E 4885.29 '_--, 77 50 E O.'P':~ PRO,JEL"TED ] 0 PBTD ::.::E:7 Z'. ]:0 l 3 'B 77 I 2 E ~:1'--~. 6856.25 5044.87 6751.2~i 1065.07 '--_, 4°~:2.14 E ~.,045.83 S 77 4o F 0. PRO,JEC I[SD lIJ TD :::..,2:()_ .. .-:o 1 3 'B 77 1-' E ~',':'_,_.. /-.'=.~0/-.. :37 ..... .~,c)74 . (')/-.. 6801 . 37 1071 . 56 S, 4':~60.60 E 5075.02 ':_, 77 4':~ E ('). ("h') FINAL CLOSURE - DIRECTION: ]~ISTANCE: S 77 DEGS 48 M IN:_:; 38 SECS E 507s.02 FEET AR'tO.Al ASI A, INC, F'~D l..r.~ I,,IEt_L NO: 5 '.=.TC, MA-GYRO .JOB NO: A0~83Z0205 · I I IPAI-~I.II... F ] EEL II, i',IORTH '.-:.L OPE, ALA'.:..kA 'BIGMA-OM':'::, (')--,:,,=,7.,:. MD, SURVEYOR':_;: EORAM/F'FFFEF(FORN, [sATE RUN: 10-'E. EF'-83 ':.II-,MA 17'5 NO. 181:_::4, PROBE NO. 064 I:OI(E'SIOHT: N45 56E '..URVEY "IA~ EN FROM WELl_HEAD RFCORD OF INTERPOLATED SURVEY ARCO ALAS~ A, II"IL'. F'AD lr~, WELl._ bIFf: 5 '_:,I[.,MA-C, YRC~ FIJPARIlF' FIEL_D, NORTH SLOPE, AI.A'_:,F.A ,_Il]lB NO: A098 E:Z02C~5 COMPUTAT I ON 1 I ME [~ATE 14: ! 2: 2:'2 07- 0 ~] T-::,' :: PAGE NO. · i, MP~RI' E R .............. C ODE ........ NAME TR~ ~E 'E,~ ~B'E;EA MEA'],URED VFRTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL DEPTI~ DEPTH DIFF DEPTH E ~:~ 0 R D I N A T E S DISTANCE DIRECTION ]-ttlF~ NES':, FEET FEET FEET FEET FEET FEE'r D M '1OF" tlr'PER '3Al,ID I-:A':",E IJl: 'F'E R '.::AND TOP I_~ IWI:]R SAI',ID ~¢A?,I- I..I)WE"R '~-.-,ANB 8402.r~0 6450.74 !'751.3 6345.74 1012.58 '-:, 4700.37 E 8514.00 654 6. '--¢8 1967.0 6441.98 1025.1 7 '.:'; 4756.2':¢ E 8/.,.3':¢ ,, Ou 66~,4. ':) 1 1 ':¢84. I 654'--¢. 9:1 10 39. 11 '---; 481 7.79 E 8734.00 67'37.00 1':~97.0 6632.00 1049.70 S 4864.4:1 E 480:--:.22 S 77 51 E 4865.52 S 77 5¢~ E 4928.57 '_:; 77 50 E 4'.:~76.38 S 77 4'? E t t ~ ~ io , CLOS RE 5 7 .0 t Ticket F L U I D S A M P L E D A T A Date 2-10-80 Number 564381 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu Ft. Gas of D.S.T. CASING PACKER WITRc~otion ANCHORAGE cc. Oil APR cc. Water Tester H. ~/~NN W,tness C. K. JONES cc. Mud Drilling Tot. Liquid cc. Contractor ROWAN #34 T3H S Gravity ° APl @ °F. EQU I PM E NT & H aLE DATA Gas/Oil Ratio ~'u. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation 3 05' RKB Ft. CONTENT Net Productive Interval Ft. Recovery Water ~ @ ~ °F. ppm All Depths Measured From Kelly Bushing Recovery Mud ~ ~ °F. .ppm Total Depth ;?~)~)l ' Ft. Recovery Mud F,Itrate ~ @ ~ °F.. ppm Mo,n Hole/Casing Size 10 3/4" Mud P,t Sample ~ ~ ~ °F. ppm Drill Collar Length I.D Drill Pipe Length. .9.9 I.D. ?? Mud Pit Sample Fdtrate ~ @ ~ °F. ppm Packer Depth(s) ? ;? RD ' Ft. Mud Weight 9.9 v,s sec. Depth Tester Valve 2264' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Diesel 31.7 bbls. 1362~t. Pres. Valve Choke Choke 2.25" Recovered 1362 Feetof _.cushion._ _ ,~ L Recovered 129 Feetof rathole fluid small trace - Recovered Feet of F D .~, ,~ , t ~ r ~ ~ Recovered Feet of Recovered Feetof SEE PRODUCTION TEST DATA SHEET .~U?C~.N, OKLAHOMA Remarks * - CHARTS INDICATE TOOLS WERE OPENED FOR APPROXIMATELY 5 1/2 HOURS, THEN CLOSED FOR APPROXIMATELY 130 MINUTES AND THEN WERE RE-OPENED AND REMAINED OPEI~ UNTIL START OF REVERSING. F]~NAL 50 MINUTES CLOSED.IN PRESSURB NON-USABLE. APPARENTLY THERE WAS A PROBLEM MANIPULATING THE TOOLS DUE TO SURFACE VALVE PROBLEMS... i Gauge No. H-52 Gauge No. H-56 Gauge No. TIME TEMPERATURE I Depth' 2294'I ~t. Depth: ,?.2941 Ft. Depth' Ft. (00.00-24:00 hrs.) . 48 HourClock 48HourClock HourClock Tool 2-10 Est. 75 8 °F. Blanked Off NO Blanl~ed Off NO Blanked Off Opened 0400 Opened 2-31 Actual CF. Pressures Pressures Pressures . Bypass 0820 Field Office Field Office Field Office Rel~orted Computed Initial Hydrostatic 11 51 11 09.8 11 08 1105.1 "1 Minutes Minutes Initial 381 4 94.0 376 488, g .... Flow ~'~ F,na~ 381 557.0 376 557, 1 8 * Closed in 530 651.0 5;?7 6B3.0 60 * =-a Initial 530 558.0 527 557, l c o Flow u°': Final 550 612.0 E,~R 61 3.2 430 * Closed in 650 frill 942 Initial 550 61 g ~ ~ Flow.,, Final 610 61q 210 aosed ~n 1971 945 50 F,nal Hydrostatic 1110 11 gl. ~ I 1 7q 1104. R -- Casing perfs. Bottom choke Surf. temp 'F Ticket No, 56438l Gas gravity Oil gravity GOR Spec. gravity. Chloride~ I')pm Res, @ 'F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED , , : Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks p.m. psi MCF BPD 2-8-80 0500 Called for job. 0700 Loaded equipmen t. 0830 On 1 oca1:ion. 0900 Made up 1:ools. 1000 Recorder case collapsed. Took 1:o Tri S1:a1:e 1:o drill ou1:. 1330 Back on local:ion. Circula1:ing condil:i drilling fluid wil:h drill pipe. Pulled drill pipe. ,, 1802 Made up 1:oo.~g and si:afl:ed in hole. 15 si:ands diesel cushion. , 2131 Se1: pack er. 2432 Opened 1:ool - 2254'. Z-9-80 0130 Star1:ed in hole wi1:h wire line. 0130 Wire line 1:ools will no1: go 1:hrough circul a1:ing valve. 0230 Try 1 11/16" anchor bar. OK. 0907 Shear out circula1:ing valve 2750 PS[. O.K. 0923 Reversed 0954 Repai red 1:ool s. 2200 Loaded clock for re-1:esl:. 2300 Made up 1:ools. 2-10-80 0130 15 si:ands diesel cushion. 5e1: RTTS al: 2283'. PRODUCTION TEST DATA Casing perfs Bottom choke Surf. temp 'F Ticket No 564381 Gas gravity Oil gravity GOR PAGE 2 Spec. gravity Chloride~ ppm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date Choke Surface Gos Liquid Time a.m. Size Pressure Rate Rate Remarks p.m. iisi MCF BPD 0400 Opened tool. 0408 Closed tool. 0508 Opened tool.. 1218 Closed tool. 2-11-80 0400 Opened tool for flow and sample catcher. 0730 Closed tool and reve'rsed out. Sheare¢ at 2900 PSI. 0820 Pulled tools loose, ran in 2 stands to clean up hook. 1030 Broke down tool s. 1400 Loaded equipment. 1400 Made out ticket and charts. , , , , s PRODUCTION TEST DATA TICKET NO. 564381 Drill P~pe or Tub,ng Drill Collars Revers,ng Sub Water Cush~on Valve Dnll P,pe Drill Collars Handl,ng Sub & Choke Assembly ~i~i~x~,v~x Circulatin. g Va.l. ve xx~mx~x~mx APR x~x~myx~ 9 5/8" Circulating Valve Multiple CIP Sampler ... aa Do 6.12" 5" 5" fi_ 12" 9 5/8" 6.50" Extension Joint AP Running Case Hydraulic Jar VR Safety Jo,nt Pressure Equal,zing Crossover RTTS Packer Assembly Ia D° 11 2.25" 2.25" 3" 2.44" 2.25" 4.69' 3' 12.69' 3.67' 7.13' 7.98' D~stributor Packer Assembly . Flush Joint Anchor Pressure Equalizing Tube BUNDLE CARRIER Blanked-Off B.T. Running Case Dr, II Collars Anchor Pipe Safety Joint .. Packer Assembly D~stributor Packer Assembly Anchor Pipe Safety Jo~nt S~de Wall Anchor Drill Collars Flush Joint Anchor Blanked-Off B T. Runn,ng Case Total Depth DEPTH 2260' 2264' 2283' 2294' 2991' ,o,.,,._.,_.,.,,~ ,. u, ~ EQUIPMENT DATA ""'"'"'°" ~ Ec~ch -T~ME Horizontal Line Equal to 1000 ' I ENG ', 2 ENG I 4 ?'4G %EOL_ t r ~,T TEC DATE' ~-/7-- ~;~0 -- j ~TAT TEC _ C~qFER: Transmi~zed herewith are the fgQ~owing, ,. -~f~ TO' DISTRICT ENG II,IEERII,!G -RANSMITTAL -'~'/'~/-/' WELL NAME- r the subject well- DATE SCALE XEROX SEPIA BL LINE ~.C Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey- Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log RECEIPT ACKNOWLEDGED FOR' DATE' ~~LEAS[ RETURN RECEIPT TO- ARCo Oil and Gas Company Attn' Mr. Pete Woodring P.O. Box 360- Rm. :';449 Anchorage, AK 99510 1/10/80 DATE' Transmit:ed herewith are the followin DATE EIiGI[~EE~IE:G ~ :~,;_c~L_ ~ROH: Jerry O. Pawel~~ ¥,~dring D FILF: .... ] SCALE XEROX SEPIA BL lINE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Cor.:pensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey- Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log RECEIPT ACKHO~,.ILEDGED FOR' LPLE DATE' ASE RETURN RECEIPT TO' ARCo Oil and Gas Co'npany Attn' Mr. Pete Woodring P.O. Box 360- Rm. ~-449 Anchorage, AK 99510 1/lO/gO NORTH SLOPE DISTRICT ENGINEERING TRAN SM I TTAL ~-/~ ~ Jerry J. Pawele~Pet~ DATE: ~ - ~- ~-~ ~ WELL NAME: Transmitted herewith are the following for the subject well- DATE SCALE XEROX SEPIA BL LINE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval ..... Core Description (Conv.) - Core Nb. Directional Survey- Gyro ~..z/. ~ Single Shot - Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat I:VD-DIL Differential Temperature Log Spinner-Survey Fluid Density Casing Collar Log t _ 'PeYforating Record Nuclear Flo-log RECEIPT ACKNOWLEDGED FOR: BY: P~LEAS DATE' E RETURN RECEIPT TO' ARCo Oil and Gas Company Att. n: Mr. Pete ~lood~ng ~P.O. Box 3~0- Rm. ~4g I/lo/so ARCO Oil and G~r ~ :)any North Alas~,~ _ .,[r~ct Post Ofhce Box 360 Anchorage Alaska 99510 Telephone 907 277 5637 February 21, 1980 Mr. Hoyl e Hamilton State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject- Core Summary, Kuparuk D-5 Dear Mr. Hamilton' Enclosed please find the Core Summary for Kuparuk D-5, submitted as Item No. 36 on Form P-7 for the above well. Very truly yours, R. W. Crick District Explorationist RWC' GSL' kdm Enclosure ARCO Oil and Gas Company Is a D~ws~on of AtlanhcR~chf~eldCompany Core # 1 2 3 RecoverS Depths Ft. % 2275'-2295' 6.0' 30% 2295'-2315' 9.0' 45% 2315'-2335' 14.0' 70% KUPARUK D-5 Section 23-TllN-RlOE, UM ARCo Operated CORE SUMMARY Li thol ogy Clay with interbeds of sand Sandstone, clay Sandstone, clay Shows Oil stained sand Ss - tar stained Ss - tar stained ARCO Od and Gas Company Pr, ~ C,I[ICr~ ~0 ,3 ~'~o~ag~ Alan, r, 97510 -',, r~hon,) ~" ',F .337 January 28, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcqpine Drive Anchorage, AK 99501 Subject: DS 2-8, Permit No, 74-63 Dear Sir~ DS 2-1, Permit No. 70-29 D-5 , Permit No. 79-95 DS 4-4, Permi't No. 71-11 DS 4-10, Permit No. 76.-42 Enclosed please fi'nd Sundry Notices outlining our plans for the above-mentioned wells, Very truly yours~ P, A, VanDusen District Drilling Engineer PAV/mb ARCO OIt and Gas Company ~s a Dl,,iston of At~3ntlcRIchf~eldCompal y Form'l'O-403 REV. 1-10-73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for pro~os~ls to drill or to d~en Use "APPLICATION FOR PERMIT--" for such I~rOl~Osels.) 1. O,L ITl GAs WELLi,~.I WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company ~. ADDRESS OF OPERATOR P..O. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At surface 243'FNL, 600~FEL, Sec 23= TllN, RIOE, UM 99510 5. APl NUMERICAL CODE 50~029_.204] 7 6, LF.d~SE DESIGNATION ANO SERIAL NO. ADL 25650 7, IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME K,upa,~u k 25650 9. WELL NO. ~ , 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Kuparuk Rfver 0i',l Pool 11. SEC., T., R., M., (BOTTOM HOLi=~OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' RKB Sec 24~ TllN; R10E~ 12- PERM IT'NO. 79~95 14, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [-------1 PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Tp;t'_ 91Eft;' Shallnw Sand SUBSE(~UENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER I NG CAS lNG SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well C~l~l~Dlltloft or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly irate all Dertlnent ~letllls, and give pertinent dates, Including estimated date of starting any proposed worE. Atlantic Richfield Company i'nten,ds to perforate and test a shallow sand at 2150~ after running and cementing the 10~3/4~' surface Pi'pe,~ The test wi'l] consi's~t o,f qett~'ng a cased hole DST tool, perforate 20~'~ flow enough to catch a wire!i~e sample~ perforate the remaining 40'~, and flow unt!l e!'ther the fluid comes to surface or the well d!~s, A cement retai~ner will be set above the perforated i'nterval and the zone will be squeezed with 500 sacks Arcti'cset !~ cement, hereby certify that the foregoing is true and correct · CONDITIONS OF A~t'PROVAL, IF TITLE [') i C, 1"' Y' 'i" (" '~' Fl~ln Fnn'i np~ ii TITLE, , BY ORDER OF THE COMMISSION See Instructions On Reverse Side DATE,//Z.~/~ O DATE Approved Copy Returne~t PHILLIPS PETROLEUM COMPANY ENGLEWO00, COLORAIX) 80111 7800 E. DORADO PLACE January 4, 1980 Re: Letter of Non-Objection Proposed wells located west of Prudhoe Bay Unit, AK Commissioner Harry W. Kugler Alaska Oil & Gas Conservation Commission Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Kugler: Reference is made to the applicatio~mitted by Atlantic Richfield Company for a permit to drill wel~ith a bottom hole location of 1320 feet west of the common line-~f section 24, TllN, R10E and section 19, TllN, RilE, and 1320 feet south of the common line between sections 13 and 24, TllN, R10E. Also, it is our understanding that Atlantic Rich- field Company will file an application for well #D%~ with a bottom hole location of 1320 feet west of the common line et~~n section 13, TllN, R10E, and section 18, TllN, RllE, and 1320 feet south of the common line between sections 12 and 13, TllN, R10E. Phillips Petroleum Company, as an adjoining leaseholder to said wells, does not object to the drilling of said wells. Sincerely, JHW:sjl cc: Mobil Oil Corporation P.O. Box 5444, Denver, CO Attn: Mr. E. G. Koelling Arco Oil & Gas Company' P.O. Box 360, Anchorage, AK Attn: Mr. Roger C. Stevens Mobil Oil Corporation State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Harry W. Kugler, Commissioner January 10, 1980 P O BOX 5444 DENVER, COLORADO 80217 ARCO-KUPARUK 25650 NO. D-5 SECTION 24-TllN-R10E, UM Gentlemen: This is in reference to your recent letter to ARCO Oil and Gas Company regard- ing ARCO's application for permit to drill the Kuparuk 25650 No. D-5 well lo- cated in Section 24, TllN, R10E, UM. This is to advise you that ARCO, in accordance with 11 AAC 22.050, furnished Mobil with a copy of its application for permit to drill the subject well, and we therefore are aware of their proposed operations offsetting our lease. Mobil Oil Corporation, as an adjoining leaseholder, does not object to the drilling of the well. Yours very truly, JLDouglass/nb CC: ARCO Oil & Gas Company Attn: Mr. Roger C. Stevens Box 360 Anchorage, AK 99510 Phillips Petroleum Company 7800 E. Dorado Place Englewood, CO 80111 A. J. McCredie Division Regulatory Engineer December 3.1. ~ 2.979 Ret Kuparuk 2S6S0 ~ Oil and ~as Cmspany . Persdt I~o, 79-95 S~. ~o.t 243* ~L ~ 600* FBL~ S~. 23, T~, R~0E, ~tt~Ole L~.t 1320° ~L i 1)20 FEL, Sec. 24, ~l~, Mr. P. A. VanDusen and ~as Company ~P. O, BOX 360 Anchorage, Alaska 995~0 Dear J~r. VanOu~ent ~ Encl.osed is the approved application for permit to drill the above referenced vel 1. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ~ng the d~g.it~sed log infozmat~on on all logs shall be submitted ~or Copying except experimental logs, velocity surveys and ~ny rivers in Alaska and their drainage systems have been claesi£ied a~ important for the spawning or migration of anadromous f~sh. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title Alaska Adm~nist~ative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of' any waters of the $~ate 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 Mr. P. A. Vard)usen Kuparuk 25550 D-5 -2- December 31, 1979 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Depertnent of Labor is being notified of ~he issuance of this permit to drills 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 l~ke to be notified 8o that a repre- sentative of the commission may be present to witness testing of blowout preventer equipnent before surface casing shoe is drilled. In ~he event of suspension or abandonment, please give this offioe adequate advance notification so that we may have a Very truly yours, Harry W. Kugler Commissioner of BY OAD~ O~ THE COMMIS$10N Alaska Oil & Gas Conoe~atton C~tssion Enclosure cc~ Department of F~sh & Game, Habitat Section w/o encl. Department of l~nviro.nnental Conservation w/o/encl. Departlnent of Labor; Supervisor, Labor Law Compliance Division w/o encl. Form 10-401 (~ SUBMIT IN T( 2ATE REV. 1-1-71 (Other InstrtICl~ ~ on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL I'~ DEEPEN [-] b TYPE OF WELL OIL [~ GAS ~ SINGLE WELL WELL OTHER ZONE ~-~ 2 NAME OF OPERATOR ARCo 0il and Gas Company 3 ADDRESS OF OPERATOR P.O. Box 360, Anchoraqe, Alaska 99510 4. LOCATION OF WELL At surface 243' FNL & 600' FEL, Sec 23, TllN, RIOE, UM At proposed prod zone ~/t?n" qq 1 ~gN' KNI g 1 27N' FFI _ ~pr ?&. T11N RI NF IIM 30 miles Northwest of Deadhorse MULTIPLE £C£1Vi!D ADL 25650 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Kuparuk 25650 9 WELL NO. D-5 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River il s~c, T, R., M., (BOTTOM 0 i 1 Poo 1 HOLE OBJECTIVE) Sec 24, TllN, RIOE 14. BOND INFORMATION Oil & Gas Bond m~ Statewidesurety,.a/o, No. #8011-30-40 (Federal 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 4680' (Also to nearest dng, umt, · any) 18 DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 120 21 ELEVATIONS (Show whether DF, RT, CR, etc.) Not surveyed - approx 70' ak Ins. Co.) 16 No OF ACRES IN LEASE 2560 19 PROPOSED DEPTH 6945'TVD Amount $100.00 17 NO.ACRES ASSIGNED TO THIS WELL 320 ! 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORK WILL START 1 - 15-80 23 PROPOSED CASING AND CEMENTING PROGRAM , , SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement , 24" 16" 65 H-40 80_+MD Cmt t'o surf - aDDrOX 200 ft3. 13-3/4" 10-3/4" 45.5 <-55BTC 2800+_MD Cmt to surf - a~rox 2300 ft° q-7/R" 7" ?fi <-EERTN qNql_+MB (i. mt with annrn×' ~2N0 ftj · ! m ARCo Oil and Gas Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately +9091'MD,+6945' TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole~ A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal ~s to deepen g~ve data on present productive zone and proposed new productive zone. If proposal ~s to drill or deepen dlrectionally, g~ve pertinent data on subsurface locations and measured and true vertical depths. G~ve blowout preventer program. 24. I hereby cert_l~t that the ]~oregomg2s True and Correct · TITLE Dist. Drl.q. Engr. Crlus space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~NO DIRECTIONAL SURVEY REQUIRED MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY OTHER REQUIREMENTS A P.I NUMERICAL CODE PERMITNO. 7 ~' ?f APPROVALDATEDeGember 31, 1979 APPOVED BY ~-~ ~'J' ~~ ~TLEc°mmi ssi°her DATE 12/31/79 *See Instruction On Reverse Side ARCO Oil and Gas,~~'~mpany North Alas~,'l strict Post Ofhce Box 360 Anchorage At~ska 99510 To!~phone 907 277 5637 December 12, 1979 R'.bbil 0il Corporation Mr. W.S. Blanton District Exploration Manager P.O. Box 5444 Denver, Colorado 80217 Re- Mobil - Phillips Lease ADL- 28243 Registered Mail Return Receipt Requested Dear Mr. Blanton; Atlantic Richfield Company is currently developing the Kuparuk 20 Section Oilfield as outlined in yellow on the attached plat. A jointly held lease by Mobil ~d Phillips - ADL # 28243, adjoins our development area. We have applied to the State of Alaska -~~~~d Gas ~ Conservation Cormmission for a permit to dril~ell No. D-.5, 0see attached). In response to ou~ application, Conm~issioner Harry W. Kugl~r has requested we obtain a Letter of Consent to drill from the adjoining lease holder - Mobil and Phillips. The targeted bottom hole location for well No. D-5 is 1320 feet west of the comon line of Section 2a, TllN, R10E; and Section 19, Ti]N, RltE; and 1320 feet south of the co, non line between Sections 13 and 24, TllN, RiOE; - Umiat Meridian (see attached plat). Additionally, we plan to file an application for well No. D-2; (also at bached) and anticipating the same requirement from the Commission, ARCO also requests a Letter of Non-Objection for the D-2 well. The well No. D-2 targeted bottom hole location is 1320 feet west of the common line between Section 13, TllN, R10E; and Section ]8 T1]J~. RllE~ L~iat Meridian and 1320 feet south of the comon line between Sections 12 and 13, TllN, RIOE; Umiat Meridian (see attached plat). Your prompt evaluation of our requesv and forwarding of your Letter of Non-Objection will be appreciated. Very truly your0 cc' Co,~issioner Harry W. Kugler/ Alaska 0il mhd Gas Conservation Commission At t ac hment s ARCO O' and G'~$ Company ~s a D .,~*icn of Att ,~,cR.r hh6tdCompany STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE o PERMIT TO DRILL OR DEEPEN h. T~ PE OF ~,,Ortk DRILL [~] O,L [--,--~ CAS [~] WELL WELL ~. N^ME OI- OH-RATOR ARCo Oil and Gas 3. ADDRESS OF OPFR kTOR OTtlER DEEPEN F1 SULtMIF IN 1 RIPer' ' (Othc[ m~ttuc! resctse slde}~ ZOXE, '1.~ ZONe ~ t_~ 6. L! ASE DESIGNAllON ANDSEKIAL NO. AfL 25650 ?. IFISD! XN, ALLOFFEEOR'IRIBENAME 8. UNll I'AR\! OR LEASENAME Kuparuk 25650 9. WELL NO. P.O. Box 360, Anchorage, Alaska 9951~=.. LOCATION OF WELL At surface 243' FNL & 600' FEL, Sec 23, TllN, RIOE, UM At pt0posed pr~. zone .6420' ~~~nt.~N~ & 132n' FE~~c_?4 TllN_ RIO~ 30 miles Northwest of Deadhorse ~o~.~o~u.¥nom Oil & Gas Bond D-5 10.HFLD AND POOL, OR~¥1LDCAT Prudhoe Bay Kuparuk River !1. SFC..T..P..,~!.(I,OTIO.Xi Oi 1 Pool .OLd: O,,V~Cr, VL) Sec 24, TI lN, RIOE 12. ~P~. Sta~e~ddes::et~...~/o, eo. #8011-30-40 (Federal Ins. Co.) ~$. DIKFANCE i RO~I PRO~SED * ' L~ATION TO NEAREST J,s. No. O,' AC,~s ,s L,AS~ PROPERTY OR LEASE LINE, Fr. 4680' ~.u~,.o,.~,,,, ~,¢.,.i,. ~,~> 2560 ~s. ,,,s~,~sc,, ,o, ,~O~SE,, ~oc~r,o, ~. ~Ot'~SCD,m. 6945'TVD 'fO ~g F. ARES f WELL DRILLING, COMPI.FTED, OR APPLIED I OR, I~F. 120 21. ELEVATIONS (Show whether DF, RT, CR. ere) Not surveyed- approx 70' GL ^,,,o.., $1o0.00 17. NO ACRt-S ASSIGNED 'fO 'l Ills V, FLL 320 30. ROI'ARY OR CAIHoE TOOl S Rotary APPRO\. l)A1 L ~ORK ~iLL STAR'I 1-15-80 23. PROPOSED CASING AND Cl- MFNI lNG PROGR HOLE SILE OF CASING ,J V, TtG.tll PERI-OOT GRADE SLITING DEIqH ~.ant,t> orccment . ..... 65,,, H- o zOO, __13: 3/4" _ LO-__3/4" 45.5 ~- 5_5.B_ZC.'.. 2800.+_HD Cmt t o__5_ur f · ~" 7" ........ [ _ __- ' /~3 ...... 2~ ~-B.~RT£ 90ql+MD £mt with ap~ 220Qf~' ....i ' ......... .... RCo Oil and Gas Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool developmen~ well o approximately +-9091'MD,+6945' TVD. Selected intervals will be logged and tested. A 20" x 000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It w~ll be tesbed pon installation and weekly thereafter. Test pressure will be 3000 psi\. The well will be ompleted with 3;~" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented nnuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk ormation and reported on subsequent report. A downhole safety valve will be installed and ested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM' If propo~l i, to d:epen 1,ire data on present psodu~tive zone and l~oposed new productive zone. If pto~l is to dtiU or deepen d~ectmnally, give pertinent data on sub;urface locahonsand measuzed and Due vet/i~ depths. Give blowout preventer program. hereby certLfY that the ~o~egoingj~ True and Correct s,os~o~~~ ~m~_ ~o,e~_~_S~ 1979 ~n.~ Dist. Orlq. En,r. spa~e for State office u~) CDgD! f[O~S O~ APPROVAl., IF ANY. OTItLR RLQblRI MI N 1 g SAMPLi:s .%SD CORi'. CillPS RI QUIRFD J MUD LOG I]"~S ~ so J E]vrs DJREC'I 'O'~AL SUR¥1 Y RLQUIRLD !] v~s E3 ~,o [] NO A P.! KUMFRICAL CODE PERMIT NO. AI'PROVAL DATE __ APPOVED BY . ,TI'FLE ~ DATE. *See Instruction On Reverse Side, WE'LL§ (TI T__ TWEET ~P,K S ~RIO~UM) · !¥ WELL :2 Y = 5,959,784.20 X = ~60,485.20 LAT = 70 18'02.492" LOtlC = 149°30'36.421,'.' ~.leLt ;'~ Y = 5,959,664.22 X = ~,60,486.26 LAT = 70~'18'O1.312 LONG = 149°30'36.42 WELL -'~ ' Y = 5,959,544.23 x-- ~6o,487 32 LAT = 70'"18'OO. i31" LON6 = 149°30'36.418" WELL --'5 Y = 5,959,424.2~ x = ~,6o,488.38 LAT = LONG = 149030'36.415~ WEt. L =7 .. Y = 5,959,18~.28 X = ~60 490.51 tAT = 70 17;56.591" LONG = 149030, 36. 409' WELL .~'8 Y = 5,959,O64.29 · X = ~60,49.1 56 ~ LAT = 70 17'55.~ LONG = 149~30,36.407~ ':: . ,~- *i tlEREBY gERTIFY THAT I Alt PROPERLY REGISTERED AIID L ICEIISED TO PRACTICE LAND SURVEYI,"IG TIle STATE OF ALASKA AIID TtlAT. Ttll S PLAT REPRESEII'FS AN AS- - BUILT SURVEY HADE BY fIE, Al'ID TiiAT ALL DIHEIISIONS Al'ID OTIIER DE'FAlLS ARE CORREC'r AS OF : ... .,.,... .. , , q/ / ....,. -,., .,:,..:~. "DATE 7 -/¢~ D. %. D ~ WELLS 1,2,B,4,'3,ro~7,~8 LOCAT i Ui'~l ..)~/i-. l NORTH AMERICAH PRODUCING DIVISION ( f t j/.".' ' ~ck 2588' !- '--"384 .; D 5659 ALK 4-t3 · a is=. i ' i ' ~ALI',. 9,.o,~_,,~,., =,..XXON ," 3 a4 ARCO Oil and Gas ~ lpany North Alaska~,. otnct Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 26, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99051 Subject: D-5 Dear Mr. Hamilton- Enclosed is our Application for Permit to Drill, a sketch of the surface diverter system, a certified survey plat, and the $100.00 filing fee. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:mb Enclosures RECEIVED ARCO Oil and Gas Company ~s a Diws~on of AtlanhcR~chf~eldCompany (( SURFACE L3l¥~:~'T~i',_.,.~., S¥STEil . .o · · 16"-'x 20" X-over 20110 iisi drilling spool 2000 ]~si annular preventer butterfly w~l yes LO. ~CK LIST FOR NEW $~ PERMITS Ocmpany ~ ~ Yes No Remarks 1. Is the ~ermit fee attached ........................................ 2. Is ~.ell to be located in adefined pool .i. 3. Is a registered 8ur~ey plat attached ................................ ~., 4. Is ~11 located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells .................... 6. Is. sufficiennt underdicated acreage available in this pool ........... ~. 3 woll to t~ deviated .............................................. $. Is operator the only affected party ................................. ~~~.~ 9. Can p~rmit be approved ]~fore ten-day ~.it .......................... Li. 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 ......... 12. 13. Lease & ~ii No. Item ~)~ove " ( 1 ) Fee, 14. !5 ~-~:7ill cement tie in surface and intermediate or production strings ... ~_ 16. Will cement cover all known Uroductive horizons ..................... ~ Date (3) Admin. (4) Casg. , ,,~..,~_ '17. 18. Will surface casing protect fresh ~ter zones ....................... Will all casing give adequate safety in collapse, tension ~ burst.. 19. Additional ~=quirements: Does BOPE have sufficient pressure rating - Test to .~ o~ ~ psig .. ~ Approval Recommended: T,4 'tt + ./ 7 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 11 000000 11 000000 1111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 OUO0 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 11 O0 O0 11 O0 O0 111111 000000 111111 O00OO0 777/717777 1177771777 77 77 77 77 77 17 77 77 77 71 77 77 OOO000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7 ~77777 ~ 77 e~ d 77 :~ 77 17 ~ 17 77 ,~ 77 77 77 77 6bb66b 000000 b66666 000000 66 O0 O0 Ob O0 O0 66 O0 0000 66 O0 0000 b666bbbb O0 O0 O0 bbb~b6bb O0 O0 O0 fib b6 0000 O0 66 66 0000 O0 66 66 O0 O0 Ob O0 O0 O0 OObbbb 000000 Obbbbb OOO000 222222 222222 22 22 22 22 22 72 22 22 22 22 22 22 2222222222 2222222222 44 44 44 44 44 444444 444444 44 44 44 44 44 44 44 44 44 q4 44 44 &4 44 44 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 GGGG G G G G GGG G G GGG H H BB~B PPPP HRRH H H B B P P R ~ HHHHH BEB~ ..... PPPP HRHH H H B ~ P R R H M BBB5 P R ~ U U DDDD U U D D U U D D U U [) D U U D D U U D D UUUUU DDDD UUO EEEEE O k 0 k DUO E~EE~ MONITOR USER PCAb L10707,60245] JU~ Sw8 KLlOE34 JUL-19. *START* UbER PC:AL [10701,60245] JUN 8W8 KL1OE34 JUL-/9. *6TAPT* bHIP 8EQ, 18~7 DATb SHIP 5k~. 1887 DAT& 14-P EB-80 14:00:)8 $8 HH HH 88 HH HH $$$$SSSS HH HH SSS$SSSS HH HH I1 II i1 ii Ii II I1 i1 II II II I1 11 II 11 11 I1 II i1 IL1 11 I1 PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTrT'I~T~ TTTTT1' ] I 1T uO00OO TT [,)0 TT UO OO ]' T (.JO IT dO UU ~T UO O0 'I1 uO OU TT 00 OO IT O0 DU ~T OO OO I'l UO OO TT UUUL)UO ~T UUUUUI.J ,$rAR~* usEA PCAb [10701,60245] 0ol5 SHIP $.%(J. 1887 MONITtlR ~$ KLlOE34 JUL-19, *START* FILE: DSKhjSHIP.TU<255>[i0707,602451 CREATED: 14-FEB-80 PHXNTkD: 14-F&S'I~O ~:O0:5b OUEUk SWI'ICHES: /~ILE:F'~T /COPIES:I /SPAC1NG:I /LI~I~:l18 /~ORN~S:NURMAb DA'I'm 14-~EB-80 12:01:38 14:00118 SIdiPPING 1NSTRUC I 1UN8 18,.5 UED I,~-~ [,B-80 12:00 SHiP TO VENIURA, CALIFORNIA 9300~ PCCC S~ GaB PCCC VV VV VV VV VV VV VV vV VV VV VV vV VV VV VV VV VV VV VV VV VV VV VV VV VV VV ~ ~R RR RB RR R~ ~H Illlll llllli ii I1 II iI I1 ]l II ii lI li Iil111 IlllI1 YY YY 000000 000000 00 00 0 00 0 0000 00 0000 00 O0 00 O0 O0 O0 0000 O0 0000 00 00 00 00 00 000000 000000 000000 44 44 000000 44 44 00 00 44 44 00 00 44 44 00 0000 44 44 00 0000 44 44 00 00 00 4444444444 00 00 00 4444444444 0000 00 44 0000 O0 44 O0 O0 44 00 00 44 000000 44 000000 44 *STAE't* [JSkR PCA6 [lOT07,bO245J job SHIP FiLth: DSI~H:VERIPi/' ~ ~0 <05 >i10707 b02~bJ CREATED: PEINIE, D: 1 FEB 80 1410{ 106 QULUk SWl~CHk6: /FILk:FUHT /COPiES:I /SPACING: i /LiMII :118 1887 DAT~ 14-FEB-BO 14-kEB-80 13:53:]5 14:00:38 SChLUMDERGEP CUNPUTING C~NI'~R 10707,60245 RkEL HEADER [,ENG1M: 132 ~YIES REEL NAME: F.C.A.L. SERV1CE NAME: EDII REEL CUNTINUATIi~N NUMDk, R: O! PREVIUU$ REEL NAME: CLJMMENTS: bi& ~URMAT CUS~OMk~ IAPE DATE: 80/ 2/14 TAPE HLADgR LENGTH: IAPE NA I'APE CO PR~ViUU C~IMMEN~ TAPE CSG=I~ EM=6.! 132 BYTES ME: 60245 DALE: 80/ 2/14 NAME: EDIT NI'[NUA'IION NUMDE~: 01 $ TAPh, NAME: $: @@lI4/B'ISZ=13.75/~bUIO=~GM/UkNS=lO.1/VISC=44/Ffl=8.5/~L=8.4/ 2~65/RM~=5.O8@~5/RMC=7.IT~Sb/BHT=90 FiLE HEADER hkNGIH: 62 BYTES NAME: kDl% .001 MAX[MUM PHYSICAL RECORD [REVIUU6 ~ILE NAME: FILE COMMENTS LTN=EPIIHE~MAL NEUTNUN. UNLX VUNCT1UN FORMER IS 1024 B~TE6 BECAUSE THE w[,_,l.,l.~ SI'IE 1N~URMATI(.]_N AECOPD LENGI'H: 172 I~XIE6 CLIMPAN i': ~ 1BED: RANGE; T[JW N: S~.,C ~lO STARE: N: : ATLANTIC RICHFIELD CO. D-5 KUPARUg lIN 23 N. ALASKA DA'lA ~OAMA'I SPgCI?ICAIION I,F, NG I'H: 770 ~3 ~ T kS kNTR~ bLOCKS: $iZ~ RkP COD5 bNIR~ 0 ] 66 O DAI'UM SPECIP1CATIUN t~LUCK6: ENTRY lC l UUb l 2 8P DID 3 ILO m 1L~ bib 5 LLSU 6 G~ DiD 8 CALl CNb DRHO ~DC NPHi CNb 11 b~UB CNb 12 N~AT 14 ~CNL 15 G~ 16 DT 17 N~AT 18 NCNb E'IN 19 fCNL ~TN ~VURO~ ONi[8 APl APl AP1 APl Fib~ 6IZ~ EXP PROC ~AM HgP D~Pf b~IP'I' PT 0 0 0 0 0 4 0 0 1 08 0 0 MY ? 1 0 0 0 ~ 0 0 I bi 0 0 (JSNM 7 12 46 0 0 4 0 0 I b~ 0 0 OR~ 7 12 44 0 0 4 0 0 I b8 0 0 0~ ! 22 8 0 0 4 0 0 I 08 0 O GAP£ 7 31 32 O 0 4 0 O 1 b8 0 0 GAPi 42 31 32 0 0 4 0 0 I b8 0 0 1N ~2 28 1 0 0 ~ 0 0 I b8 0 0 G/C] ~2 44 0 0 0 4 0 0 I 08 0 0 PO 42 68 3 0 0 4 0 0 I b8 0 0 G/C~ 4~ ]5 1 0 0 ~ 0 0 I 68 0 0 C/C ~2 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 ~ 0 0 1 ~ 0 0 CPS q2 34 93 0 0 4 0 0 1 b8 0 0 GAPi bO 31 32 0 0 4 0 0 I 08 0 0 US/~ bO 52 32 0 0 4 0 0 1 08 0 0 C/C 42 42 I 0 0 4 0 0 I 08 0 0 CPS 42 34 92 0 0 4 0 0 1 ~8 0 0 CPS 42 34 93 0 0 4 0 0 I 08 0 0 · 7 iDbPI'}-i 9093. 000 $000.000 2900.000 2800.000 2100.000 2600.000 2500,000 2400,000 ? ;~00.0O0 MNEMONIC ~CNb NCNb SP NCNL SP NPH1 I~CNb NCNb SE> NPHi ? CNb NCNb NPH1 ~CNL NCNL SP NPIJl NCNb SP GR NPH1 ~CNb NCNb SP GR NPHI ~CNL NCNL 8P NPHI ~CNL NCNb VAL -67 53 8 7296 1833 -52 51 52 405 1927 -87 42 37 bTO 2110 -81 49 39 554 1994 59 47 490 1997 43 40 537 1888 34 25 1079 2318 -62 57 45 501 2128 -77 39 40 b37 2082 UE .000 .438 .398 .000 .000 .000 .063 .539 .250 .000 .000 .b25 .500 .000 .000 .438 .188 .941 .500 .000 .000 .938 .461 .250 .000 .500 .594 .381 .000 .000 .000 .31J .000 .000 .000 .969 .719 .361 .250 .000 .375 .219 .967 .500 .000 MNEMUNIC ILD GR I'CNL 1 LD (JR ~CNL ILL) ~CNL RHUB i'CNb GR RHUB (JR i~CNb ILD ~CNL ILD (JR I~HUB ~CNb IbD Gk RHtJB ~CNL ~CNb VAbU o 432· 2. 04. 358. · 57. 2. 57. 407. 14. 2. . 13. 52. 2. 51. 451. 10. 63. 2. 66. 462. 12. 48. 2. 42. 395. 24. 28. 2. 28. 6bl. 16. 44. 2. 54. 474. 64. 33. 1. 33. 461. 055 000 211 Ob3 500 496 594 131 875 750 750 531 076 844 500 ~50 19 080 844 750 266 500 143 000 750 727 625 100 250 500 672 078 262 828 000 625 969 045 000 750 250 469 977 219 75O MN~MUNIC IbM CALl NRA9 DT IbM CALl NRA1 DT IbM CALl NRAr DT ibm CALl CAb1 CALl CALl NlrA 1' DT IbM CALl NRAT IBM CALl NhAI DT VALUE 11.281 13.750 0.792 127.000 1.328 13.77~ 4.262 133.125 14./58 13.b88 3.428 143.000 13.117 13.813 3.566 149.000 9.750 14.172 3.992 144.125 11.570 1~.438 3.580 140.125 26.984 13.828 2.b68 131.000 15.54/ 13.914 3.~b9 153.000 54.344 lo.O00 3.080 193.750 M~{kMtlN lC LLSU DRHU NCNb NHAT bbSU DHHU NCNb NHA'I bbBU nCNb NRAT bbSO NCNb NRA'I bbSU NCNb NHA'I NCNb NHA'£ LbSU DRHU NCNb N RAT bb8U DHHU NCNb bbSO DRHU NCNb NRAI' VAbUb 10.281 0.110 0192.000 4.51b O.719 -O.00/ 1951.000 4.152 15.320 -0.024 2420.000 4.129 12.891 -0.005 21U0.U00 3.920 U.750 -0.011 2098.000 3.8U7 13.008 -0.004 20bb.O00 4.201 -O.OOl 3014.000 3.201 11.041 0.004 /lbO.000 4.121 bO.bbb -0.02~ Zzu4.000 3.932 2200. 000 2 1 O0. 000 2000.000 900. 000 1800.000 1700.000 lbO0.O00 i500.000 1 ~00. 000 MNLMUNIC 8P GR NPHI ~CNL NCNb SP GR NPH1 ~CNL NCNb NPHi NCNb (.,14 NPH! FCNb NCNb SP NPH 1 fCNL, NCNb SP NPH1 fCNL NCNb SP NPHI ?CNL NCNL SP NPH1 liCmb NCNb Gl.{ NPttl ~ CNL NCNL VAL 52 46 4O5 2048 -60 28 72 223 1699 IJk, .500 .531 .875 .500 .000 .g38 .bib .266 .250 .000 -70.938 59.844 48.291 425.750 2264.000 -71. 61. 51. 402. 1768. -72. 47. 44. 466. 1901. -bl. 44. 39. 556. 2050. 44. 4~. 464. 2100. -54. 51. 49. 334. 1771. -58. 52. 55. 383. -999. 500 750 172 000 000 500 656 873 500 000 5OO 969 697 000 000 000 313 045 5O0 000 313 344 854 500 000 5OO 625 711 000 25O MNLMONiC ILL ?CNL GR ~CNL ILL GE IRHUB PCNL GR GR ~CNb IbD GR RHUB GR ~CNL GR ~HtJt:5 PCNL ILD IRHOB (.,iR GR ILL ~ CNL VALUE i3.~44 60.063 2.160 b0.625 412.750 20.891 29.891 1.]86 29.938 232.375 18.547 5J.125 2.203 57.125 416.500 lb.031 5b.406 2.184 67.000 327.250 24.203 50.281 2.137 54.906 377.000 60.688 44.531 2.080 44.656 405.000 52.625 43.594 2.115 43.750 367.500 57.469 54.750 2.078 47.025 220.375 51.063 55.588 2.102 -999.250 -999.250 MNLMONIC CALl NRAI DI CALl NRAT CALl NRAI DT CALl NRAT ibm CALl NRAT UT ibm CALl NRAT DT CALl NRAT CALl NRAI Ol ILM CALl DT VALUL 12.359 14.766 ].975 152.500 20.250 14.789 5.387 158.500 16.625 14.094 4.035 151.000 13.742 14.531 4.207 154.375 22,172 13.750 152.500 46.344 15.258 3.590 lu0.750 43.~75 16.109 3.965 177.750 42.063 16.625 4.188 1~5.750 38.531 . 98 -999.250 MNLMUNIC bhSU DRHU NCNb NRAT bbSU DRHU NCNb NIRAT bbSU DRHU NCNb NRAI' hbSU DHHU NCNb NRAT hb8U DRHU NCNb NRAi bb8U DRHU NCNb bbSU DIRHU NCNb miRAT bbSU DRHU NCNb NLRA1 bbSU DRHU NCNb NHAT VAbUL 11.008 -0.001 1913.000 4.512 Zl .5lu -0.021 1378.000 u.0?0 11.041 -O.OOb 1931.000 4.078 12.bbb -O.OOb 1694.000 4.594 23.375 -0.011 1090.000 03.406 -0.024 1950.000 q.15U 65.8~4 -O.OU8 1941.000 b. UZ3 49.313 0.021 1o90.000 6.016 42.375 u.000 1733.O00 -999.250 DEPth 1300.000 1200.000 ~100.000 1000.000 900.000 800.000 700.000 600.000 500.000 MNEMONIC NPNi ~CNL NCNL NPHi ~CNL NCNb SP NPHI fCNb NCNb SP G~ NPHI ~CNL NCNb SP NPHI FCNb NCNb SP G~ NPHI ~CNb NCNb NPHi FCN6 NCNb SP NPHI ~CNL NCNL NPHi ~CNL NCNL V 3 -9 3 -9 AL 63 53 58 43 95 99 52 44 49 7O 99 ~8 5~ 51 30 99 59 57 98 99 40 40 47 07 99 58 ~5 47 25 99 91 47 5O 99 5~ 51 52 99 .000 .969 ,861 .250 ,250 .938 .844 .2~2 .500 .250 .000 .219 .268 .500 .250 .4~8 .938 .367 ,750 .250 .438 ,625 .715 .250 .250 .406 .344 .559 .500 .250 .875 .094 .412 .000 .250 o000 .656 .781 .250 .250 .250 .469 .465 .000 .250 MNEMuN lC GR ~' CNL, fCNL G~ fCNL lbo GH fCNh RHuB fCNb R~uB GM fCNL FCN6 G~ G~ ~CNL VALO 2~. 62. 2. -999. -999. 52. 1. -999. -999. 108. 54. 1. -999. -999. 35. 67. 1. -999. -999. 453. 1. -999. -999. 105. 41. 2. -99g. -999. 350. ~7. 2. -999. -999. 84. 58. 2. -999. -999. 95. 2. -999. -99g. E 203 125 O23 25O 25O 813 905 866 250 25O 188 642 25O 25O 4O6 3i3 481 250 25O 000 188 975 25O 25O 813 O25 250 25O 000 344 O33 25O 2.5O 531 O2O 25O 25O 188 344 021 25O 25O MNEMONIC CALl NRA~ bi' CALl NRAr IbM CALl NRA'I CALl ~RAi~ OT ibm CALl NRAT UT CALl NRAI CAh£ NRAT OT .Ibm CALl NRA'i OT CALl NRAT Ol VALUE 20.959 16,453 4.529 -999,250 29.000 18.103 ~.87'7 -99 .250 b4.003 18.359 ~.203 -999.250 23.781 10,828 4.277 -999,250 22.172 13.150 4.535 -999.250 58.188 15.o09 4.035 -999.250 9b.375 18.844 4.109 -999.250 44.594 14.898 4.195 -999.250 40,~Ob 14.95~ 4.234 -999,250 MNEMUNIC 6LSU DRHU NCNb NRAI 668U DRHU NCNb NRAT 668U DRHU NCNb NRAT 6680 DRHU NCNb NRAI bbSU O~HU NCNb NRA'I' 6680 DRHU NCNb N~Ai 66~U DRHU NCNb NRAT 668U ORHu NCNb NRA'I 668U ORHU NCNb NRAI VALU~ 24.150 0.003 1464.000 -999.250 bl.l~b 0.007 9.250 104.000 0.021 1~1~.000 -999.250 29.d03 -u.025 1501.000 -999.250 13.313 0.0lq 14~1.000 -999,250 221,000 0.004 16~.000 -99~,250 91/.500 -0.013 1955.000 -999.250 125.b~8 -0.0lb 1805.000 -9~9.250 195.500 0.004 lb~4.000 -999.250 DLPT~ 4UO.O00 300.000 200.000 100.000 95.000 NN kMONiC SP NPH 1 FCNL NCNb SP GF NPHi NCNb SP NPH1 ~CNL NCNb SP NPHI t' CNL NCNi~ SP G~ NPHI ~CNL NCNb VALUE, -118.500 39.281 40.967 435.000 -999.250 -119.750 35.625 47.754 375.250 -999.250 -56.906 33.594 20.068 1000.000 -999.250 -0.250 17.813 71.729 230.250 -999.250 -999.250 -999.250 -99925.000 -999.250 -999.250 NN iLD FCNL i bi) GR RHUB ~CNb ILD G~ ~HOb GB fCNL G~ RH{JB ~CNL 1 ~CNL VAL 154 39 1 -999 -999 661 32 1 -999 -999 104 30 2 -999 -999 2000 16 1 -999 -999 -999 -999 -999 -999 -999 LJE .500 .094 .962 .250 .250 .500 .906 .976 .250 .250 .438 .719 .414 .2b0 .250 .000 .703 .781 .250 .250 .250 .250 .250 .250 .250 MNEMONIC CALl NRAf CAb1 NRAT DT ILM CALl NRA1 CALl NRAf UT IbM CALt NRA£ UT VALUE 54.344 18.900 3.756 -999.250 88.125 19.875 4.156 -999.250 47.719 15.54/ 2.385 -999.250 1.B51 15.281 5.367 -999.250 -999.250 -999.250 -999.250 -999.250 MNLMON lC bbHU D~HU NCNb NRAT 6680 DRHU NCNb NRA'I 6680 DRHU NCNb N~AI 6bOb DRHU NCNb NRA! bbSU DRHU NCNb N~A'I VALUE 565.500 -U.0Z0 1/40.000 -999.250 lb04.000 -0.001 1/90.000 -99~.250 111.025 0.022 2510.000 -999.250 0.5~9 -0.511 l&04.000 -99~.2b0 -999.250 -999.250 -999.250 -999.250 ~I, JMMAA~ U~ DATA R[~CUI~D,S NUMBI~.R OF AkCURD6: 402 ]JkNGlh OF AkCURDS: 994 I.,~,NG~[Id [)F LAST R~.CURD: 918 ~.lLk I'I~AILkR ~16£ NA~E: ~:DII .001 MAXI~JUN PH¥SICA6 AECUI~D LkNGTId: Nfi~AT ~ILE NAME: TAPE '~ HA ILEI~ LENGTH: 132 tAPE NAME: b02~5 SERVICE NAME: EDiT TAPE CONTINUAT1UN NUM~kR: O1 NBXI ]APB NAME: PA[k: 801 2/14 11 000000 11 000000 1111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 i1 O0 O0 1! O0 O0 111111 000000 111111 000000 7777777777 7 77777777~7 77 77 77 77 77 77 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 666666 000000 666666 000000 66 00 00 66 00 00 66 00 0000 66 00 0000 66666666 00 00 00 66666666 00 00 O0 66 66 0000 O0 66 bb 0000 O0 66 66 O0 O0 66 66 00 00 666666 000000 666666 000000 333333 333333 33 33 33 t3 33 33 33 33 33 33 33 33 333333 333333 22222~ 22222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 11 11 1111 1111 11 11 11 11 11 11 11 11 111111 111111 GGGG H H BBBB PPPP ~RRR G H H B B P P R R G H H G B P P R R G HBDHB BBGB ..... PPPP RRRR G GGG H H ~ B P R k G G H ~ B B P R R GGG H H BBBB P ~ k U U DDDD U U O D U U D D U U D D U U D D U U D D UUUUU DDDD H H OOO LLEEE H H O O E H H O O E HHH~H O O EEEE H H 0 O E H H 0 O k H H OOO EEEEL ,START~ USER PCAb [10707,60321J JuB MONITOR Sw8 KLI0k34 JUL-79. ,START* *START* USLR PCAb [10707,60321] jOB MON1T(}P 6W$ KLlOL34 JUL-79. ,START* SHiP SEQ. 2638 SHIP SEQ. 2638 DATE 08-APR-B0 DATE 08-APR-80 14:01:31 14:01:31 SSSSSSSS MM HH SSSSSSSS HH MH SS ~ HB SS HH HM SS H~ HH SS MH HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS ~H HH SSSSSSSS HH HH ii II II II II II II ii II II Ii II Ii II ii II II II i1 II II PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTT UOOOOO TTTTTTTTT'I OOOOOO TT OD DO TT ~0 OD TT O0 O0 TT 00 DO TT 0[3 OO T T O O U O T T 00 O O TT O0 OO TT O0 OD TT O0 DO TT UOOUO0 TT OOOOOO *START* bSER PCAL L10707,60321] dOB SHiP SEQ. 26]8 MONITOR SWS KL10E34 JUL-79. *START* FILE: DSKH:SHIP.TU<255>[10707 60321] CREATED: 08-APR-80 PRIN~ED: 08-APR-80 1~:01:48 QUEUE SWITCHES: /FILE:FURT /COPIES:I /SPACING:I /LiMiT:125 /FORMS:NORMAL DATE 08-APR-80 13:46:38 14:01:31 -[ 6HIPP1NG INSTRUCTIONS iSSUeD 8-Al°R-80 i~:46 SHIP Tf] : V~NTURA, CALIfOrNiA 93003 PCCC BY GHB PCCC 9V ¥~ EEEEEEEEEE RRRPRR~R ¥¥ ¥~ EEEEEEEEEE RRRRRRRP VV ~¥ EE RR RR YV V~ EE RR RR VV VV E~ ~R RR VV VV EE RR RR VV VV EEEEEEEE RRR~RRRR VV VV EEEEEEEE RRR~RRRR VV V¥ EE ~R RR VV VV EE RR RR VV VV kk R~ RR VV VV E5 RR RR VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR Illiii IIIIII II 1I II II Ii II II I1 I1 II IIIIII iiiiii f 1' f FFFFf i;F f't' f I' FFi~ i' F F fF Ff Ff I' ff i' FFFf fF l.'F YY YY YY YY YY Y¥ YY YY YY YY YY Y¥ YY YY YY YY 000000 000000 000000 000000 11 O0 O0 O0 O0 1111 O0 O0 O0 O0 1111 O0 0000 O0 0000 11 00 0000 O0 0000 O0 O0 O0 oO O0 O0 11 O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 O0 O0 O0 O0 11 O0 O0 O0 O0 11 000000 000000 111111 000000 000000 111111 *START* USER PCAL [10707,60321] dOB S,IP SEQ. MONITOR FIWS KLlOE34 JUL-79. *START* fiLE: DS~H:VERiF~.O01<051>[]0707 60321] CREATED: PR1NTED: 08-APR-80 14:0~:01 QUEUE SWITCHES: /flLE:FDRT /CUPIES:I /SPACING:I /LIMIr:125 /FORMS:NORMAL 2638 DATE 08-APR-80 08-APR-80 13:55:09 14:01:tl LIS VERSI[]N 15.H01 79101126 SCHLUMBERGER COMPUTING CBNTkB 10707,60321 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CUNTINUATIUN NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: L1S ~ORMAT CUSTOMER TAPE DATE: 80/ 4/ 8 TAPE HEADER LENGIH: 132 BYTES TAPE NAM5: 60321 DATE: 80/ 4/ 8 SERVICE NAME: EDIT TAPE CONTINUATION NUMB~: O! PREVIUUS TAPE NAME: COMMENTS: TAP~ COMMENTS CSG:lO.75~]O76/BTSZ=8.5/FLUID:KCL/DBNS:IO.5/PH=O.0/Vi$C:55/~L:O.O/ RM:.2@62/RMF=.14@62/RMC:.25@62/BHT:127 FILE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECURD LENGTH: PREVIOUS FILE NAME: COMPANY : ATLANTIC RICHFIELD C WELL : D-5 ~IELD : KUPARUK RANGE: : lOg TOWNSHIP : llN S~CTION : 23 COUNTY : N. SLOPg STATE : AbASKA DENSITY : 800. 1024 DA~A ~ORMA~ SPgCi~ICABION LgNG?H: ~50 ENTRY BLOCKS: TYPE 0 SIZE R~P CODE ENTR~ 1 66 0 DATU~I SPP~CIf ICATJUN BLOCKS: []Nil APl AP1 AP1 AP1 FILE SIZE SAM REP PROCESS INDICATORS 1 DEPT 2 LLD DLL ]LLS DLL 4 GR DLL 5 CALl DLL 6 MSFL DLL 7 GR CNL 8 CALl CNL 9 DRHO ~DC 10 NPHI CNb RHOB CNL NRAT CNL 1 NCNL CNG FCNL CNL 15 GR BBC 16 DT BHC ET 0 0 0 0 0 4 OHMM I I 22 10 0 0 4 OHM~ 11 22 9 0 0 4 GAPi 11 31 32 0 0 4 IN 11 28 2 0 0 4 OHMM 11 27 1 0 0 4 GAPI 42 ]1 32 0 0 4 IN 42 28 1 0 0 4 G/C ~ 42 44 0 0 0 4 PU 42 68 3 0 0 4 G/C3 42 35 I 0 0 4 C/C 42 42 1 0 0 4 CPS 42 34 92 0 0 4 CPS 42 34 93 0 0 4 GAP1 60 31 32 0 0 4 US/f' 60 52 32 0 0 4 1 68 I 68 I 68 1 68 1 68 1 68 1 b8 1 08 I 68 1 68 1 68 USER DEFINED OUIPUT ARRAY OUTPUT LLD AT 2 OUTPUT LLS A~ 3 OUTPUT GR AT 4 OUTPUT CAL] A~ 5 OUTPUT MS, L- A7 6 OUTPUT GP AT 7 OUTPUT CALl AT 8 OUTPUT DRHO AT 9 OUTPUT NPHI AT ~0 OUTPUT RHUB AT 11 OUTPUT NRAT AT ~2 OUTPUT NCNL A~ 13 OUTPUT FCNL AT 14 OUTPUT GR AI 15 OUTPUT DT AT 16 DkPTH 8930.000 8900.000 88O0.0O0 87O0.OO0 8600.000 8500.000 84OO.000 8300.000 8200.000 8100.000 8000.O00 kN(JN lC LLD MSfL NPHI ~CNL LLD MSFL NPHI FCNL L1, D MSFL NPH! FCNL LLD MSfL NPHI FCNL LLD NPHI ~CNL LLD NPHI ~ CNL LLD MSFL NPflI FCNL LLD NPMi fCNL LLD NPHI ~CNL LLD MSFL NPHI ~CNL LbD MLFL NPHI ~CNL VALUE 38.119 12.047 59.814 188.250 2.817 1.920 8.594 1151.000 2.132 2.055 41.797 329.250 4.381 5.318 30.371 449.000 4.700 5.646 33.984 489.500 6.154 25.745 32.324 467.500 3.862 6.217 31.934 488.000 1.467 0.965 -99925.000 -999.250 2.723 2.376 -99925.000 -999.250 2.216 ).115 -99925.000 -999.250 3.101 1.73b -999~5.000 -999.250 MN kMONIC BLS GR RHOB bLS RHOB GR bLS GR R/dOB GR bLS GR HHOB GR bLS GR RHOB GR bLS RHUB GR bLS GR RHOB GR LbS GR GR LLS GR RHOB bLS GH RHUB GR bLS RfttIB VALUE 159.000 14.102 2.648 97.750 3.007 14.102 2.254 97.750 2.062 106.688 2.]73 100.125 4.599 80.813 2.398 79.063 4.885 87.250 2.438 84.375 5.499 60.031 2.844 6].000 3.964 100.000 2.6~7 96.1 5 1.507 -999.250 -999.250 -999.250 2.881 -999.250 -999.250 -999.250 2.501 -999.250 -999.250 -999.250 ].074 -999.250 -999.250 '999.250 MN gM(]N lC GR CALl NRAI DT GR CALI NRAT DT GR CALI NRAT DT GR CALl NRAT DT GR CALl NRAT GR C Al., 1 NRAT DT GR CALl NRAT DI GR CALl NRAT DT GR CALl NRAT DT GR CALl NRAT DT CALl NRAT DT VALUk 0.000 8.500 3.959 101.188 0.000 8.961 1.353 101.150 108.500 12.125 3.623 104.563 84.375 10.242 2.9~8 93.3 5 94.375 10.734 3.156 90.000 59.500 10.813 3.078 71.000 108.625 10.961 3.055 87.J75 1 8 000 -999.250 -999.250 138.625 -999.250 -999.250 -999.250 1~1.500 -9 9.250 -999.250 -999.250 173.500 -999.250 -999.250 -999.250 MNEMONIC CAbI DRHU NCNb CALl DRHU NCNb CALl DRHU NCNb CALl DRHO NCNb CALl ORHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHU NCNb CALl DRHO NCNb CALk DRHO NCNb CALI DRHO NCNb VALUE 8.500 822.500 9.945 0.057 lbl5.000 10.922 0.084 1343.000 10.383 0.038 1490.000 10.539 O.O0b 1551.000 10.b25 -O.Olb 1553.000 10.117 O.Ob3 lb53.000 9.922 -999.250 -999.250 10.398 -999.250 -999.250 10.b88 -999.250 -999.250 10.109 -999.250 -999.250 DE.P'I H 7900.000 7800,000 7700.000 7600.000 7500.000 7400,000 7300.000 7200.O00 7100.000 7O00.0OO 6900.000 MNEMUNIC VALUE bLD 5.332 MSTL 5.229 NPHi -99925.000 fCNL -999.250 bind 4.415 MSFL 4.567 NPHI -99925.000 FCNL -999.250 LLD 3.032 MSPL 4.660 NPHI -99925.000 ~CNL -999.250 MNEMONIC VALUE LL$ 5.706 GR -999.250 RHUB -999.250 GR -999.250 LbS 4.689 GR -999.250 RHOB -999.250 GR -999.250 bLS ].377 GR -999.250 RMOB -999.250 GR -999.250 LLD 3.502 LbS 3.326 MSFL 2.782 GR -999.250 NPHI -99925.000 RHOB -999.250 FCNL -999.250 GR -999.250 LLD 2.195 MSf'L 3.000 NPHI -99925.000 fCNL -999.250 ULD 3.188 MSfb 5.483 NPHI -99925.000 ~CNL -999.250 LLD 2.047 MSFL 2.299 NPHI -99925.000 FCNL -999.250 bbD 2.621 MSFL 3.601 NPHI -99925.000 FCNL -999.250 LLD 2.670 MSFL 2.839 NPHI -99925.000 FCNL -999.250 GR -999.250 bLS 3.552 GR -999.250 RHOB -999.250 GR -999.250 LbS 2.471 GR -999.250 RH00 -999.250 GR -999.250 bLS 2.629 GR -999.250 RH[JB 999 250 GR :999:2S0 Lb6 2.64] GR -999.250 RHOB -999.250 GR -999.250 LLD 2.499 bLS 2.349 MSFL 1.246 GR -999.250 NPHI -99925.000 RHUB -999.250 FCNL -999.250 GR -999.250 LLD 2.741 MS~L 2.495 NPHi -99925.000 FCNL -999.250 LL$ 2.716 GR -999.250 RHOB -999.250 GR -999.250 MNEMONIC VALUE GR 100.313 CALl -999.250 NRA1 -999.250 D~ -999.250 GR 148.375 CALl -999.250 NRAT -999.250 DT -999.250 GR 108.938 CALl -999.250 NRAI -999.250 DT -999.250 GR 126.813 CALl -999.250 NRA~ -999.250 DT -999.250 DT -999.250 GR 163.375 CALl -999.250 NRAT -999.250 DX -999.250 GR 154.500 CALl -999.250 NRAT -999.250 DT -999.250 GR 122. 125 : .2so GR 163.375 CALl -999.250 NRAI -999.250 DT -999.250 GR 115.063 CALl -999.250 ~RAT -999.250 T -999.250 GR 111.063 CALl -999.250 NRA~ -999.250 DT -999.250 MNEMONIC CALl DRHO NCNb CALl DRHO NCNb CALl DRHU NCNb CALl DRHU NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CAbI DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHU NCNb VAbU~ 10.b25 -999.250 -999.250 10.484 -999.250 -999.250 10.445 -999.250 -999.250 10.367 -999.250 -999.250 10.383 -999.250 -999.250 9.945 -999.250 -999.250 10.078 -999.250 -999.250 10.391 -999.250 -999.250 10.188 -999.250 -999.250 10.180 -999.250 -999.250 9.984 -999.250 -999.250 DEPIH 6800.000 6700,000 6600,000 6500,000 6400.000 6300,000 6200.000 6100.000 6000.000 5900,000 5800,O00 MNEMONIC ELD MSPL NPHI FCNL LLD MSi~L NPHI f CNL LLD MSFL NPHi ~'CNL 6LD MS~L NPHI FCNL LLD MSFL NPHi ~CNL LLD NSF ~, NPHi FCNL LLP MSFL NPH! fCNL LLD MSFL NPHI PCNL LED M$~L NPHI fCNL LLD MSFL NPHI ~CNL LLD MSPL NPHI ~CNL VA -9992 -99 -9992 -99 -9992 -99 -9992 -99 -9992 -99 -9992 -99 -9992 -99 -9992 -99 -9992 -99 4 35 4 35 LU , 2. 5. 9. , 2. 5. 9. , 3. 5. 9. . 2. 5. 9. . 2. 5. 9. 2. 5. 9. 3. 5. 9. , 3. 5. 9. , 3, 5. 9. , 2. 8. 1. , 2. 8. 1. 2O2 3O8 000 25O 828 402 000 250 883 363 000 25O 782 939 000 25O 147 576 000 250 O55 829 000 25O 707 466 000 250 717 678 000 250 854 566 000 250 647 325 730 50O 287 510 730 5OO MNEMUNIC RHUB GR bls GR RHOB GR LLS GR RHOB GR bls GR RHUB GR LLS GR RHOB GR bLS GR RHOB GR LbS GR RHUB GR LLS GR GR bls GR RHOB GR LLS GH GR LLS GR RHOB GR VALU , -999. -999. -999. -999 -999 -999 . -999. -999. -999. . -999. -999. -999. 0 -999. -999. -999. 0 -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . 94. 1. 88. . 94. 1. 88. 107 25O 25O 25O 709 250 250 25O 664 250 250 250 597 250 250 250 967 25O 250 25O 668 25O 25O 25O 246 250 250 250 368 250 250 250 464 25O 25O 250 111 125 624 188 682 125 624 188 MNEMONIC GR CALl NRAI DT GR CALl NRAI DT GR CALl NRAI DT GR CALl NRAT Dr GR CALl NRAT DT OR CALl NRA'r DT GR CALl NRAI DT GR CALL NRAT DT GR CALl NRAT DT GR CALl NRAT DT GR CALl NRAI DT VALUE 102.250 -999.250 -999.250 -999.250 92.500 -999.250 -999.250 -999.250 108.625 -999,250 -999.250 -999.250 90.750 -999.250 -999.250 -999.250 90.250 -999,250 -999.250 -999.250 109.813 -999.250 -999.250 -999.250 90.875 -999.250 -999.250 -999.250 87.250 -999.250 -999.250 -999.250 94.688 -999.250 -999.250 -999.250 113.125 8.500 3.b27 110.000 100.188 8.5O0 3.627 110.000 MNEMONIC CALl DRHO NCNL CALl DRHO NCNb CALl DRHO NCNL CALl DRHU NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALI DRHO NCNb VALUE 10.359 -999.250 -999,250 9.930 -999.250 -999.250 10.180 -999.250 -999.250 10.211 -999.250 -999.250 10.219 -999.250 -999.250 9.586 '999.250 -999.250 9.883 '999.250 -999.250 10.359 -999.250 -999.250 4.172 -9 .250 -999.250 11.359 -O.01b 1406.000 11.898 -0.016 1406.000 DkPTH 5700,000 5600.000 5500.000 5400.000 5300.000 5200.000 5100.000 5000.000 4qO0.O00 4800.000 4700.000 MN~ON1C bbb NPHI ~CNL bbD NPHI FCNL LLD f,4Sl~ L NPttl t. CNL bLD NPHI ~CNL BLD MS~L NPHI ~CNL LLD MSFL NPHI FCNL LLD MS~L NPHi FCNL LLD MSFL NPHI FCNL bLD MSFL NPHI FCNb LLD MSFL NPHI FCNL LLD MSfb NPH! ~CNb VALUE 3.729 2.676 48.730 ]51.500 4.]44 3.7]q 48.730 351.500 3.270 3.089 48.730 351.500 3.351 2.803 48.730 351.500 3.874 2.230 48.730 351.500 4.13{ 3.488 48.730 351.500 4.828 2.322 43.408 394.000 5.190 2.312 41.357 363.250 5.592 2.375 42.871 364.750 0.066 1.919 42.969 323.500 28.238 6.473 22.852 693.000 MN EMUNIC GR GR LbS RHOB GR bLS GR RHOB bLS GR RHOB GR bLS OR bbs GR RHOB GR bLS GR RHOB GR bLS GR RHOB GR bbs GR RHOB GR bbb GR RHUB GR bLS RHOB GR VALUE 3.094 94.125 1.624 88.188 3.575 94.125 1.624 88.188 2.754 94.125 1.O24 88.188 2.594 94.125 1.624 88.188 2.985 94.125 I .624 88.188 2.932 94.125 1.624 88.188 3.318 88.375 1.623 86.875 3.515 71.313 2.143 65.813 3.753 83.438 2.~09 68. 38 4.574 87.750 2.279 84.813 12.600 52.625 2.451 53.281 MN ~2 ML)N IC (.,R CALl NRAT DT GR CALl NRAT DT GR CALl NRAI DT GR CALi NRAT DI GR CAbi NRAT UT GR CALl NRAT DT GR CALl NRAI DT GR CALl NRAI DT GR CALl NRAT DT GR CALl NRAT DT GR CALl NRAT DT VA 9 11 10 11 10 11 7 11 10 11 9 11 9 12 8 1 12 8 1 12 8 1 11 5 1 5 LUE 9.250 8.500 3.627 0.000 9.188 8.500 3.027 0.000 4.06] 8.500 3.627 0.000 9.813 8.500 3.627 0.000 3.438 8.500 3.627 0.000 8,503 8.500 3.627 0.000 6.313 6.016 3.332 0.188 3.563 1.109 3.574 4.750 5.375 3.048 3.725 2.000 4.688 3.180 3.715 8.188 4.188 1.352 2.461 7.781 MNEMONIC CALl DRHU NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHU NCNb CALl DRHO NCNb CALl DRHU NCNb CA6i DRHO NCNb CAb1 DRHO NCNb CA6I DRHO NCNb CA6i DRHO NCNb CALl DRHO NCNb VALU~ 9.734 -0.016 1400.000 10.063 -0.016 1406.000 10.445 -0.016 1406.000 10.109 -0.016 1406.000 8.219 -0.010 1406.000 9.901 -0.016 140b.O00 10.586 -0.013 1388.000 9.523 0.053 i576.000 8.711 0.01] 14Bq.O00 10.047 0.069 1200.000 9.503 0.088 1822.000 DEFTH /600.000 4500.000 4400.000 4300.000 4200.000 4100.000 4000.000 3900.000 3800.000 3700.000 3600. 000 MNkMONIC VALU~ MNEMONIC VAbU bLi) 24.579 LbS 9. MSFb 3.057 GR 68. NPHI 38.623 RHUB 2. PCNL 414.750 GR 59. LCD 6.874 MSPL 1.640 NPHI 34.082 PCNI, 348.750 bLO 6.429 M6Fb 1.876 NPHI -99925.000 kCNb -999.250 bLD 4.871 MSFI., 1.042 NPH1 -99925.000 FCNL -999.250 LLD 20.859 MSPb 2.463 NPHI -99925.000 PCNL -999.250 LCD 5.603 MSPL 0.845 NPHI -99925.000 ~CNL -999.250 LCD 10.844 MSPL 3.637 NPHI -99925.000 FCNL -999.250 bbD 7.138 MSPb 0.831 NPHi -99925.000 PCNL -999.250 LLD 7.655 MS~L 1.648 NPHI -99925.000 FCNb -999.250 LCD 10.078 MSFL 1.140 NPHI -99925.000 ~CNL -999.250 bLS GR RHOB GR bLS GR RHOB GR bLS GR RHOB GR bLS GR RHUB GR bLS GR RHUB GR LbS GR RHOB GR LbS GR RHOB GR LLS GR RHOB GR bbs GR GB LbS GR GR LLD 6.209 MSFb 2.193 NPH1 -99925.000 ~CNL -999.250 . 84. 2. 78. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. , -999. -999. -999. 1 -999. -999. -999. ,~75 625 11! 688 997 063 256 813 714 250 250 250 876 250 25O 25O 790 250 250 250 759 250 250 250 304 250 250 250 834 250 25O 250 541 25O 25O 25O 362 250 250 250 704 25O 250 25O MNLM(JN1C GR CALk DT GR CALl bRAT DT GR CALl bRAT DT GR CALl NRAT DT GR CALl NRAI UT GR CALl NRAT DT GR CALl NRAT DT GR CALl NRAT DT GR CALl bRAT DT GR CALl NRAT DT GR CALl bRAI VALU 72. 10. 3. 131. 95. 21. 3. 121. 76. -999. -999. -999. 79. -999. -999. -999. 56. -999. -999. -999. 61. -999. -999. -999. 53. -999. -999. -999. 51. -999. -999. -999. 90. -999. -999. -999. 84. -999. -999. -999. 86. -999. -999. -999o 938 711 412 375 938 766 447 563 75O 25O 25O 25O 25O 25O 25O 25O 688 250 250 250 813 250 250 250 188 250 250 250 000 250 25O 250 375 250 25O 25O 313 250 250 250 375 250 250 250 MNEMONIC CALl DRHO NCNb CALl DRHO NCNb CAbl DRHO NCNb CALl DRHO NCNb CALl DMHO NCNb CALl ORHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DRHU NCNb CALl DRHO NCNb CALl DRHO NCNb VALUL 9.750 0.021 1534.000 7.250 0.049 1294.000 6.859 -999.250 -999.250 8.438 -999.250 -999.250 9.50O -999.250 -999.250 9.500 -999.250 -999.250 9.414 -999.250 -999.250 9.492 -999.250 -999.250 9.250 -999.250 -999.250 9.078 -999.250 -999.250 9.438 -999.250 -999.250 DEPTH 3500. 000 3400.000 3300.000 3200.000 3100.000 3000.000 2900,000 2800.000 2710.000 MNEMUNlC VALUE MNEMONIC VALUE bbD 9,543 bLS 7,7 MSFL 1.987 GR -999.2 NPHI -99925.000 BHOB -999,2 FCNL -999.250 GR -999.2 LLD 7.374 bLS 5.1 MS~L 5.8R4 GR -999.2 NPH1 -99925.000 RHUB -999.2 ~CNL -999.250 GR -999.2 LbD 8.057 bLS 4.2 MS~L 1.066 GR -999.2 NPHI -99925.000 RHOB -999.2 ~CNL -999.250 GR -999.2 MSFL, 1. GR NPHI -99925.000 RHUB ~CNL -999.250 GR 3.5 -999.2 -999.2 -999.2 LLD 5.011 LbS 3.6 MSFL 1.410 GR -999.2 NPH1 -99925.000 RHUB -999.2 ~CNL -999.250 GR -999.2 LLD 56.754 LbS 0.1 MS~L 68.688 GR -999.2 NPHI -99925.000 RHOB -999.2 ~CNL -999.250 GR -999.2 LbO 14.889 LbS 0.1 MS~L 55.615 GR -.999 2 NPHI -99925.000 RHUB '999'2 t'CNL -999.250 GR -999.2 LLD 70.496 LL6 0.1 MSfL 2000.000 GR -999.2 NPH! -99925.000 RHOB -999.2 fCNL -999.250 GR -999.2 bLD -999.250 MSFL -999.250 NPHI -99925.000 FCNL -999.250 bLS GR GR -999.2 -999.2 -999.2 -999.2 60 50 50 50 30 50 50 50 22 50 50 50 55 5O 5O 5O 24 50 50 50 38 50 50 50 37 5O 5O 5O 39 50 50 50 50 50 50 50 MNEMONIC GR CALl NRAI UT GR CALl NRAI DT GR CALl NRAT UT GR CALl NRAT DT GR CALl NRAT DT CALk NRAT DT GR CALl NRAI DT GR CALl NRAT DT GR CALl NRAI UT VALU 72. -999. -999. -999. 70. 2999. 999. -999. 78. -999. -999. -999. 91. -999. -999. -999. 90. -999. -999. -999. 54. -999. -999. -999. 45. -999. -999. -999. 49. -999. -999. -999. -999. -999. -999. -999. 188 250 250 250 25O 25O 25O 250 625 250 250 25O 875 250 250 250 063 250 250 250 688 250 250 250 500 250 250 250 150 250 250 250 250 250 250 250 MNEMONIC CALl DRHO NCNb CALl DRHO NCNb CALl DRHO NCNb CALl DP, HO NCNb CALl DRHU NCNb CALl DRHO NCNb CALl DRHU NCNb CALl 'DRHO NCNb CALl DRHO NCNb VAbUE 9.586 -999.250 -999.250 9.102 -999.250 -999.250 9.641 -999.250 -999.250 9.541 -999.250 -999.250 9.781 -999.250 -999.250 10.328 -999.250 -999.250 10.281 -999.250 -999.250 10.188 -999.250 -999.250 -999.250 -999.250 -999.250 SUMMAI~2 [~1; DATA RECOiqDS NUMBER 0~- RECORDS: 830 LENGTH O~ RECORDS: 966 BYTES LENG~IH OF LAST RECORD: 390 BYqES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENG?H: NEXT ~ILE NAME: EOF TAPE TBAILEB LENGTH: 132 BYTES TAPE NAME: 60321 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O! NEXT %APE NAME: C[]MM~NTS: 1024 BYTES DATE: 80/ 4/ 8
