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189-071
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 2K-07 50-029-21351-00-00 189-071 Kuparuk River WL PPROF FINAL FIELD 1-Oct-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.11 08:44:58 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2K-07 JBR 09/12/2023 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:4 Tested with 3 1/2 and 7 " test joints. 3 1/2 " FOV failed on test #2 c/o retest and pass. H2s in pits and cellar had plugged intake caps, c/o caps, recalibrate and pass. BOP misc FP was a gland nut leak on test spool under stack. Tighten up and pass. Test #8 had a leak on the test joint connection. Tighten up and test , pass. Test Results TEST DATA Rig Rep:Al HansenOperator:ConocoPhillips Alaska, Inc.Operator Rep:T. Wiese Rig Owner/Rig No.:Nordic 3 PTD#:1890710 DATE:7/5/2023 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSTS230705063427 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2092 Sundry No: 323-241 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 FP Inside BOP 1 P FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 2 7/8 x 5 vari P #2 Rams 1 blinds P #3 Rams 1 7 "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 1 3 1/8 P Check Valve 0 NA BOP Misc 3 2 1/16 FP System Pressure P3120 Pressure After Closure P1600 200 PSI Attained P20 Full Pressure Attained P121 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc NA P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector FP FPH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P17 #1 Rams P4 #2 Rams P4 #3 Rams P4 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 9 9 FP FP FP9 FP FOV failed H2s in pits and cellar had plugged intake gland nut leak 4 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 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 8310' feet 7641' feet true vertical 6489' feet None feet Effective Depth measured 7974' feet 7612', 7689' feet true vertical 6234' feet 5965', 6021' feet 7838-7846' 7920-7930' 7950-7984' Perforation depth Measured depth feet 6134-6138' 6193-6201' 6216-6241' True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 7664' 7759' 6002' 6073' Packers and SSSV (type, measured and true vertical depth) PACKER: PACKER: 7612' 7689' 5965' 6021' 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: Elliott Tuttle Contact Email:elliott.tuttle@conocophillips.com Authorized Title: RWO/CTD Engineer Contact Phone: 907-263-4742 323-365 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. Gas-Mcf ~ ~~ ~ 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ SLB Bluepack Max RH BAKER HB Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Well Shut-In N/A N/A Length 79' 3445' 115'Conductor Surface Tie-Back String STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-071 50-103-20107-00-00 P.O. Box 100360, Anchorage, AK 995103. Address: KRU 2K-07 MD Burst Collapse measured true vertical Packer N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025588, ALK2674 Kuparuk Field/ Kuparuk Oil Pool ConocoPhillips Alaska, Inc. 7" measured TVD Plugs Junk measured 115' 7" Production 2086' 8270' Casing 1998' 6484' 2117' 8303' 3480' 2951' 16" 9-5/8" Size Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:50 pm, Aug 11, 2023 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle @conocophillips.com Reason: I am approving this document Location: Date: 2023.08.11 07:09:00-08'00' Foxit PDF Editor Version: 12.1.2 Elliott Tuttle Page 1/38 2K-07 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/22/2023 00:00 6/22/2023 02:30 2.50 MIRU, MOVE RURD P Rig down equipment, and prepare for rig move. 6/22/2023 02:30 6/22/2023 03:30 1.00 MIRU, MOVE MOB P PJSM. Pull rig off of well and spot on location. 6/22/2023 03:30 6/22/2023 04:30 1.00 MIRU, MOVE RURD P P/U matting boards, berm, and herculite on location. 6/22/2023 04:30 6/22/2023 16:30 12.00 MIRU, MOVE MOB P Move from 2L to staging point at 2M access road. 6/22/2023 16:30 6/23/2023 00:00 7.50 MIRU, MOVE MOB P Wait on Rig mats to be laid from 2M to four corners. Lay herculite, and lay mats around 2K 07. Stage well head equipment near well. 6/23/2023 00:00 6/23/2023 01:00 1.00 MIRU, MOVE MOB P Wait at 2 M access road for Tool house to lay mats to four corners intersection (2H-2K access road). 6/23/2023 01:00 6/23/2023 04:00 3.00 MIRU, MOVE MOB P Move Rig from 2M access road to four corners intersection. 6/23/2023 04:00 6/23/2023 05:00 1.00 MIRU, MOVE MOB P Rig stand by and allow fuel truck to pass rig move, and move mats from behind the rig to 2H/2K access road. 6/23/2023 05:00 6/23/2023 06:00 1.00 MIRU, MOVE MOB P Move rig from four corners down 2H access road. 6/23/2023 06:00 6/23/2023 07:30 1.50 MIRU, MOVE MOB T Right front tire fell through portable road. Crib up under tire and back out of hole. 6/23/2023 07:30 6/23/2023 14:30 7.00 MIRU, MOVE MOB P Wait on road prep. KDTH lay mats on road in front of rig. 6/23/2023 14:30 6/23/2023 16:00 1.50 MIRU, MOVE MOB P Move rig to end of mats. 6/23/2023 16:00 6/24/2023 00:00 8.00 MIRU, MOVE MOB P Move rig shuffleing matts each time, Move rig to .6 miles down 2H/2K access road. 6/24/2023 00:00 6/24/2023 03:00 3.00 MIRU, MOVE MOB P Continue to Move rig to 2H shuffling mat's. Offline while waiting on matts general housekeeping around rig. Lower stabbing board, connect stabbing board hydraulic hoses. 6/24/2023 03:00 6/24/2023 12:00 9.00 MIRU, MOVE MOB P Continue to move rig towards 2H shuffling rig mats. Offline while waiting on mats: Continue with general housekeeping. Disconnect stabbing board hydraulic hoses. 6/24/2023 12:00 6/24/2023 18:00 6.00 MIRU, MOVE MOB P Continue moving towards 2H shuffling mats. Offline while shuffling mats: Remove stabbing board. Prep floors in pipe shed, and on rig floor for paint. 6/24/2023 18:00 6/24/2023 21:00 3.00 MIRU, MOVE MOB P Move rig to 2H, and pull onto pad. Tool house begin to move mats, and lay mats on the access road form 2H to 2K. Offline: Continue to prep floors on rig floor, and in pipe shed for paint. 6/24/2023 21:00 6/25/2023 00:00 3.00 MIRU, MOVE MOB P Rig stand by on 2H while matting boards moved around rig, and laid mats and portable road from 2H to 2K. Offline: Continue with prep for painting on floors in pipe shed, and on rig floor. General maintenance, and housekeeping around the rig. Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 2/38 2K-07 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/25/2023 00:00 6/25/2023 08:00 8.00 MIRU, WELCTL MOB P Move mats around rig at 2H to 2K. Place mats and portable road. Offline: Rig crew work on general maintenance, and house keeping. Prep and paint throughout the rig. 6/25/2023 08:00 6/25/2023 10:30 2.50 MIRU, WELCTL MOB P Pre job safety meeting. Move rig from 2H to 2K. 6/25/2023 10:30 6/26/2023 00:00 13.50 MIRU, WELCTL MOB P Pull rig on to location. Store tree in cellar, and spot DSA's, and well head components behind well. Move, and stage Job box in place near well. Move equipment around location in preperation of spotting the rig over 2K- 07 6/26/2023 00:00 6/26/2023 02:00 2.00 MIRU, WELCTL MOB P Spot Rig over 2K-07. Set down rig and shim as needed. Pump open surface safety valve, and get initial pressures: Tubing: 850 PSI IA: 825 PSI OA: 50 PSI 6/26/2023 02:00 6/26/2023 04:00 2.00 MIRU, WELCTL MOB P Rig up. Spot in cuttings tank, tiger tank, and open top tank. Rig up hardline in cellar, and to tiger tank/ open top tank. Spot high line trailer into the rig. 6/26/2023 04:00 6/26/2023 08:30 4.50 MIRU, WELCTL COND P Offload fluid into the pits. Build 35 Bbls deep clean pill pit. Rig up squeeze manifold in cellar. Call out slick line to place hold open sleeve in SSSV. Bleed OA F/ 50 T/ 0 PSI. Rig accepted @ 04:00 Hrs. 6/26/2023 08:30 6/26/2023 09:00 0.50 MIRU, WELCTL PRTS P PT squeeze manifold and tiger tank line T/ 3000 PSI 6/26/2023 09:00 6/26/2023 09:30 0.50 MIRU, WELCTL KLWL P Bleed PSI of TBG & IA, went to fluid quickly. TGB=65 PSI , IA=0 PSI. 6/26/2023 09:30 6/26/2023 11:30 2.00 MIRU, WELCTL KLWL P Pump 30 Bbls deep clean pill followed by 384 Bbls 10.8 PPG NaCl/NaBr down tubing taking returns out IA to tiger tank, maintaining 1/1 with choke @ 3.5 BPM, ICP=75, FCP=670. 10.8 PPG returns to surface. 6/26/2023 11:30 6/26/2023 12:00 0.50 MIRU, WELCTL OWFF P OWFF, no flow from tubing, slight flow from IA. 6/26/2023 12:00 6/26/2023 12:30 0.50 MIRU, WELCTL KLWL P Pump additional 25 Bbls @ 3.5 BPM, 670 PSI 6/26/2023 12:30 6/26/2023 13:00 0.50 MIRU, WELCTL OWFF P OWFF, 30 Min no flow. 6/26/2023 13:00 6/26/2023 13:30 0.50 MIRU, WELCTL RURD P B/D squeeze manifold and taker tank line. R/D tubing line. 6/26/2023 13:30 6/26/2023 15:30 2.00 MIRU, WELCTL SLKL P PJSM. Spot slick line unit, and rig up lines/ sheaves, and R/U surface equipment. R/U slick line. 6/26/2023 15:30 6/26/2023 17:30 2.00 MIRU, WELCTL SEQP P Attempt to pressure test HAL slick line surface equipment to 3000 PSI. Leak observed from ottis connection from tree to riser extension. 6/26/2023 17:30 6/26/2023 18:00 0.50 MIRU, WELCTL SEQP T Drain HAL slick line riser, and change out O ring on leaking OTIS connection 6/26/2023 18:00 6/26/2023 18:30 0.50 MIRU, WELCTL SEQP P Pressure test HAL surface equipment to 3K: GOOD TEST. Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 3/38 2K-07 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/26/2023 18:30 6/26/2023 19:00 0.50 MIRU, WELCTL SLKL P Slick line run in the hole from surface to 1779'. Locate and no-go out on SSSV hold open sleeve. Pick up 10' and tag again to confirm. Slick line Jar down 5 times to shear, and verify. Pick up and verify loss in weight. 0.0 1,779.0 6/26/2023 19:00 6/26/2023 19:30 0.50 MIRU, WELCTL SLKL P Slick line POOH, and L/D tools. 1,779.0 0.0 6/26/2023 19:30 6/26/2023 20:30 1.00 MIRU, WELCTL SLKL P R/D HAL slick line surface equipent, and sheaves. L/D and clear all slick line equipment from the rig. 0.0 0.0 6/26/2023 20:30 6/26/2023 21:30 1.00 MIRU, WELCTL MPSP P PJSM. Set BPV in tubing hanger neck profile per FMC reps. 0.0 0.0 6/26/2023 21:30 6/26/2023 22:00 0.50 MIRU, WELCTL PRTS P Line up manifolds, and fill lines. Pressure test BPV from below to 1000 PSI for 10 min: GOOD TEST. Calculated volume to pressure~ .7 BBLS, Actual pumped 1.1 BBLS. Aprox 1 bbl bled back. B/D rig down surface lines. 0.0 0.0 6/26/2023 22:00 6/26/2023 22:30 0.50 MIRU, WHDBOP NUND P PJSM for N/D Tree, and adaptor flange. Verify L.D.S. function IN: 3.75" OUT: 4.75" Replace two L.D.S. 0.0 6/26/2023 22:30 6/27/2023 00:00 1.50 MIRU, WHDBOP NUND P N/D Bolts on Tree, and adaptor flange. R/U top drive to tree. "Break connections loose" using top drive. Adaptor flange free @ 18K. 6/27/2023 00:00 6/27/2023 00:30 0.50 MIRU, WHDBOP NUND P Inspect hanger neck, and treads. Hanger neck had minor pitting above where hanger neck seals were. Hanger neck threads in good condition. Test threads with blanking plug. 10 turns by hand. 6/27/2023 00:30 6/27/2023 01:00 0.50 MIRU, WHDBOP NUND P FMC reps dress top of hanger neck. Install slip over blanking plug per FMC rep. 6/27/2023 01:00 6/27/2023 07:30 6.50 MIRU, WHDBOP NUND P PJSM. N/U DSA, and adaptor flange. Install 7" fixed rams in LPR. Hook up choke and kill lines, install low pressure riser. 6/27/2023 07:30 6/27/2023 08:30 1.00 MIRU, WHDBOP RURD P Fluid pack BOPE. Grease mud cross. Leak on gray-lock clamp on kill line. Replace gasket. Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 4/38 2K-07 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/27/2023 08:30 6/27/2023 18:30 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular w/ 3 ½ TJ, tested UVBR's w/ 3 ½ & 5 ½ TJ, tested LPRs w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Conduct Accumulator Draw Down Test. Initial pressure=3080 PSI, after closure=1650 PSI, 200 PSI attained =23 sec, full recovery attained =129 sec. UVBR's= 5 sec, Annular= 16 sec. Simulated blinds= 5 sec. Simulated LPR's= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby. CMV #8 failed on test #3. 6/27/2023 18:30 6/28/2023 00:00 5.50 MIRU, WHDBOP BOPE T Remove CMV #8 and Replace with new valve. 6/28/2023 00:00 6/28/2023 01:45 1.75 MIRU, WHDBOP BOPE T Continue repairs on Choke Manifold. 6/28/2023 01:45 6/28/2023 07:30 5.75 MIRU, WHDBOP BOPE T Test choke manifold breaks Low/High 250/3000 psi. PT CMV #8 Low/High 250/3000 psi. 6/28/2023 07:30 6/28/2023 08:30 1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment. Suck out stack. 6/28/2023 08:30 6/28/2023 09:15 0.75 MIRU, WHDBOP MPSP P Pull blanking plug and ISA BPV. 6/28/2023 09:15 6/28/2023 09:45 0.50 COMPZN, RPCOMP PULL P Make up landing joint to hanger and top drive. Set down 10K. BOLDS. P/U on string, hanger free @ 50K, pipe free @ 120K. Pull hanger above to rig floor. Pull F/ 7664 T/ 7629', PUW=100K w/ 5K drag. 7,664.0 7,629.0 6/28/2023 09:45 6/28/2023 11:15 1.50 COMPZN, RPCOMP CIRC P Circ 355 Bbls 10.8 Nacl/NaBr @ 5 BPM, 600 PSI. Dump initial 15 Bbls overboard. Dump 65 Bbls towards end of circulation. Good 10.8 PPG back to surface. Terminate SS control line. Verify ability to pump down tubing. 7,629.0 7,629.0 6/28/2023 11:15 6/28/2023 11:30 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow. 7,629.0 7,629.0 6/28/2023 11:30 6/28/2023 12:15 0.75 COMPZN, RPCOMP PULD P Break out TD. L/D hanger and landing joint. B/D TD. 7,629.0 7,629.0 6/28/2023 12:15 6/28/2023 14:15 2.00 COMPZN, RPCOMP PULL P L/D hanger and 29 joints of 3 1/2" completion F/ 7629' T/ 6747', PUW=100K, spooling up SS control line. Total footage pulled 917'. 16 stainless steel bands recovered. 7,629.0 6,747.0 6/28/2023 14:15 6/28/2023 14:30 0.25 COMPZN, RPCOMP SFTY P PJSM w/ Baker, SLB and rig crew on terminating control line and making up 6" OD mill to drift tubing head. 6,747.0 6,747.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 5/38 2K-07 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/28/2023 14:30 6/28/2023 15:00 0.50 COMPZN, RPCOMP BHAH P P/U 2 joints bring SSSV depth T/ 805'. PUW=90K, SOW=70K . Install 2 stainless steel band on joint #31 out of the hole, Install cross collar clamp (4,9375" OD on box of joint # 31. Terminate SS control line. Install cap on line. Install 2 bands above cross collar clamp on joint #30. 6,747.0 6,747.0 6/28/2023 15:00 6/28/2023 15:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 - 6" string mill T/ top of joint #30 out of hole T/ 7' bottom of mill depth. 6,747.0 6,754.0 6/28/2023 15:30 6/28/2023 16:00 0.50 COMPZN, RPCOMP PULD P RIH w/ 6" mill on DP T/ 33'. Cleared well head. Pull mill back up to surface. 6,754.0 6,747.0 6/28/2023 16:00 6/28/2023 16:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 - 6" mill w/ jars and bumper sub T/ 6775'. PUW=92K, SOW=72K. 6,747.0 6,775.0 6/28/2023 16:30 6/28/2023 18:00 1.50 COMPZN, RPCOMP PULD P PUDP, RIH w/ BHA #2 F 6775' T/ 7478' on Joint 23 and set down 10K inside 7" CSG at 734' ORKB, 127 feet from target depth. 6,775.0 7,478.0 6/28/2023 18:00 6/28/2023 19:45 1.75 COMPZN, RPCOMP TRIP P TOOH standing back Drill Pipe. 7,478.0 6,747.0 6/28/2023 19:45 6/28/2023 20:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #2 - 6" mill w/ jars and bumper sub 6,747.0 6,747.0 6/28/2023 20:30 6/28/2023 21:00 0.50 COMPZN, RPCOMP SVRG P Rig Services. BI-Weekly Derrick Inspection. Grease Blocks and Top Drive. 6,747.0 6,747.0 6/28/2023 21:00 6/28/2023 23:30 2.50 COMPZN, RPCOMP WAIT P Waiting for Offsite Tools for next stage of Operation. 6,747.0 6,747.0 6/28/2023 23:30 6/29/2023 00:00 0.50 COMPZN, RPCOMP BHAH P MU Baker L10 On/Off Tools to 3.5" Completion. 6,747.0 6,752.0 6/29/2023 00:00 6/29/2023 01:30 1.50 COMPZN, RPCOMP TRIP P TIH with Baker L10 On/Off Tool on Drill Pipe. Up Wt 104K / Dn Wt 80K. Lightly Tag top of Cut section @ 7664'. PUH 5' and Wait on 12.9 ppg LSND. 6,752.0 7,664.0 6/29/2023 01:30 6/29/2023 10:00 8.50 COMPZN, RPCOMP WAIT P MU DP to Top Drive. Monitor Well on Trip Tank. Waiting of 12.9 PPG LSND 7,664.0 7,661.0 6/29/2023 10:00 6/29/2023 12:30 2.50 COMPZN, RPCOMP CIRC P Close in annular. Fill poor boy with 10.8 PPG Brine. Obtain SPR @ 2 BPM, 155 PSI. Pump 230 Bbls 12.9 PPG mud cap @ 2 BPM, controlling hydrostatic differential with choke. Maintain 1/1 in and out. Chase w/ 6 Bbls 10.8 PPG brine down DP. 7,661.0 7,661.0 6/29/2023 12:30 6/29/2023 13:30 1.00 COMPZN, RPCOMP OWFF P Open up DP and choke to shakers - no flow. Open annular. OWFF on trip tank for 30 Min. Static. Bleed OA F/ 120 PSI T/ 0 PSI. 7,661.0 7,661.0 6/29/2023 13:30 6/29/2023 14:00 0.50 COMPZN, RPCOMP PULD P Break out TD. PUW-110K, SOW=78K. S/O T/ 40K. 1/4 turn to left. Release L10 On/Off tool. Leaving top of toll 914'. PUW=50K. 7,661.0 914.0 6/29/2023 14:00 6/29/2023 15:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 914' T/ surface PUW=50K. L/D upper section of L10 On/Off tool. 914.0 0.0 6/29/2023 15:00 6/29/2023 16:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #4, IBP T/ 21' 0.0 21.0 6/29/2023 16:00 6/29/2023 18:00 2.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #4 on DP T/ 879' COE. Top of IBP 873' / Bottom of IBP 883'. Crew C/O. 21.0 879.0 6/29/2023 18:00 6/29/2023 18:30 0.50 COMPZN, RPCOMP RURD P Drop 1/2" Ball for setting IBP. RU Test Pump to DP. 879.0 879.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 6/38 2K-07 Report Printed: 8/10/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/29/2023 18:30 6/29/2023 19:00 0.50 COMPZN, RPCOMP MPSP P Up Wt 48K. Stage up pressure to 500 psi for 10 min's to start the IBP setting process. Increase pressure to 1000 psi for 10 min's. Stack 1K down weight. Increase pressure to 1500 psi for 10 mins, Increase pressure to 1800 psi. Seen IBP set and shear at 1800 psi. Smooth releave with Drill Pipe. 879.0 879.0 6/29/2023 19:00 6/29/2023 19:30 0.50 COMPZN, RPCOMP RURD P RD Testing equipment. 879.0 879.0 6/29/2023 19:30 6/29/2023 20:00 0.50 COMPZN, RPCOMP TRIP P TOOH standing back Drill Pipe. 879.0 14.8 6/29/2023 20:00 6/29/2023 20:30 0.50 COMPZN, RPCOMP BHAH P RD Hydraulic Running Tool. 14.8 0.0 6/29/2023 20:30 6/29/2023 21:30 1.00 COMPZN, RPCOMP PRTS P PT 7" casing aginst IBP T/ 1000 PSI for 15 Min. Monitor OA - no pressure transfer. 0.0 0.0 6/29/2023 21:30 6/29/2023 22:00 0.50 COMPZN, RPCOMP OWFF P OWFF 0.0 0.0 6/29/2023 22:00 6/30/2023 00:00 2.00 COMPZN, RPCOMP RURD P Drain BOP Stack. Remove Riser and ND BOPE 0.0 0.0 6/30/2023 00:00 6/30/2023 00:30 0.50 COMPZN, RPCOMP RURD P RD Annular Valves from spool. Remove Lock Down Screws. 0.0 0.0 6/30/2023 00:30 6/30/2023 01:00 0.50 COMPZN, RPCOMP SFTY P PJSM on the proper use of the Hydratight equipment. 0.0 0.0 6/30/2023 01:00 6/30/2023 02:00 1.00 COMPZN, RPCOMP RURD P RU Hydratight Equipment to the TBG Head. 0.0 0.0 6/30/2023 02:00 6/30/2023 06:00 4.00 COMPZN, RPCOMP CUTP P Start Casing Growth Process. Had a total of 21" of Casing growth. Allow 30 Min for casing to relax. Remove TBG head. 0.0 0.0 6/30/2023 06:00 6/30/2023 07:30 1.50 COMPZN, RPCOMP WWSP P Inspect and clean Slips and Pack off. RU 7" CSG Spear and run to well head. Rig is on centered up over hole. Consult w/ town decision made to empty pits and reposition rig. 0.0 0.0 6/30/2023 07:30 6/30/2023 14:00 6.50 COMPZN, RPCOMP WAIT T Call out truck to empty pits. Call out hi- line. Power down hi-line and disconnect from rig. Suck pits out. Move rig. Level rig. Press 5 1/2" bushing out of new tubing spool. 0.0 0.0 6/30/2023 14:00 6/30/2023 16:00 2.00 COMPZN, RPCOMP WWSP P Engage spear. P/U 92K over blocks, 10.5" of stretch. OAL growth 31.5". Reset emergency slips. Engage pack off in casing head. Make rough cut on 7" casing. 0.0 0.0 6/30/2023 16:00 6/30/2023 16:15 0.25 COMPZN, RPCOMP BHAH P L/D BHA #5. Break joint off of spear & L/D 0.0 0.0 6/30/2023 16:15 6/30/2023 23:15 7.00 COMPZN, RPCOMP NUND P N/U DSA and BOP and Secure same. RU Circulating system. Install Riser and obtain new RKB Measurements. Air up Boot Riser. Install Mouse Hole Riser. 0.0 0.0 6/30/2023 23:15 6/30/2023 23:30 0.25 COMPZN, RPCOMP SFTY P PJSM for Picking up BHA 0.0 0.0 6/30/2023 23:30 7/1/2023 00:00 0.50 COMPZN, RPCOMP BHAH P PU/MU BHA #6. Model "G" Lock set RBP with setting tool for 7" Casing. 0.0 0.0 7/1/2023 00:00 7/1/2023 00:30 0.50 COMPZN, RPCOMP MPSP P TIH w/G-Plug to 99' . Rotate while stacking weight down to 20K and G Lock set RBP. 0.0 99.0 7/1/2023 00:30 7/1/2023 01:30 1.00 COMPZN, RPCOMP MPSP T Lost SCR Controls to the Rig floor. 99.0 99.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 7/38 2K-07 Report Printed: 8/10/2023 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) 7/1/2023 01:30 7/1/2023 02:00 0.50 COMPZN, RPCOMP TRIP P TOOH and L/D Setting tool. 99.0 0.0 7/1/2023 02:00 7/1/2023 02:30 0.50 COMPZN, RPCOMP SEQP P RU Testing equipment. Fluid pack and Shell test Break on BOPE. 0.0 0.0 7/1/2023 02:30 7/1/2023 06:00 3.50 COMPZN, RPCOMP PRTS T Leak on the GrayLock connection. Remove, clean and make repairs on Connection. GrayLock hold pressure. 0.0 0.0 7/1/2023 06:00 7/1/2023 07:00 1.00 COMPZN, RPCOMP PRTS P PT well head break, choke and kill lines T/ 250/3000 PSI for 5 min each. 0.0 0.0 7/1/2023 07:00 7/1/2023 07:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6 G-plug retrievel tool. Latch into G-plug. 0.0 95.0 7/1/2023 07:30 7/1/2023 08:00 0.50 COMPZN, RPCOMP MPSP P Rotate to right while picking up string weight. Release G-plug. Verify no pressure under plug. 95.0 95.0 7/1/2023 08:00 7/1/2023 08:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #6 F/ 95' to surface. 95.0 0.0 7/1/2023 08:30 7/1/2023 09:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7 - 6" sting mill w/ jars and bumper sub T/ 28'. Rig on shore power @ 09:00 Hrs. 0.0 28.0 7/1/2023 09:00 7/1/2023 10:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 28' T/ 730' (mill depth) PUW=45K, SOW=45K. Set down 10K @ 730', unable to pass obstruction in 7" casing. Call out Yellow Jacket E-line for caliper run. 28.0 730.0 7/1/2023 10:00 7/1/2023 11:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 730' T/ 28', PUW=45K. 730.0 28.0 7/1/2023 11:00 7/1/2023 11:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #6 to surface. 28.0 0.0 7/1/2023 11:30 7/1/2023 12:30 1.00 COMPZN, RPCOMP SVRG P Service rig. Grease cown, TD, blocks and draw works. 0.0 0.0 7/1/2023 12:30 7/1/2023 13:30 1.00 COMPZN, RPCOMP RURD P R/U Yellow Jacket E-line. 0.0 0.0 7/1/2023 13:30 7/1/2023 15:00 1.50 COMPZN, RPCOMP ELNE P Run in hole w/ 40 arm caliper and CCL T/ 860'. Log up T/ surface. Run back in hole and make 2nd pass F/ 825' T/ 600'. 0.0 0.0 7/1/2023 15:00 7/1/2023 15:30 0.50 COMPZN, RPCOMP RURD P R/D E-line. 0.0 0.0 7/1/2023 15:30 7/1/2023 16:30 1.00 COMPZN, RPCOMP TRIP P Make up 4.75" mule shoe, RIH on DP T/ 860', PUW=48K, SOW=48K. 0.0 860.0 7/1/2023 16:30 7/1/2023 17:00 0.50 COMPZN, RPCOMP CIRC P Move fluid around in pits in preparation of building viscous system. Circ 46 Bbls 10.8 PPG brine @ 6 BPM, 210 PSI. Taking returns overboard to make room in pits for viscous system. 860.0 860.0 7/1/2023 17:00 7/1/2023 17:30 0.50 COMPZN, RPCOMP TRIP P TOOH 1 stand and L/D 1 Joint. 860.0 741.0 7/1/2023 17:30 7/1/2023 19:30 2.00 COMPZN, RPCOMP RURD P Blow down TD. Space out and Rig up sand Hopper to Drill Pipe. 741.0 741.0 7/1/2023 19:30 7/1/2023 23:30 4.00 COMPZN, RPCOMP CIRC P Start Dumping (20) 60# Bags of all purpose sand down Drill Pipe. Total of 1200#. Allow time for sand to settle on top of IBP. 741.0 741.0 7/1/2023 23:30 7/2/2023 00:00 0.50 COMPZN, RPCOMP RURD P Rig down the KB-1000 Sand Hopper. 741.0 741.0 7/2/2023 00:00 7/2/2023 00:15 0.25 COMPZN, RPCOMP TRIP P TIH and tagged top of sand at 816' Estimated top of sand was 823'. 741.0 816.0 7/2/2023 00:15 7/2/2023 01:15 1.00 COMPZN, RPCOMP TRIP P TOOH standing back DP from 816' to surface. 816.0 0.0 7/2/2023 01:15 7/2/2023 01:45 0.50 COMPZN, RPCOMP PULD P Load Cutter Assembly to RD. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 8/38 2K-07 Report Printed: 8/10/2023 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) 7/2/2023 01:45 7/2/2023 02:15 0.50 COMPZN, RPCOMP SFTY P PJSM for Making BHA #8 0.0 0.0 7/2/2023 02:15 7/2/2023 02:45 0.50 COMPZN, RPCOMP BHAH P MU 4.5" MSC BHA on Drill Pipe 0.0 3.9 7/2/2023 02:45 7/2/2023 04:00 1.25 COMPZN, RPCOMP TRIP P TIH with BHA #8 and locate 7" CSG collar at ~758' at 32 SPM, 205 psi. 3.9 758.0 7/2/2023 04:00 7/2/2023 04:30 0.50 COMPZN, RPCOMP CUTP P Drop down 7' below CSG collar at 758' to 765' and started cutting 7" CSG at 80 RPM, 2.4 BPM, 335 psi, 1-2K WOB, 5K Torque. Seen good indication 7" CSG is cut after pressure fall to 230 psi and OA pressure increased to 200 psi. 758.0 765.0 7/2/2023 04:30 7/2/2023 05:15 0.75 COMPZN, RPCOMP SVRG P Lost SCR Controls to the Rig Floor. Rig Services 765.0 765.0 7/2/2023 05:15 7/2/2023 06:00 0.75 COMPZN, RPCOMP TRIP P TOOH with BHA #8 and L/D Same. 765.0 0.0 7/2/2023 06:00 7/2/2023 07:45 1.75 COMPZN, RPCOMP RURD P Close in blind rams. R/U circ equipment F/ OA T/ Open top tank. 0.0 0.0 7/2/2023 07:45 7/2/2023 08:00 0.25 COMPZN, RPCOMP SFTY P PJSM w/ MI and rig crew on circulation freeze protect out of OA. 0.0 0.0 7/2/2023 08:00 7/2/2023 08:30 0.50 COMPZN, RPCOMP DISP P Circ 125 Bbls @ 3 BPM, 113 PSI, down 7" taking returns out OA to open top tank. Diesel and arctic pac observed at surface. At end of circulation returns were 10.7 PPG cut w/ diesel. 0.0 0.0 7/2/2023 08:30 7/2/2023 09:30 1.00 COMPZN, RPCOMP OWFF P Shut down pumps. Allow diesel from below cut to migrate to surface. OA open to open top tank, slight flow out OA. Suck out open top tank. 0.0 0.0 7/2/2023 09:30 7/2/2023 10:00 0.50 COMPZN, RPCOMP DISP P Circ 15 Bbls @ 1 BPM, 68 PSI, down 7" taking returns out OA to open top tank. Gas & crude retruns observed at surface. 0.0 0.0 7/2/2023 10:00 7/2/2023 11:00 1.00 COMPZN, RPCOMP OWFF P Shut down pumps. Allow crude / gas from below cut to migrate to surface. OA open, slight flow out of OA. Suck out open top tank. Send dirty vac to disposal. Oreder truck load of 10.8 PPG brine. Load GBR tongs T/ RF. 0.0 0.0 7/2/2023 11:00 7/2/2023 11:15 0.25 COMPZN, RPCOMP DISP P Circ 25 Bbls @ 1 BPM, 68 PSI, down 7" taking returns out OA to open top tank. Gas & arctic pack retruns observed at surface. 0.0 0.0 7/2/2023 11:15 7/2/2023 12:15 1.00 COMPZN, RPCOMP OWFF P Shut down pumps. Allow crude / gas from below cut to migrate to surface. OA open, slight flow out of OA. Suck out open top tank. Send dirty vac to disposal. 0.0 0.0 7/2/2023 12:15 7/2/2023 12:30 0.25 COMPZN, RPCOMP DISP P Circ 25 Bbls @ 1 BPM, 68 PSI, down 7" taking returns out OA to open top tank. Gas & arctic pack retruns observed at surface. 0.0 0.0 7/2/2023 12:30 7/2/2023 13:00 0.50 COMPZN, RPCOMP OWFF P Shut down pumps. Close in OA. Allow crude / gas from below cut to migrate to surface. Open up choke. Bleed 10 PSI gas off of 7". OWFF in IA - No flow. 0.0 0.0 7/2/2023 13:00 7/2/2023 14:00 1.00 COMPZN, RPCOMP PULD P M/U mule shoe and PUDP T/ 650', SOW=42K. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 9/38 2K-07 Report Printed: 8/10/2023 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) 7/2/2023 14:00 7/2/2023 14:30 0.50 COMPZN, RPCOMP DISP P Close in pipe rams. Circ 25 Bbls @ 1 BPM, 68 PSI, own 7" taking returns out OA to open top tank. Gas & arctic pack retruns observed at surface. 0.0 0.0 7/2/2023 14:30 7/3/2023 00:00 9.50 COMPZN, RPCOMP DISP P Added isolation valve to open top tank. OWFF gas and arctic pack flowing from OA after shutting in for 30 Min. Pump 10 Bbls. Shut of pumps for 30 Min. Vent OA after pumping gas and arctic pack observed. Repeat process allowing gas and arctic pack to migrate up OA to surface. 0.0 0.0 7/3/2023 00:00 7/3/2023 02:30 2.50 COMPZN, RPCOMP DISP P Continue to Lubricate & Bleed OA. Pump 10 Bbls. Close in for 30 Min. Repeat process allowing gas and arctic pack to migrate up OA. IA showing 10- 20 psi before bleeding gas off. 48 psi IA pressure while pumping at 1 bpm, 63 psi of DP. Allowing OA to breathe to the Cutting Tank before pumping again. 0.0 0.0 7/3/2023 02:30 7/3/2023 03:00 0.50 COMPZN, RPCOMP DISP P Pumped at 1 bpm, IA 50 psi, DPP, 60 psi. Starting to show less Arctic pack at surface after pumping 145 bbls. Obtain Fluid sample from OA valve, showing 10.7 PPG heavy. 0.0 0.0 7/3/2023 03:00 7/3/2023 03:30 0.50 COMPZN, RPCOMP OWFF P Shut In OA and observe pressure build up for 30 minutes. After 30 mins build up, had 10 psi on the OA. Opened OA up to tank and still showed trace of gas. 0.0 0.0 7/3/2023 03:30 7/3/2023 05:30 2.00 COMPZN, RPCOMP DISP P Continue to Lubricate & Bleed OA. Pump 10 Bbls. Close in for 30 Min. Repeat process allowing gas and arctic pack to migrate up OA and bleed to cuttings tank. Dirty10.8 PPG KWF back pressurized balance scale. . 0.0 0.0 7/3/2023 05:30 7/3/2023 08:30 3.00 COMPZN, RPCOMP DISP P Continue to Lubricate & Bleed OA. Pump 10 Bbls. Close in for 30 Min. Repeat process allowing gas and arctic pack to migrate up OA. Identified clean 10.8 PPG retunes out of OA. Pumped 25 Bbls w/ clean 10.8 PPG returns to surface. 0.0 7/3/2023 08:30 7/3/2023 09:30 1.00 COMPZN, RPCOMP OWFF P Bled 10 PSI off of IA. Opened pipe rams. Suck out stack. OWFF from IA and OA. 30 Min no flow. 7/3/2023 09:30 7/3/2023 10:30 1.00 COMPZN, RPCOMP TRIP P POOH racking back DP F/ 650' to surface, PUW=42K. L/D mule shoe. 7/3/2023 10:30 7/3/2023 11:00 0.50 COMPZN, RPCOMP OWFF P Closed in blinds. Open OA to cutting tank. Flow identified out of OA mixture of arctic pack, gas and brine. 7/3/2023 11:00 7/3/2023 19:15 8.25 COMPZN, RPCOMP DISP P Continue to Lubricate & Bleed OA. Pump 10 Bbls @ 1 BPM, 65 PSI on IA. Shut pumps off for 30 Min. Allow OA to vent to cuttings tank. Repeat process allowing gas and arctic pack to migrate up OA and bleed to cuttings tank. Started out with dirty 10.8 PPG KWF back pressurized balance scale. Now seeing distinct arctic pack and gas at surface. Building 10 PSI on OA. 7/3/2023 19:15 7/3/2023 19:45 0.50 COMPZN, RPCOMP CIRC P Circulated a surface to surface volume of 10.8 PPG brine @ 2 BPM, 67 psi. Total pumped 55 bbls. Opened OA valve at surface and OWFF for flow for 30 mins. Small trace of gas and no flow at surface. Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 10/38 2K-07 Report Printed: 8/10/2023 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) 7/3/2023 19:45 7/3/2023 20:45 1.00 COMPZN, RPCOMP DISP P Continue to Lubricate & Bleed OA. Pump 10 Bbls @ 1 BPM, 65 PSI on IA. Shut pumps off for 30 Min. Allow OA to vent to cuttings tank. 7/3/2023 20:45 7/3/2023 21:30 0.75 COMPZN, RPCOMP OWFF P OWFF on the OA. Still no flow. 7/3/2023 21:30 7/3/2023 22:00 0.50 COMPZN, RPCOMP BHAH P PU/MU 7" Spear BHA. TIH on 1 Joint of DP. Engage top of 7" CSG. PUH 2' to unseat packoffs and Slips at 106K. 765.0 763.0 7/3/2023 22:00 7/3/2023 22:30 0.50 COMPZN, RPCOMP OWFF P OWFF after unseating slips & packoff. 763.0 763.0 7/3/2023 22:30 7/3/2023 23:00 0.50 COMPZN, RPCOMP RURD P Split BOP Stack while observing OA for flow. 763.0 763.0 7/3/2023 23:00 7/3/2023 23:15 0.25 COMPZN, RPCOMP WWSP P Remove 7" Casing Slips. 763.0 763.0 7/3/2023 23:15 7/4/2023 00:00 0.75 COMPZN, RPCOMP RURD P NU BOP Stack, Choke and Kill Lines. 763.0 763.0 7/4/2023 00:00 7/4/2023 01:00 1.00 COMPZN, RPCOMP RURD P Finish NU BOP Stack, Choke and Kill Lines. Secure stack and air up boot on riser. Fluid Pack BOP stack and check for leaks. 763.0 763.0 7/4/2023 01:00 7/4/2023 02:45 1.75 COMPZN, RPCOMP PULL P Starting TOOH with 7" CSG. Casing up wt 105K, after pulling 25', seen instant increase in up weight to 165k. Attempted to RIH back in hole with no success. Worked CSG for movement. Unable to gain in movement in either direction. Discuss options with Town. 763.0 738.0 7/4/2023 02:45 7/4/2023 05:30 2.75 COMPZN, RPCOMP CUTP P Pull CSG in tension, close 7" Pipe Rams on CSG. Release 7" CSG Spear and L/D Same. RU MSC on Drill Pipe and TIH. Locate CSG collar inside 7"above damaged 9-5/8" CSG at 695'. PUH 5' and Cut 7" CSG at 690' at 3 bpm, 415 psi, 1500 torque, 90 RPM. 738.0 695.0 7/4/2023 05:30 7/4/2023 06:00 0.50 COMPZN, RPCOMP TRIP P TOOH f/690' with 7" MSC. 690.0 690.0 7/4/2023 06:00 7/4/2023 07:30 1.50 COMPZN, RPCOMP FISH P RU 7" Spear and engage 7" Casing. Able to pull CSG to surface after cut. P/U 45K. 690.0 685.0 7/4/2023 07:30 7/4/2023 09:30 2.00 COMPZN, RPCOMP PULL P Pull 7" CSG f/690' to surface. 685.0 0.0 7/4/2023 09:30 7/4/2023 09:45 0.25 COMPZN, RPCOMP SFTY P PJSM on setting 11" test plug. 0.0 0.0 7/4/2023 09:45 7/4/2023 10:30 0.75 COMPZN, RPCOMP MPSP P MU and Set 11" Test Plug. 0.0 0.0 7/4/2023 10:30 7/4/2023 11:30 1.00 COMPZN, RPCOMP PRTS P Shell test BOP, choke and kill lines to 250/3500 psi. Passed. Lost rig high- line power for 15 minutes. Back online at 11:30 AM. 0.0 0.0 7/4/2023 11:30 7/4/2023 14:15 2.75 COMPZN, RPCOMP BHAH P Pull 11" Test Plug. Set Wear Ring. MU Baker 7" MSC on DP. 0.0 0.0 7/4/2023 14:15 7/4/2023 15:00 0.75 COMPZN, RPCOMP CUTP P RIH w/ Baker MSC w/ no bullnose on 3 1/2" DP. Set down @ top of fish @ 690'. Could not get into 7" stub. Discuss with Baker Fishing hand. Need bullnose. 0.0 690.0 7/4/2023 15:00 7/4/2023 15:30 0.50 COMPZN, RPCOMP TRIP P TOOH from 690' w/ Baker 7" MSC. Clean rig floor. 690.0 0.0 7/4/2023 15:30 7/4/2023 16:30 1.00 COMPZN, RPCOMP WAIT T Baker Fishing rep on route to pickup bullnose for 7" MSC. Baker Rep back on location at 16:30. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 11/38 2K-07 Report Printed: 8/10/2023 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) 7/4/2023 16:30 7/4/2023 17:45 1.25 COMPZN, RPCOMP TRIP P MU bullnose to bottom of cutter. RU and RIH w/ Baker 7" MSC with bullnose on 3 1/2" DP. SOW = 48K. Tag 7" stub @ 690'. Rotate and slide into 7" stub. 0.0 728.0 7/4/2023 17:45 7/4/2023 18:45 1.00 COMPZN, RPCOMP CUTP P Bring pumps online @ 2 BPM (256 psi). TIH and locate collar @ 735'. Set 5K down. Offline with pumps. PU 7' to cut depth of 728' Unable to take returns to Pits 2-4 at 2 BPM. Overflows shakers. Transfer high vis pill to Pit #4 and brine to Pit #1 to allow for high rate circulation. Bring pumps online @ 3 BPM (500 psi) and cut 7" casing @ 728' (7' above collar @ 735'). RPM @ 70 RPM. Torque = 2K ft-lbs. 728.0 728.0 7/4/2023 18:45 7/4/2023 19:45 1.00 COMPZN, RPCOMP TRIP P Blow down Top Drive. PJSM. TOOH and L/D MSC BHA. 728.0 0.0 7/4/2023 19:45 7/4/2023 20:45 1.00 COMPZN, RPCOMP BHAH P MU 7" Spear with Bumper sub, Jars and Drill Collars. 0.0 168.0 7/4/2023 20:45 7/4/2023 21:45 1.00 COMPZN, RPCOMP TRIP P TIH w/Spear to Top of 7" cut section at 690' to engage top of fish. 168.0 690.0 7/4/2023 21:45 7/4/2023 22:15 0.50 COMPZN, RPCOMP FISH P Up Wt 95K. Engage 7" CSG, stack 5K down weight. PUH and seen 2K increase in weight. 690.0 690.0 7/4/2023 22:15 7/4/2023 22:45 0.50 COMPZN, RPCOMP CIRC P Circulate Bottoms up @ 5 BPM, 210 psi. Blow down Top Drive. 690.0 690.0 7/4/2023 22:45 7/4/2023 23:30 0.75 COMPZN, RPCOMP TRIP P TOOH with fishing BHA #11 690.0 206.0 7/4/2023 23:30 7/5/2023 00:00 0.50 COMPZN, RPCOMP BHAH P Standback Drill Collars and L/D Fishing Spear BHA. 206.0 38.0 7/5/2023 00:00 7/5/2023 01:00 1.00 COMPZN, RPCOMP PULL P L/D Fishing Spear BHA #11. 38' Cut CSG section at surface. Clean & Clear Floor. 38.0 0.0 7/5/2023 01:00 7/5/2023 02:30 1.50 COMPZN, RPCOMP PULD P Unload Baker Tools and Load Baker tools to Pipe Shed. 0.0 0.0 7/5/2023 02:30 7/5/2023 04:15 1.75 COMPZN, RPCOMP BHAH P MU BHA #12. 8.375" Pilot Packer Mill, 8.375" String Mill, Bumper Sub & Jars, 6 Drill Collars 0.0 219.0 7/5/2023 04:15 7/5/2023 05:00 0.75 COMPZN, RPCOMP TRIP P TIH with BHA #12 to 720' and obtain parameters for Milling 7" CSG. 219.0 727.0 7/5/2023 05:00 7/5/2023 08:30 3.50 COMPZN, RPCOMP MILL P Dry tagged top of 7" CSG Stub at 727', get parameters and start milling on 7" casing at 8 bpm, 230 psi, rotating at 80 RPM's. Mill from 727' to 733'. 727.0 733.0 7/5/2023 08:30 7/5/2023 09:30 1.00 COMPZN, RPCOMP TRIP P PJSM. TOOH from 733' to 219'. 733.0 219.0 7/5/2023 09:30 7/5/2023 10:30 1.00 COMPZN, RPCOMP BHAH P L/D DC's and BHA #12 (Pilot Packer Mill w/ string mill). Damaged 2 threads on drill collars. Broke out drill collars to be sent in for inspection. Cont. L/D BHA. Clean and clear rig floor. 219.0 0.0 7/5/2023 10:30 7/5/2023 12:30 2.00 COMPZN, RPCOMP RURD P Wash BOP stack. Pull Wear Ring. Set 11" test plug. Prepare for BOP test. Fluid pack surface lines. 0.0 0.0 7/5/2023 12:30 7/5/2023 13:30 1.00 COMPZN, RPCOMP BOPE P Perform BOP shell test. 250 psi low / 3,000 psi high. Bump back up for retest. Bleed air from system and bump backup. Shell Test Passed. Called AOGCC Inspector (Sean Sullivan) for witness. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 12/38 2K-07 Report Printed: 8/10/2023 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) 7/5/2023 13:30 7/5/2023 20:00 6.50 COMPZN, RPCOMP BOPE P Weekly BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular w/ 3 ½ TJ, tested UVBR's w/ 3 ½ TJ, tested LPRs w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Conduct Accumulator Draw Down Test. Initial pressure=3120 PSI, after closure=1600 PSI, 200 PSI attained =20 sec, full recovery attained =121 sec. UVBR's= 4 sec, Annular= 17 sec. Simulated blinds= 4 sec. Simulated LPR's= 4 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness by AOGCC rep Sean Sullivan. 0.0 0.0 7/5/2023 20:00 7/5/2023 21:00 1.00 COMPZN, RPCOMP RURD P RD Testing Equipment. Drain BOP Stack. Pull 11" test plug. Install Wear Ring. 0.0 0.0 7/5/2023 21:00 7/5/2023 23:15 2.25 COMPZN, RPCOMP BHAH P MU BHA #13. 8.375" Pilot Packer Mill, 8.375" String Mill, Bumper Sub & Jars, 6 Drill Collars 0.0 219.0 7/5/2023 23:15 7/5/2023 23:45 0.50 COMPZN, RPCOMP TRIP P TIH with BHA #13 to 400' 400.0 400.0 7/5/2023 23:45 7/6/2023 00:00 0.25 COMPZN, RPCOMP SFTY P PJSM for Slip & Cut Drill Line 400.0 400.0 7/6/2023 00:00 7/6/2023 02:00 2.00 COMPZN, RPCOMP SLPC P Slip & Cut 66' of Drill Line 400.0 400.0 7/6/2023 02:00 7/6/2023 02:30 0.50 COMPZN, RPCOMP TRIP P TIH f/400' to top of 7" CSG @ 730' 400.0 730.0 7/6/2023 02:30 7/6/2023 05:00 2.50 COMPZN, RPCOMP MILL P Dry Tagged top 7" CSG Stub at 730', UP Wt 51K, DN Wt 52K. PUH 5' and set Parameters. Pump Rate 8 bpm, SPP 240 psi, 80 RPM, 1-2K Torque. Mill 7" to 733.2'. 730.0 733.0 7/6/2023 05:00 7/6/2023 05:30 0.50 COMPZN, RPCOMP SVRG P PUH. Come offlline w/ pumps. Top Drive leak identified. Stand back 1 stand. Lower Top Drive to rig floor for inspection and repair. Service Top Drive leak and service drawworks. 733.0 679.0 7/6/2023 05:30 7/6/2023 06:00 0.50 COMPZN, RPCOMP MILL P Obtain milling parameters. TBIH and continue milling. Mill to 735'. 8 BPM. 80 RPM. 250 psi. 6K torque. 4K WOB. P/U 50K. S/O = 53K. 679.0 735.0 7/6/2023 06:00 7/6/2023 08:00 2.00 COMPZN, RPCOMP MILL P Cont. milling down to 758'. 4-6K torque. 2-4K WOB. Work mill and ream from 735' - 745'. 735.0 758.0 7/6/2023 08:00 7/6/2023 08:15 0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss tripping pipe. 758.0 758.0 7/6/2023 08:15 7/6/2023 08:45 0.50 COMPZN, RPCOMP TRIP P Circ. BU. TOOH from 735' to surface 758.0 36.0 7/6/2023 08:45 7/6/2023 09:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #13 (8 3/8" pilot packer mill w/ 8 3/8" string mill). 36.0 0.0 7/6/2023 09:30 7/6/2023 10:15 0.75 COMPZN, RPCOMP BHAH P M/U BHA #14 (Bull nose, 7" ITCO Spear w/ 6.220" GR, Stop sub, Bumper sub, Oil Jar, XO, 6 DC's). 0.0 30.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 13/38 2K-07 Report Printed: 8/10/2023 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) 7/6/2023 10:15 7/6/2023 11:15 1.00 COMPZN, RPCOMP TRIP P TIH w/ 7" Spear. PUW @ 706' = 51K, SOW = 52K 30.0 706.0 7/6/2023 11:15 7/6/2023 11:30 0.25 COMPZN, RPCOMP FISH P TIH slowly from 730' - 756' Slight bobble seen @ 756'. Set 5K dow on top of fish @ 758'. Not fully stabbed into fish. PU 3'. Bring pumps online @ 4 BPM to wash top of fish. TIH to 760'. Stack 10K down. Push spear into 7" fish to 761'. Repeat set down to confirm latched. 706.0 761.0 7/6/2023 11:30 7/6/2023 12:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #14 (7" spear). 761.0 30.0 7/6/2023 12:30 7/6/2023 13:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #14. 7" casing fish at surface. OAL = 8.93' (1.49' Top to Collar - Joint #19, 7.44' Collar to 1st cut - Joint #20). Spear stuck in fish due to swedged 7" casing. Milled approx. 5' of 7" casing (Joint #19). 30.0 0.0 7/6/2023 13:00 7/6/2023 14:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #15 (Bullnose, 8 3/8" String Mill, 8.50" String Mill, Bumper Sub, Oil Jar, XO, 6 DC). 0.0 221.7 7/6/2023 14:00 7/6/2023 15:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ string mill assembly to 720'. 221.7 720.0 7/6/2023 15:00 7/6/2023 17:30 2.50 COMPZN, RPCOMP MILL P Bring pumps online @ 8 BPM. Reciprocate string mills across buckled 9 5/8" casing interval from 720' - 760'. Saw 4.1K torque spike @ 741' on 1st pass (8.50" string mill @ 732'). On 2nd pass saw 4.4-4.8K torque spikes from 744' - 748' (8.50" string mill @ 735- 739'). Smoothed out to 3.0-3.3K torque below 748'. 30# of steel gathered on magnets from previous milling operations. 720.0 760.0 7/6/2023 17:30 7/6/2023 18:15 0.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #15. 760.0 221.7 7/6/2023 18:15 7/6/2023 19:00 0.75 COMPZN, RPCOMP BHAH P L/D BHA #15 (Bullnose, 8 3/8" String Mill, 8.50" String Mill, Bumper Sub, Oil Jar, XO, 6 DC). 221.7 0.0 7/6/2023 19:00 7/6/2023 19:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #16 (Bullnose, 8.50" String Mill, 8.50" String Mill, Bumper Sub, Oil Jar, XO, 6 DC). 0.0 221.7 7/6/2023 19:45 7/6/2023 20:45 1.00 COMPZN, RPCOMP TRIP P TIH w/ string mill assembly. 221.7 722.0 7/6/2023 20:45 7/6/2023 22:45 2.00 COMPZN, RPCOMP REAM P Bring pumps online @ 8 BPM, 190 psi, 60 RPM, 3.5K WOB. Reciprocate string mills across buckled 9 5/8" casing interval from 720' - 760' 5 times. 3-4K Ft/Lbs of torque while Reciprocating across 9-5/8" CSG at 736' to 747'. 722.0 760.0 7/6/2023 22:45 7/6/2023 23:30 0.75 COMPZN, RPCOMP TRIP P TOOH f/760' P/U 51K / S.O 53K 760.0 221.7 7/6/2023 23:30 7/7/2023 00:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #16, Tandem 8.5" String Mills. 221.7 0.0 7/7/2023 00:00 7/7/2023 01:00 1.00 COMPZN, RPCOMP BHAH P Load Baker tools to rig floor. MU 8-3/8" x 7" Dress off shoe, 8-1/8" SWP EXT, 8- 1/8" Tripple Connect with Jars and Drill collars. 0.0 217.8 7/7/2023 01:00 7/7/2023 01:45 0.75 COMPZN, RPCOMP TRIP P TIH w/BHA #17. 217.8 760.0 7/7/2023 01:45 7/7/2023 02:45 1.00 COMPZN, RPCOMP REAM P Bring pumps online @ 5 BPM, 100 psi, 60 RPM, 3.5K WOB. Located top of 7" @ 766'. Ream down on top of 7" CSG f/766' to no go depth of 773' with dress off shoe. Blow down Top Drive. 760.0 773.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 14/38 2K-07 Report Printed: 8/10/2023 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) 7/7/2023 02:45 7/7/2023 03:30 0.75 COMPZN, RPCOMP TRIP P TOOH f/773' to BHA #17. 773.0 217.8 7/7/2023 03:30 7/7/2023 05:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #17 217.8 0.0 7/7/2023 05:00 7/7/2023 05:30 0.50 COMPZN, RPCOMP RURD P PU/MU Wear Ring Retrieval Tool and Pull wear ring. R/U GBR 7" pipe handling equipment. 0.0 0.0 7/7/2023 05:30 7/7/2023 06:00 0.50 COMPZN, RPCOMP SFTY P PJSM. Discuss 7" casing running operations 0.0 0.0 7/7/2023 06:00 7/7/2023 09:00 3.00 COMPZN, RPCOMP PUTB P PU/MU 7" x 8.370" External Casing Patch. TIH w/ 7" 26# L-80 HYD563 casing using Best-O-Life 2000. GBR torque turn connections to 9,000 ft-lbs. TIH to 751'. PUW = 52K. SOW = 54K. TIH T/ tag @ 769'. Swallow 7" stub with patch. No-go @ 771' (2' swallow). Set 18K down. PU 25K over. Confirmed good latch. Set 18K down. 0.0 771.0 7/7/2023 09:00 7/7/2023 09:45 0.75 COMPZN, RPCOMP RURD P Clean and clear rig floor. RU circ hose and sensor for PT. Setup chart recorder. Purge air from last joint of casing circulating through bleeder. Bleed off and reset chart recorder to read 7" casing pressure. 771.0 771.0 7/7/2023 09:45 7/7/2023 11:30 1.75 COMPZN, RPCOMP PRTS P Pressure up 7" casing to 250 low. No leaks. Cont. to pressure up casing to 2,500 psi test. At 2,500 psi pressure dropped off to 1,000 psi. Possible that the IBP set @ 879' slipped. Bled pressure off. Call Town to discuss. Develop new plan forward to set and test shallow G-plug prior to ND operations. Call Baker to redress 7" spear and prepare 7" test packer for upcoming operations. 771.0 771.0 7/7/2023 11:30 7/7/2023 13:00 1.50 COMPZN, RPCOMP PRTS P Pressure up 7" casing to 500 psi. OA pressure remained at 30 psi. RU hose and bleed OA to tank. Drain Stack. Blowdown hardline to open top. OWFF. No Flow test passed. OA bled to 0 psi with 500 psi on 7" casing. Shut-in and monitor OA gauge pressure for build up. Bleed 500 psi off 7" casing. OWFF for 30 min. R/D circ hose and 1502 head pin. Load FMC 7" casing cutter to rig floor. 771.0 771.0 7/7/2023 13:00 7/7/2023 18:00 5.00 COMPZN, RPCOMP WAIT T Wait on additional tools (Test Packer and 7" Spear) from Deadhorse for new plan forward. Baker tools ready at shop @ 14:20. Driver headed over from Deadhorse. 771.0 771.0 7/7/2023 18:00 7/7/2023 19:00 1.00 COMPZN, RPCOMP CUTP P PJSM. Fill out Hot Work Permit. Start cutting 7" CSG at surface. 771.0 771.0 7/7/2023 19:00 7/7/2023 20:30 1.50 COMPZN, RPCOMP MPSP P PU/MU BHA #18, 7" G-Plug Assy. TIH with G-Plug and set same at 90' COE. Made several attempts to set G-Plug with no success. 0.0 90.0 7/7/2023 20:30 7/7/2023 22:30 2.00 COMPZN, RPCOMP WAIT P Wait on another G-Plug from Yellowjacket. 0.0 0.0 7/7/2023 22:30 7/8/2023 00:00 1.50 COMPZN, RPCOMP MPSP P PU/MU BHA #19, 7" G-Plug Assy. TIH with G-Plug and set same at 90' COE. 0.0 90.0 7/8/2023 00:00 7/8/2023 00:45 0.75 COMPZN, RPCOMP MPSP P PU/MU 7" Test Plug Assy. TIH with Plug and set same at 50'. 0.0 50.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 15/38 2K-07 Report Printed: 8/10/2023 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) 7/8/2023 00:45 7/8/2023 01:00 0.25 COMPZN, RPCOMP PRTS P RU Testing equipment. Fluid Pack and PT G-Plug to 250/3000 psi. 50.0 50.0 7/8/2023 01:00 7/8/2023 02:00 1.00 COMPZN, RPCOMP MPSP P Bleed down pressure. Had issues getting test plug to release. Pull Test Plug and L/D same. 50.0 0.0 7/8/2023 02:00 7/8/2023 02:30 0.50 COMPZN, RPCOMP OWFF P Drain BOP Stack. OWFF for 30 mins. 0.0 0.0 7/8/2023 02:30 7/8/2023 04:30 2.00 COMPZN, RPCOMP NUND P Nipple down Choke & Kill Lines. ND BOPE and lift same to cut 7" CSG. Remove Riser and Boot. 0.0 0.0 7/8/2023 04:30 7/8/2023 07:00 2.50 COMPZN, RPCOMP CUTP P Cut 7" CSG above casing flange. Install dummy slip spacer and install Packoffs. 0.0 0.0 7/8/2023 07:00 7/8/2023 09:00 2.00 COMPZN, RPCOMP NUND P NU BOP Stack, choke, kill, riser, and air up boots. RU rig floor to PT break. 0.0 0.0 7/8/2023 09:00 7/8/2023 12:00 3.00 COMPZN, RPCOMP PRTS P Fill Stack. PT BOP Break, choke and kill lines to 250/3000 psi. 250 low passed. Found leak in choke line greylock during 3,000 psi high. Bleed off and tighten up greylock. Restart test. Found leak at flange between DSA and Wellhead. Tightened up. Retest. Pressure up to 3,000 psi and pressure bled off to 2,500 psi. Hear fluid movement through Drilling Spool around Packoffs. Saw slight flow from OA indicating packoffs are leaking. Bled off pressure. Drain BOP stack. OWFF for 30 minutes. NFT passed. 0.0 0.0 7/8/2023 12:00 7/8/2023 14:00 2.00 COMPZN, RPCOMP MPSP P Send FMC to bring out new packoff assembly. MU/PU 7" Test Packer and set @ 50'. Nordic cleaned out pipe rack drain. Trouble shoot and calibrate Top Drive RPM and Torque in Pason. 0.0 50.0 7/8/2023 14:00 7/8/2023 15:00 1.00 COMPZN, RPCOMP PRTS P RU to PT backside of Test Packer through test spool. Close UPR on 3 1/2" DP. PT to 250 low / 3000 psi. At 3,000 psi pressure bled down to 600 psi. Noticed top drive and 3 1/2" DP moved downhole approx. 6" during pressure test. Without slips in the wellhead pressure tests are failing because we have floating 7" casing down to approx. 2,000'. Started having issues with Koomey pump after cycling UPR. Nordic troubleshooting. Suction screen plugged. Cleaned out. 50.0 50.0 7/8/2023 15:00 7/8/2023 15:30 0.50 COMPZN, RPCOMP MPSP P Drain Stack. Pull 7" Test Packer and L/D same. 50.0 0.0 7/8/2023 15:30 7/8/2023 20:30 5.00 COMPZN, RPCOMP NUND P ND BOPE, choke, kill. Pull riser from air boot. Set BOP on stump. Backoff packoff bolts. Pull packoffs. Pull slip spacer. 0.0 0.0 7/8/2023 20:30 7/8/2023 21:15 0.75 COMPZN, RPCOMP PULL P PU/MU 7" Spear. Spear 7" casing. Pull tension to allow slips to be set. Install and Torque Pack-Off. Release 7" Spear and L/D same. 0.0 29.0 7/8/2023 21:15 7/9/2023 00:00 2.75 COMPZN, RPCOMP NUND P NU BOP Stack, choke, kill, riser, and air up boots. 0.0 0.0 7/9/2023 00:00 7/9/2023 01:00 1.00 COMPZN, RPCOMP PRTS P RU Testing Equipment, Fluid Pack BOP Stack and PT break on stack, choke and kill lines to 250/3000 psi. RD Testing Equipment. Blow down Choke and Mud Manifold. 0.0 0.0 7/9/2023 01:00 7/9/2023 01:45 0.75 COMPZN, RPCOMP MPSP P RU and TIH w/G-Plug retrieving head, engage and pull G-Plug and L/D Same. 0.0 80.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 16/38 2K-07 Report Printed: 8/10/2023 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) 7/9/2023 01:45 7/9/2023 02:00 0.25 COMPZN, RPCOMP CLEN P Clean & Clear Rig floor. Remove tools from pipe shed and unload CSG. 0.0 0.0 7/9/2023 02:00 7/9/2023 02:45 0.75 COMPZN, RPCOMP BHAH P PU/MU BHA #18 (RCJB w/mill tooth space from basket) with 6 drill collars on Drill Pipe. 0.0 212.3 7/9/2023 02:45 7/9/2023 03:30 0.75 COMPZN, RPCOMP TRIP P TIH w/Clean Out Assy. on DP. 212.3 816.0 7/9/2023 03:30 7/9/2023 08:30 5.00 COMPZN, RPCOMP CIRC P Circulate and clean sand and debris from top of IBP at 873' @ 7 bpm, 1140 psi, 60 rpm. Park and circulate at 870', 3' above top of IBP. Pump 7 BPM 10.8# Brine and 4 - 10 bbl hi-vis gel sweep to lift sand off top of IBP. Returns clean. Suck out Cuttings Tanks and send returns truck in for offload. 816.0 873.0 7/9/2023 08:30 7/9/2023 10:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #18 (RCJB). 873.0 212.3 7/9/2023 10:00 7/9/2023 10:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #18. Found chunk of twisted 7" casing in RCJB (4.5" wide x 12" long), and 40 lbs of metal shavings. Decision made to re-rin RCJB to ensure top of IBP is clean. 212.3 0.0 7/9/2023 10:30 7/9/2023 11:00 0.50 COMPZN, RPCOMP BHAH P PU/MU BHA #19 (RCJB Re-run). 0.0 212.3 7/9/2023 11:00 7/9/2023 12:00 1.00 COMPZN, RPCOMP TRIP P TIH w/ RCJB to 870' . 212.3 870.0 7/9/2023 12:00 7/9/2023 13:30 1.50 COMPZN, RPCOMP WASH P Wash down to 3' above top of IBP. Circ. 10.8# brine at 7BPM, 1400 psi, 60 RPM. Chase with 2 - 10 bbls hi-vis pills to surface. 870.0 873.0 7/9/2023 13:30 7/9/2023 14:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ RCJB. 873.0 212.3 7/9/2023 14:30 7/9/2023 15:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #19 (RCJB). Check for debris. Clean. 212.3 0.0 7/9/2023 15:00 7/9/2023 15:30 0.50 COMPZN, RPCOMP SVRG P Grease crown, TD, blocks, drawworks. 0.0 0.0 7/9/2023 15:30 7/9/2023 16:00 0.50 COMPZN, RPCOMP BHAH P PU/MU BHA #20 (IBP retrieving head). 0.0 6.2 7/9/2023 16:00 7/9/2023 16:45 0.75 COMPZN, RPCOMP TRIP P TIH w/ IBP retrieving head to 870'. 6.2 870.0 7/9/2023 16:45 7/9/2023 17:15 0.50 COMPZN, RPCOMP WASH P With pumps @ 4 bpm, wash around IBP fish neck with retrieving head to top of IBP @ 873'. 870.0 873.0 7/9/2023 17:15 7/9/2023 18:15 1.00 COMPZN, RPCOMP MPSP P Latch IBP. Set down 6K to equalize. Release. Wait 15 min for element to relax. 873.0 873.0 7/9/2023 18:15 7/9/2023 19:00 0.75 COMPZN, RPCOMP TRIP P TOOH w/ IBP. 873.0 0.0 7/9/2023 19:00 7/9/2023 19:30 0.50 COMPZN, RPCOMP BHAH P L/D retrieving head with IBP. 0.0 0.0 7/9/2023 19:30 7/9/2023 19:45 0.25 COMPZN, RPCOMP BHAH P MU L-10 On/Off Tool w/2.875" x 3.5" IF Crossover. 0.0 2.8 7/9/2023 19:45 7/9/2023 20:15 0.50 COMPZN, RPCOMP TRIP P TIH w/L-10 On/Off Tool on Drill Pipe. 2.8 916.0 7/9/2023 20:15 7/9/2023 20:30 0.25 COMPZN, RPCOMP PULL P Latched L-10 Tool, PUH 6' Up Wt 105K. Latched up to the 3.5" Completion. 916.0 916.0 7/9/2023 20:30 7/9/2023 22:45 2.25 COMPZN, RPCOMP CIRC P Line up pumps and circulating lines to take returns to the open top tank. Start circulating @ 5 bpm, 1190 psi until clean 10.8 PPG KWF is seen at the choke. Blow Down circulating system. 916.0 916.0 7/9/2023 22:45 7/10/2023 00:00 1.25 COMPZN, RPCOMP PULL P TOOH to L-10 BHA and L/D same. Up Wt 105K. 916.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 17/38 2K-07 Report Printed: 8/10/2023 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) 7/10/2023 00:00 7/10/2023 07:00 7.00 COMPZN, RPCOMP PULL P Continue to TOOH laying down 3.5" Completion. PUW = 56K, SOW = 56K. Pull SSSV through 7" casing patch clean. Recovered 19 SS bands and 1 clamp with pins. 6,747.0 2,537.0 7/10/2023 07:00 7/10/2023 10:00 3.00 COMPZN, RPCOMP PULL P Fixed hydraulic leak in Eckels. Cont. TOOH w/ remaining 3 1/2" completions to surface. Pulled 7 GLM's and 239 joints of 3 1/2" tubing. Cut Joint measured 20.26'. Welltec cut good. 180 deg around the cut had a slight flare. See pictures. 2,537.0 0.0 7/10/2023 10:00 7/10/2023 11:30 1.50 COMPZN, RPCOMP CLEN P Clean & Clear Rig floor. Unload Tbg from Pipe shed. Send out GLM's and Control line spooler. R/D Power Tongs. R/U Rig Tongs and Hyd. Spinners. 0.0 0.0 7/10/2023 11:30 7/10/2023 13:30 2.00 COMPZN, RPCOMP BHAH P PU/MU BHA #22. Baker WRBP with J- 20 pump out sub. Drifted 1 7/16" ball through pump out sub. Confirmed 1 13/16" dart fits in pump out sub profile. Drain Stack/Suck out to guide 5.968" OD WRBP into 7" casing. 0.0 23.0 7/10/2023 13:30 7/10/2023 21:30 8.00 COMPZN, RPCOMP TRIP P Single in BHA #22 (WRBP w/ J-20 Pump out Sub) on 3 1/2" Drill Pipe down to 7,625'. 23.0 5,600.0 7/10/2023 21:30 7/10/2023 22:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. 5,600.0 5,600.0 7/10/2023 22:00 7/11/2023 00:00 2.00 COMPZN, RPCOMP TRIP P Continue to Single in BHA #22 (WRBP w/ J-20 Pump out Sub) on 3 1/2" Drill Pipe down to 7,000'. 5,600.0 7,000.0 7/11/2023 00:00 7/11/2023 01:15 1.25 COMPZN, RPCOMP TRIP P Continue to Single in BHA #22 (WRBP w/ J-20 Pump out Sub) on 3 1/2" Drill Pipe down from 7000' to 7625' 7,000.0 7,625.0 7/11/2023 01:15 7/11/2023 02:15 1.00 COMPZN, RPCOMP MPSP P Drop 1-7/16" Ball and circulate at 2.5 BPM, 380 psi to set WRBP. Seen pressure spike to 3k, pulled 35k over sting weight and RBP set. 7,625.0 7,625.0 7/11/2023 02:15 7/11/2023 03:30 1.25 COMPZN, RPCOMP CIRC P Circulate well over to 8.5 PPG Seawater at 5.5 bpm, (271 bbls) 7,625.0 7,595.0 7/11/2023 03:30 7/11/2023 04:00 0.50 COMPZN, RPCOMP PRTS P PT and Chart WRBP to 2500 psi. Took approx. 2.7 bbls to pressure up. Perform 30 min NFT (drawdown on WRBP). 7,595.0 7,595.0 7/11/2023 04:00 7/11/2023 09:00 5.00 COMPZN, RPCOMP TRIP P TOOH f/7595' to BHA. Up Wt 144k. 7,595.0 23.0 7/11/2023 09:00 7/11/2023 09:15 0.25 COMPZN, RPCOMP BHAH P L/D BHA #22 (WRBP pump out sub + setting tool). 23.0 0.0 7/11/2023 09:15 7/11/2023 09:45 0.50 COMPZN, RPCOMP RURD P Clean and Clear rig floor. Prep for E- line operations. Spot in and RU Yellow Jacket E-line. 0.0 0.0 7/11/2023 09:45 7/11/2023 10:00 0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss E-line operations and risks. 0.0 0.0 7/11/2023 10:00 7/11/2023 10:15 0.25 COMPZN, RPCOMP ELOG P PU/MU CBL toolstring. Zero E-line depth at rig floor. 0.0 22.0 7/11/2023 10:15 7/11/2023 12:00 1.75 COMPZN, RPCOMP ELOG P RIH to 3,500'. Log from 3,500' to surface. 22.0 3,515.0 7/11/2023 12:00 7/11/2023 12:30 0.50 COMPZN, RPCOMP ELOG P L/D CBL toolstring. Download Data. Review data with Town Engineer. Identify TOC @ 2,150', w/ potential stringers up to 2,135'. Decide on 7" cut depth of 2,095' (collars at 2,079' and 2,116'). RD E-line and release. 3,515.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 18/38 2K-07 Report Printed: 8/10/2023 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) 7/11/2023 12:30 7/11/2023 12:45 0.25 COMPZN, RPCOMP BHAH P PU/MU BHA #23 (G-Plug). 0.0 13.4 7/11/2023 12:45 7/11/2023 15:00 2.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #23 (G-plug) to 2,330' (180' below 7" TOC). 13.4 2,330.0 7/11/2023 15:00 7/11/2023 17:30 2.50 COMPZN, RPCOMP MPSP P Set G-plug @ 2,330'. PT to 2,500 psi / 30 minPass. Volume used to test = 1 bbl. 2,330.0 2,330.0 7/11/2023 17:30 7/11/2023 18:30 1.00 COMPZN, RPCOMP TRIP P Rig down test equipment, PUH approx. 100' above G-Plug. Space out 3 1/2" connection close to rig floor. 2,330.0 2,230.0 7/11/2023 18:30 7/11/2023 21:30 3.00 COMPZN, RPCOMP RURD P RU sand hopper. Load 1200# of all purpose sand to rig floor. (20 bags, 60# bag) Many bags wet and clumping. Locate dry sand while continueing to dump. Recip pipe every three bags 2,230.0 2,230.0 7/11/2023 21:30 7/12/2023 00:00 2.50 COMPZN, RPCOMP OTHR P Recip pipe after 6 bags. Fluid coming over top of pipe. Monitor. Nor slowing down. Rig up and circulate surface to surface. All good. Continue dumping sand 2,230.0 2,230.0 7/12/2023 00:00 7/12/2023 05:30 5.50 COMPZN, RPCOMP CIRC P Dump 1,200# of sand down 3 1/2" DP through G-plug running tool. Wait 1 hour for sand to settle. Dry Tag TOS @ 2,275'. Process 7" casing while dumping sand (7" drift used was 6.17" OD). Found 14 joints of 7 5/8" casing mix in with 7" casing. 2,230.0 2,275.0 7/12/2023 05:30 7/12/2023 07:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ 3 1/2" DP and BHA #23 (G- plug setting tool). 2,275.0 13.0 7/12/2023 07:00 7/12/2023 07:30 0.50 COMPZN, RPCOMP BHAH P PU/MU BHA #24 (G-Plug). 13.0 13.0 7/12/2023 07:30 7/12/2023 08:00 0.50 COMPZN, RPCOMP TRIP P TIH w/ G-plug to 98'. 13.0 98.0 7/12/2023 08:00 7/12/2023 08:30 0.50 COMPZN, RPCOMP MPSP P Set G-plug @ 98'. 98.0 98.0 7/12/2023 08:30 7/12/2023 08:45 0.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #24. L/D same. 98.0 13.0 7/12/2023 08:45 7/12/2023 09:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #24. 13.0 0.0 7/12/2023 09:00 7/12/2023 10:30 1.50 COMPZN, RPCOMP MPSP P PT G-plug @ 98' to 250 / 3000 psi. 0.0 0.0 7/12/2023 10:30 7/12/2023 11:00 0.50 COMPZN, RPCOMP RURD P Clean and Clear rig floor. Prep for weekly BOP test. 0.0 0.0 7/12/2023 11:00 7/12/2023 11:30 0.50 COMPZN, RPCOMP BOPE P Flood lines and purge air from system. Perform weekly BOPE test (witness waived by Kam StJohn). Test BOP's to 250/3000 psi. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 19/38 2K-07 Report Printed: 8/10/2023 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) 7/12/2023 11:30 7/12/2023 19:30 8.00 COMPZN, RPCOMP BOPE P Weekly BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular w/ 3 ½ TJ, tested UVBR's w/ 3 ½ TJ, tested LPRs w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Conduct Accumulator Draw Down Test. Initial pressure=3000 PSI, after closure=1650 PSI, 200 PSI attained =24 sec, full recovery attained =115 sec. UVBR's= 4 sec, Annular= 13 sec. Simulated blinds= 4 sec. Simulated LPR's= 4 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1937 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam StJohn. 0.0 7/12/2023 19:30 7/12/2023 20:30 1.00 COMPZN, RPCOMP BHAH P R/D test eqipment. Make up BHA #24etrieve G plug set for BOPE test 0.0 13.5 7/12/2023 20:30 7/12/2023 21:00 0.50 COMPZN, RPCOMP TRIP P P/U single and one stand. set down @93''. PUH. Rotate into G plug. See it unlatch. RIH past set depth. POOH with G plug 13.5 0.0 7/12/2023 21:00 7/12/2023 21:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA #25 MSC 5.5" w/ DC 0.0 185.0 7/12/2023 21:30 7/12/2023 23:30 2.00 COMPZN, RPCOMP TRIP P Trip in hole to 2095'. 69K up 64K Dn.Locate collar on joint to be cut@ 2084. Trip in to locate next collar @ 2121'. PUH to 2095 185.0 2,095.0 7/12/2023 23:30 7/12/2023 23:42 0.20 COMPZN, RPCOMP OTHR P Start rotating 65 RPM. Bring pumps online 5 BPM @ 970 PSI. Indication of cut with 10 PSI pressure drop, 2K Tq drop. Ease down on tubing 2K 2,095.0 2,095.0 7/12/2023 23:42 7/13/2023 00:00 0.30 COMPZN, RPCOMP CIRC P Shut down pump & top drive. PUH to 2071'. R/U to circulate artic pack from well 2,095.0 2,071.0 7/13/2023 00:00 7/13/2023 02:30 2.50 COMPZN, RPCOMP CIRC P Start circulating to flush out artic pack. Well pressured right up to 980 PSI. Double check all valve alignment. Pressure uo to 1500 PSI. see pressure drop to 900PSI then drop to 450. Come online. Able to circulate. Pump 20 BBl slug of deep clean followed with 140 BBls of hot water. 140°. 4 BPM @ 1000PSI. Chase hot water with 80 BBls seawater 2,071.0 2,071.0 7/13/2023 02:30 7/13/2023 03:00 0.50 COMPZN, RPCOMP OWFF P Perform no flow test 2,071.0 2,071.0 7/13/2023 03:00 7/13/2023 03:15 0.25 COMPZN, RPCOMP TRIP P PUH 3 1/2" DP and cutter. 2,071.0 2,036.0 7/13/2023 03:15 7/13/2023 03:45 0.50 COMPZN, RPCOMP CIRC P Well out of balance, circ BU to balance. 2,036.0 2,036.0 7/13/2023 03:45 7/13/2023 06:00 2.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #25. 2,036.0 186.0 7/13/2023 06:00 7/13/2023 06:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #25. Stand back Drill Collars 186.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 20/38 2K-07 Report Printed: 8/10/2023 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) 7/13/2023 06:30 7/13/2023 06:45 0.25 COMPZN, RPCOMP RURD P Clean and Clear rig floor. Prep for pulling 7" casing. 0.0 0.0 7/13/2023 06:45 7/13/2023 07:30 0.75 COMPZN, RPCOMP OWFF P Bleed 7" and OA to 0 psi. OWFF for 30 minutes. RU 600 psi gauge to OA and monitor for 30 min to ensure OA is not charging through shallow leak. NFT passed. 0 psi with no build up after 30 min. 0.0 0.0 7/13/2023 07:30 7/13/2023 09:30 2.00 COMPZN, RPCOMP NUND P Drain Stack. ND BOPE. Pull Pack Off. 0.0 0.0 7/13/2023 09:30 7/13/2023 11:30 2.00 COMPZN, RPCOMP BHAH P MU BHA #26 (7" spear). TIH and spear 7" below wellhead. Pull tension. Pull 150K. Pipe appeared to be free. Weight dropped to 140K. Pulled slips. PU to confirm free. PUW = 115K. SOW = 75K. Snagged Top Drive link tilt hose on torque track. 0.0 9.0 7/13/2023 11:30 7/13/2023 13:00 1.50 COMPZN, RPCOMP NUND P NU BOPE. R/U GBR casing handling equipment. 9.0 9.0 7/13/2023 13:00 7/13/2023 13:30 0.50 COMPZN, RPCOMP SVRG P L/D Spear. Lower Top Drive and replace link tilt hydraulic fitting. 9.0 0.0 7/13/2023 13:30 7/13/2023 14:30 1.00 COMPZN, RPCOMP PULL P PU Spear. Engage 7" CSG and pull to rig floor. Set in slips. L/D BHA #26. Break out cut joint. 9.0 0.0 7/13/2023 14:30 7/13/2023 18:30 4.00 COMPZN, RPCOMP PULL P Pull 7" casing from cut @ 2,095' to surface. L/D 7" HYD563 to temporary casing patch. Begin laying down original 7" BTC casing. Have some difficulty breaking out original 7" BTC connections. Backup with rig tongs to get tight one free. 2,095.0 0.0 7/13/2023 18:30 7/13/2023 19:30 1.00 COMPZN, RPCOMP RURD P R/D GBR rig tongs, R/U running quipment. Offload remaining 7" from shed 0.0 0.0 7/13/2023 19:30 7/13/2023 20:00 0.50 COMPZN, RPCOMP WWWH P P/U BOP wash tool, Wash out stack, Lay down wash tool 0.0 0.0 7/13/2023 20:00 7/13/2023 21:30 1.50 COMPZN, RPCOMP MPSP P Make up and install 11" test tool. PT BOP flange break. 250/3000 PSI. Pull test plug. Set wear ring 0.0 0.0 7/13/2023 21:30 7/14/2023 00:00 2.50 COMPZN, RPCOMP BHAH P Load BHA into shed, M/U BHA #27 w/Bullnose, two 8.5" string reamers, Bumper sub, jars, and 6 DC's 0.0 221.7 7/14/2023 00:00 7/14/2023 02:30 2.50 COMPZN, RPCOMP TRIP P Trip in hole BHA #27 clean to 2,093'. Circ BU. Getting lots of arctic pack coming out. LEL alarm on BU. Circ 1.2 BU 221.7 2,093.0 7/14/2023 02:30 7/14/2023 03:30 1.00 COMPZN, RPCOMP TRIP P POOH F/2093 to surface, PUW=72K. Pulled 17 joints of 7" HYD563 temp tieback, 1 temp casing patch, 33 original 7" BTC, 11.39' cut joint, and 11 centralizer. 2,093.0 220.0 7/14/2023 03:30 7/14/2023 06:30 3.00 COMPZN, RPCOMP BHAH P At collars, Start laying down BHA #27 220.0 0.0 7/14/2023 06:30 7/14/2023 07:30 1.00 COMPZN, RPCOMP BHAH P PU/MU BHA #28 (8 3/8" x 7" Dress off Shoe). 0.0 218.0 7/14/2023 07:30 7/14/2023 10:30 3.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #28. Tag stub @ 2,095' PUH. Obtain dress off parameters. 4.5 BPM @ 270 psi. Free Torque = 4.5K ft- lbs. See arctic pack in returns. 218.0 2,095.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 21/38 2K-07 Report Printed: 8/10/2023 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) 7/14/2023 10:30 7/14/2023 13:00 2.50 COMPZN, RPCOMP MILL P Begin to dress off 7" casing. Total swallow = 7'. Stalled out after dressing to 2,097'. Saw slight cement mixed in with Arctic Pack in returns. Increase Top Drive torque to continue dressing off 7" stub. Dress off 7" casing from 2,095' to 2,102'. Est. new Top of 7" stub is at 2,096'. 2,095.0 2,102.0 7/14/2023 13:00 7/14/2023 14:30 1.50 COMPZN, RPCOMP CIRC P Circ bottoms up. Pump 15 bbl DeepClean pill. Chase with Seawater. Pumped two circulations to ensure 9 5/8" casing walls are clear of Arctic Pack. Spot in cementers and vac trucks. 2,102.0 2,102.0 7/14/2023 14:30 7/14/2023 16:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #28. 2,102.0 218.0 7/14/2023 16:00 7/14/2023 18:00 2.00 COMPZN, RPCOMP BHAH P L/D BHA #28. Pull wear ring. 218.0 0.0 7/14/2023 18:00 7/14/2023 18:30 0.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. Prep for 7" casing running operations. RU GBR. 0.0 0.0 7/14/2023 18:30 7/14/2023 19:00 0.50 COMPZN, RPCOMP LOT P Close blind rams. Pressure up 9 5/8" casing to 500 psi to confirm LLR. Estabish 1 BPM injection @ 180 PSI. Went 4 BBls then shut down. Pressure dropped right off. Consult town to see if they wanted to modify cement volumes. Run with current plan 0.0 0.0 7/14/2023 19:00 7/14/2023 20:00 1.00 COMPZN, RPCOMP RURD P R/U GBR Torque turn, Verify talley count, Verify centeralizer count, Function test GBR tongs, Install 563 X- O on floor valve 0.0 0.0 7/14/2023 20:00 7/15/2023 00:00 4.00 COMPZN, RPCOMP PUTB P TIH w/ 7" Tieback to 7" stub @ 2,061'. Prior to latching stub, PU space out pups and latch stub w/ full joint of 7" casing across BOP stack. SOW=80K, PUW=85K 0.0 2,160.0 7/15/2023 00:00 7/15/2023 00:30 0.50 COMPZN, RPCOMP WAIT T Wait on tool hand, Called @ 22:30 2,160.0 2,160.0 7/15/2023 00:30 7/15/2023 01:00 0.50 COMPZN, RPCOMP OTHR P TIH 2,061' to 2,097'. See bobble @ 2,095' appears to be seals going over stub. Set down 30K @ 2,097'. PUH to 30K over (150K). Latched up. Slack off. Pull 7" to 15K tension. 2,160.0 2,097.0 7/15/2023 01:00 7/15/2023 02:00 1.00 COMPZN, RPCOMP RURD P PJSM, R/D floor from casing running ops, Lay down GBR tongs and load out. PT lines from OA to OT tank and cuttings box to 2500 PSI 2,097.0 2,097.0 7/15/2023 02:00 7/15/2023 02:30 0.50 COMPZN, RPCOMP RURD P Inspect cement head. Load wiper in cement head. Install cement head. PT Cement lines to cement head. Open uphead to tubing. pump down tubing. Getting full returns out OA to OT tank. verified pressure chart from cement van. Pressures never over 350 PSI 2,097.0 2,097.0 7/15/2023 02:30 7/15/2023 03:00 0.50 COMPZN, RPCOMP OTHR P Consult town on plan forward. Plan to retrieve casing patch. Call out BOT and BR 2,097.0 2,097.0 7/15/2023 03:00 7/15/2023 05:30 2.50 COMPZN, RPCOMP RURD P Rig back cementers. Blow down all lines, P/U GBR tongs. Prep rig floor to lay down 7". Crew C/O. 2,097.0 2,097.0 7/15/2023 05:30 7/15/2023 10:30 5.00 COMPZN, RPCOMP PULL P Release casing patch overshot from 7" stub. TOOH w/ 7" tieback. L/D 7" joints. Inspect casing threads. 2,097.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 22/38 2K-07 Report Printed: 8/10/2023 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) 7/15/2023 10:30 7/15/2023 10:45 0.25 COMPZN, RPCOMP LOT P Close blinds and perform LOT (max press. 500 psi) of 9 5/8" casing to confirm prior LLR. 1 BPM @ 205 psi. Bleeds off quickly. 9 5/8" casing leak is not as tight as pre-rig. Arctic Pack may have been restricting flow through leak. 0.0 0.0 7/15/2023 10:45 7/15/2023 11:45 1.00 COMPZN, RPCOMP BHAH P Break out Casing Patch to inspect seals. ES Cementer was closed (pins not sheared). Found control packer seal was good, Packer lower seal was good, and Packer upper seal was cut/worn. Packer lower seal would have isolated 7" interal press. so it is likely the casing stub is damaged. Packer protector had slight damage but nothing that would impact pressure integrity. 0.0 0.0 7/15/2023 11:45 7/15/2023 14:00 2.25 COMPZN, RPCOMP SEQP P Call Town to discuss plan forward. Order tools from Baker in Deadhorse. Set 11" Test Plug. Close 7" lower pipe rams. Test lower pipe rams. Pass. Pull test plug. Set Wear Ring. Confirm flow path. Ensure kill line valves are closed. 0.0 0.0 7/15/2023 14:00 7/15/2023 18:30 4.50 COMPZN, RPCOMP WAIT T Send in GBR and Halliburton Cementers. Wait on 7" Grapple w/ Type A Packoff from Deadhorse. R/D GBR tongs. R/U Spinners and rig tongs, Bring in bumper sub and jars. Prep for DP run 0.0 0.0 7/15/2023 18:30 7/15/2023 20:00 1.50 COMPZN, RPCOMP BHAH P PU/MU BHA #29 (7" Grapple w/ Type A Packoff). 0.0 208.0 7/15/2023 20:00 7/15/2023 21:00 1.00 COMPZN, RPCOMP TRIP P TIH to 7" casing stub @ 2,096'. PUW=70K, SOW=66K. Swallow Stub. PU 30K over to confirm latched. 208.0 2,096.0 7/15/2023 21:00 7/15/2023 22:00 1.00 COMPZN, RPCOMP PRTS P Line up to pump down the 7" casing w/ lower pipe rams closed. Open annulas to OT tank. Pump down DP. Get returns from OH at 2 bbls pumped. Shut down consult town. Packoff on 7" not holding 2,096.0 2,099.0 7/15/2023 22:00 7/15/2023 23:00 1.00 COMPZN, RPCOMP TRIP P Release grapple from stub. Trip out with DP 2,099.0 208.0 7/15/2023 23:00 7/16/2023 00:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #28, Seals look good in packoff. were over stub 208.0 0.0 7/16/2023 00:00 7/16/2023 01:45 1.75 COMPZN, RPCOMP BHAH P M/U BHA #30 to mill 3' off 7 inch stub 0.0 218.5 7/16/2023 01:45 7/16/2023 02:45 1.00 COMPZN, RPCOMP TRIP P Trip in hole 3.5" stands T/ 2098' dry tag. . 218.5 2,098.0 7/16/2023 02:45 7/16/2023 05:45 3.00 COMPZN, RPCOMP MILL P PUH PUW=72K, SOW=66K, Bring pump 5 BPM /315PSI. Rotary @ 65 RPM. Start milling 7" @ 2096'. Dress off top 3' of 7" casing to 2,099'. Final dress off shoe depth @ 2,106' (7' of swallow). 2,098.0 2,106.0 7/16/2023 05:45 7/16/2023 06:30 0.75 COMPZN, RPCOMP CIRC P Circulate 2X bottoms up @ 5 BPM. 2,106.0 2,106.0 7/16/2023 06:30 7/16/2023 08:30 2.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #30. L/D Same. Inspect for wear/casing swallow tattle tail. 2,106.0 218.5 7/16/2023 08:30 7/16/2023 09:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #30. 218.5 0.0 7/16/2023 09:00 7/16/2023 09:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA #31 (8.50" RCJB) 0.0 215.0 7/16/2023 09:30 7/16/2023 11:00 1.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #31 to 2' (2097'). Drop 7/8" ball to activate RCJB. 215.0 2,097.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 23/38 2K-07 Report Printed: 8/10/2023 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) 7/16/2023 11:00 7/16/2023 13:00 2.00 COMPZN, RPCOMP CIRC P Kelly Up. Circulate 5 BPM @ 1945 psi to clean metal debris from 7" casing stub. Reciprocate pipe above top of stub. 2,097.0 2,097.0 7/16/2023 13:00 7/16/2023 14:30 1.50 COMPZN, RPCOMP TRIP P Come offline with pumps. Bleed off. TOOH w/ BHA #31 (RCJB) from 2,097'. 2,097.0 215.0 7/16/2023 14:30 7/16/2023 15:00 0.50 COMPZN, RPCOMP BHAH P L/D RCJB. Inspect for debris. Recovered 4" x 2" and 1.5" x 1" piece of metal. Recovered 15# of metal shavings and small amount of scale. 215.0 0.0 7/16/2023 15:00 7/16/2023 15:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #32 (Re-run of 8.50" RCJB). 0.0 215.0 7/16/2023 15:45 7/16/2023 16:30 0.75 COMPZN, RPCOMP TRIP P TIH w/ 8.50" RCJB to 2' above the 7" casing stub. 215.0 2,097.0 7/16/2023 16:30 7/16/2023 18:30 2.00 COMPZN, RPCOMP CIRC P Circulated Seawater @ 5 BPM, 1900 psi. Clean off top of 7" stub. 2,097.0 2,099.0 7/16/2023 18:30 7/16/2023 19:30 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #32. 2,099.0 215.0 7/16/2023 19:30 7/16/2023 20:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #32. Pull basket apart. No metal in tool. Prep - torque to run again if needed. 215.0 0.0 7/16/2023 20:30 7/16/2023 22:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA #33 (7" grapple w/ packoff). 0.0 208.0 7/16/2023 22:00 7/16/2023 23:00 1.00 COMPZN, RPCOMP PRTS P TIH w/ 7" grapple w/ packoff. Latch casing stub @ 2,099'. PU 50K over to confirm good latch. Line up down DP. Open OA to OT tank. Wll circulating with full returns. Pump 10 BBls @ 2 BPM. @ 80 PSI 208.0 2,101.0 7/16/2023 23:00 7/16/2023 23:30 0.50 COMPZN, RPCOMP RURD P Blow down lines to TT & top drive 2,101.0 2,101.0 7/16/2023 23:30 7/17/2023 00:00 0.50 COMPZN, RPCOMP TRIP P Rotate to disengauge OS. POOH, PUW=77K 2,101.0 1,000.0 7/17/2023 00:00 7/17/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Continue out of well BHA #33 1,000.0 208.0 7/17/2023 00:30 7/17/2023 02:30 2.00 COMPZN, RPCOMP BHAH P Lay down BHA #33 / M/U BHA #34 208.0 208.0 7/17/2023 02:30 7/17/2023 03:30 1.00 COMPZN, RPCOMP TRIP P Trip in BHA #34 to mill 3' of 7" stub 208.0 2,099.0 7/17/2023 03:30 7/17/2023 05:30 2.00 COMPZN, RPCOMP MILL P 2099', Start milling, 5 bpm @ 320 psi, rpm 77. Torque=3.3k PUW=70K, RIW=67K. Dress off 7" stub to 2,103'. 2,099.0 2,103.0 7/17/2023 05:30 7/17/2023 06:30 1.00 COMPZN, RPCOMP CIRC P Circ BU @ 5 BPM, 300 psi. 2,103.0 2,103.0 7/17/2023 06:30 7/17/2023 07:00 0.50 COMPZN, RPCOMP SVRG P Service Top Drive. Service spinners. Grease blocks, crown, TD, and Drawworks. 2,103.0 2,103.0 7/17/2023 07:00 7/17/2023 09:00 2.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #34 (Dress Off Shoe). L/D same. Inspect. 2,103.0 208.0 7/17/2023 09:00 7/17/2023 09:30 0.50 COMPZN, RPCOMP BHAH P L/D same. Inspect. 208.0 0.0 7/17/2023 09:30 7/17/2023 10:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #35 (RCJB). 0.0 215.0 7/17/2023 10:30 7/17/2023 12:30 2.00 COMPZN, RPCOMP TRIP P TIH w/ RCJB (7/8" ball on seat) to 2' above new 7" stub @ 2,103'. 215.0 2,101.0 7/17/2023 12:30 7/17/2023 13:30 1.00 COMPZN, RPCOMP CIRC P Bring pumps on at 5 BPM. Clean up top of fish. Pump 10 bbl Hi-Vis sweep to carry dress off debris to surface. Circ. 2 BU, chased Hi-Vis pill out. 2,101.0 2,101.0 7/17/2023 13:30 7/17/2023 15:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #35. 2,101.0 215.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 24/38 2K-07 Report Printed: 8/10/2023 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) 7/17/2023 15:00 7/17/2023 15:30 0.50 COMPZN, RPCOMP BHAH P L/D same. Inspect for debris. Recovered 5" x 2" piece of casing and 13# of metal shavings on ditch magnets. 215.0 0.0 7/17/2023 15:30 7/17/2023 15:45 0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss crane pick for GBR Power Tongs and tripping pipe hazards. 0.0 0.0 7/17/2023 15:45 7/17/2023 16:15 0.50 COMPZN, RPCOMP RURD P Crane on location. Pick GRB Power Tongs and set on rig floor. 0.0 0.0 7/17/2023 16:15 7/17/2023 17:00 0.75 COMPZN, RPCOMP BHAH P M/U BHA #36 (Re-Run of RCJB). 0.0 215.0 7/17/2023 17:00 7/17/2023 18:00 1.00 COMPZN, RPCOMP TRIP P Trip in RCJB to 2069, KU on stand 21 215.0 2,069.0 7/17/2023 18:00 7/17/2023 19:30 1.50 COMPZN, RPCOMP CIRC P Break circulation, 2.7 BPM @ 565PSI. Recip over stump. Circ 1.5X's BU @ 4 BPM until returns clean up 2,069.0 2,069.0 7/17/2023 19:30 7/17/2023 22:00 2.50 COMPZN, RPCOMP SLPC P Slip and Cut 67'' of Drill Line 2,069.0 2,000.0 7/17/2023 22:00 7/17/2023 22:30 0.50 COMPZN, RPCOMP SVRG P Lubricate / service rig 2,000.0 2,000.0 7/17/2023 22:30 7/17/2023 23:30 1.00 COMPZN, RPCOMP RGRP T Need replacement tourque wrench to tighten deadman properly. Get one from Nordic 4 2,000.0 2,000.0 7/17/2023 23:30 7/18/2023 00:00 0.50 COMPZN, RPCOMP TRIP P Trip out with RCJB, PUW=70K 2,000.0 1,736.0 7/18/2023 00:00 7/18/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Continue out of well with RCJB 1,736.0 208.0 7/18/2023 00:30 7/18/2023 02:00 1.50 COMPZN, RPCOMP BHAH P Lay down BHA #36, Break down basket. No material in it. 208.0 0.0 7/18/2023 02:00 7/18/2023 02:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #37, Overshot w/pack off 0.0 210.0 7/18/2023 02:30 7/18/2023 04:00 1.50 COMPZN, RPCOMP TRIP P Trip in BHA #37 to 2062 PUW=70K, SOW=66K, KU stand #21. RIH tag @ 2106, Top of stub 2103. PUH. No latch. RIH set down 2.5' high on 2 attempts. Rotate over stub @ 10 RPM. got back down to original set down. No latch on pick up. Roll pump and wash over stub. No pressure increase going over stub. Full returns. Try 3 more times to get latch. No good. Pull up. Blow down lines 210.0 2,103.0 7/18/2023 04:00 7/18/2023 05:00 1.00 COMPZN, RPCOMP TRIP P PJSM to trip out. Inspect pack off 2,103.0 0.0 7/18/2023 05:00 7/18/2023 06:30 1.50 COMPZN, RPCOMP BHAH P At surface. Fish in overshot. Unable to get fish out. Tool Hand take to Baker shop. 0.0 0.0 7/18/2023 06:30 7/18/2023 14:30 8.00 COMPZN, RPCOMP WAIT T Consult with town. Decision made to mobilize mill package and break apart fish to be examined at Baker. 0.0 0.0 7/18/2023 14:30 7/18/2023 15:45 1.25 COMPZN, RPCOMP RURD P Mobilize BHA # 38 tools to RF. 0.0 0.0 7/18/2023 15:45 7/18/2023 16:00 0.25 COMPZN, RPCOMP SFTY P PJSM of M/U BHA 0.0 0.0 7/18/2023 16:00 7/18/2023 18:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #38. 8 1/2" concave flat bottom mill w/ boot basket, 8 1/2" string mill, LBS, jars and 2 magnets T/ 252', SOW=48K. 0.0 252.0 7/18/2023 18:00 7/18/2023 19:45 1.75 COMPZN, RPCOMP TRIP P RIH F/ 252' T/ 2014', PUW=72K, SOW=69K. Wash down @ 5 BPM, 270 PSI, SOW=68K w/ pumps on Locate 7" stub @ 2105.5'. 5K string weight 252.0 2,105.5 7/18/2023 19:45 7/18/2023 21:15 1.50 COMPZN, RPCOMP MILL P Mill F/ 2105.5' T/ 2108' @ 5 BPM, 280 PSI, 80 RPM, 2.2K Free TQ, ROT=70K. 5-10K WOB, TQ=3--5K. Appeared to be milling on a solid top. 2,105.5 2,108.5 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 25/38 2K-07 Report Printed: 8/10/2023 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) 7/18/2023 21:15 7/19/2023 00:00 2.75 COMPZN, RPCOMP CIRC P PUH, Circ 1.5X BU with Hi Vis sweep. 3 PM with sweep @ 70 PSI. 5 BPM chasing @ 280 PSI Returns cleaned up 2,108.5 2,100.0 7/19/2023 00:00 7/19/2023 00:30 0.50 COMPZN, RPCOMP SFTY P Perform kick whil tripping drill. PJSM to trip pipe 2,100.0 2,100.0 7/19/2023 00:30 7/19/2023 01:30 1.00 COMPZN, RPCOMP TRIP P POOH BHA #38 2,100.0 201.0 7/19/2023 01:30 7/19/2023 03:00 1.50 COMPZN, RPCOMP BHAH P PJSM. Lay down BHA #38. Clean DH magnets 201.0 0.0 7/19/2023 03:00 7/19/2023 03:30 0.50 COMPZN, RPCOMP BHAH P PJSM, P/U BHA #39. 3" x 6" taper mill T/ 230' 0.0 230.0 7/19/2023 03:30 7/19/2023 05:00 1.50 COMPZN, RPCOMP TRIP P RIH F/ 230' T/ 2084', SOW=68K. 230.0 2,084.0 7/19/2023 05:00 7/19/2023 06:00 1.00 COMPZN, RPCOMP REAM P Wash in hole F/ 2084' @ 4 BPM, 225 PSI. Observed 2K drag as mill entered stub @ 2108.5'. ROT @ 65 RPM, Free TQ=2.2K. Worked through F/ 2100' T/ 2132' 3 times no drag observed. 2,084.0 2,116.0 7/19/2023 06:00 7/19/2023 07:30 1.50 COMPZN, RPCOMP TRIP P POOH F/ 2132' T/ 230', PUW=70K. 2,116.0 230.0 7/19/2023 07:30 7/19/2023 08:15 0.75 COMPZN, RPCOMP BHAH P L/D BHA #39. Clean off string magnets and empty boot baskets. 230.0 0.0 7/19/2023 08:15 7/19/2023 09:00 0.75 COMPZN, RPCOMP BHAH P M/U BHA #40 RCJB T/ 237', SOW=48K. 0.0 237.0 7/19/2023 09:00 7/19/2023 09:45 0.75 COMPZN, RPCOMP TRIP P RIH F/ 237' T/ 2105', PUW=70K, SOW=68K 237.0 2,105.0 7/19/2023 09:45 7/19/2023 11:30 1.75 COMPZN, RPCOMP CIRC P Circ @ 5 BPM, 1820 PSI. Pump 20 Bbls Hi-vis pill around. 2,105.0 2,105.0 7/19/2023 11:30 7/19/2023 11:45 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow 2,105.0 2,105.0 7/19/2023 11:45 7/19/2023 12:45 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2105' T/ 237', PUW=70K. 2,105.0 237.0 7/19/2023 12:45 7/19/2023 13:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #40 RCJB. No debris in basket minimal metal shavings on magnets. 237.0 0.0 7/19/2023 13:30 7/19/2023 14:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #41 Overshot w/ pack off T/ 226'. 0.0 226.0 7/19/2023 14:00 7/19/2023 15:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 226' tagged 7" stub hi @ 2105'. PUW=72K, SOW=68K 226.0 2,105.0 7/19/2023 15:00 7/19/2023 16:30 1.50 COMPZN, RPCOMP FISH P ROT @ 14 RPM, Free Tq = 1.8K. ROT=70K. Rotate over stub F/ 2105' T/ 2107' set down 30K. P/U T/ 100K bleed jars. P/U T/ 125K. Attempt to pressure test 7" with overshot w/ pack off. Pump at 1 BPM returns to surface. Pump @ 2 BPM 880 PSI, @ 3 BPM 1610 PSI. Work grapple up and down. Attempt to pressure test again with same results. Release F/ 7". L/D single T/ 2077', PUW=72K. 2,105.0 2,077.0 7/19/2023 16:30 7/19/2023 17:00 0.50 COMPZN, RPCOMP RURD P B/D circ equipment. 2,077.0 2,077.0 7/19/2023 17:00 7/19/2023 18:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2077' T/ 226', PUW=72K. 2,077.0 226.0 7/19/2023 18:00 7/19/2023 19:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #41 Overshot. Inspect cut lip and pack off. Small divet in cutlip guide. Seal tore, Grapple broken 226.0 0.0 7/19/2023 19:00 7/19/2023 20:00 1.00 COMPZN, RPCOMP RURD P PJSM, Run BOP swizzle stick, Jet stack in preperation for weeky BOPE test 0.0 0.0 7/19/2023 20:00 7/19/2023 21:30 1.50 COMPZN, RPCOMP RURD P Pull wear ring. Set 11 test plug in prep for BOPE test 0.0 0.0 7/19/2023 21:30 7/19/2023 22:30 1.00 COMPZN, RPCOMP RURD P PJSM R/U test equipment, M/U FOSV & Dart, Fill stack 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 26/38 2K-07 Report Printed: 8/10/2023 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) 7/19/2023 22:30 7/19/2023 22:45 0.25 COMPZN, RPCOMP BOPE T Start Weekly BOPE test. CMV #11 failed initial test. (Test #1) Greased and functioned valve. Passed retest. 0.0 7/19/2023 22:45 7/20/2023 00:00 1.25 COMPZN, RPCOMP BOPE P Start Weekly BOPE test. Perform Accumulator Draw Down Test while filling purging stack. Initial pressure=3050 PSI, after closure=1650 PSI. 200 PSI attained =22 sec, full recovery attained =131 sec. UVBR's= 6 sec, Annular= 13 sec. Simulated blinds= 7 sec. Simulated LPR's= 7 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1995 PSI. Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular & UVBR's w/ 3 ½ TJ, tested LPRs w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Witness waived by AOGCC rep Brian Bixby 0.0 7/20/2023 00:00 7/20/2023 07:00 7.00 COMPZN, RPCOMP BOPE P Continue BOPE at 250/3000 PSI for 5 Min each, Tested annular w/ 3 ½ TJ, tested UVBR's w/ 3 ½ TJ, tested LPRs w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Conduct Accumulator Draw Down Test. Initial pressure=3000 PSI, after closure=1650 PSI, 200 PSI attained =24 sec, full recovery attained =115 sec. UVBR's= 4 sec, Annular= 13 sec. Simulated blinds= 4 sec. Simulated LPR's= 4 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1937 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby 0.0 0.0 7/20/2023 07:00 7/20/2023 08:00 1.00 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 7/20/2023 08:00 7/20/2023 08:30 0.50 COMPZN, RPCOMP MPSP P Pull 11" test plug and intall wear busing. 0.0 0.0 7/20/2023 08:30 7/20/2023 09:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Baker and rig crew on M/U BHA. Verify BHA lengths. 0.0 0.0 7/20/2023 09:00 7/20/2023 11:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #42 sizing shoe and pilot mill T/ 236', SOW=45K. 0.0 236.0 7/20/2023 11:00 7/20/2023 12:30 1.50 COMPZN, RPCOMP TRIP P RIH F/ 236' T/ 2090', PUW=73K, SOW=69K. Kelly up and wash down @ 5 BPM, 260 PSI. S/O saw cut lip swallow 7" @ 2108.5'. Set down 5K @ 2111.5' w/ sizing shoe. P/U off bottom 10'. 236.0 2,101.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 27/38 2K-07 Report Printed: 8/10/2023 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) 7/20/2023 12:30 7/20/2023 13:00 0.50 COMPZN, RPCOMP MILL P Mill @ 5 BPM, 260 PSI. 65 RPM, Free Tq = 2.3K. ROT=70K. F/ 2108.5' T/ 2109', 5K WOB, 3-4K Tq. Sizing mill appears to have slid over 7" stub cleanly. 2,101.0 2,109.0 7/20/2023 13:00 7/20/2023 13:45 0.75 COMPZN, RPCOMP CIRC P P/U off bottom T/ 2106. Circ 20 Bbls hi- vis pill around @ 5 BPM, 260 PSI. Dump pill at surface. 2,109.0 2,106.0 7/20/2023 13:45 7/20/2023 14:15 0.50 COMPZN, RPCOMP RURD P L/D single T/ 2090', PUW=73K. B/D TD. 2,106.0 2,090.0 7/20/2023 14:15 7/20/2023 15:00 0.75 COMPZN, RPCOMP TRIP P POOH F/ 2090' T/ 236', PUW=73K. 2,090.0 236.0 7/20/2023 15:00 7/20/2023 16:15 1.25 COMPZN, RPCOMP BHAH P L/D BHA #42 sizing shoe and pilot mill F/ 236' T/ surface, PUW=45K. 236.0 0.0 7/20/2023 16:15 7/20/2023 17:30 1.25 COMPZN, RPCOMP BHAH P M/U BHA #43 Overshot w/ pack off T/ 230', SOW=45K 0.0 230.0 7/20/2023 17:30 7/20/2023 19:30 2.00 COMPZN, RPCOMP TRIP P Trip in BHA #43 230.0 2,001.0 7/20/2023 19:30 7/20/2023 20:30 1.00 COMPZN, RPCOMP PRTS P P/U Single, KU, PUW=70K SOW=66K Set down 2108.5. PUH to 100K. Latched upStage pumps up to 3 BPM. Flow at shaker. Pullmore tension, No Go. Set down more weight. Rotate to change seal spot. Work pipe and pump. No good. Lay down single 2,001.0 2,108.5 7/20/2023 20:30 7/20/2023 21:30 1.00 COMPZN, RPCOMP TRIP P PJSM, Trip out of well, PUW=70K 2,108.8 230.0 7/20/2023 21:30 7/20/2023 22:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA # 43. Clean magnets, Disassemble overshot. Seal in good condition, Grapple out. No marks on overshot 230.0 100.0 7/20/2023 22:00 7/20/2023 22:30 0.50 COMPZN, RPCOMP OTHR P Consult town. P/U 7" test packer 100.0 100.0 7/20/2023 22:30 7/20/2023 23:00 0.50 COMPZN, RPCOMP BHAH P Continue lay down BHA #43. Lay down jars and bumper sub. Lay down magnets. 100.0 0.0 7/20/2023 23:00 7/21/2023 00:00 1.00 COMPZN, RPCOMP TRIP P PJSM, P/U , BHA#44, 7" test packer, Trip in well 0.0 512.0 7/21/2023 00:00 7/21/2023 01:00 1.00 COMPZN, RPCOMP TRIP P Continue trip in hole, PUW=66K, SOW=64K 512.0 2,085.0 7/21/2023 01:00 7/21/2023 03:00 2.00 COMPZN, RPCOMP TRIP P K/U to stand 23. RIH clean through top of 7" down to 2156. Center of element 2150. Set test packer. Pressure up to 1200 with light bleed off, Minor flow at shaker. Repeat tests @ 2140, 2145, 2150. Test @ 2168. Best test yet with very slow bleed off. Attempt to test @ 2170. Unable to get packer to test 2,085.0 2,165.0 7/21/2023 03:00 7/21/2023 04:30 1.50 COMPZN, RPCOMP TRIP P PUH to 2080. K/D, Blow down top drive, Trip out of well 2,165.0 48.0 7/21/2023 04:30 7/21/2023 06:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #44 test packer. F/ 48' T/ surface. Inspect packer. Locked up w/ metal shavings. 48.0 0.0 7/21/2023 06:00 7/21/2023 07:30 1.50 COMPZN, RPCOMP BHAH P M/U BHA #45, mule shoe, boot baskets, magnets T/ 239', SOW=45K. 0.0 239.0 7/21/2023 07:30 7/21/2023 09:30 2.00 COMPZN, RPCOMP TRIP P RIH F/ 239' T/ 2200', PUW=71K, SOW=68K. Kelly up. 239.0 2,200.0 7/21/2023 09:30 7/21/2023 10:15 0.75 COMPZN, RPCOMP CIRC P Circ 26 Bbls hi-vis pill @ 7 BPM, 550 PSI. Overboard pill at surface. 2,200.0 2,200.0 7/21/2023 10:15 7/21/2023 10:45 0.50 COMPZN, RPCOMP RURD P L/D single, B/D TD. 2,200.0 2,182.0 7/21/2023 10:45 7/21/2023 11:45 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2182' T/ 239', PUW=71`K. 2,182.0 239.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 28/38 2K-07 Report Printed: 8/10/2023 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) 7/21/2023 11:45 7/21/2023 12:30 0.75 COMPZN, RPCOMP BHAH P L/D BHA #45. F/ 239' T/ surface. Clean magnets, heavy metal shavings and some wickers. Empty boot baskets metal shavings with arctic pack. 239.0 0.0 7/21/2023 12:30 7/21/2023 13:15 0.75 COMPZN, RPCOMP BHAH P Re run BHA #45 T/ 239', SOW-45K. 0.0 239.0 7/21/2023 13:15 7/21/2023 14:45 1.50 COMPZN, RPCOMP TRIP P RIH F/ 239' T/ 2200'. PUW=70K, SOW=68K. Kelly up. 239.0 2,200.0 7/21/2023 14:45 7/21/2023 15:30 0.75 COMPZN, RPCOMP CIRC P Circ 10 Bbls hi vis pill @ 7 BPM, 540 PSI. Overboard pill at surface. 2,200.0 2,200.0 7/21/2023 15:30 7/21/2023 16:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2183' T/ 239', PUW=70K. 2,183.0 239.0 7/21/2023 16:30 7/21/2023 17:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #45 F/ 239' T/ surface, PUW=45K. 239.0 0.0 7/21/2023 17:30 7/21/2023 18:00 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 7/21/2023 18:00 7/21/2023 18:30 0.50 COMPZN, RPCOMP BHAH P P/U BHA #46, 7" test packer 0.0 48.5 7/21/2023 18:30 7/21/2023 19:30 1.00 COMPZN, RPCOMP TRIP P Trip in hole F/48.5 to 2085, PUW=66, SOW=65 48.5 2,085.0 7/21/2023 19:30 7/21/2023 19:48 0.30 COMPZN, RPCOMP CIRC P Pump DP volume 2,085.0 2,085.0 7/21/2023 19:48 7/21/2023 20:12 0.40 COMPZN, RPCOMP TRIP P Continue in w/DP. Clease pass into 7" @2108.5 to 2156. Set test packer element @ 2150' Roll pump. 1070 PSI to 1050PSI / 10 minutes. No flow at sheakers 2,085.0 2,156.0 7/21/2023 20:12 7/21/2023 20:30 0.30 COMPZN, RPCOMP PRTS P PUH to 2140, PUW=70L. Set down on test packer. Pressure up to 1120. Bleed down to 1090 / 10 minutes No flow to shaker 2,156.0 2,140.0 7/21/2023 20:30 7/21/2023 20:48 0.30 COMPZN, RPCOMP PRTS P PUH to 2130. Set down on packer. 1040PSI to 1020PSI 10 min. No flow to shaker 2,140.0 2,130.0 7/21/2023 20:48 7/21/2023 21:06 0.30 COMPZN, RPCOMP PRTS P PUH to 2120. Set down on test packer, 1050 PSI to 1020 PSI 10 min. no flow to shaker 2,130.0 2,120.0 7/21/2023 21:06 7/21/2023 21:36 0.50 COMPZN, RPCOMP PRTS P PUH to 2115. 2109' COE. Pressure uo to 1030. @ 1000PSI 10 Min. 2,120.0 2,115.0 7/21/2023 21:36 7/21/2023 23:00 1.40 COMPZN, RPCOMP TRIP P PJSM, Blow down top drive / Trip out BHA 46 2,115.0 48.5 7/21/2023 23:00 7/22/2023 00:00 1.00 COMPZN, RPCOMP BHAH P Packer at surface. Clean. Lay down packer. Clear floor 48.5 0.0 7/22/2023 00:00 7/22/2023 00:30 0.50 COMPZN, RPCOMP BHAH P Complete laying down BHA #46 7" test packer, R/D floor. 0.0 0.0 7/22/2023 00:30 7/22/2023 01:30 1.00 COMPZN, RPCOMP SVRG P Perform weekly full derrick inspection, Load out BH tools, Organize pipe shed 0.0 0.0 7/22/2023 01:30 7/22/2023 02:42 1.20 COMPZN, RPCOMP BHAH P 7" casing patch on location, PJSM to load in pipe shed, PJSM Pick up BHA #47, Redressed casing patch. 0.0 41.7 7/22/2023 02:42 7/22/2023 03:00 0.30 COMPZN, RPCOMP TRIP P Trip in well, BHA #47 41.7 648.0 7/22/2023 03:00 7/22/2023 03:30 0.50 COMPZN, RPCOMP SFTY P New day crew, Welcome back meeting, PJSM to trip pipe 648.0 648.0 7/22/2023 03:30 7/22/2023 04:30 1.00 COMPZN, RPCOMP TRIP P Continue in well with casing patch 648.0 2,081.0 7/22/2023 04:30 7/22/2023 04:42 0.20 COMPZN, RPCOMP CIRC P CirculateDP volume before stabbing casing patch, 3.6 BPM @97 PSI, PUW=65K, SOW=65K 2,081.0 2,081.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 29/38 2K-07 Report Printed: 8/10/2023 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) 7/22/2023 04:42 7/22/2023 05:30 0.80 COMPZN, RPCOMP PRTS P Continue in well, See packing go over stub, Travel down to 2111, Set down 15K. PUH to 100K,35K over. Latched up. Set back down. PUH to 5K over. Roll pumps 1 BPM @ 45 PSI. Immediate returns. S/D pump. Get to neutral weight. Rotate 4 turns. Set back down. Roll pump. still have full by pass. Go to 3 BPM @ 495 PSI. returns matching pump rate. 2,081.0 2,111.0 7/22/2023 05:30 7/22/2023 06:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2111' T/ suface. 2,111.0 0.0 7/22/2023 06:30 7/22/2023 08:00 1.50 COMPZN, RPCOMP BHAH P Disassemble, inspect casing patch. Seals and grapple still in good condition. Reassamlbe. Make up BHA #47 run #2. 0.0 41.0 7/22/2023 08:00 7/22/2023 09:15 1.25 COMPZN, RPCOMP TRIP P RIH F/ 41' T 2081'. Kelly up. 41.0 2,081.0 7/22/2023 09:15 7/22/2023 10:00 0.75 COMPZN, RPCOMP CIRC P Establish circ rates @ 1 BPM = 40 PSI, 2 BPM = 40 PSI, 3 BPM = 57 PSI, 4 BPM= 122 PSI. PT surface equipment T/ 2500 PSI- Good test. 2,081.0 2,081.0 7/22/2023 10:00 7/22/2023 10:30 0.50 COMPZN, RPCOMP PRTS P Continue RIH, See patch go over stub, Travel down to 2111, S/O 20K. P/U T/ 35K over = 100K,. Latched up. Set back down. PUH to 5K over. Turn on charge pump, immediate retunes to surface. Stage pumps up @ 1 BPM = 40 PSI. @ 2 BPM = 140 PSI @ 3 BPM = 310 PSI @ 4 BPM = 500 PSI. Attempt to pull and push on patch w/ no change in pressures. Turn pumps off PSI bleed T/ 0 immediately . 2,081.0 2,111.0 7/22/2023 10:30 7/22/2023 11:00 0.50 COMPZN, RPCOMP RURD P Rack back stand T/ 2078', PUW=65. B/D TD. Consult w/ town, decision made to make another cut in 7" and inspect tubing stub top. 2,111.0 2,078.0 7/22/2023 11:00 7/22/2023 12:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2078' T/ 41', PUW=65K. 2,078.0 41.0 7/22/2023 12:00 7/22/2023 12:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #47 T/ surface. 41.0 0.0 7/22/2023 12:30 7/22/2023 13:15 0.75 COMPZN, RPCOMP BHAH P M/U BHA #48 5 1/2' x 7" mechanical cutter T/ 186', SOW=42K. 0.0 186.0 7/22/2023 13:15 7/22/2023 14:30 1.25 COMPZN, RPCOMP TRIP P RIH F/ 186' T/ 2109'. PUW=69K, SOW=67K. Tagged up on top of 7". Attempt to rotate in. Unsuccessful. 186.0 2,109.0 7/22/2023 14:30 7/22/2023 15:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2109' T/ 186' 2,109.0 186.0 7/22/2023 15:30 7/22/2023 16:15 0.75 COMPZN, RPCOMP BHAH P POOH w/ BHA #48. Add 3 1/2' mule shoe. RIH w/ BHA #48. 186.0 186.0 7/22/2023 16:15 7/22/2023 17:30 1.25 COMPZN, RPCOMP TRIP P RIH F/ 186' T/ 2125', PUW=69K, SOW=67K. Kelly up. 186.0 2,125.0 7/22/2023 17:30 7/22/2023 18:00 0.50 COMPZN, RPCOMP CPBO P Pump @ 2 BPM, 130 PSI. P/U T/ 2115'. S/O locate collar @ 2122', Shut pumps. P/U T/ 2114'. Cut 7" Rot @ 65 RPM, 2.3K Free Tq. Bring pumps on @ 5.2 BPM, 1000 PSI. ROT=65K. Pressure drop T/ 840 PSI when knifes extended indicating 7" is cut. Tq while cutting 3- 3.3K. 2,125.0 2,114.0 7/22/2023 18:00 7/22/2023 18:30 0.50 COMPZN, RPCOMP RURD P Rack back stand T/ 2040'. B/D TD. 2,114.0 2,040.0 7/22/2023 18:30 7/22/2023 19:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2040' T/ 186'. PUW=69K. 2,040.0 186.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 30/38 2K-07 Report Printed: 8/10/2023 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) 7/22/2023 19:30 7/22/2023 20:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #48 Cutter, Cutter blades in spec. 186.0 0.0 7/22/2023 20:30 7/22/2023 21:12 0.70 COMPZN, RPCOMP BHAH P Make up BHA #49 Spear to grab cut section. Hung up on wear ring going in. Shook pipe and popped through 0.0 40.2 7/22/2023 21:12 7/22/2023 22:12 1.00 COMPZN, RPCOMP TRIP P Trip in well, Hung up on wear ring going in. Shook pipe and popped through 40.2 2,086.0 7/22/2023 22:12 7/22/2023 22:30 0.30 COMPZN, RPCOMP FISH P 2086', KU, PUW=70K, SOW=69. Trip in, 2110 see grapple working in. 2112 set down 6K. PUH. Set back down @ 2112. No sign of grapple going in. 2,086.0 2,112.0 7/22/2023 22:30 7/23/2023 00:00 1.50 COMPZN, RPCOMP TRIP P PUH T/2086, KD, Blow down top drive. PJSM, Trip out, PUW=70K 2,112.0 2,086.0 7/23/2023 00:00 7/23/2023 01:00 1.00 COMPZN, RPCOMP BHAH P On surface. 7" fish in grapple. Remove fish from grapple. OAL=5.25' 2,086.0 0.0 7/23/2023 01:00 7/23/2023 04:00 3.00 COMPZN, RPCOMP WAIT P Hot shot dress off mill from BOT deadhorse 0.0 0.0 7/23/2023 04:00 7/23/2023 05:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #50 w/ wavy bottom smooth ID shoe & pilot mill, Bumper sub , Jars, magnets, and collars, 1.45' pilot mill, 2.45 to 7" mill. 0.0 235.2 7/23/2023 05:00 7/23/2023 06:45 1.75 COMPZN, RPCOMP TRIP P RIH F/ 235" T/ 2089', PUW=72K, SOW=68K. Kelly up. 235.0 2,089.0 7/23/2023 06:45 7/23/2023 09:30 2.75 COMPZN, RPCOMP MILL P RIH T/ 2113.78' tagged 7" top. Attempted to roll in w/ rotary - no go. P/U 2108'. Pump @ 3 BPM, 105 PSI. Rot @ 40 RPM, 2.1K Free Tq. ROT=70K. RIH jump over 7" top. Work in hole swallow T/ 2116.23'. Increase rotary T/ 65 RPM, 2.3K Free Tq. Mill F/ 2113.78' T/ 2114.38'. 10-15K WOB, On bottom Tq 3.5-4K. On bottom pump PSI=100-600 PSI. Cement returns at shakers. Worked wavy bottom smooth ID shoe on and off stub as cement cuttings increased pump pressure. 2,089.0 2,114.4 7/23/2023 09:30 7/23/2023 10:30 1.00 COMPZN, RPCOMP CIRC P Pump 21 Bbls hi vis pill on bottom. When pill cleared bit P/U T/ 2111'. Chase out of hole @ 7 BPM, 480 PSI. Overboard sweep at surface. 2,114.4 2,111.0 7/23/2023 10:30 7/23/2023 11:30 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2114' T/ 2087'. B/D TD. POOH F/ 2087' T/ 235', PUW=72K. 2,111.0 235.0 7/23/2023 11:30 7/23/2023 12:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #50 F/ 235' T/ surface. Metal on magnets. Wear on wavy bottom shoe from cement. 235.0 0.0 7/23/2023 12:30 7/23/2023 14:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA #51 7" patch w/ DC's, jars & lbs T/ 215', PUW=44K, SOW=44K. 0.0 215.0 7/23/2023 14:00 7/23/2023 14:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease crown, block, TD and draw works. 215.0 215.0 7/23/2023 14:30 7/23/2023 16:00 1.50 COMPZN, RPCOMP TRIP P RIH F/ 215' T/ 2069', PUW=71K, SOW=69K. Kelly up. S/O T/ 2117' w/ 20K S/O. 215.0 2,117.0 7/23/2023 16:00 7/23/2023 16:24 0.40 COMPZN, RPCOMP PRTS P PT 7". Pressure up T/1100 PSI bled T/ 850 in 10 Min. Pressure up T 2550 PSI bled T/ 2250 PSI in 25 Min. Bleed PSI off. 2,117.0 2,117.0 7/23/2023 16:24 7/23/2023 16:30 0.10 COMPZN, RPCOMP FISH P P/U on srting T/ 100K bleed jars. P/U T/ 125K. Rotate T/ the right release grapple, Blow down top drive. 2,117.0 2,110.0 7/23/2023 16:30 7/23/2023 17:30 1.00 COMPZN, RPCOMP TRIP P Trip out of well 2,110.0 214.0 7/23/2023 17:30 7/23/2023 18:00 0.50 COMPZN, RPCOMP BHAH P PJSM, Lay down BHA %51 Test casing patch overshot 214.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 31/38 2K-07 Report Printed: 8/10/2023 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) 7/23/2023 18:00 7/23/2023 19:00 1.00 COMPZN, RPCOMP RURD P PJSM, Pull wear ring 0.0 0.0 7/23/2023 19:00 7/23/2023 20:30 1.50 COMPZN, RPCOMP RURD P PJSM, R/U Hndleing equipment for 7" casing run, C/O elevators, R/D Spinners, Make up ES cemeter to casing patch. Lay down casing patch. R/D rig tongs. Function test GBR tongs 0.0 0.0 7/23/2023 20:30 7/24/2023 00:00 3.50 COMPZN, RPCOMP RURD T Unable to get tong torq turn system to deliver proper torq. Trouble shoot, C/O tongs. Still unable to get stem to deliver proper torq. 0.0 0.0 7/24/2023 00:00 7/24/2023 03:15 3.25 COMPZN, RPCOMP OTHR P Tongs operational, Run 7" tie back per tally, Kelly up. 0.0 2,110.0 7/24/2023 03:15 7/24/2023 03:30 0.25 COMPZN, RPCOMP CIRC P Circ tubing 85 BBls down 7" BPM @ 80 PSI 2,110.0 2,110.0 7/24/2023 03:30 7/24/2023 03:45 0.25 COMPZN, RPCOMP OTHR P RIH, See grapple go over stub @ 2115'. Set down @ 2116. Set down 20K, PUH to 137 K. 50K over. Line up to pump down tubing 2,110.0 2,116.0 7/24/2023 03:45 7/24/2023 04:15 0.50 COMPZN, RPCOMP PRTS P PT 7" to 2600 PSI. Bled down to 2540 30/min 2,116.0 2,116.0 7/24/2023 04:15 7/24/2023 04:45 0.50 COMPZN, RPCOMP RURD P R/D load out GBR casing tools / crew 2,116.0 2,116.0 7/24/2023 04:45 7/24/2023 05:15 0.50 COMPZN, RPCOMP SFTY P PJSM, Pump out stack. 2,116.0 2,116.0 7/24/2023 05:15 7/24/2023 07:15 2.00 COMPZN, RPCOMP NUND P Nipple down BOP 2,116.0 2,116.0 7/24/2023 07:15 7/24/2023 08:00 0.75 COMPZN, RPCOMP WWSP P Set C-21 11" x 7" emergency slips. P/U T/ 137K (50K tension). S/O and set emergency slips. 2,116.0 2,116.0 7/24/2023 08:00 7/24/2023 09:30 1.50 COMPZN, RPCOMP NUND P N/U BOP Spot & R/U HES cement tuck & head. 2,116.0 2,116.0 7/24/2023 09:30 7/24/2023 10:30 1.00 COMPZN, RPCOMP RURD P Suck out cuttings tank and spot contamination pill in cuttings tank, open top tank and pill pit. 2,116.0 2,116.0 7/24/2023 10:30 7/24/2023 11:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ HES cement crew and rig crew on cementing 7" to surface. 2,116.0 2,116.0 7/24/2023 11:00 7/24/2023 11:45 0.75 COMPZN, RPCOMP CIRC P HES flood cement hose to cement head. Shut in and PT T/ 4500 PSI. Good test. Open up and pressure up and open ES cementer @ 2900 PSI. verified returns to surface. Pump 159 Bbls 140* fresh water @ 4 BPM, 450 PSI. Good returns to surface. 2,116.0 2,116.0 7/24/2023 11:45 7/24/2023 12:45 1.00 COMPZN, RPCOMP CMNT P HES batch up & pump 20 Bbls 10.0 PPG spacer & 121 Bbls 15.3 PPG cement. Cement wet @ 12:15 Hrs. Pump cement @ 4 BPM, 550 PSI. Drop closing plug. Chase w/ 10 Bbls of fresh water. 2,116.0 2,116.0 7/24/2023 12:45 7/24/2023 13:15 0.50 COMPZN, RPCOMP DISP P D@ 5 BPM, 5.5 Bbls to catch plug ICP=450 PSI. 60 Bbls away 880 PSI w/ diminishing returns. Slowed pumps T/ 3 BPM lost returns completely ICP=714, FCP=765. Bump plug on time w/ 70.13 Bbls. Pressure up T/ 3000 PSI and held for 3 MIn. Highest recorded weight at surface 11.7 PPG. Cement in place @ 13:10 Hrs. 2,116.0 2,116.0 7/24/2023 13:15 7/24/2023 13:45 0.50 COMPZN, RPCOMP OWFF P OWFF - Bleed off open up verify no flow at surface. 2,116.0 2,116.0 7/24/2023 13:45 7/24/2023 14:15 0.50 COMPZN, RPCOMP RURD P R/D cement head. Wash up cement truck. 2,116.0 2,116.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 32/38 2K-07 Report Printed: 8/10/2023 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) 7/24/2023 14:15 7/24/2023 15:15 1.00 COMPZN, RPCOMP CLEN P B/D cement line and circ hose. Open LPR pump contamination pill through return lines. B/D return lines. 2,116.0 2,116.0 7/24/2023 15:15 7/24/2023 17:00 1.75 COMPZN, RPCOMP RURD P Remove equipment from pipe shed, 2,116.0 2,116.0 7/24/2023 17:00 7/24/2023 18:00 1.00 COMPZN, RPCOMP RURD P Vac out stack and 7". Nipple down choke and kill line. 2,116.0 2,116.0 7/24/2023 18:00 7/24/2023 19:30 1.50 COMPZN, RPCOMP NUND P PJSM, Split stack for 7" cut. Un Flange BOP from casing head. Remove TT hose. Remove stack tie downs. Lift stack, Remove mouse hole. . 2,116.0 2,116.0 7/24/2023 19:30 7/24/2023 21:30 2.00 COMPZN, RPCOMP RURD P Clean out casing head bowl, pull 6K on 7" for cut. R/U WHACHS cutter. Cut 7" casing with 6 inch stick up above casing flange. Pull cut to floor. 19.72' of Jt 50 2,116.0 0.0 7/24/2023 21:30 7/24/2023 22:30 1.00 COMPZN, RPCOMP NUND P ND DSA drop off. break off choke and kill line off stack. Rack back stack towards stump 0.0 0.0 7/24/2023 22:30 7/25/2023 00:00 1.50 COMPZN, RPCOMP WWSP P PJSM. Install 7" pack off, N/U tubing head 0.0 0.0 7/25/2023 00:00 7/25/2023 01:45 1.75 COMPZN, RPCOMP NUND P N/U new 7 1/16" 5K x 11" 3K tubing head. 0.0 0.0 7/25/2023 01:45 7/25/2023 02:00 0.25 COMPZN, RPCOMP PRTS P PT 7" casing void. 1000 PSI/10 minutes 0.0 0.0 7/25/2023 02:00 7/25/2023 08:00 6.00 COMPZN, RPCOMP NUND P N/U DSA, BOP, Install choke and kill lines. Install riser. Connect hole fill line. 0.0 0.0 7/25/2023 08:00 7/25/2023 08:30 0.50 COMPZN, RPCOMP RURD P Fill BOPE w/ fresh water. R/U testing equipment. 0.0 0.0 7/25/2023 08:30 7/25/2023 09:30 1.00 COMPZN, RPCOMP PRTS P PT BOP breaks, choke and kill breaks against blinds 250/3000 PSI for 5 Min each. Good test. 0.0 0.0 7/25/2023 09:30 7/25/2023 09:45 0.25 COMPZN, RPCOMP RURD P Drain BOPE. R/D testing equipment. 0.0 0.0 7/25/2023 09:45 7/25/2023 10:15 0.50 COMPZN, RPCOMP MPSP P Pull 7" test plug. Install 7" wear bushing. 6.375" ID., 0.0 0.0 7/25/2023 10:15 7/25/2023 11:15 1.00 COMPZN, RPCOMP RURD P Mobilize BHA #52 T/ pipe shed & RF. 0.0 0.0 7/25/2023 11:15 7/25/2023 11:30 0.25 COMPZN, RPCOMP SFTY P PJSM on picking up BHA 0.0 0.0 7/25/2023 11:30 7/25/2023 12:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #52 6 1/8" rolller cone & 6 1/2" string mill T/ 211', SOW=46K. 0.0 211.0 7/25/2023 12:30 7/25/2023 14:00 1.50 COMPZN, RPCOMP TRIP P RIH F/ 211' T/ 2060'', PUW=70K, SOW=65K. Tagged up on cement top. P/U T/ 1973' 211.0 1,973.0 7/25/2023 14:00 7/25/2023 14:15 0.25 COMPZN, RPCOMP DRLG P Wash & ream T/ 1973' T/ 2060' @ 5 BPM, 235 PSI. Rot @ 65 RPM, Free Tq = 2.4K. ROT=67K. Drill cement F/ 2060' T/ 2066', 2-3K WOB, 2-27K Tq. 1,973.0 2,066.0 7/25/2023 14:15 7/25/2023 14:30 0.25 COMPZN, RPCOMP CIRC P Circ BU @ 5 BPM, 235 PSI. 2,066.0 2,066.0 7/25/2023 14:30 7/25/2023 15:00 0.50 COMPZN, RPCOMP SVRG P Circ @ 2 BPM, 70 PSI. Change shaker screen. 2,066.0 2,066.0 7/25/2023 15:00 7/25/2023 21:30 6.50 COMPZN, RPCOMP DRLG P Dill F/ 2060' T/ 2091' found plug cont T/2204' @ 4 BPM, 185 PSI, Rot @ 65 RPM, Free Tq = 2.4K, ROT=65K. 8-10K WOB, 2-3K Tq. Seen Drilling break at 2200' and 2204'. Continue to work Mill down to 2248'. 2,066.0 2,248.0 7/25/2023 21:30 7/25/2023 21:45 0.25 COMPZN, RPCOMP REAM P Back Ream through area Drilled f/2248' t/2158' at 70 RPM, 4 BPM, 255 psi, Up Wt 67K. 2,248.0 2,158.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 33/38 2K-07 Report Printed: 8/10/2023 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) 7/25/2023 21:45 7/25/2023 22:15 0.50 COMPZN, RPCOMP DRLG P Continue to work Mill f/ 2248' to top of sand at 2275'. 70 RPM, 4 BPM, 235 PSI. 2,158.0 2,275.0 7/25/2023 22:15 7/25/2023 23:30 1.25 COMPZN, RPCOMP CIRC P PUH 10' to 2265' and Circulate 20 bbls High Vis Sweep to clean up wellbore. Blow down Top Drive. 2,275.0 2,265.0 7/25/2023 23:30 7/26/2023 00:00 0.50 COMPZN, RPCOMP TRIP P TOOH standing back DP. 2,265.0 1,425.0 7/26/2023 00:00 7/26/2023 01:15 1.25 COMPZN, RPCOMP TRIP P Continue TOOH standing back DP. 1,425.0 211.0 7/26/2023 01:15 7/26/2023 02:15 1.00 COMPZN, RPCOMP BHAH P L/D BHA #52. 211.0 0.0 7/26/2023 02:15 7/26/2023 03:45 1.50 COMPZN, RPCOMP PRTS P RU Testing Equipment. PT 7" CSG to 2500 psi for 30 mins. MIT-OA to 500 psi for 30 mins. Estimated top of cement at or near surface. R/D Testing Equipment. Blow down Top Drive. 0.0 0.0 7/26/2023 03:45 7/26/2023 04:45 1.00 COMPZN, RPCOMP BHAH P MU BHA #53. 6-1/8" Concave Mill with 4 -3/4" x 2 Boot Baskets, 5-7/8" x 2 Strings Magnets, 4-3/4" Jars with 6- 4- 3/4" DP. 0.0 240.0 7/26/2023 04:45 7/26/2023 06:00 1.25 COMPZN, RPCOMP TRIP P TIH w/BHA #53. F/ 240' T/ 2275', PUW=70K, SOW=70K. Tag sand top. 240.0 2,275.0 7/26/2023 06:00 7/26/2023 07:00 1.00 COMPZN, RPCOMP MILL P Beet down on sand top setting 10-12K sting weight down on sand top. Pick up and repeat. Dry drill @ 65 RPM, ROT=69K. Free Tq = 2K. WOB=10K, 6 -7K Tq. Turn on pumps @ 5 BPM, 425 PSI. Drill down T/ 2300', WOB 3-6K. 3- 3.5K Tq. 2,275.0 2,300.0 7/26/2023 07:00 7/26/2023 08:15 1.25 COMPZN, RPCOMP CIRC P Circ 3x BUS @ 6 BPM, 615 PSI, ROT @ 7 RPM, Free torque 1.8K. P/U T/ 2995', Pump 20 Bbls High-Vis pill around. Sand seen at shakers. Overboard pill at surface. 2,300.0 2,295.0 7/26/2023 08:15 7/26/2023 08:45 0.50 COMPZN, RPCOMP RURD P Rack back stant T/ 2280'. B/D TD 2,295.0 2,280.0 7/26/2023 08:45 7/26/2023 09:45 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2280' T/ 240', PUW=70K. 2,280.0 240.0 7/26/2023 09:45 7/26/2023 11:15 1.50 COMPZN, RPCOMP BHAH P L/D BHA #53. F/ 240' T/ surface. Large chunks of metal and shavings on magnets. Some large metal and aluminum in boot baskets. 240.0 0.0 7/26/2023 11:15 7/26/2023 12:30 1.25 COMPZN, RPCOMP BHAH P M/U BHA #54 RCJB. T/ 246', SOW=48K. 0.0 246.0 7/26/2023 12:30 7/26/2023 13:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 246' T/ 2188', PUW=70K, SOW=66K. 246.0 2,188.0 7/26/2023 13:30 7/26/2023 14:00 0.50 COMPZN, RPCOMP SFTY P PJSM on slip and cut drill line. 2,188.0 2,188.0 7/26/2023 14:00 7/26/2023 16:00 2.00 COMPZN, RPCOMP CUTP P Cut & slip 66' drill line. 2,188.0 2,181.0 7/26/2023 16:00 7/26/2023 17:15 1.25 COMPZN, RPCOMP MILL P RIH F/ 2181' T/ 2304'. Dry tag sand top. Pump @ 6 BPM,, 780 PSI. Rot @ 45 RPM, Free Tq = 2.2K. ROT=70K. Wash sand out through RCJB F/ 2304' T/ 2315'. WOB=3K, 3-4K Tq. 2,181.0 2,315.0 7/26/2023 17:15 7/26/2023 18:15 1.00 COMPZN, RPCOMP CIRC P P/U T/ 2305'. Pump BU @ 6 BPM, 780 PSI. Pump 20 Bbls of High-Vis pill around. Overboard pill at surface. 2,315.0 2,315.0 7/26/2023 18:15 7/26/2023 19:30 1.25 COMPZN, RPCOMP TRIP P TOOH standback DP. 2,315.0 246.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 34/38 2K-07 Report Printed: 8/10/2023 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) 7/26/2023 19:30 7/26/2023 20:30 1.00 COMPZN, RPCOMP BHAH P Clean BHA. More chunks of metal and shavings on magnets. Some large metal and aluminum in boot baskets. 246.0 0.0 7/26/2023 20:30 7/26/2023 21:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #55 RCJB. T/ 246'. 0.0 246.0 7/26/2023 21:30 7/26/2023 22:00 0.50 COMPZN, RPCOMP TRIP P RIH F/ 246' T/ 570'. 246.0 570.0 7/26/2023 22:00 7/26/2023 23:00 1.00 COMPZN, RPCOMP SVRG P Rig Service 570.0 570.0 7/26/2023 23:00 7/27/2023 00:00 1.00 COMPZN, RPCOMP RGRP T Trouble shoot top drive issue. 570.0 570.0 7/27/2023 00:00 7/27/2023 01:00 1.00 COMPZN, RPCOMP TRIP P Continue to TIH w/ BHA #55 from 570' to 2275'. 570.0 2,275.0 7/27/2023 01:00 7/27/2023 02:45 1.75 COMPZN, RPCOMP CIRC P Pump @ 5 BPM, 930 PSI. Rot @ 10 RPM, Wash sand out through RCJB F/ 2275' T/ 2322'. WOB=3K, 3-4K Tq. P/U T/ 2320'. Pump BU @ 5 BPM, 920 PSI. Pump 20 Bbls of High-Vis pill around. 2,275.0 2,322.0 7/27/2023 02:45 7/27/2023 03:45 1.00 COMPZN, RPCOMP TRIP P POOH F/ 2320' T/ 246', PUW=68K. 2,322.0 246.0 7/27/2023 03:45 7/27/2023 05:15 1.50 COMPZN, RPCOMP BHAH P Stand Back Drill Collars and L/D BHA #55. Recovered Minimum amount of Metal and Aluminum in boot baskets and Magnet 246.0 0.0 7/27/2023 05:15 7/27/2023 06:00 0.75 COMPZN, RPCOMP CLEN P Function rams and jet BOP stack. 0.0 0.0 7/27/2023 06:00 7/27/2023 07:00 1.00 COMPZN, RPCOMP MPSP P Pull Wear Bushing and Install Test Plug. 0.0 0.0 7/27/2023 07:00 7/27/2023 09:15 2.25 COMPZN, RPCOMP NUND P Change LPR F/ 7" T/ VBR's 2 7/8" x 5 1/2". Rig up testing equipment. 0.0 0.0 7/27/2023 09:15 7/27/2023 09:30 0.25 COMPZN, RPCOMP SFTY P PJSM on testing BOPE. 0.0 0.0 7/27/2023 09:30 7/27/2023 10:30 1.00 COMPZN, RPCOMP PRTS P Attempt shell test on BOPE. Leak on test spool valve. Grease and service valves. 0.0 0.0 7/27/2023 10:30 7/27/2023 15:30 5.00 COMPZN, RPCOMP BOPE P Weekly BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1600 PSI, 200 PSI attained =23 sec, full recovery attained =132 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 17 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sean Sullivan. 0.0 0.0 7/27/2023 15:30 7/27/2023 16:30 1.00 COMPZN, RPCOMP RURD P Suck out stack. B/D, R/D testing equipment. 0.0 0.0 7/27/2023 16:30 7/27/2023 18:30 2.00 COMPZN, RPCOMP BHAH P Mobilize Baker Rep. PJSM. P/U BHA #56. G-Plug removal tools. 0.0 216.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 35/38 2K-07 Report Printed: 8/10/2023 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) 7/27/2023 18:30 7/27/2023 19:30 1.00 COMPZN, RPCOMP TRIP P TIH f/216' t/2323'. Up Wt 70K / Dn Wt 65K. 216.0 2,323.0 7/27/2023 19:30 7/27/2023 21:15 1.75 COMPZN, RPCOMP WASH P PJSM. Establish Parameters. Start washing down f/2323' t/ 2328', circulating at 5 bpm, 325 psi. Circulate 35 bbls Hi-Vis Sweep, chase with seawater @ 8 bpm, 900 psi SPP until clean seawater is seen at surface. Total seawater pumped 115 bbls. 2,323.0 2,328.0 7/27/2023 21:15 7/27/2023 21:45 0.50 COMPZN, RPCOMP MPSP P Engage G-Plug. Pulled xx# and release plug. 2,328.0 2,329.0 7/27/2023 21:45 7/27/2023 23:00 1.25 COMPZN, RPCOMP TRIP P TOOH with G-Plug standing back DP. 2,329.0 216.0 7/27/2023 23:00 7/28/2023 00:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #56 and G-Plug. 216.0 0.0 7/28/2023 00:00 7/28/2023 00:45 0.75 COMPZN, RPCOMP BHAH P MU BHA #57, Model "M" Retrieval Head an 2 String Magnets. 0.0 26.0 7/28/2023 00:45 7/28/2023 05:30 4.75 COMPZN, RPCOMP TRIP P TIH w/BHA #57 to 7606' 26.0 7,606.0 7/28/2023 05:30 7/28/2023 07:00 1.50 COMPZN, RPCOMP CIRC P Displace well over to 10.8 PPG KWF at 6 bpm, ICP=1650, FCP=2495. Pump total of 423 Bbls. Taking returns out to the open top. 7,606.0 7,606.0 7/28/2023 07:00 7/28/2023 07:30 0.50 COMPZN, RPCOMP OWFF P OWFF - No flow. 7,606.0 7,606.0 7/28/2023 07:30 7/28/2023 07:45 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 7,606.0 7,606.0 7/28/2023 07:45 7/28/2023 09:00 1.25 COMPZN, RPCOMP PRTS P PT 7" CSG to 2500 psi for 5 mins. 7,606.0 7,606.0 7/28/2023 09:00 7/28/2023 10:30 1.50 COMPZN, RPCOMP MPSP P PUW140-145K (weight swings) SOW=98K. RIH F/ 7606' Engage WRBP @ 7623'. S/O 20K plug appeared to shear down. Equalize pressure. OWFF on TT for 10 Min- No flow. Stage P/U saw plug appeared to shear up @ 170K. P/U T/ 7597'. OWFF on TT for 15 Min - No flow. RIH - unable to run down past set depth. Indication plug is released on up stroke. Decision made to POOH. 7,606.0 7,597.0 7/28/2023 10:30 7/28/2023 11:00 0.50 COMPZN, RPCOMP OWFF P Rack stand back T/ 7532''. B/D TD. 7,597.0 7,532.0 7/28/2023 11:00 7/28/2023 15:30 4.50 COMPZN, RPCOMP TRIP P TOOH F/ 7523' T/ 26'. PUW=140-145K 7,523.0 26.0 7/28/2023 15:30 7/28/2023 17:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #57. F/ 26' T/ surface. Metal shavings on magnets. No plug recovered. Inspect retrieval tool. Colette in good condition packed of w/ what appeared to be scale and metal. 26.0 0.0 7/28/2023 17:00 7/28/2023 18:00 1.00 COMPZN, RPCOMP SVRG P Rig Service. Made repairs to TD 0.0 0.0 7/28/2023 18:00 7/28/2023 18:30 0.50 COMPZN, RPCOMP RGRP T Trouble shoot top drive pipe handler lock. 0.0 0.0 7/28/2023 18:30 7/28/2023 19:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #58 WRBP model M retrieval tool & 2 string magnets. 26.0 26.0 7/28/2023 19:00 7/29/2023 00:00 5.00 COMPZN, RPCOMP TRIP P TIH w/BHA #58, WRBP retrieval tool. 26.0 7,617.0 7/29/2023 00:00 7/29/2023 00:30 0.50 COMPZN, RPCOMP SFTY P PJSM on Circulating on top of WRBP. 7,617.0 7,617.0 7/29/2023 00:30 7/29/2023 00:45 0.25 COMPZN, RPCOMP TRIP P Up Wt 150K / Dn Wt 95K. TIH just above WRBP to 7621' 7,617.0 7,621.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 36/38 2K-07 Report Printed: 8/10/2023 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) 7/29/2023 00:45 7/29/2023 02:00 1.25 COMPZN, RPCOMP CIRC P Start circulating 30 bbl Hi-Vis Sweep at 6 BPM, 1235 psi, washing across WRBP. 7,621.0 7,623.0 7/29/2023 02:00 7/29/2023 03:00 1.00 COMPZN, RPCOMP FISH P Engaged WRBP at 7625' never seen good indication that we could latch or shear the WRBP. Tried Rotating, pumping and stacking addition weight down to get latched. No Success. 7,621.0 7,625.0 7/29/2023 03:00 7/29/2023 08:00 5.00 COMPZN, RPCOMP TRIP P Blow down top drive. L/D working joint. POOH F/ 7625' T/ 26', PUW=140-145K. 7,625.0 26.0 7/29/2023 08:00 7/29/2023 09:15 1.25 COMPZN, RPCOMP BHAH P L/D BHA #58. Metal on magnets. Recovered releasing sleeve and top nut in retrieval tool. 26.0 0.0 7/29/2023 09:15 7/29/2023 10:30 1.25 COMPZN, RPCOMP BHAH P M/U BHA #59 _5 3/4" overshot w/ 2.125" grapple & 2 string magnets, jars & llbs. T/ 228', SOW=45K. 0.0 228.0 7/29/2023 10:30 7/29/2023 14:45 4.25 COMPZN, RPCOMP TRIP P RIH F/ 228' T/ 7554', PUW=155K, SOW=98K. 228.0 7,554.0 7/29/2023 14:45 7/29/2023 15:45 1.00 COMPZN, RPCOMP FISH P RIH tag WRBP 7625'. Set 10-30K down. P/U @ 160K lost weight. Re tag w/ pumps on @ 5 BPM, 1260 PSI. P/U - same results. Rotate over fish neck @ 15 RPM, 1.8K Free Tq. Kill rotation. P/U - same results. Decion made to POOH and inspect grapple. 7,554.0 7,625.0 7/29/2023 15:45 7/29/2023 16:00 0.25 COMPZN, RPCOMP RURD P Rack stand back T/ 7551'. B/D TD. 7,625.0 7,551.0 7/29/2023 16:00 7/29/2023 20:15 4.25 COMPZN, RPCOMP TRIP P POOH F/ 7551' T/ 228', PUW 155K. Seen 30K overpull at 6444' 25K @ 4086' 20K @ 4219'. 7,551.0 228.0 7/29/2023 20:15 7/29/2023 21:15 1.00 COMPZN, RPCOMP BHAH P Stand Back Drill Collars. L/D BHA #59. Metal on magnets. L/D Bent WRBP. 228.0 0.0 7/29/2023 21:15 7/29/2023 22:00 0.75 COMPZN, RPCOMP BHAH P MU BHA #60. 3.5" Sizing Mill and 2.875" Inner Mill 0.0 237.5 7/29/2023 22:00 7/30/2023 00:00 2.00 COMPZN, RPCOMP TRIP P TIH w/BHA #60 237.5 4,000.0 7/30/2023 00:00 7/30/2023 01:30 1.50 COMPZN, RPCOMP TRIP P Continue to TIH with BHA #60 to top of 3.5" TBG stub. Tagged at 7633' w/10K down. Up Wt 152K / S/O Wt 95K 4,000.0 7,633.0 7/30/2023 01:30 7/30/2023 02:00 0.50 COMPZN, RPCOMP SVRG P Rig Service 7,633.0 7,633.0 7/30/2023 02:00 7/30/2023 03:45 1.75 COMPZN, RPCOMP REAM P Ream down f/7633 t/7654' @ 65 RPM, Pumping at 5 BPM, 1600 psi. Pick up 5' to P/U another working joint. RIH and Dry Tagged at 7655' with 20K down. Pick up to 7644' and started Ream back down to tag depth, rotating at 65 RPM, Pumping at 5 bpm, 1680 psi. Pressure increased to 2500 to 2800 psi at 7655' while reaming on top of TBG stub. PUH reaming f/7655' t/7644' and pressure drop down to 1700 psi. Good indication we were on top of TBG stub with dress off Assy. Top of Tubing stub 7649'. Repeat process twice more to confirm top of TBG stub. 7,633.0 7,654.0 7/30/2023 03:45 7/30/2023 05:00 1.25 COMPZN, RPCOMP CIRC P Park at 7,644' and circulate 24 bbl Hi- Vis Sweep at 5 bpm, 1880 psi. Chase sweep with 10.8 PPG KWF. 7,654.0 7,644.0 7/30/2023 05:00 7/30/2023 09:00 4.00 COMPZN, RPCOMP SLPC P Slip & Cut Drilling Line. 7,644.0 7,400.0 7/30/2023 09:00 7/30/2023 15:00 6.00 COMPZN, RPCOMP PULD P LDDP F/ 7400' T/ 237', PUW=152K. 7,400.0 237.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 37/38 2K-07 Report Printed: 8/10/2023 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) 7/30/2023 15:00 7/30/2023 17:00 2.00 COMPZN, RPCOMP BHAH P L/D BHA #60 F/ 237' T/ surface, PUW=45K. 237.0 0.0 7/30/2023 17:00 7/30/2023 18:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear RF and pipe shed. 0.0 0.0 7/30/2023 18:00 7/30/2023 19:00 1.00 COMPZN, RPCOMP RURD P C/O Handling equipment. RU Eckel and function test same. Verify joint count and jewelry running order. Bring hanger T/ RF. 0.0 0.0 7/30/2023 19:00 7/30/2023 19:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ SLB packer Rep and rig crew on running completion. 0.0 0.0 7/30/2023 19:15 7/31/2023 00:00 4.75 COMPZN, RPCOMP PUTB P MU and TIH with 3.5" Completion per- tally. 0.0 3,230.0 7/31/2023 00:00 7/31/2023 01:30 1.50 COMPZN, RPCOMP PUTB P Continue TIH f/3230' to target depth. 3,230.0 4,110.0 7/31/2023 01:30 7/31/2023 02:00 0.50 COMPZN, RPCOMP SVRG P Rig Service on Hydraulic Manifold failure under pipe skate. Reported 1 gallon Hydraulic leak into secondary containment from manifold failure. 4,110.0 4,110.0 7/31/2023 02:00 7/31/2023 08:00 6.00 COMPZN, RPCOMP PUTB P Continue to TIH f/4110' T/ 7637'. PUW=95K, SOW=75K. Kelly up. Pump @ 3 BPM, 250 PSI. RIH saw pressure increase to 365 PSI @ 6753'. Turn off pumps. RIH saw shear pins shear 12K @ 7657'. RIH fully located 7660.5'. P/U 2' and mark pipe @ 7658.5'. 4,110.0 7,658.0 7/31/2023 08:00 7/31/2023 10:00 2.00 COMPZN, RPCOMP PUTB P L/D joints #241, #240, & #239. Install space our pups 2.06', 2.05', 10.15' & 10.17'. M/U joint #239. P/U landing joint and M/U to hanger. Make up hanger to string. Kelly up. 7,658.0 7,628.0 7/31/2023 10:00 7/31/2023 11:30 1.50 COMPZN, RPCOMP CRIH P Pump 200 Bbls CI 10.8 PPG brine, chased w/ 13 Bbls 10.8 PPG brine @ 3 BPM, 230 PSI. 7,628.0 7,628.0 7/31/2023 11:30 7/31/2023 12:00 0.50 COMPZN, RPCOMP HOSO P RIH and land tubing hanger w/ bottom of overshot @ 7664.02' ORKB. 1.88' F/ fully located. RILDS 7,628.0 7,664.0 7/31/2023 12:00 7/31/2023 13:30 1.50 COMPZN, RPCOMP RURD P Break out and B/D TD. Drop ball and rod. R/U testing equipment T/ TBG & IA. 7,664.0 7,664.0 7/31/2023 13:30 7/31/2023 14:15 0.75 COMPZN, RPCOMP PACK P Stage pumps up in 500 PSI increments and hold for 1 Min T/ 4500 PSI & hold for 30 Min to set SLB Bluepack Max Packer. 7,664.0 7,664.0 7/31/2023 14:15 7/31/2023 17:00 2.75 COMPZN, RPCOMP PRTS T Attempt to PT tubing & IA. Failed surface valves. Changed out isolation vlaves. 7,664.0 7,664.0 7/31/2023 17:00 7/31/2023 18:30 1.50 COMPZN, RPCOMP PRTS P PT tubing T/ 3000 PSI for 30 Min. PT IA to 2500 PSi for Mins. Dump Tubing Pressure to shear SOV. 7,664.0 7,664.0 7/31/2023 18:30 7/31/2023 18:45 0.25 COMPZN, RPCOMP CIRC P Circulate @ 2 BPM, 265 PSI to confirm SOV is Sheared. 7,664.0 7,664.0 7/31/2023 18:45 7/31/2023 19:00 0.25 COMPZN, RPCOMP RURD P RD Testing Equipment. Pull Landing Joint and L/D Same. 0.0 0.0 7/31/2023 19:00 7/31/2023 19:15 0.25 COMPZN, RPCOMP MPSP P Install Type "H" BPV. 0.0 0.0 7/31/2023 19:15 7/31/2023 19:30 0.25 COMPZN, RPCOMP PRTS P PT BPV to 1000 psi for 10 mins by pumping down the IA. 0.0 0.0 7/31/2023 19:30 7/31/2023 20:00 0.50 COMPZN, RPCOMP RURD P RD Testing Equipment. Blow Down Choke Manifold and Mud Manifold. Pull Riser. 0.0 7/31/2023 20:00 7/31/2023 22:00 2.00 COMPZN, WHDBOP RGRP T Repair Rig Hydraulics System to operate bridge crane. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Page 38/38 2K-07 Report Printed: 8/10/2023 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) 7/31/2023 22:00 8/1/2023 00:00 2.00 COMPZN, WHDBOP RURD P RD BOPE and set back on stump. 0.0 0.0 8/1/2023 00:00 8/1/2023 02:00 2.00 COMPZN, WHDBOP RURD P Finished RD BOPE and set back on stump. 0.0 0.0 8/1/2023 02:00 8/1/2023 04:00 2.00 COMPZN, WHDBOP RURD P Install Test Dart and NU Wellhead. 0.0 0.0 8/1/2023 04:00 8/1/2023 05:00 1.00 COMPZN, WHDBOP PRTS P PT Packoffs and Void to 5000 psi. PT wellhead 250/5000 for 5 mins. 0.0 0.0 8/1/2023 05:00 8/1/2023 05:15 0.25 COMPZN, WHDBOP MPSP P Pull Type "H" BPV. 0.0 0.0 8/1/2023 05:15 8/1/2023 07:00 1.75 COMPZN, WHDBOP FRZP P Circulate 80 bbls of Diesel down IA taking returns up the Tubing at 2 BPM, 700 psi. Allow Well to U-Tube. 0.0 0.0 8/1/2023 07:00 8/1/2023 12:00 5.00 DEMOB, MOVE RURD P RDMO. Clean Wellsite and Cellar. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/1/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,974.0 2K-07 3/1/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: New Tubing Install 2K-07 8/1/2023 Nordic3cm Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic 11/1/2010 ninam NOTE: WAIVERED WELL: IA x OA COMMUNICATION 10/26/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,480.4 2,950.5 36.00 J-55 BTC Tie-Back String 7 6.28 31.1 2,116.8 1,997.6 26.00 L-80 HYD563 PRODUCTION 7 6.28 33.0 8,302.6 6,483.5 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.1 Set Depth 7,664.0 Set Depth 6,002.0 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 31.1 31.1 0.28 Hanger 7.000 FMC Gen IV 3 1/2" Tubing Hanger FMC Gen IV 2.910 533.4 533.3 1.41 Nipple - Landing 3.500 2.813" X-Nipple, 8RD EUE HES X-Nipple 2.813 2,601.0 2,348.1 46.19 Mandrel GAS LIFT 5.940 3.5" x 1.5" Camco MMG GLM Camco MMG 2.920 5,389.5 4,316.5 41.94 Mandrel GAS LIFT 5.940 3.5" x 1.5" Camco MMG GLM Camco MMG 2.920 6,935.3 5,464.0 42.67 Mandrel GAS LIFT 5.940 3.5" x 1.5" Camco MMG GLM Camco MMG 2.920 7,461.6 5,851.9 42.45 Mandrel GAS LIFT 5.940 3.5" x 1.5" Camco MMG GLM Camco MMG 2.920 7,614.8 5,965.4 41.89 PACKER 6.018 3.5" x 7" SLB Bluepack Max RH, VAM BxP Schlumb erger BluePac k 2.885 7,640.9 5,984.8 41.89 Nipple - Landing 3.500 2.813" X-Nipple, 8RD EUE, HES X-Nipple 2.813 7,657.1 5,996.9 41.89 Overshot 5.990 3 1/2" x 7" PoorBoy Overshot w/ shear screws 6.53' of swallow (space out 1.88' off tag) Baker Poorboy Oversho t 3.630 Top (ftKB) 7,659.0 Set Depth 7,759.1 Set Depth 6,072.8 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMO D ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,674.5 6,009.9 41.89 PBR 4.500 BAKER PBR BAKER 3.000 7,689.1 6,020.7 41.89 PACKER 6.062 BAKER HB PACKER BAKER HB 2.892 7,705.8 6,033.1 41.89 GAS LIFT 5.793 CAMCO MMG-2 CAMCO MMG-2 2.920 7,747.2 6,063.9 41.86 NIPPLE 4.545 OTIS 2.813" XN NIPPLE w/2.75" NO GO OTIS XN 2.750 7,758.4 6,072.3 41.85 SOS 4.500 BAKER SHEAR OUT SUB BAKER 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) 31.1 31.1 0.28 EMERGENCY SLIPS 11 x 7" C-21 emergency slips 7/24/2023 7.000 7,634.0 5,979.7 41.89 BALL & ROD Standard ball & rod (82" OAL w/ 1.375" F/N, 1-5/16" Ball) 7/31/2023 0.000 7,640.9 5,984.8 41.89 TUBING PLUG RHC plug installed in X nipple 7/31/2023 1.000 7,659.0 5,998.3 41.89 CUT 2.375" WELLTEC MECHANICAL TUBING CUT AT 7664' RKB 6/3/2023 2.992 7,691.9 6,022.8 41.89 LEAK LEAK IDENTIFIED WITH ACOUSTIC LDL IN PRODUCTION PACKER AT 7691.9' RKB 4/6/2023 2.992 7,697.5 6,027.0 41.89 CIBP 2.75" CIBP AT 7698' RKB, OAL 1' LEGACY HPBP N/A 5/1/2023 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) 2,601.0 2,348.1 46.19 1 GAS LIFT DMY RK 1 1/2 7/31/2023 SLB MMG 5,389.5 4,316.5 41.94 2 GAS LIFT DMY RK 1 1/2 7/31/2023 SLB MMG 6,935.3 5,464.0 42.67 3 GAS LIFT DMY RK 1 1/2 7/31/2023 SLB MMG 7,461.6 5,851.9 42.45 4 GAS LIFT SOV REK 1 1/2 7/31/2023 SOV is shear ed out SLB MMG 2K-07, 8/10/2023 1:26:47 PM Vertical schematic (actual) PRODUCTION; 2,114.4-8,302.6 IPERF; 7,950.0-7,984.0 APERF; 7,920.0-7,930.0 APERF; 7,838.0-7,846.0 GAS LIFT; 7,705.8 CIBP; 7,697.5 PACKER; 7,689.1 LEAK; 7,691.9 Cement Plug; 7,675.0 ftKB CUT; 7,659.0 TUBING PLUG; 7,640.9 Nipple - Landing; 7,640.9 BALL & ROD; 7,634.0 PACKER; 7,614.8 Mandrel GAS LIFT; 7,461.6 Mandrel GAS LIFT; 6,935.3 Mandrel GAS LIFT; 5,389.5 SURFACE; 35.0-3,480.4 Mandrel GAS LIFT; 2,601.0 Tie-Back String; 31.1-2,116.8 Production String 1 Cement; 32.1 ftKB Nipple - Landing; 533.4 CONDUCTOR; 36.0-115.0 EMERGENCY SLIPS; 31.1 Hanger; 31.1 KUP PROD KB-Grd (ft) 40.19 RR Date 7/21/1989 Other Elev 2K-07 ... TD Act Btm (ftKB) 8,310.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032010700 Wellbore Status PROD Max Angle & MD Incl (°) 47.37 MD (ftKB) 3,100.00 WELLNAME WELLBORE2K-07 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 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) 2,089.9 1,977.1 40.11 Collar - Stage 8.300 7" ES Cementer (SN#: 102463867 -A) Halliburto n HES Cementer 6.171 2,112.8 1,994.5 40.47 Patch 8.390 7" x 8.370" External Casing Patch w/ 3' Swallow (SN#: AW 3217885- 2) NOV 8 3/8" Casing Patch 7.190 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,838.0 7,846.0 6,131.7 6,137.6 C-4, 2K-07 9/29/2004 6.0 APERF 2.5" HSD 2506 PJ HMX, 60 deg Ph 7,920.0 7,930.0 6,193.0 6,200.5 A-5, 2K-07 9/29/2004 6.0 APERF 2.5" HSD 2506 PJ HMX, 60 deg Ph 7,950.0 7,984.0 6,215.5 6,241.3 A-4, 2K-07 11/12/1989 4.0 IPERF 90 deg. Phase, 4" Super Omnikone Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,675.0 7,697.5 6,010.2 6,027.0 Cement Plug Dump bailed 10 gallons of Portland Type 1 cement on top of CIBP 5/4/2023 2K-07, 8/10/2023 1:26:48 PM Vertical schematic (actual) PRODUCTION; 2,114.4-8,302.6 IPERF; 7,950.0-7,984.0 APERF; 7,920.0-7,930.0 APERF; 7,838.0-7,846.0 GAS LIFT; 7,705.8 CIBP; 7,697.5 PACKER; 7,689.1 LEAK; 7,691.9 Cement Plug; 7,675.0 ftKB CUT; 7,659.0 TUBING PLUG; 7,640.9 Nipple - Landing; 7,640.9 BALL & ROD; 7,634.0 PACKER; 7,614.8 Mandrel GAS LIFT; 7,461.6 Mandrel GAS LIFT; 6,935.3 Mandrel GAS LIFT; 5,389.5 SURFACE; 35.0-3,480.4 Mandrel GAS LIFT; 2,601.0 Tie-Back String; 31.1-2,116.8 Production String 1 Cement; 32.1 ftKB Nipple - Landing; 533.4 CONDUCTOR; 36.0-115.0 EMERGENCY SLIPS; 31.1 Hanger; 31.1 KUP PROD 2K-07 ... WELLNAME WELLBORE2K-07 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8310'N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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: AOGCC USE ONLY Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742 Senior RWO/CTD Engineer Tubing Grade: Tubing MD (ft): Packer: 7689'MD/6021'TVD SSSV: 1783'MD/1731'TVD Perforation Depth TVD (ft): Tubing Size: J-55 7759' 6/22/2023 Packer: Baker HB SSSV: CAMCO TRDP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL25588, ALK2674 189-071 P.O. Box 100360, Anchorage, AK 99510 50-103-20107-00-00 ConocoPhillips Alaska, Inc. KRU 2K-07 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6489' 7974' 6234' 2092 7737' MD 115' 2951' 115' 3480' 6484'8303' 16" 9-5/8" 79' 3445' Perforation Depth MD (ft): 7838-7846' 7920-7930' 7950-7984' 8270' 6132-6138' 6193-6201' 6216-6241' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:02 am, Jun 30, 2023 323-365 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.06.29 17:14:30-08'00' Foxit PDF Editor Version: 12.1.2 Elliott Tuttle X DSR-7/5/23 X BOP test to 3000 psig Annular preventer test to 2500 psig 10-404 VTL 7/4/2023 MDG 7/3/2023 GCW 07/11/2023 07/12/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.12 08:14:08 -05'00' RBDMS JSB 071323 2K-07 RWO Procedure – V2.0 Kuparuk Producer PTD #189-071 Page 1 of 3 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. (Passed, 4/12/2023) 2. Install hold-open sleeve in SSSV as necessary. (Installed) 3. SBHP. (3461psi @ 6178’ TVD, 4/28/23) 4. Attempt to install plug at base of packer and achieve a Draw Down Test on the plug. (CIBP @ 7698’ MD, Cement to 7675’ MD passes 2500psi CMIT passed, fails IA-DDT 61psi 8hrs) 5. Open lowest GLM in upper completion. Dummy off the rest. (Completed) 6. Cut the tubing nominally at ~7675’ RKB in the middle of the first full joint above the production packer. (Successful cut obtained @ 7664’ ELMD) 7. Prepare well within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors Nordic 3 on 2K-07. (If risk assessment for Nordic 3 has been done by start of this well, no BPV will needed to be installed for MIRU/RDMO.) (Spot sub over well, 6/26/23) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3000 psi. Test annular 250/3000 psi. (completed) Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~7675’ RKB). a. Stopped pulling @ ~890’ out of hole, MU 6” OD drift RIH. Tag inside 7” @ 734’ RKB 6. Lay down drift, RIH to bottom with tubing, increase KWF weight in preparation to set inflatable Bridge plug @ 850’ RKB, obtain needed barriers. _____________________Current Step, 6/29/23 Pull Subsided 7.0” Casing 7. Set storm packer or RBP and PT to confirm as barrier. 8. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow 7.0” casing and cut off excess as necessary in this step. b. RIH below casing flange with RBP, set as test plug. Test break to 250psi/3000psi 9. Re-Drift 7” Casing down to plug @ 850’ RKB a. If Successful – Pull IBP, connect to tubing roll well to KWF to surface, TOOH and lay down tubing. Move to “Run new 7” Tie back Assy” b. If unsuccessful, Cut 7” below trouble spot. Set annular and circulate the backside of the 7” to KWF. Perform 30min no flow test. 10. Split stack at Casing flange, Spear 7” remove slips, let packoffs ride. Set stack back down and flange up, TOOH and lay down 7” down to cut. a. Land 11” test plug, test break to 250psi/3000psi 11. Using string mills, create 8 3/8” drift down to 7” cut. 12. RIH with 7” Tie back with external casing patch and pull into tension. 13. Perform 30 minute no flow test, Split stack and land slips, cut excess casing and install IC packoffs. Land stack and MU to casing flange. a. RIH below casing flange with RBP, set as test plug. Test break to 250psi/3000psi 14. Pull IBP on DP. 15. Pull Rest of tubing out of hole and lay down. 2K-07 RWO Procedure – V2.0 Kuparuk Producer PTD #189-071 Page 2 of 3 Run New 7” and Cement 16. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. a. Set plug below Artic Pack Job, obtain needed barriers 17. Cut 7.0” casing with cutter above OA cement. Circulate out Arctic Pack diesel/slurry. 18. Pull 7.0” casing down to cut (~2000’). 19. RIH with 7” Tie back with external casing patch and Cementer. Test casing to 2500psi. 20. Drop fall plug, open cementer, Cement Annulus of 7” x 9 5/8” Casing. 21. Perform 30 minute no flow test, Split stack and land slips, cut excess casing and install IC packoffs. Land stack and MU to casing flange. a. Test Flange break to 250psi/3000psi 22. Mill Cement/ plugs in cementer. Pull plug below Arctic Pack. Run New 3.5” x 5.5” Tie-back Liner 23. RIH with 3.5” overshot, Nipple profile, 3.5” x 7.0” packer, 3.5” x 5.5” crossover, 5.5” x 7.0” packer, and 5.5” casing to surface. (Crossover to 7.0” at surface for last joint if needed for wellhead termination.) 24. Reverse circulate in CI fluid and freeze protect as needed. 25. Pressure up on tubing to set both the 3.5” x 7.0” and the 5.5” x 7.0” packers. 26. RU SL and RIH to pull isolation sleeve across communication ports in top of PBR assembly. a. Communication port allows pressure communication from 3.5” x 5.5” annulus down to 3.5” x 7.0” annulus. Covered up on initial install to allow packer setting. b. RIH and pull sleeve with tubing if SL not available. 27. PT 5.5” liner to 2500 psig for 30 minutes and chart. (This is the new IA envelope.) 28. Set 5.5” RBP near surface. PT to confirm as barrier. 29. ND BOPE. NU new tubing spool. NU BOPE. Test flange breaks. Install in 3-½” Completion 30. MU 3 ½” slim completion with seals non sealing overshot, Packer, nipples, and GLMs. RIH with completion. 31. Once on depth, stab in seals and space out as needed. Space out, circulate in CI fluid and set packer. 32. Pressure test tubing to 3000 psi for 30 minutes and chart. 33. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 34. Confirm pressure tests, then shear out SOV with pressure differential. 35. Install BPV. 36. ND BOPE. NU tree. PT tree. 37. Pull BPV, freeze protect well, and set BPV if necessary. 38. RDMO. Post-Rig Work 39. Pull BPV 40. Pull dual flapper valve. 41. Install GLD. 2K-07 RWO Procedure – V2.0 Kuparuk Producer PTD #189-071 Page 3 of 3 General Well info: Wellhead type/pressure rating: FMC Gen IV, 5M psi top flange, 3M psi bottom flange Production Engineer: Natalie Dye Reservoir Development Engineer: Mandy Pogany Estimated Start Date: 5/14/2023 Start Date: 6/26/23 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com)/ Elliott Tuttle (907-252-3347/ Elliott.tuttle@conocophillips.com Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Pull buckled 7.0” casing near surface. Run new 3.5” x 5.5” tie-back liner with dual packers deep. Run new 7” tie back liner and cement. Run slim new 3-1/2” upper completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failed 3/19/2022 MIT-IA Passed 3/19/2022 MIT-OA Failed 12/2/2021 IC POT &PPPOT N/A TBG POT &PPPOT N/A MPSP: 2843 psi using 0.1 psi/ft gradient Static BHP: 2710 psi / 6178’ TVD measured on 3/1/2022 2K-07 Proposed RWO Completion - Std Subsidence Repair COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 3480 2951 9.625 8.92 36 J-50 BTC BTC Production/ Intermediate 8303 6484 7 6.28 26 J-50 BTC BTC Tubing 7675 6010 3.5 2.992 9.3 L-80 EUE8rd MoEUE8rd Mod PROPOSED TUBING COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco KBG29 gas lift mandrels @ TBD 3-1/2" Seals Cement PC 7.0" Casing to Surface 7.0" HES Cementer 7.0" Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 7689' RKB Nipple @ 7747' RKB SOS @ 7758' RKB Surface Casing Leak @ 736' Surface Casing Production/Intermediate Casing Conductor C/A-sand perfs 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8310'N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Wells Engineer Tubing Grade:Tubing MD (ft): Packer: 7689'MD/6021'TVD SSSV: 1783'MD/1731'TVD Perforation Depth TVD (ft):Tubing Size: J-55 7759' Packer: Baker HB SSSV: CAMCO TRDP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL25588, ALK2674 189-071 P.O. Box 100360, Anchorage, AK 99510 50-103-20107-00-00 ConocoPhillips Alaska, Inc. KRU 2K-07 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6489'7974'6234'2092 7737' MD 115' 2951' 115' 3480' 6484'8303' 16" 9-5/8" 79' 3445' Perforation Depth MD (ft): 7838-7846' 7920-7930' 7950-7984' 8270' 6132-6138' 6193-6201' 6216-6241' 3-1/2" 7" P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 5/20/2023 323-241 By Kayla Junke at 1:22 pm, Apr 20, 2023 X DSR-4/20/23VTL 5/17/2023 BOP test to 3000 psig Annular preventer test to 2500 psig X MDG 4/28/2023 X 10-404 GCW 05/17/23JLC 5/17/2023 5/17/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.17 11:00:08 -08'00' RBDMS JSB 051823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 30, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2K-07 (PTD# 189-071). Well 2K-07 was drilled and completed in July of 1989 as a Kuparuk A-sands producer. The C-sands were perforated in 2004 as well. In 2021 the well was shut in due to a slow TxIA leak on gas and a casing leak on the surface casing. Subsidence is expected on the well. This well was moved forward as a RWO candidate in 2023. If you have any questions or require any further information, please contact me at +1503-476-2519. A slim subsidence will be performed on the well. The tubing will be pulled. Then the buckled 7.0" casing near surface will be pulled. Then a 3.5" x 5.5" tie-back liner with gas-tight threads will be ran. Then a slim 3.5" completion will be ran inside the new liner. 2K-07 RWO Procedure Kuparuk Producer PTD #189-071 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Install hold-open sleeve in SSSV as necessary. 3. SBHP. 4. Attempt to install plug at base of packer and achieve a Draw Down Test on the plug. 5. Open lowest GLM in upper completion. Dummy off the rest. 6. Cut the tubing nominally at ~7675’ RKB in the middle of the first full joint above the production packer. 7. Prepare well within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors Nordic 3 on 2K-07. (If risk assessment for Nordic 3 has been done by start of this well, no BPV will needed to be installed for MIRU/RDMO.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3000 psi. Test annular 250/3000 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~7675’ RKB). Pull Subsided 7.0” Casing 6. Set storm packer or RBP and PT to confirm as barrier. 7. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow 7.0” casing and cut off excess as necessary in this step. 8. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. 9. Cut 7.0” casing with cutter above OA cement. Circulate out Arctic Pack diesel/slurry. 10. Pull 7.0” casing down to cut (~2000’). Run New 3.5” x 5.5” Tie-back Liner 11. RIH with 3.5” overshot, Nipple profile, 3.5” x 7.0” packer, 3.5” x 5.5” crossover, 5.5” x 7.0” packer, and 5.5” casing to surface. (Crossover to 7.0” at surface for last joint if needed for wellhead termination.) 12. Reverse circulate in CI fluid and freeze protect as needed. 13. Pressure up on tubing to set both the 3.5” x 7.0” and the 5.5” x 7.0” packers. 14. RU SL and RIH to pull isolation sleeve across communication ports in top of PBR assembly. a. Communication port allows pressure communication from 3.5” x 5.5” annulus down to 3.5” x 7.0” annulus. Covered up on initial install to allow packer setting. b. RIH and pull sleeve with tubing if SL not available. 15. PT 5.5” liner to 2500 psig for 30 minutes and chart. (This is the new IA envelope.) 16. Set 5.5” RBP near surface. PT to confirm as barrier. 17. ND BOPE. NU new tubing spool. NU BOPE. Test flange breaks. Install in 3-½” Completion 18. MU 3 ½” slim completion with seals, nipples, and GLMs. RIH with completion. 19. Once on depth, stab in seals and space out as needed. Circulate in CI fluid at opportune time. 20. Pressure test tubing to 3000 psi for 30 minutes and chart. 21. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 2K-07 RWO Procedure Kuparuk Producer PTD #189-071 Page 2 of 2 22. Confirm pressure tests, then shear out SOV with pressure differential. 23. Install BPV. 24. ND BOPE. NU tree. PT tree. 25. Pull BPV, freeze protect well, and set BPV if necessary. 26. RDMO. Post-Rig Work 27. Pull BPV 28. Pull dual flapper valve. 29. Install GLD. General Well info: Wellhead type/pressure rating: FMC Gen IV, 5M psi top flange, 3M psi bottom flange Production Engineer: Natalie Dye Reservoir Development Engineer: Mandy Pogany Estimated Start Date: 5/14/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Pull buckled 7.0” casing near surface. Run new 3.5” x 5.5” tie-back liner with dual packers deep. Run slim new 3-1/2” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failed 3/19/2022 MIT-IA Passed 3/19/2022 MIT-OA Failed 12/2/2021 IC POT &PPPOT N/A TBG POT &PPPOT N/A MPSP: 2092 psi using 0.1 psi/ft gradient Static BHP: 2710 psi / 6178’ TVD measured on 3/1/2022 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,974.0 3/1/2022 2K-07 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag depth, Set PXN Plug, Gas Lift, & Identified poss leak 3/5/2022 2K-07 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,480.4 Set Depth (TVD) … 2,950.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,302.6 Set Depth (TVD) … 6,483.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,759.1 Set Depth (TVD) (… 6,072.8 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 31.1 31.1 0.28 HANGER 3.500 8.000 1,783.2 1,731.4 32.83 SAFETY VLV 2.812 5.937 CAMCO TRDP 2,579.6 2,333.3 46.14 GAS LIFT 2.875 5.620 MERLA TMPD 4,676.2 3,786.8 42.09 GAS LIFT 2.875 5.620 MERLA TMPD 5,755.5 4,589.3 41.80 GAS LIFT 2.875 5.620 MERLA TMPD 6,258.2 4,966.2 41.33 GAS LIFT 2.875 5.620 MERLA TMPD 6,718.3 5,303.7 42.48 GAS LIFT 2.875 5.620 MERLA TMPD 7,171.8 5,638.2 42.43 GAS LIFT 2.875 5.620 MERLA TMPD 7,633.5 5,979.3 41.89 GAS LIFT 2.920 5.793 CAMCO MMG-2 7,674.5 6,009.9 41.89 PBR 3.000 4.500 BAKER 7,689.1 6,020.7 41.89 PACKER 2.892 6.062 BAKER HB 7,705.8 6,033.2 41.89 GAS LIFT 2.920 5.793 CAMCO MMG-2 7,747.2 6,063.9 41.86 NIPPLE 2.750 4.545 OTIS XN 7,758.4 6,072.3 41.85 SOS 2.992 4.500 BAKER Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,736.7 6,056.1 41.86 TUBING PLUG 2.813" PXN Plug (Plug Body=23" OAL & Has a 2.72" Bait Sub attached to P-prong=101" OAL) 3/1/2022 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,579.6 2,333.3 46.14 1 GAS LIFT DMY BK 0.000 0.0 3/5/2022 2 4,676.2 3,786.8 42.09 1 GAS LIFT DMY BK 0.000 0.0 3/5/2022 3 5,755.5 4,589.3 41.80 1 GAS LIFT DMY BK 0.000 0.0 4/4/1998 4 6,258.2 4,966.2 41.33 1 GAS LIFT DMY BK 0.000 0.0 4/8/1998 5 6,718.3 5,303.7 42.48 1 GAS LIFT DMY BK 0.000 0.0 3/5/2022 6 7,171.8 5,638.2 42.43 1 GAS LIFT DMY BK 0.000 0.0 10/17/2007 7 7,633.5 5,979.3 41.89 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/5/2022 8 7,705.8 6,033.2 41.89 1 1/2 PROD DMY RK 0.000 0.0 5/18/1990 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,838.0 7,846.0 6,131.7 6,137.6 C-4, 2K-07 9/29/2004 6.0 APERF 2.5" HSD 2506 PJ HMX, 60 deg Ph 7,920.0 7,930.0 6,193.0 6,200.5 A-5, 2K-07 9/29/2004 6.0 APERF 2.5" HSD 2506 PJ HMX, 60 deg Ph 7,950.0 7,984.0 6,215.5 6,241.3 A-4, 2K-07 11/12/1989 4.0 IPERF 90 deg. Phase, 4" Super Omnikone Notes: General & Safety End Date Annotation 11/1/2010 NOTE: View Schematic w/ Alaska Schematic 10/26/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 2K-07, 3/7/2022 6:12:39 PM Vertical schematic (actual) PRODUCTION; 33.0-8,302.6 IPERF; 7,950.0-7,984.0 APERF; 7,920.0-7,930.0 APERF; 7,838.0-7,846.0 SOS; 7,758.4 NIPPLE; 7,747.2 TUBING PLUG; 7,736.7 GAS LIFT; 7,705.8 PACKER; 7,689.1 PBR; 7,674.5 GAS LIFT; 7,633.5 GAS LIFT; 7,171.8 GAS LIFT; 6,718.3 GAS LIFT; 6,258.2 GAS LIFT; 5,755.5 GAS LIFT; 4,676.2 SURFACE; 35.0-3,480.4 GAS LIFT; 2,579.6 SAFETY VLV; 1,783.2 CONDUCTOR; 36.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.19 Rig Release Date 7/21/1989 2K-07 ... TD Act Btm (ftKB) 8,310.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032010700 Wellbore Status PROD Max Angle & MD Incl (°) 47.37 MD (ftKB) 3,100.00 WELLNAME WELLBORE2K-07 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 2K-07 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 3480 2951 9.625 8.92 36 J-50 BTC BTC Production/ Intermediate 8303 6484 7 6.28 26 J-50 BTC BTC Liner 7675 5.5x3.5 4.95 15.5 L-80 HYD563 HYD563 Tubing 7634 5979 3.5 2.992 9.3 L-80 EUE8rd MoEUE8rd Mod PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface 5-1/2" x 7.0" Packer PBR for 3-1/2" Seals (with port to IA covered with sleeve on install) 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" x 7" Packer 2.75" D-landing nipple at xxxx' RKB (2.75" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 7689' RKB Nipple @ 7747' RKB SOS @ 7758' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-06_22090_KRU_2K-07_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22090 KRU 2K-07 50-103-20107-00 LeakPoint Survey 06-Apr-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 189-071 T37589 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.13 10:39:38 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-01_21065_KRU_2K-07_ArcherVIVID-SRO_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21065 KRU 2K-07 50-103-20107-00 Archer VIVID™- SRO 01-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:189-071 T36556 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.09 11:31:33 -08'00' RECEIVED • --t� �°► MAY 10 2013 WELL LOG TRANSMITTAL# ACC To: Alaska Oil and Gas Conservation Comm. May 6, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED5 iv./201e K BENDER RE: Production Profile: 2K-07 Run Date: 12/25/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-07 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20107-00 Production Profile Log 1 Color Log 50-029-20107-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / ,,aga-ouLd / ...E;dta WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2K -07 Run Date: 10/3/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -07 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 103 20107 -00 Production Profile Log 1 Color Log t, i EE! ND e' 2 7 200: 50 -103- 20107 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto l 6900 Arctic Blvd. 9 a q Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburton .co Date: NOV 0 6 200 Signed: 2K-07 (PTD 1890710) Failed TIF~ • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, October 08, 2007 5:50 PM ~ i~ v? To: Regg, James B (DOA) t Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2K-07 (PTD 1890710) Failed TIFL Jim, Page 1 of 2 2K-07 was added to the weekly SCP report because it failed a TIFL and the Commission requires us to report all failed TIFL's through the SCP system, even though the weekly report is no longer emailed; it is still completed. The TxIA communication will be repaired or the well will be secured with in the next 28 days. It is on the quarterly report for slow IAxOA communication through the packoffs and equalizes just under 1400 psi. Pease let me know if you have any more questions. Brent Rogers Problem Wells Supervisor 659-7224 ~~~ ~~~ ~ ~~~7 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] _~.,~._~_.,_._. .~;.:.:~~ Sent: Monday, October 08, 2007 9:53 AM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 2K-07 (PTD 1890710) Failed TIFL I'm confused; 2K-07 has been on the SCP report provided quarterly, presumably for IAxOA communication - I found a note attached to a past report referencing packoff issues. Your TIO plot certainly bears that out. If that is not the case, when did IA and OA equalize at 1500psi? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage; AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Weli Supv [mailto:n1617@conocophillips.com] Sent: Saturday, October 06, 2007 2:48 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 2K-07 (PTD 1890710) Failed TIFL Tom & Jim, Kuparuk gas lifted producer 2K-07 (PTD 1890710) failed a TIFL on 10/05/07 and has been added to the SCP report. The TIO immediately prior to SI for the TIFL was 200/1380/1140. A leaking GLV is suspected.. Slickline will trouble shoot the tubing leak and repair if possible. Attached is a 90 day TIO plot and a schematic. Please let me know if you have any questions. 10/11/2007 2K-07 (PTD 1890710) Failed TIF~ Page 2 of 2 «2K-07 schematic.pdf» «2K-07 ay TIO plot.jpg» • Brent Rogers Problem Wells Supervisor 659-7224 10/ 11 /2007 • ILo-bg~ ~4:d Lo-~Z ~~i • }~ ~an~coPhillips Alaska, tnc. KRU 2K-07 ~T 2K-07 API: 501032010700 Well T e: PROD An le TS: 42 de 7836 SSSV T e: TRDP Ori Com letion: 7/21/1989 An le TD: 41 de 8310 SSSV ~ _ . L ~ Annular Fluid: Last W/O: Rev Reason: TAG TD, PERF (1783-178x, 500 OD:3 ~ ~ _~ - Reference Lo Ref Lo Date: Last U date: 10/6/2004 ) . Last Ta : 8045 TD: 8310 ftKB Last Ta Date: 9/28/2004 Max Hole An le 47 deg @ 3100 Casing String -ALL 5TRINGS Gas Lin Descri lion Size To Bottom TVD Wt Grade Thread andrelNalve ~ CONDUCTOR 16.000 0 115 115 62.50 H-40 1 (2580-2581 ~ SUR. CASING 9.625 0 3480 2950 36.00 J-55 , PROD. CASING 7.000 0 8285 6470 26.00 J-55 Tubin Strin -TUBING Gas lift ' ~ Size To Bottom TVD Wt Grade _ Thread andrelNalve ~ ~ 3.500 0 r _ ~ 6073 9.30 J-55 E'~.JE'3RD AB-MOD 2 (4676-4677 _ Perforations Summa , Interval TVD Zone Status Ft SPF Date T e Comment 7838 - 7846 6132 - 6138 C-4 8 6 9/29/2004 APERFS 2.5" HSD 2506 PJ HMX, 60 ~ ~ . de Ph ~ ~ 7920 - 7930 6193 - 6201 A-5 10 6 9/29/2004 APERFS 2.5" HSD 2506 PJ HMX, 60 ~ de Ph ~ 7950 - 7984 6216 - 6241 A-4 34 4 11/12/1989 IPERFS 90 deg. Phase, 4"Super i Omnikone Gas Lift Gas Lift MandrelslValves andret/valve I ~~. `` St MD TVD Man Mfr Man Type V Mfi V Type V OD Latch Port TRO Date Run Vlv 4 5 r Cmnt (6258-s2 9, i ~ 1 2580 2334 Merla TMPD GLV 1.0 BK 0.125 1255 4/8/1998 i 2 4676 3787 Merla TMPD GLV 1.0 BK 0.156 1277 4/8/1998 J 3 5756 4590 Merla TMPD DMY 1.0 BK 0.000 0 4/4/1998 ~ ~ ~ 4 6258 4966 Mer1a TMPD GLV 1.0 BK 0.188 1300 4/8/1998 ~ ' 5 6718 5304 Merla TMPD DMY 1.0 BK 0.000 0 4/4/1998 ~ 6 7172 5638 Merla TMPD DMY 1.0 BK 0.000 0 4/4/1998 7 7633 5979 Camco MMG2 OV 1.5 RK 0.156 0 4/8/1998 dd ~ I Production Mandrels/Valves ` ~' ~ ~ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 8 7706 6033 Camco MMG2 DMY 1.5 RK 0.000 0 5/18/1990 Closed Other lu s, e ui ., etc. -JEWELRY Gas Lin , ~. De th TVD T e Descri lion ID andrel/Valve ® .4 1783 1731 SSSV Camco TRDP-1A-SSA 2.812 7 '"~ ' ` 7675 6010 PBR Baker 4" Seal Bore Diameter 3.000 (7633-7634, 7689 6021 PKR Baker'HB' 2.892 7747 6064 NIP Otis'XN' NIPPLE NO GO 2.750 PBR 7758 6072 SOS Baker 2.992 (7675-7676, 7759 6073 TTL 2.992 OD3.500) - General NOteS Date Note 4/571998 Note on Schematic: dsl ca - 2000 MD/1907 TVD ~~ 10/26/2003 WAIVERED WELL: IAx OA COMMUNICATION (7689-7690, ~~ OD:6.151) ~-'"- `` ®E ?'. { NlP (7747-7748, I OD:3.500) TUBING (0-7759, OD:3.500, I D:2.992) Perf (7838-7646) Pert (7920-7930) Pert (7950-7984) Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # I ~1- ¡II 1 F-02 /95 ;() 2"_ 2T -23 :r- 2W-12 I~'f 22.cf 2Z-19 If~-r;() 1C-111 e2С--li,. ~ 1C-117 )...ef- /2.. ( 3F-14 18'5- :z 72 2K-07 Q 2Z-12A 107.., 07 ( ('15- /eft 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Des~ription Date NO. 3292 Company: 12/23/04 û (}- tJl ,.' '/-.SJ-:1~ \11 1 '. .....~~ r~1 Alaska Oil & Gas Cons Comm ~?~ ~ Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 1 1 -' Color CD INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG 12/14/04 12/08/04 12/15/04 12/04/04 12/06/04 12/06104 12/03/04 12/05/04 12/04/04 - ct t ~ -. ~~, ' 11~- '"i G 'lQf1í1 f 0 ~r:J.\NNt::r, n... R .L 0 bU,.,!''''' SIGN D: eL-./ W~ ,"'. - " -- ,,,.. DATE: ~ 03 0; Please sign and return on(opy of this iransm ¡Ita I to Beth at the above address or fax to (907) 561-8317. Thank you. Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~iIIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2K-07 (APD # 189-071) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk weIl2K-07. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, MINl~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED OCT 1 92004 Alaska Oil & Gas Cons. Commission Anchorage ORtG\NAL STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 189-071 1 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 50-103-20107-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 154' 2K-07 8. Property Designation: 10. Field/Pool(s): ADL 25588, ALK 2674 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8310' feet true vertical 6489' feet Plugs (measured) Effective Depth measured 8045' feet Junk (measured) true vertical 6288' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 115' 115' SUR. CASING 3445' 9-5/8" 3480' 2950' PROD. CASING 8252' 7" 8285' 6470' RECEIVF Perforation depth: Measured depth: 7838'-7846',7920'-7930',7950'-7984' OCT 1 92004 Alaska Oil & Gas Cons. Ct c. c'r .~ . true vertical depth: 6132'-6138',6193'-6201',6216'-6241' Anchorage Tubing (size, grade, and measured depth) 3-1/2' ,J-55, 7759' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' 7689' sssv= 1783' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 215 202 153 -- 221 Subsequent to operation 232 329 564 -- 233 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature Úi4"y -^, Phone Date )0 'IS) 1 p" harnn AI/sun-Drake 263-4612 Form 10-404 Revised 04/2004 o~tG\NAL ~ ~tOriginalOnlY 2K-07 Well Events Summary Dffie Summary 09/28/04 TAGGED TO @ 8045' RKB (EST. 61' OF RAT HOLE) W/2.5 DUMMY GUN.O [Tag] 09/29/04 PERFORATE THE INTERVALS: 7838-7846 & 7920-7930 USING 2.5" HSD GUNS LOADED 6 SPF 60 DEG PHASING WITH 2506 POWERJET HMX CHARGES. API CHARGE DATA: PENETRATION: 25.2", ENTRANCE HOLE: 0.32"0 TAGGED TO AT 8057'. WELL LEFT SHUT IN. [Perf] SSSV (1783-1784, 00:3.500) Gas Lift andrelNalve 1 (2580-2581, Gas LIft andrelNalve 2 (4676-4677, Gas Lift andrelNalve 4 (6258-6259, Gas Lift andrelNalve 7 (7633-7634, PBR (7675-7676, 00:3.500) PKR (7689-7690, 00:6.151) NIP (7747-7748. 00:3.500) TUBING (0-7759, 00:3.500, 10:2.992) Perf (7838-7846) Perf (7920-7930) Perf (7950-7984) ConocoPhillips Alaska, Inc. KRU 2K-O7 2K-O7 Size To Bottom TVD Wt Grade Thread 16.000 0 115 115 62.50 H-40 9.625 0 3480 2950 36,00 J-55 7.000 0 8285 6470 26.00 J-55 Thread EUE 8RD AB-MOD Zone Status Ft SPF Date C-4 8 6 9/29/2004 7920 - 7930 6193 - 6201 A-5 10 6 9/29/2004 7950 - 7984 6216-6241 A-4 34 4 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port 1.0 BK 0.125 1.0 BK 0.156 1.0 BK 0.000 1.0 BK 0.188 1.0 BK 0.000 1.0 BK 0,000 1.5 RK 0.156 TRO Date Run Vlv Cmnt TMPD TMPD TMPD TMPD TMPD TMPD MMG-2 GLV GLV DMY GLV DMY DMY OV 1255 4/8/1998 1277 4/8/1998 0 4/4/1998 1300 4/8/1998 0 4/4/1998 0 4/4/1998 0 4/8/1998 Vlv Cmnt Closed Cameo TRDP-1A-SSA Baker 4" Seal Bore Diameter Baker 'HB' Otis 'XN' NIPPLE NO GO Baker ID 2.812 3,000 2.892 2.750 2.992 2.992 Date Note 4/5/1998 Note on Schematic: dsl ea - 2000 MD/1907 TVD 10/26/2003 WAIVERED WELL: IA x OA COMMUNICATION THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR' BEFORE OCTOBER 24 2000 P C:LORIWIFILM. DOC E L E W ATE R IA L U N D E TH IS M ARK ER R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 154' RKE 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 219' FSL, 94' FEU Sec 2, T10N, R8E, UM 2K-07 At top of productive interval: 9. Permit number/approval number: 2018' FSU 1076' FEL Sec 1, T10N, R8E, UM 89-71 At effective depth: 10. APl number: 1877' FSL, 1328' FEL, Sec 1, T10N, R8E, UM 50-103-20107-00 At total depth: 11. Field/Pool: 1825' FSU 1434' FEI. Sec 1, T10N, R8E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth'. true measured vertical 64898310 feet feet Plugs(measured)None t~~~ Effective Deptt measured 8153 feet Junk (measured) None true vertical 6370 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 179 Sx AS I 115' 115' Surface 3445' 9-5/8" 900 Sx AS III & 3480' 2950' 650 Sx Class G Production 8252' 7" 328 Sx Class G 8285~ , '"' ~'''. 6470' Liner ..,: .: <, ~'~ ,- , Perforation Depth measured 7950' - 7984' I ; :' ~ ' :' ~ 5 t true vertical 6216'- 6241' ,~t?~'~'~'~" ~" Tubing (size, grade, and measured depth) 3,5", 9.3#/fl., J-55 @ 7759' Packers and SSSV (type and measured depth) Pkr: Baker HB @ 7689'; SSSV: Camco TRDP-1A-SSA @ 1783 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 4/5/98. Intervals treated (measured) 7950' - 7984' Treatment description including volumes used and final pressure Pumped 183783 lbs of 16/20 and 12/18 ceramic proppant into the formation, final pressure = 6500 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to welt operation 342 210 10 1205 269 Subsequent to operation 389 220 168 1223 217 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repon' of Well Operations ~X Oil ~X Gas _ Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Wells Superintendent Date Form 10-404 ~v 06/15/81~'-- SUBMIT IN DUPLICATE~ ARCO Alaska, Inc' ) . ¼UPARUK RIVER UNIT A K1(2K-07(w4-6)) WELL JOB SCOPE JOB NUMBER 2K-07 FRAC, FRAC SUPPORT 0402981925.3 DATE DAILY WORK UNIT NUMBER 04/05/98 "A" SAND REFRAC '"DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON -SUPERVISOR I (~) Yes O NoI (~) Yes O NO DS-GALLEGOS CHANJ~ 'FIELD AFC# CC# DALLY COST AC CUM COST ie~~~F~u~te n~ ESTIMATE KD1962 230DS28KL ... $134,940 . $140,545 Initial Tbg Press25 PSIFinal Tbg Press500 PSI Initial Inner Ann100 PSI Final Inner Ann I Initial Ou400 PSI 500 I~ISI r~'5An~;~ DALLY SUMMARY "A" SAND REFRAC SCREENED OUT EARLY. INJECTED 183783 LBS OF PROP IN THE FORM W/10# PPA OF #12/18 @ THE PERF°S. MAXIMUM PRESSURE 6500 PSI & F.G. (.79) . UNABLE TO FREEZE PROTECT THE TBG. TIME 06:30 09:30 09:50 10:45 11:30 12:05 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL TRUCK, AND APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9200 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. SLURRY VOLUME PUMPED 407 BBLS. USED 5679 LBS OF #16/20 PROP FOR SCOURING. MAXIMUM PRESSURE 5200 PSI AND ENDING PRESSURE 3200 PSI. S/D. GEL NOT CROSS-LINKED. DECIDED TO REDO A PORTION OF THE BREAKDOWN, FOR DATA GATHERING. MONITORED WHTP AND STOOD-BY FOR CLOSURE. RE-PUMP PARTIAL BREAKDOWN W/50# DELAYED XL GW @ 15 BPM. SLURRY VOLUME PUMPED 205 BBLS. MAXIMUM PRESSURE 5000 PSI AND ENDING PRESSURE 3700 PSI. STEPPED DOWN THE RATE AT THE END OF THE STAGE AND S/D. OBTAINED ISIP OF 2394 PSI W/F.G. @ (.83). MONITORED WHTP AND PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 BPM. SLURRY VOLUME PUMPED 127 BBLS. GEL NOT WORKING RIGHT AGAIN SHUT DOWN AGAIN. FLUSHED OUT TBG W/STRAIGHT WATER. STOOD-BY TO QC WATER. RE-PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 187 BBLS. MAXIMUM PRESSURE 6500 PSI AND ENDING PRESSURE 3500 PSI. S/D AND OBTAINED ISIP OF 2147 PSI W/F.G. @ (.79). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 5 MINS @ 1856 PSI. PAD VOLUME = 850 BBLS. 13:00 STOOD-BY FOR MORE SEAWATER. 14:15 PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT EARLY TO SURFACE. MAXIMUM AND ENDING PRESSURE 6500 PSI. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL $0.00 $320.00 APC $8,570.00 $8,570.00 DIESEL $500.00 $500.00 DOWELL $123,230.73 $123,230.73 HALL IB U RTON $0.00 $3,085.00 LITTLE RED $2,640.00 $4,840.00 TOTAL FIELD ESTIMATE $134,940.73 $140,545.73 TIME 16:45 17:45 18:45 LOG ENTRY PUMPED 203397 LBS OFf ' (21873 LBS OF #16/20 & 181524 LBS OF #12/18). INJECTED 183783 LBS OF PROP IN THE FORMATION W/ 10# PPA OF #12/18 @ THE PERF'S. LEFT 19614 LBS OF PROP IN THE WELLBORE, W/FILL @ THE SURFACE. ESTIMATED EXTREMELY LOW BHP OF 1600 PSI. UNABLE TO FREEZE PROTECT THE TBG. STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL TRUCK. REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETED AND ALL WELL SERVICE PERSONNEL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, Inc. Date: January 19, 1990 Transmittal #: 7650 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. signed copy of this transmittal. 2K - 0 7 5" Acoustic Cement Bond Log 22 K 07 5" PET Log K 0 8 5" Acoustic Cement Bond Log K 1 3 5" Acoustic Cement Bond Log Please acknowledge receipt and return one 09-27-89 10-20-89 09-27-89 11-05-89 5144-7993 6570...-8016... 6384-9315 6400-9464 Receipt Acknowledged: RECEIVED JAN2 4 19,00 i~Se ..ka 011 '8[A.,.hnr~neGas Cons. Co~t~lssi0~ DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) STATE Of ALASKA ALAsKA~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 1. Status of Well Classification of Service Well OIL ~. GAS ~ SUSPENDED ~J ABANDONED [] SERVICE F-} ,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 89-71 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 103-20107 4. Location of well at surface 9. Unit or Lease Name 146' FSL, 94' FEL, Sec. 2, T10N, R8E, UN ~ LOCATIO:'~Si Kuparuk River Unit ,, At Top Producing Interval VERIFJF--L) 10. Well Number 1283' FSL, 1129' FEL, Sec. 1, T10N, R8E, UN ~llr~-/'~ [ 2K-7 At Total Depth j~_:/~j__~ j 11. Field and Pool 1342' FSL, 825' FEL, Sec. 1, T10N, R8E, UM ~- - Kuparuk River/ 5. Elevation in feet (indicate KB, DF', etc.) I 6. Lease Designation and Serial No. 154' RKBI ADL:25588 ALK:2674 Kuparuk 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 07/1 2/89 7/19/89 11/08/89I - -- feet MS LJ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+'I'VD) 19. Directional Survey ~ 20. Depth where SSSV set I 21. Thickness of Permafrost 8,310'MD&6489'TVD 8] 53'md 6370't-_vc3 YES ~ NO []J . 1783' feet MDJ --- 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL/CAL, CET, Gyro ... 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , 1g', ;:;? :;~ H-40 .c;,, r f 115' -- 9-~/R" ~# .I-~ ~urf ~4RO' 12-1/4" 900.~x AS III & 650sx '.lass G ~ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER sET (MD) 3½",9.3#,J-55 7,759' 7,689' 7,950 ' -7,98/+ ' MD /+" Super 0mnikone (~ 4 spf, 90° phase. 6,216'-6,2/+1 ~ TVD 26. ACID, FRAcTuRE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS~MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED=l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (Corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. None RECEIVED Form 10-407 Submit in duplicate Rev. 7-1-80 WC1/27 CONTINUED ON REVERSE SIDE 29. 30. NAME Kuparuk C Kuparuk A GEOLOGIC MARKERS TOPS MEAS. DEPTH 7,835' 7,902' TRUE VERT. DEPTH i 6,129' 6,179' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Gyro ~ 32, I hereby certify that the foregoing es true and correct to the best of my knowledge Signed_ ~,_S d Title Area Drilling Engr. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO L,,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit d~e "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. County or Parish NORTH SLOPE Field Lease or Unit I Well no. I KUPARUK RIVER UNIT ADL: 25588 ALK: 2674 2K-7 Title COMPLETIONS District ARCO ALASKA INC. Accounting cost center code State AK Auth. or W.O. no. AK3625 Operator A.R.Co. W.I. ARCO I 55 . 8533 Spudded or W.O. begun IDate SPUD I 07~12/89.- complete record for each day reported Date and depth as of 8:00 a.m. 11/09/89 (13) TD: 8310 PB: 8153 SUPV:DB NORDIC I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prtor status if a W.O. I 08:30 RIG RELEASED 9-5/8"@ 3480' MW: 0.0 NaCl PERF 7950-7970, RD WA E-LINE, PU & TIH W/ 3-1/2" COMPLETION ASSEMBLY, TEST CONTROL LINE, LAND TBG, PRESSURE TBG TO 2500 AND SET PKR (TBG OK), BLED PRESS, PU AND SHEAR PBR, RELAND TBG, RILDS, TEST ANNULUS TO 2500, CLOSE SSSV, BLED TBG PRESS, SSSV OK, PRESS UP TBG AND SHEAR OUT BALL AT 3500, BLED PRESS, SET BPV, ND HOPE, NU TREE, TEST TREE AND PACKOFF TO 5000, DISPLACE 5 BBLS DIESEL DOWN ANNULUS, BULLHEAD 2 BBLS DIESEL DOWN TBG, CV HOLDING, RELEASE RIG AT 2400 11/8/89 DAILY:S186,814 CUM:$1,167,083 ETD:S1,167,083 EFC:$1,315,000 Old TD INewTD I PB Depth Released rig I Date IKind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day ,, Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Drilling, Pages 86 and 87. AR3B'459-3-C INumber all daily well history forms consecutively · es they are prepared for each well. jPage no. Dlvlalon of AtllntlcRIchfteldCompany ARCO Oil and Gas Company Well History - Initial Report- Daily. Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded Or workover oporations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER UNIT County, parish or borough NORTH SLOPE ILease or Unit ADL: 25588 AKL: 2674 ITitle COMPLETIONS State AK 2[4-'7 IWoII no. Field Auth. or W.O. no. AK3625 Operator ARCO Spudded or W.O. begun IDate IHour SPUD J 07/12/89' J 08:30 Date and depth as of 8:00 a.m., 11/07/89 (11) TD: 8310 PB: 8153 SUPV:GB 11/08/89 (12) TD: 8310 PB: 8153 SUPV:DB Complete record for each day reported NORDIC IARCO W.I. 55.8533 Prior status if a W,O. DRLG CMT @ 8075 9-5/8"@ 3480' MW: 0.0 NaCl MOVE RIG FROM 2K~4, ACCEPT RIG AT 1600 11/6/89, ND DRYHOLE TREE, NU BOPE, TEST T© 3000 PSI, PU 6-1/8" BIT, 6 4-3/4" DC, AND TIH ON 3-1/2" DP, TAG CMT AT 7998, DRILL CMT FROM 7998-8075 DAILY:S37,106 CUM:$952,122 ETD:S952,122 EFC:$1,315,000 PU PERF GUN #2 9-5/8"@ 3480' MW: 0.0 NaCl CONT. DRLG CMT F/ 8075-8153, LD KELLY, REVERSE CIRC. AND FILTER BRINE, POH, RU WA E-LINE, PERFORATE 7970-7984 AT 4SPF, PU PERF GUN #2 DAILY:S28,147 CUM:$980,269 ETD:S980,269 EFC:$1,315,000 RECEIVED The above I.~"~ect slgnatur~.~~ ~ For form preparatlon~afi'(I distribution, ~ see Procedures Manj~al,~Section 10, Drilling, Pages 86 attiCS7. IDate/ AR3B-459-1-D INumber all dally' well history forms consecutively aa they are prepared for each well. jPage no. October 9, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-90098 Well: 2K-7 Field: Kuparuk Survey Date: 9/17/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copies have been sent to UNOCAL and BP EXPL. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures MICROFILMED '-- '~" -- - , -.. ~,-.' 8537 Corbin Drive (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. 2K-7 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -154.00 100 99.99 -54.01 200 199.98 45.98 300 299.96 145.96 400 399.95 245.95 0 0 0 53 0 56 1 8 0 58 N .00 E .00 .00 .00 S 45.70 W .89 .54S .56W S 31.90 W .23 1.78S 1.55W S 39.10 W .25 3.26S 2.61W S 36.00 W .19 4.72S 3.74W .00 -.68 -1.95 -3.35 -4.82 500 499.92 345.92 600 599.89 445.89 700 699.87 545.87 800 799.86 645.86 900 899.84 745.84 1 25 1 23 0 59 1 0 58 S 30.40 W .46 6.47S 4.87W S 34.40 W .10 8.54S 6.18W S 23.00 W .46 10.34S 7.20W S 19.10 W .08 11.98S 7.83W S 47.90 E 1.10 13.40S 7.50W -6.35 -8.15 -9.59 -10.62 -10.66 950 949.80 795.80 1000 999.63 845.63 1050 1049.23 895.23 1100 1098.58 944.58 1150 1147.61 993.61 3 15 5 55 8 30 10 0 12 23 S 75.20 E 4.86 14.05S 5.81W S 79.70 E 5.38 14.87S 1.91W S 81.30 E 5.20 15.89S 4.29E S 81.50 E 3.00 17.09S 12.24E S 83.40 E 4.84 18.35S 21.87E -9.20 -5.62 .11 7.49 16.49 1200 1196.19 1042.19 1250 1244.31 1090.31 1300 1292.10 1138.10 1350 1339.65 1185.65 1400 1386.84 1232.84 14 52 16 38 17 28 18 32 20 0 S 85.30 E 5.04 19.49S 33.60E S 88.10 E 3.85 20.26S 47.16E N 87.30 E 3.17 20.145 61.82E N 84.60 E 2.70 19.04S 77.24E N 83.00 E 3.12 17.25S 93.64E 27.54 40.46 54.67 69.86 86.18 1500 1480.01 1326.01 1600 1571.46 1417.46 1700 1660.23 1506.23 1800 1745.42 1591.42 1900 1827.75 1673.75 22 35 25 6 29 40 33 27 35 39 N 82.60 E 2.58 12.69S 129.68E N 81.20 E 2.58 6.97S 169.70E N 79.40 E 4.63 .83N 215.02E N 78.70 E 3.81 10.79N 266.40E N 80.80 E 2.50 20.85N 322.21E 122.19 162.35 208.16 260.39 316.92 2000 1907.48 1753.48 2100 1984.70 1830.70 2200 2060.15 1906.15 2250 2097.49 1943.49 2300 2134.88 1980.88 38 35 40 16 41 47 41 35 41 36 N 82.80 E 3.18 29.43N 381.94E N 82.40 E 1.70 37.61N 444.93E N 76.70 E 4.03 49.56N 509.43E N 74.20 E 3.35 57.91N 541.61E N 71.70 E 3.32 67.64N 573.34E 376.87 439.87 505.29 538.53 571.69 2400 2207.74 2053.74 2500 2277.95 2123.95 2600 2347.32 2193.32 2700 2416.38 2262.38 2800 2485.43 2331.43 44 50 45 57 46 11 46 27 46 11 N 72.40 E 3.27 88.73N 638.49E N 72.80 E 1.16 l10.02N 706.43E N 73.50 E .55 130.90N 775.36E N 74.00 E .45 151.13N 844.80E N 74.60 E .51 170.71N 914.42E 640.0'6 711.18 783.16 855.46 927.77 ARCO ALASKA, INC. 2K-7 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA 9/22/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 2900 2554.32 2400.32 3000 2622.68 2468.68 3100 2690.61 2536.61 3200 2758.54 2604.54 3300 2826.84 2672.84 46 43 47 2 47 22 47 3 46 48 3400 2895.18 2741.18 46 58 3500 2963.92 2809.92 46 10 3600 3033.12 2879.12 46 15 3700 3102.07 2948.07 46 32 3800 3170.83 3016.83 46 34 3900 3239.40 3085.40 4000 3307.96 3153.96 4100 3376.55 3222.55 4200 3445.04 3291.04 4300 3513.38 3359.38 4400 3583.25 3429.25 4500 3656.10 3502.10 4600 3730.24 3576.24 4700 3804.43 3650.43 4800 3878.64 3724.64 4900 3952.86 3798.86 5000 4027.11 3873.11 5100 4101.34 3947.34 5200 4175.58 4021.58 5300 4249.87 4095.87 PAGE 2 46 50 46 35 46 47 46 44 47 2 DATE OF SURVEY: 9-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 44 17 42 9 42 8 42 4 42 7 N 75.40 E .79 189.46N 984.43E N 76.30 E .73 207.31N 1055.21E N 77.20 E .74 224.12N 1126.63E N 78.20 E .80 239.76N 1198.34E N 74.10 E 3.01 257.23N 1269.24E 1000.25 1073.24 1146.59 1219.91 1292.93 N 74.10 E .16 277.23N 1339.45E N 75.20 E 1.13 296.46N 1409.48E N 74.70 E .37 315.21N 1479.20E .N 74.70 E .29 334.32N 1549.05E N 74.40 E .22 353.66N 1619.04E 1365.92 1438.53 1510.73 1583.15 1655.75 42 1 42 5 42 2 42 4 41 58 N 74.50 E .29 373.17N 1689.16E N 74.40 E .27 392.69N 1759.30E N 74.60 E .26 412.14N 1829.42E N 74.40 E .16 431.61N 1899.63E N 74.80 E .42 450.99N 1970.02E 1728.53 1801.32 1874.09 1946.94 2019.94 5400 4324.24 4170.24 41 56 5500 4398.70 4244.70 41 48 5600 4473.30 4319.30 41 42 5700 4547.86 4393.86 41 52 5800 4622.40 4468.40 41 43 N 73.80 E 2.83 470.34N 2038.88E N 73.80 E 2.14 489.44N 2104.64E N 73.50 E .20 508.33N 2169.03E N 73.30 E .15 527.49N 2233.28E N 73.50 E .14 546.64N 2297.53E 2091.46 2159.91 2227.00 2294.01 2361.01 5900 4697.07 4543.07 6000 4771.92 4617.92 6100 4847.06 4693.06 6200 4922.37 4768.37 6300 4997.49 4843.49 N 73.30 E .16 565.78N 2361.74E N 73.40 E .09 584.98N 2425.93E N 73.30 E .08 604.17N 2490.12E N 73.30 E .02 623.42N 2554.29E N 73.00 E .22 642.83N 2618.35E 2427.98 2494.94 2561.90 2628.85 2695.75 N 73.50 E .34 662.10N 2682.37E N 75.80 E 1.54 679.76N 2746.73E N 75.60 E .17 696.21N 2811.26E N 75.50 E .19 712.84N 2875.79E N 75.60 E .16 729.48N 2940.34E 2762.56 2829.29 2895.89 2962.52 3029.18 41 39 41 25 41 7 41 9 41 27 N 75.40 E .15 746.13N 3004.74E N 75.40 E .23 762.85N 3068.92E N 75.40 E .30 779.48N 3132.76E N 75.40 E .03 796.06N 3196.43E N 75.10 E .35 812.87N 3260.26E 3095.70 3162.02 3227.99 3293.79 3359.80 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-7 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH DATE OF SURVEY: 9-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6400 5071.09 4917.09 43 44 N 74.20 E 2.37 830.79N 3325.51E 3427.46 6500 5143.63 4989.63 43 15 N 73.50 E .68 849.94N 3391.63E 3496.27 6600 5216.66 5062.66 42 55 N 73.10 E .44 869.57N 3457.06E 3564.54 6700 5290.10 5136.10 42 33 N 72.20 E .71 889.80N 3521.84E 3632.34 6800 5364.01 5210.01 42 7 N 71.80 E .52 910.61N 3585.90E 3699.58 6900 5437.89 5283.89 42 37 N 71.50 E .55 931.83N 3649.87E 3766.84 7000 5511.39 5357.39 42 45 N 71.20 E .24 953.52N 3714.11E 3834.49 7100 5585.04 5431.04 42 22 N 70.90 E .42 975.48N 3778.08E 3901.95 7200 5658.87 5504.87 42 27 N 70.90 E .07 997.55N 3841.82E 3969.20 7300 5732.59 5578.59 42 32 N 70.30 E .42 1019.99N 3905.55E 4036.54 7400 5806.38 5652.38 42 20 N 69.70 E .45 1043.08N 3968.97E 4103.75 7500 5880.19 5726.19 42 31 N 69.70 E .17 1066.49N 4032.25E 4170.90 7600 5954.26 5800.26 41 53 N 69.50 E .64 1089.90N 4095.22E 4237.75 7700 6028.70 5874.70 41 53 N 71.70 E 1.47 1112.08N 4158.19E 4304.29 7800 6103.20 5949.20 41 49 N 75.70 E 2.67 1130.80N 4222.20E 4370.96 7900 6177.86 6023.86 41 34 N 78.90 E 2.14 1145.42N 4287.07E 4437.42 8000 6253.28 6099.28 40 30 N 79.10 E 1.08 1157.95N 4351.53E 4502.94 8100 6329.31 6175.31 40 30 N 79.10 E .02 1170.23N 4415.31E 4567.75 8200 6405.34 6251.34 40 30 N 79.10 E .02 1182.52N 4479.10E 4632.56 8300 6481.37 6327.37 40 30 N 79.10 E .02 1194.80N 4542.89E 4697.38 8310 6488.97 6334.97 40 30 N 79.10 E .20 1196.03N 4549.26E 4703.86 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4703.86 FEET AT NORTH 75 DEG. 16 MIN. EAST AT MD = 8310 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 75.27 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-7 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -154.00 1000 999.63 845.63 2000 1907.48 1753.48 3000 2622.68 2468.68 4000 3307.96 3153.96 .00 .00 .00 14.87 S 1.91 W .37 .37 29.43 N 381.94 E 92.52 92.16 207.31 N 1055.21 E 377.32 284.80 392.69 N 1759.30 E 692.04 314.72 5000 4027.11 3873.11 6000 4771.92 4617.92 7000 5511.39 5357.39 8000 6253.28 6099.28 8310 6488.97 6334.97 584.98 N 2425.93 E 972.89 280.85 762.85 N 3068.92 E 1228.08 255.19 953.52 N 3714.11 E 1488.61 260.52 1157.95 N 4351.53 E 1746.72 258.11 1196.03 N 4549.26 E 1821.03 74.31 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-7 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH 0 .00 54 54.00 154 154.00 254 254.00 354 354.00 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE -154.00 .00 .00 .00 -100.00 .08 S .08 W .00 .00 1.15 S 1.14 W .01 100.00 2.54 S 2.04 W .03 200.00 4.08 S 3.28 W .05 VERTICAL CORRECTION .00 .01 .01 .02 454 454.00 554 554.00 654 654.00 754 754.00 854 854.00 300.00 5.51 S 4.30 W .06 .02 400.00 7.62 S 5.55 W .09 .03 500.00 9.60 S 6.87 W .12 .03 600.00 11.21 S 7.56 W .14 .02 700.00 12.86 S 8.02 W .15 .02 954 954.00 1054 1054.00 1156 1154.00 1260 1254.00 1365 1354.00 800.00 14.11 S 5.55 W .21 .06 900.00 16.00 S 5.01 E .82 .61 1000.00 18.51 S 23.27 E 2.54 1.72 1100.00 20.35 S 50.06 E 6.12 3.58 1200.00 18.57 S 82.06 E 11.15 5.03 1471 1454.00 1580 1554.00 1692 1654.00 1810 1754.00 1932 1854.00 1300.00 14.05 S 119.16 E 17.92 1400.00 8.19 S 161.70 E 26.76 1500.00 .20 N 211.59 E 38.87 1600.00 11.90 N 271.96 E 56.29 1700.00 23.80 N 341.17 E 78.52 6.77 8.84 12.11 17.42 22.23 2059 1954.00 2191 2054.00 2325 2154.00 2465 2254.00 2609 2354.00 1800.00 34.17 N 419.15 E 105.77 1900.00 48.35 N 504.10 E 137.77 2000.00 73.03 N 589.74 E 171.76 2100.00 102.70 N 682.77 E 211.55 2200.00 132.87 N 782.04 E 255.65 27.25 32.00 33.99 39.79 44.10 2754 2454.00 2899 2554.00 3045 2654.00 3193 2754.00 3339 2854.00' 2300.00 161.98 N 882.82 E 300.58 2400.00 189.38 N 984.10 E 345.53 2500.00 215.24 N 1087.92 E 391.98 2600.00 238.76 N 1193.56 E 439.34 2700.00 265.16 N 1297.07 E 485.69 44.93 44.95 46.45 47.35 46.35 3485 2954.00 3630 3054.00 3775 3154.00 3921 3254.00 4067 3354.00 2800.00 293.82 N 1399.48 E 531.67 2900.00 320.97 N 1500.24 E 576.20 3000.00 348.88 N 1601.91 E 621.51 3100.00 377.34 N 1704.17 E 667.34 3200.00 405.76 N 1806.27 E 713.06 45.98 44.53 45.31 45.83 45.72 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA, INC. 2K-7 - KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4213 3454.00 3300.00 4358 3554.00 3400.00 4497 3654.00 3500.00 4632 3754.00 3600.00 4766 3854.00 3700.00 434.17 N 1908.80 E 759.07 46.01 462.32 N 2010.88 E 804.72 45.65 488.91 N 2102.81 E 843.17 38.44 514.44 N 2189.64 E 878.04 34.88 540.31 N 2276.17 E 912.79 34.75 4901 3954.00 3800.00 5036 4054.00 3900.00 5170 4154.00 4000.00 5305 4254.00 4100.00 5440 4354.00 4200.00 566.08 N 2362.73 E 947.53 34.74 591.92 N 2449.21 E 982.24 34.71 617.83 N 2535.63 E 1016.92 34.68 643.91 N 2621.90 E 1051.55 34.62 669.69 N 2708.01 E 1086.01 34.46 5574 4454.00 4300.00 5708 4554.00 4400.00 5842 4654.00 4500.00 5976 4754.00 460-0.00 6109 4854.00 4700.00 691.94 N 2794.60 E 1120.15 34.14 714.22 N 2881.12 E 1154.25 34.10 736.49 N 2967.63 E 1188.34 34.09 758.86 N 3053.62 E 1222.11 33.77 781.00 N 3138.62 E 1255.21 33.10 6242 4954.00 4800.00 6376 5054.00 4900.00 6514 5154.00 5000.00 6650 5254.00 5100.00 6786 5354.00 5200.00 803.04 N 3223.20 E 1288.02 32.81 826.34 N 3309.77 E 1322.34 34.33 852.71 N 3400.99 E 1360.24 37.90 879.70 N 3490.23 E 1396.96 36.72 907.79 N 3577.29 E 1432.50 35.53 6921 5454.00 5300.00 7057 5554.00 5400.00 7193 5654.00 5500.00 7329 5754.00 5600.00 7464 5854.00 5700.00 936.54 N 3663.93 E 966.21 N 3751.31 E 996.09 N 3837.61 E 1026.62 N 3924.05 E 1058.16 N 4009.73 E 1467.90 35.40 1503.97 36.07 1539.40 35.43 1575.06 35.66 1610.47 35.42 7599 5954.00 5800.00 7733 6054.00 5900.00 7868 6154.00 6000.00 8000 6254.00 6100.00 8132 6354.00 6200.00 1089.82 N 4095.00 E 1645.65 35.18 1118.92 N 4179.80 E 1679.97 34.32 1141.35 N 4266.30 E 1714.10 34.13 1158.07 N 4352.13 E 1746.95 32.85 1174.22 N 4436.03 E 1778.48 ,31.53 8264 6454.00 6300..00 8310 6488.97 6334.97 1190.38 N 4519.93 E 1810.01 31.53 1196.03 N 4549.26 E 1821.03 11.02 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-7 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3480 2950.07 2796.07 292.78 N 7835 6129.28 5975.28 1136.56 N 7849 6139.72 5985.72 1138.87 N 7902 6179.36 6025.36 1145.68 N 8000 6253.28 6099.28 1157.95 N 1395.53 E 9 5/8" CSG 4244.82 E TOP KUPARUK C 4253.86 E BASE KUPARUK C 4288.37 E TOP KUPARUK A 4351.53 E SURVEY DEPTH 8065 6302.70 6148.70 1165.94 N 8285 6469.96 6315.96 1192.96 N 8285 6469.96 6315.96 1192.96 N 8310 6488.97 6334.97 1196.03 N 4392.99 E BASE KUPARUK A 4533.32 E 7" CSG 4533.32 E PBTD 4549.26 E TD ARCO ALASKA, INC. 2K-7 STRATIGRAPHIC SUMMARY BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 146FSL 94FEL SEC 02 T10N R08E 9 5/8" CSG 3480 2950.07 2796.07 292.78N 1395.53E TOP KUPARUK C 7835 6129.28 5975.28 1136.56N 4244.82E BASE KUPARUK C 7849 6139.72 5985.72 1138.87N 4253.86E TOP KUPARUK A 7902 6179.36 6025.36 1145.68N 4288.37E BASE KUPARUK A 8065 6302.70 6148.70 1165.94N 4392.99E 7" CSG 8285 6469.96 6315.96 1192.96N 4533.32E PBTD 8285 6469.96 6315.96 1192.96N 4533.32E TD 8310 6488.97 6334.97 1196.03N 4549.26E mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE DATE OF SURVEY: 9-17-89 COMPUTATION DATE: 9/22/89 JOB NUMBER: AK-BO-90098 KELLY BUSHING ELEV. = 154.00 FT. 2K-7 KUPARUK ALASKA 9-17-89 eooo SO00' 4000 ~.J ~) aO0O 2000 1000 SPERF[Y-SUN HORTZONTAL DRL G.""' S VCS. PROJECTTON START FINISH TVD = SCALE IS 1000 TVD = 0 6488.97 FEET/IN 8310 10~)0 oobo DEPARTURE ~obo soho soho SPERE ~-SUN DRLG. SVCS. 2K-7 KUPARUK ALASKA 9-17-89 VERTICAL PROJECTION START TVD = 0 FINISH TVD = 6488.97 SCALE IS 1000 FEET/IN 1000 2000 0000 4000 $000 0000 7000 8310 4.703.86 1oho ~obo soho VERTICAL SECTION DZRECTZON = O. O0 soho 0000 l. oc~ttonl See '.~. e,ing Set .... :. .-.- Free,urn After Clooara.~5~_ pelt .... . ........ Chok, ~ina Veivae~=~ .... ~~ ..... Choke }tao/~old ~a.t ' ~ ' , , . , . . ,j,. 4iQ, - Jg~etvjLeoc 31:nl~pectet:~ ..... :. _ .... ._ . .,. · ': , !~"-'~SKA OIL AND GAS CONSERVATION COlt ',SION · APPL, ATION FOR SUNDRY APPROVALS0 G N 1 Type of Request: Abandon _ Suspend _ Operation Shutdown X Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance Perforate Other _ 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 146' FNL, 94' FWL, Sec. 2, T10N, R8E, UM At top of productive interval 1309' FSL, 1218 FWL, Sec. 1, T10N, R8E, UM (approx) At effective depth 1373' FSL, 847' FWL, Sec.1 T10N, R8E, UM At total depth 1376' FSL, 832' FWL, Sec. 1, T10N, R8E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 8310' 6490' 8285' 6470' 5. Type of Well' Development Exploratory Stratigraphic Service (approx) (approx) feet Plugs (measured) feet None feet Junk (measured) feet None 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 2k-7 9. Permit number 89-71 10. APl number 5o-1 03-201 07 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 8 O' Surface 344 5' Intermediate Production 825 2' Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth (approx) 179 Sx AS I 115' 115' 900 Sx AS III & 3480' 2994 650 Sx Class G 328 Sx Class G 8285' 6470' RECEIVED AUG 2 5 )989 AJaska 0ii & Gas Cons. Commission :Anchorage 13. Attachments Description summary of proposal _ Detailed operation program ~X BOP sketch 14. Estimated date for commencing operation October. 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil X Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed F~ ~ ~_-~~z~V/' Title Area Drilling Engineer ~' FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 Approved C.opy Returnect 10-4~P Commissioner IApproval Nog.....~ ~,~ _ SUBMIT IN TRIPLICATE ARC° uil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rap~d" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District ARCO ALASKA INC. KUPARUK RIVER FIELD ICounty,parish or borough NORTH ~LOPE Lease or Unit ADL: 25588 AKL: 2674 Title DRILLING Field Auth, or W,O. no, AK3625 2K-7 IWell no. Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 07/12/89 ( TD: 0'( SUPV:JR 07/13/89 ( TD: 2434'( 2 SUPV:LP 07/14/89 ( TD: 3500'( 1 SUPV:LP 07/15/89 ( TD: 4345'( SUPV:LP 07/16/89 ( TD: 7507'( 3 SUPV:LP 07/17/89 ( TD: 7600'( SUPV:LP ... J Oate 07/12/89 IH°ur 08:30 Complete record for each day reported DOYON 14 ) 0) ) i34) ~) ,66) ) 45) ) 62) ) 93) IARCO W.i. 55,8533 Prior status if a W,O, RU, PREP TO SPUD WELL MW: 0.0 VIS: ACCEPT RIG 0300 7-12-89,NU SURFACE STACK, RISER, FLOWLINE & DIVERTER LINES, TAKING ON WATER FOR SPUD MUD. DAILY:S19,400 CUM:$19,400 ETD:S19,400 EFC:$1,315,000 CIRC BU FOR TOH MW: 9.0 VIS: 76 MU BHA AND ORIENT SAME,CHK DIVERTER AND FILL HOLE,FIX LEAK IN DIVERTER VALVE, DRILL 115-2434,CIRC BTMS UP FOR TOH TO CHG BHA. DAILY:S46,473 CUM:$65,873 ETD:S65,873 EFC:$1,315,000 RUN 9-5/8" CASING MW: 9.2 VIS: 63 CIRC BU & DROP SINGLE SHOT, TOH, TITE @ 1770,STAND BACK BHA, LD NAVI,BENT SUB,& BIT, PU DTU, TIH, TITE @ 1770,DRILL 2434-2949,REPAIR WASHED OUT STANDPIPE,DRILL 2949-3500,MWD SURVEY, CIRC & COND HOLE, SHORT TRIP TO HWDP,TITE g 1700,NOT BAD, CIRC & COND, GOT ALOT OF COAL BACK FROM TITE SPOT, DROP SINGLE SHOT, TOH;LD BHA, RIG UP & RUN 9-5/8" CSG. DAILY:S63,347 CUM:$129,220 ETD:S129,220 EFC:$1,315,000 DRILLING 8-1/2" HOLE 9-5/8"g 3480' MW: 8.7 VIS: 32 FINISH RUNNNING 9-5/8" CSG, RU DOWELL, CIRC 1-1/2 CSG VOLUMES,RETURNS CLEAN, CIRC 80 BBLS WATER, 311 BBLS AS III,133 BBLS CLASS G, DISPLACE W/ WATER, FULL RETURNS, BUMP PLUG TO 2000 PSI,FLOATS HELD,NO CMT TO SURF,ND DIVERTER,DO TOP JOB,NU BOP STACK, TEST SAME, INSTALL WEAR BUSHING, PU TURBINE,PCD BIT & BHA, TIH, DRILL OUT TO ABOVE SHOE, TST CSG TO 2000 PSI,DRILL SHOE & 10' NEW HOLE,DO LOT TO 12.5 PPG EMW, DRILL AHEAD 3510-4345. DAILY:S208,677 CUM:$337,897 ETD:S337,897 EFC:$1,315,000 DRILLING 8-1/2" HOLE 9-5/8"@ 3480' MW:10.6 VIS: 38 DRILLING AND SURVEYING, 4345-7507,WEIGHT UP MUD SYSTEM FOR DRILLING INTO KUPARUK. DAILY:S47,261 CUM:$385,158 ETD:S385,158 EFC:$1,315,000 STAGE IN HOLE,CIRC 9-5/8"@ 3480' MW:10.0 VIS: 44 DRILL 7507-7600,CIRC/COND,DO OPEN HOLE LOT TO 11.1 PPG, TOH, PU ROTARY BHA, TIH TO SHOE,CIRC,CUT LINE, TIH, TITE SPOTS 4400,5300,6350,6640,CIRC & REAM THRU 7544 -7587,PACK OFF,LOST CIRC,PULL TO 7481,NO RETURNS,MIX LCM, CUT MW TO 10.0 FROM 10.6, SPOT 100 BBL LCM PILL, HOLE STABILIZED,NO RETURNS DURING SPOTTING, TOH TO SHOE,CIRC 10.0 AROUND, BIT PARTIALLY PLUGGED,TOH, CHG JETS TO 3-16'S,TIH TO SHOE CIRC,TIH, HOLE STABLE. DAILY:S72,134 CUM:$457,292 ETD:S457,292 EFC:$1,315,000 The above is correct sign ur For form prepar~a~ and distribut~%,.~ see Procedure(~lanual, Section 10, Drilling, Pages 8'6 and 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field ARCO ALASKA INC. StateAK County or Parish ] NORTH SLOPE LeaseorUnit ' KUPARUK RIVER FIELD [ ADL: 25588 AKL: 2674 2K-7 Date and depth as of 8:00 a.m. 07/18/89 ( TD: 8074'( SUPV:LP 07/19/89 ( TD: 8150' ( SUPV:LP 07/20/89 ( TD: 8310'( SUPV:JR Complete record for each day while drilling or workover in progress DOYON 14 7) 474) 8) 76) 9) 160) TOH FOR WASHOUT 9-5/8"@ 3480' MW:10.6 VIS: 40 TIH TO 4980,CBU,REAM TITE HOLE 5042-5150,TIH TO 6300,CIRC 10.1 AROUND,TIH TO 7500,REAM 7500-7600,DO OPEN LOT TO 11.1 PPG EMW, DRILL 7600-7708,CIRC 1 HOLE VOLUME,DRILL 7708-8074,LOST 500 PSI,SLOW PUMP & CIRC, TOH LOOKING FOR WASHOUT, SWAB HOLE,RUN BACK TO BTM, CIRC & ROTATE PIPE,TOH, FORCE FILL PIPE EVERY 5 STDS. AFTER REPORT TIME,FOUND WASHOUT 18 STDS OUT, TIH. DAILY:S54,147 CUM:$511,439 ETD:S511,439 EFC:$1,315,000 LOGGING W/SOS 9-5/8"@ 3480' MW:10.7 VIS: 40 POH F/WASHOUT,FOUND WASHOUT 17 STDS OUT, RIH, DRILL F/8074-8081,CIRC OUT GAS CUT MUD,DRILL F/8081-8150, SHORT TRIP TO CSG SHOE, RIH, WASH & REAM F/8105- 8150, CIRC HOLE CLEAN, DROP SS SURV, SPOT DIESEL PILL, POH STAND BACK DP, RU SOS, RIH TO LOG OPEN HOLE DAILY:S48,762 CUM:$560,201 ETD:S560,201 EFC:$1,315,000 POOH LDDP 9-5/8"@ 3480' MW:10.7 VIS: 42 FINISH LOGGING WITH TRIPLE COMBO. R/D SCHLUMBERGER. M/U BHA AND TRIP IN HOLE BREAKING CIRC AT 3450, 5500, & 7500. REAM AND WASH FROM 8063-8150. DRILL FROM 8150-8169. REAM FROM 8138-8169. DRILL FROM 8169-8310. CIRC HOLE CLEAN. SHORT TRIP 20 STANDS TO 6400', NO PROBLEM, TIH. CIRC AND COND HOLE. PUMP AND SPOTL DIESEL PILL. POOH LDDP. DAILY:S153,425 CUM:$713,626 ETD:S713,626 EFC:$1,315,000 Well no. For for~n and distributio,~'i see Procedures l~lnual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number ail daily well history forms consecutively as they are prepared for each well. Page no. ARC~- .)il and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not require(~ upon completion, report completion and representative test data in blocks provideO. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code Auth. or W.O, no, AK3625 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. District ICounty or Parish State .a~CO ALASKA INC. I NORTH SLOPE AK Fietd ILease or Unit I Well no. KUPARUK RIVER FIELD I ADL: 25588 AKL: 2674 2K-7 I Title I DRILLING Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data IA.R.Co. W.I. 55.8533 IOate 07/21/89 Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this cst center prior to plugging and ~ bandonment of this well I our I Prior status if a W,O. I 08:30 07/21/89 ( 1 TD: 8310 PB: SUPV:JR RIG RELEASED TO 2K-9 9-5/8"@ 3480' MW:10.7 NACL/BR CONT. POH LDDP, RU & RIH W/211 JTS 7" CSG, BREAK CIRC. AT SHOE, CONT. RIH TO TD, RU DOWELL, PUMP 10 BBL CW100, 20BBLS SPACER 3000, 328 SKS CL "G" CEMENT W/ADDITIVES, DISPLACE W/319 BBLS 10.6 BRINE, DID NOT BUMP PLUG, FULL RETURNS, DIDNOT MOVE PIPE, FLOATS HELD, RD DOWELL, ND BOPE STACK, SET SLIPS, INSTALL PACKOFF, NU TREE, TEST TREE, CLEAN PITS, RELEASE RIG AT 0430 7/21/89 DAILY:S201,390 CUM:$915,016 ETD:S915,016 EFC:$1,315,000 New TO I PB Depth Date IKInd of rig Type completion (single, dual, etc.) Official reservo r name(s) Well no. I Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct ;:,;, ,o rm preparing, see ~rr~e~ual, Se;ti;n AR3B-459-3-C INumber all daily well history forms consecutively I Page no. as they are prepared for each well. Dl'~l~lon of AtlentlcRIchfleldCompan¥ ARCO Alaska, Inc. Date: July 28, 1989 Transmittal #: 7527 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-07 2" & 5" Porosity FDC 7-1 9-89 3480,-81 04 ;~'K-07 , 2",.'&~5"~w,FD'C . . 7-19-89. 348,0-8104 · ~ K-'0 7: '2"'Dual ~induction' SF.L "- '~ "'7- 1 9.8-9 . 1 0 00- 81 3'0 2K-07 5" Dual Induction '- SFL 7-1 9-89 1 000-8130 2K-07 Cyberlook 7-1 9-89 7700-8080 Receipt Acknowledged: DISTRIBUTION; NSK Drilling Franzen D&M State of Alaska(+sepia) L. Johnston(vendor package) ARCO Alaska, Inc. Date: July 28, 1989 Transmittal #: 7526 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this' transmittal. 2 K - 0 7 OH LIS Tape and Listing 7 - 2 4 - 8 9 # 7 3 4 0 4 · , . Receipt Acknowledged: DISTRIBUTION: State of Alaska Craig Suchland M EMORAN D,.,.M State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C. Smitl~r.~ D^TE: July 10, 1989 Comni s8 ioner [~LE NO: D. BDF. 074 THRU: FROM: TELEPHONE NO: Mi ehae I T. Mi rider/~'~'~'~/. SUBJEC'~ Sr. Petroleum Engineer Bobby D. Fostert~,~''~'' Petrole,mn Inspector .. ': Diverter Inspection AAI KRU ~.K-7 Permit No. 89-71 Kuparuk Rv Fie ld ~dnesday, July 12, 1989, I traveled this date to Arco's 2K and [~~bd::(h~'~:i~:{~~stem which was installed in a manner approved by t he AOGCC. . Ail valves were installed and hooked up to the hydraulic system properly, all turns were 90° and targeted and the lines bifurcating were secured to prevent movement, The system was not function tested because the'" rig was drilling when I arrived on the location. / In summary, I inspected the diverter system 'on Arco's 2K-7. · 02-001A (Rev. 8~85) ' · M,EMORAND M State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO:" Loimie C. Smit~ '~ DATE: July 19, 1989 Co~i s s i one r F~LE NO: D. BDF. 076 THRU: TELEPHONE NO: Michael T. l~linder~g, .~ Sr, Petroleum Engineer BOP Test AAI KRU 2K-7 Permit No. 89-71 Kuparuk Rv FieId FROM: Bobby D, Fos t er I ~;.;;'-~ Petroleum Inspector Friday, July 14, 1989, T_vie test began at 3:15 pm and was concluded at ~.~-0-~ '-' AS--t-h~'~~hed BOP inspection report shows there was on failure which was repaired and tested. In summary, I witnessed the BOP Test on Arco's 2K-7. Attachment 02-001A (Rev. 8~85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Inspector / ~ ~',~"r}~e d /- V \ wv '~;.=. (~, % J~/ -: ~ ,,/ Operator ~ / [~ Well ~' /~ ~- Location (general) ~ Well sign General housekeeping ~' Rig ,.~ Reserve p~ Rig # DATE ft psig psig Representative _~% Permit# Casing set / L~ Rep /~./~.~/~/ ACCUMULATOR SYSTEM: Full charge pressure Press after closure MUD SYSTEMS: Visual Trip tank ~'~" ~it gauge ~'~ Flow monitor ~'"'"' Gas detectors '/'/: Audio BOPE STACK: Test Pressure Annul ar preventer Pi pe rams B1 ind rams Choke line valves HCR valve Kill line valves Check valve Pump incr clos press 200 psig Full charge press attained mi n ~, ~'3 sec ~'" mi n /--, sec ~-00..~-~-'/0 ~ psig. Controls: Master Remote Blind switch cover~ .... KELLY AND FLOOR SAFETY VALVES: Upper Kelly J Test pressure Lower Kelly J Test pressure ... Ball type / Test pressure Inside BOP / Test pressure Choke manifold ?~._ ~ Test pressure .~., .... Number valves / ,: Number flanges S C) Adjustable chokes Hydraulically operated choke TEST RESULTS: Remarks/: / Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. days Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector June 30, 1989 Telecopy: (907)276-7542 Patrick J, Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupa~k River Unit 2K- 7 ARCO Alaska, Inc. Pe~tt No. 89-71 Sur. Loc. 146' FSL, Btmhole Loc. 1381 'FSL, 94'FEL, Sec. 2, T10N, RSE, UM. 899'FEL, Sec. 1, T10N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced Well. The permit to drill does not exempt you from obtaining additional p~mits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe~itting determinations are made. To aid US in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness, testing of the equipment before the surface casing shoe is drilled. !6~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~ truly yo~urs, Chairman of / Alaska Oil and Gas Conservation Commission BY O~ER OF ~E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o ~ncl. STATE OF ALASKA ALASK,,-, ,.)IL AND GAS CONSERVATION L,..,MMISSION PERMIT TO DRILL 20 AAC 25.005 Drill ~ Redrill--I lb. Type of well. Exploratory ~ DeVelopment Oil ~ Re-Entry - Deepen la. Type of work Stratigraphic Test~ ~ Service - Developement Gas ~_ Single Zone ~ Multiple Zone [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0o Box 100360 Anchorage, AK 99510-0360 5. Datum Elevation (DF or KB) :KB 154, PAD 118'GL feet 6. Property Designation ADL 25588 ALK 267/+ 10. Field and Pool uparuk River Field uparuk River 0il Pool 4. Location of well at surface 1/+6' FSL,94 ' FEL,Sec. 2 ,T1 0N, R8E,UM At top of productive interval((~ t a r g e t ) 1320' FSL,1120' FEL,$ec. 1 ,T10N,R8E,UM At total depth 1381 'FSL, 899'FEL,Sec.1,T10N,R8E,UM 12. Distance to nearest ~ 13. Distance to nearest well property line 12K'6 Conductor 899' (~ 'ID feet 25' ~. surf~(;e feet: 16. To be completed for deviated wells Kickoff depth 900 feet Maximum hole angle 440 7. Unit or property Name Kuparuk River Unit 8. Well number 2K-7 .. 9. Approximate spud date 07/01/89 11. Type Bond (see 20 AAC 25.025) Statewi de Number #U630610 Amount $200,000 14. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1 6 6 6 psig At total depth (TVD) 2944 15. Proposed depth (MD and TVD) 8216'MD 63~)2 'TVD feet psig 18. Casing program size Specifications Hole Casing Weight GradelCouplingI b 2':" IE" ',',2 . 5# ,.__0# ,';-;.;, I. 8-1/2" 7" .~ngth 80' !339' ~182' Setting Depth Top Bottom 35' c, , ;_;, I ! 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Quantity of cement TVD (include stage data) 6292' 750 ~m...A$ !!! & , RR~ ~x ~la~ C 200 sx Class G tail of G 500' above KT~aruk Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth RECEIVED 2 8 Alaska 0ii & Gas Cons. Anchorage 20. Attachments Filing fee [] Property plat ~ BOP Sketch 1~ Diverter Sketch ~ Drilling program ~ Drilling fluid program [] Time vs depth plot ,~ Refraction analysis [] Seabed report ,ri 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed p ~- ~~ TitleArea Drilling Engineer Date ~'/?'//'¢:~' Commission Use Only TWM/JTP: PD1/4 Permit Number ! APl number Approval date I See cover letter ~'- ",Z/ I 50--/0~-.~_0/~7 06/30/89 I forotherrequirements Conditions of approval Samples required ~ Yes ~' No Mud log requ~.re.d [] Yes '~No Hydrogen sulfide.measures [] Yes ,$;~No Directional survey required ,~ Yes [] No~ Required working pr~..~sure for BJ3PE~ ' · [] 5M; [] 10M; [] 15M Other: //,~'-~/~//~~_. by order of Approved by( /... ~, ( ~'~,'~ Commissioner the commission Form 10-401 Re"V:-t2-1.8~ ' ~" / Sub~it i¢'tripl'icate 'ARCO ALASKA, !no ._ Ped 2K. 14ell No: 7 Revleed Propoeal Kuparuk Field. North Slope, Aleeka 0 . RKB ELEVA?~O#~ 154' 1 000 ~ 2000 _ 3000 4000. 5000. 6000 _ ?000 KOP TVD-gO0 THD"'go0 DEP-O 3 BUILD 3 DEe PER lO0 FT 15 B/ PERHAFROST TVD-1424 THD-,1431 DEP-?3 21 T/ UGNU SNDS TVD-1544 THD-1557 DEP-112 3e T/ 1,/ SAK SNDS TVD-2172 THD-2292 DEP-485 EOC TVD-2241 THD-2386 DEP-550 B/ 14 SAK SNDS TVD-2744 THD-3Og3 DEP-1046 g 5/8' CSG PT TVD-2944 THD-:3374 DEP-1243 K-lO TVD-3194 THD-3725 DEP-1489 K-5 TVD-4635 THD-5748 DEP-2glO AVERAGE ANGLE 44 DEO 35 MI N T/ ZONE C TVD-6069 THD"??62 DEP-4323 T/ ZONE A TVD-6122 THD"7836 DEP-4376 TARGET CNTR TVD-6160 THD-?890 DEP-4413 B/ KUP SND$ TVD-6250 THD'8016 DEP'4502 TD (LOG PT) TVD-6392 THD-8216 DEP-4642 RECEIVED LION 2 8 t989 Alaska Oil & Gas Cons. Commission Anchorage t I' iI 0 1 000 2000 3000 VERTICAL SECT[ON 4000 5000 HORIZONTAL PROJECTION SCALE 1 IN. I 1000 FEET z SURFACE LOCAT I O#, 146' F~L, 94' FEL SEC. 2, 1'tON, RItE 3000 ,, 2000 . 1000 _ ~ 1000 _ ARCO ALASKA. ! ~e. Pmd 2K. Well Nom Z Revlmed Propom, l Kuperuk Field, Nor(h Slope, Alemke 1000 0 WEST-EAST 1000 2000 3000 N 74 DEO )4 I"IIN E 4412' (TO TARGET) 4000 5000 ! .. ! TD LOCAT [ ON, 1381' FSI.. 899' FEL SEC. 1. TION. RIlE TARGET CENTER TVD~,~I ~0 Tl'l)-?SgO DEP-4413 NORTH 117'4. EASt. 4254 TARGET LOCATIONs 1320' FSL, 1120' FEL SEC:. I. TI ON. RIlE 250 200 150 100 50 0 50 450 I 400 -~/~~ '~ 350 I I I 300 .~ '- ~ 250 . 200. 150. 100 _ 50 . soo ~1100 \ \ \ \ \ \ 900 \ \ \ \ "t JO0 ~°~900 ~. 500 ~'oo ° $00 ""'900 "~' 500 500 700 / / / ~ ~ 500 .~'~ 300/v2700 /2500 / / //2300 500 I ~mmmm IIII m u i ~1 mm m m mm mm~ mm ~m~mm m~ m I 2950- I I I ' i ' 250 200 ' ! i ' i 150 1 O0 50 0 i 450 I 400 350 300 _ 250 _ 200 .150 .100 .50 DRILLING FLUID PROGRAM Spud to 9 5/8" surface casing Drill out to weight up Weight up to TD Density 9.6-9.8 8.7-9.2 10.2 PV 15-30 5-1 5 11-1 6 YP 20-40 8-12 8-1 2 Viscosity 50-100 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 minute Gel 15-30 4-8 5-12 Filtrate APl 20 10-20 6 pH 9- 1 0 9.5-10.5 9.0-1 0.5 % solids 10+ 4 - 7 1 2-1 5 Drilling Fluid System' - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.0 ppg EMW and a gas gradient of of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. - There are no wellbores within 200' of this proposed well as it is the fifth well to be drilled on the pad. The first four wells are at least 75' away at the surface, which would be the closest point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid pumping. GENERAL DRILLING PBOCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack'and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. OEGASSER MUD CLEANER SHALE SHAKERS STIF STIR STIR CLEANER ~" ~a Oil & Oa~ C~ns Co~'~*~¢~sior TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC .I I. DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~D~N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL W/10' OUTLETS 5. 10' HCR BALL VALVES WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR ~ VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 20(X) PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSI~.M AS A VARIANCE FROM 20AAC25.~) MAINTENANCE & OPERATION 3 2 1.UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. Z CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO UNDER NOT SHUT IN WELL ANY CIRCUMSTANCES JG 4/26/88 7 6 DIAGRAM #1 1t-S/Be 5(:X)O PS]: ~ BCP STACli I. I~" - 20130 I="J! TaN(CO SI'aI~I'II~I~ ~ 2, II · - ~ laeJ! C~]I~ I.~ 3. II · - ~PmJ! X I:~" - SOI:IOI:~! Sl~ ~ 4, I~-S/a" - ~ I~S! PIPE ~ KZLL LII~:8 a, I;56/8- - SOO0 I~I ~ ~1 V~=I~ ~ 0~1 TCP, ACCLMJi_AT~ CAPACITY TEST I. O-ECl< ~ FILL LEVEL WITH HYIItN. LIC FLUII1 2. ~ THAT ACCLM. I.A~ ~ I~ ::)I(:X)O I1~! WITH I SO0 I~I ~TRF.4M ~ Tt.~ I~:GLLATOR. 3. CI~SERV~ Tllk~ TI-EN ~ ALL UI~T~ $IM.I. TN~I3JSLY A~ I~(~ ~ ?I1~ AM) ~ ~'IwlINI~ AFll~ 4. RI~COI~ 01~ NI43C I~l~o TI~ AC~A~I.~ LO~ LIMIT 5 4 1::~5/8' B4~ STACK TEST I. FILL IK~ ~I'AO( ~ 00~ MI/~FCLD WITH AI~IC DIESEL. 2. OEO( THAT ~ LOI~ ~ 9C:RLrIB IN MB.U.EAD FLLLY RE'r~ 5EAT TE~T PLUG IN WITH RI.J~IikG JT ~ ~ IN L(:X:XI:XIIIN LII~ V,N.V't.~ ~ TO ~ ~'I',N3(. ,N.I. 4. I=I~SSU~ LP TO ~ I=~ AN3 I. IID FI~ I0 t~N. I~- BLEED 1=~9,RE TO 0 I~I. 51 (X)~400 ( ARCO Alaska, inc. Posl Office Box. 'i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Conductor As-Built Location Plat- 2K Pad (Wells i - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the any questions, please call me at 263-4618. Sincerely, subject wells. If you have D. Martin Engineering Aide DM'hf Enclosure RECEIVED DEC1 .1988 Alaska Oil & Gas Cons. Comfnissio~ Ancl]orage GRU13/010 ARCO Alaska, Inc'. is a Subsidi.-3ry of AtlanlicRichfieldCnmp,3ny .. c~ ,--J WELLS 1-12 ARE LOCATED IN ,. ~- SECTION 2, T. I0 N., R. 8 E., ss 36 3, ~, t WELLS 15-7.4, ARE LOCATED IN i .. .~ I SECTION II,T. ION., R. 8 E., " i I UMIAT MERIDIAN. N.T.S. ~=3 ~ Z w"" SZCTffON ~, ~0:~I S~CTION I · D.S. 2K /- PROTRACTED Notes: _ VICINITY MAI3 I": ,. zo. 4. sEcrlo, ,, ~mCle SECtiON ~ ~. ALL DISTANC~ SHOWN ARE TRUE. . ~t i ~. ELEVATIONS ARE B.P.M.S.L. IZ~=[S 4. O.G. ELEVATIONS FROM CED- RIXX-3311, re~4. ~~ R[c[IV[~ 5. HORIZONTAL POSITION BASED ON 2-KCONTROL MONUMENTS PER ~NSBURY S A~OClATES. / DEC [ ]9 8 eOOK: ~ ~;~ , ,,, ~ Well ASp's ~l~s~:a Uii & ~ ~on~. ~,, .......... Dist. Dist. O.G. ~. 'Y' 'x' ~$~M~ ~NGITUDE F.S.L. EE.L. Elev. [ Elev. ~ ~ 5,a~8,eoo.~e ~ 49e,~0.~7 70°14'56.519' ~50°00'49.~5'' age' 94' ~4.0 I " 50" I ' I 15.9 2 5,938,575.14 498,310.28 70° 14' 36.273 150°00'49'1 8" 276' 3 5,938,550.30 498,310.35 70° 14' 36.029" 150°00'49.12 24 113.8 ~ " ' 36" I 4 5,938,525.46 498,310.06 70o14' 35.784 150°00 49.1 222' 113.8 5 5,938,500.19 498,310.12 70o14, 35.536" 150°00'49.1~4'' 196'. 113.8 . ~ 6 5,9~8,475.1~ 498,310.33 70o14' 35.289" 150°00'49.1~8" 17/' 115.8 ' 7 5,938~450.36 498,310.36 70o14'35.046'' 150°00'49.12~'' 146' 113.8 I II I I 8 5,938,425.30 498,310.18 70° !~, 34.799 150°00 49.132" 12~, !13.8 ~10 5,938,375.19 498,510.14 70°! 34.30 150°00'49.15 71' 113.9 , . " ~ I 13.9 I t 5,938,350.22 498,310 14 70°14'34 061 150°00'49.133" 46' 12 5,9~8,325.20 498,~10.17 70°14'33.815'' 150°00'49.131" 21' 94' 113.9 ~ 118.5 , FN.L. 13 5,938,235.31 498~310.37 70° 14' 32.930" 150 °00' 49.125'' 69' 94' 113.7 118.5 II , 14 5,938,210.14 498,310.16 70 ° 14' 32.683'' 150°00'49.131 94' 113.7 II ~5 5,938, ~85.1~ 498,3~0.~6 70°14' 32.4~7'' 150°00'49.131, 119' i 113.8 16 5,938,160.11 498,310.20 70Ol4'32.191'' ~ 150o00'49.130 144' 113.8 4' 46" ' 17 5,938~ 135.21 498,310.18 70°14, 31.9 150°00 49.130" 169' I 1~.9 18 5,938,110.19 ; 498,310.29 70°1 31.700" 1150000'49.127'' 194; 114.0 19 5,938,085.~0 498,310.27 70e14'31.454 ~ 150°00'49.127'' 21 1.14.0 20 5,938,060.14 498,5~0.22 70° 14' 31.207'' 150 o 00',49. 128'' 244' 114.1 22 5,938,010.40 498,~0.19 70°14'30.718;; 150o00 49.129" 294' 94' 114.0 ]23 5,937,985.32 ] 498,310.13 70 °14' 30.471 150°00'49.130" 319' 95' 114.0 i I I II i ..2.4 5~937~960.29 498,310.08 ~70°14 30.225 150°00 49.132" 344' ~ 95' 113.9 118.5 I HEREBY CERTIFY THAT ~ "'''' PROPERLY REGISTERED AND LICENSED,._~,", ~ _'"~'A,__ -. ~ ~ .~~,~Sk STATE OF ALASKA AND THAT /~ ~,,,,,,, ........... · ....... ~ ' BY ME OR UNDER M)' DIRECT SUPER- · DRILL SITE 2'K V S ON AND THAT ALL D MENS ONS CONDUCTOR AS-BUILTS AND OTHER DETAILS ARE CORRECT 96 ~ ".. ~. 8~ , , ~,, , ,,~ .......... , ............. Well ASp's Ala'si:a Uii & Ga:s Oo~'~,. -L;O;", m;3s:u:: Dist Dist. O.G. ' Pod No. 'Y' 'X' L~t;~tU~ LONGITUDE F.S.L F.E.L. Elev. Elev. I 5,938,600. 18 498,310.17 70° 14'36.519 " 150°00'49.155" 296' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.27:3" 150°00'49.150" 271' 113.9 3 5,938,550.30 498,310.35 70° 14-' 36.029" 150°00'49.128" 246' 113.8 " ' 36" 4 5,938,525.46 498,310.06 70o14' 35.784 150°00 49.1 22:?-' I 1:3.8 5 5,938,500.19 498,310.12 70°14'35.536" 150°00'49.154'' 196' 113.8 6 5,938,475.14 498,310.33 70o14' 35.289" 150°00'49.128" 171' 11.5.8 7 5,938,450.36 498,310.36 70014' 35.046" 150°00'49.127'' 146' 113.8 8 5,938,425.30 498,310.18 70° 14' 34.799'' 150°00'49.137-" 121' !13.8 9 5,938,400.30 498,309.98 70°14' 34.555" 150°00'49.137" 96' I 1:5.8 I0 5,958,375.19 498,510.14 70° 14' 34.306'' 150°00'49.153'' 71' 113.9 , . " i I 13.9 I t 5,938,350.22 498,310 14 70°14'34 061 150°00'49.133'' 46' 12 5,938,325.20 498,$10.17 70014, :33.815" 150°00'49.151" 21' 94' 113.9 118.5 FN.L. 13 5,938,235.31 498,310.37 70° 14' 32.950" 150°00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 70°14' 32.683'' 150° 00' 49. I$1" 94' 113.7 15 5,938,185.1~ 498,310.16 70°14' 32.437'' 150° 00'49.131" 119' 113.8 16 5,938,160.11 498,$10.20 70o14' 32_. 191" 150°00'49.130" 144' 113.8 4' 46" ' 17 5,938, I;55.21 498,310.18 70°14, 31.9 150°00 49.130" 169' I I;3.9 18 5,938,110.19 ; 498,.310.29 70°1 31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.~0 498,310.2_7 70014' :31.454" 150°00'49.127'' 219' 114.0. I 20 5,938,060.14 498,$10.22 70° 14' 31.207'' 150° 00'49. 128'' 244' 114.1 21 5,938,035.16 498,310.16 70° 14' 30.967'' 150° 00'49. 130'' 269' 'I 114.0 22 5,958,010.40 , 498,3~0.19 70o14' 30.718" 150°00'49.129" ?.941 94' 114.0 ;)3 5,937,985.32-[ 498,310.13 70°14'30.471'' 150°00'4g. 130'' 319' 95' 114.0 24 5,957~960.29 498,310.08 70 °14' $0.27.5" 150°00'49.132'' :344' 95' I 113.9 118.5 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE · (1) Fee 2,t ]F'd~ 1. (2) Lo = (~2P~ru 8)~'2~ (8) / ~ Admin ~ ~ (9 thru 13) 10. ~,~,,~< ~-~f-~¢ 11. (10 and 13) 12. 13. (4) Casg ~,~z, ~_~mo~j~ (14 thru 22) (23 thru 28) Company /~f~p A~k~.....~, . Lease & Well No. YES NO REMARKS Is the permit fee attached .......................................... ~-- ~ 2. Is well to be located in a defined pool ............................. ~_ 3. Is we~] located proper distance from property line .................. 4. Is we~,l located proper distance from other wells .................... 5. Is suz~icient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ~ 7 Is operator the only affected party ................. 8 Can permit be approved before fifteen-day wait ..... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER ~/_~ ~~~ '(29 thru 31) (6) Add: Geo lo gy: Eng~n~erinB: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented-- Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, Additional Remarks: 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. * ALASK~ COMPUTING CENTER , ****************************** * ....... SCHLUMBERGER -- ..... ,,,,,,,,,,---'---------------, ******************** WELL NAME ARCO. ~bASKA, INC, REI~ERE~CE N[ , 73404 LIS Tape Ver~,~icati, on Listing Scblu~berqer Alaska Computing Center 24-OUL 1989 **** REEL SERVICE NAME : EDIT DATE : 89/07/24 ORIGIN : FbIC REEl, MA_~E : 73404 CONTINUATIO~/ # : PREVIOUS REEL : C~M~.~EMT : ARCO ALASKA, INC.,~RCO KUPARUK 2K-7,API 50-103-20107 **** TAPE HEADER **** SERVICE NAhE : EDIT DATE : 89/07/24 ORIG~N : FLIC TAPE NA~E : 73404 CONTINUATION ~ : 1 P~EVIOUS TAPE : COMMENT : ARCO ALASKA, INC,,ARC~ KUPA~UK 2K-7,API 50-103-20107 **** FILE HEADER **** FILE NAME : EDIT ,001 ERVICE : FbIC ERSION : O01A02 ATE : 89/07/24 AX REC SIZE : 1024 PAGE{ 1 ** ** ** ** 8CHD!IMBERGER WEbb SERVICES ** ******************************************************************************* CO~.,PANY NAME: FIELDI API NUMMER: ARCO ALASKA, INC. ~ORrH SLOPE hLASKA 50-103-20107.,00 L.CATION: , 146' FSL & 94' FEi., SECTION: 2 TOWNSHIP: 10N RANGE:SE PERMANENT DATUM: ~SL ELEVATION: LOG ~EASURED FRO~ RKB 154 ABO¥~ PER.~ANENT DATU~ LIS TaPe Verification Listing Schlumberger AlasKa Computing Center 24-jUL-1989 20~23 PAGE: 2 ELEVATIONS K~: 154 DF: 153 DATE LOGGED: !9-J RUN NUMBER: ONE TD DRILLER: 8150 TD LOGGER: 8138 UL-198g CASING 1: 9 5/8" ~ DRILLER DEPTH OF 3480' BIT SIZE 1: 8 1/2" e 8150' TYPE FLUID IN HOLE: LSND POLYMER DENSITY: 10.7 VISCOSITY: 40 PH: 9 ~b~ID LOSS: 4,4 ~UD RESISTIVITY: T ],82 ~ 70 FILTRATE RESISTI¥I Y: ],]5 8 68 ~UD CAKE RESISTIVITY~ 3,5 0 68 ' N TIME CIRCUSArIO ENDED: 19:30 18-jUL-89 TI~E LOGGER O~ BOTTOm: 02:00 iH-JUL-89 MAXIMUM TE~P RECORDED: 116 . , T· LOGGING [.)I~aiC ,, LOGGING EMGINEER: WITNESS: PRUDH E BAY TI~KHA~ FLEtCHER/PEA GL: 1,13 TOOL NU~BERSoIs- 1457 DIC 1308 PG~ 508 CNC 1238 SGi.C 2626 IEM 1.3:47 NLM 1378 FIELD REMARKS: STANDOFF & 2 HOLE ~I ~DER USED ON DIT ~ATR1X DENSITY : 2 '~ L ,,6~ G/C3 . F~U CML ~IATRIX : SAND , HOLE CORRECT 1,00 G/C3 LDP/ANA' R KRUg. Ebb TABLE TYPE ~ CONS '~[,,NI VALlt APIN 50~103'20107-00 DEFI el ~e APi Serial Number (_ LIS Tape Verl, flcation Listino Schlumberger AlasKa Computing Center 24-jUL-19§9 20:23 PAGEJ 3 TUN~ SFC~ 2 TOWN 1 COON STAT A NATI U ENGI T WITN F SON 549130 PDAT EPD FT APD FT 154, EKB FT EOF FT 153, EGL FT TDD FT 815~, BLI FT 8130, TLI FT 1000, TCS !9~30 TLAB 02:00 STE. D..~G~ VALU DEFI Section 0~ Township E Range ORTH SLOPE County LASKA State or Province SA Nation INKHAM Engineer's Name LETCH~R/PEAK Witness's name Service Order Number Permanent datum Log ~easured From 8-JUL-89 ,9-JUL'89 Bottom Log Interval Top Log Interval Time Circulation StOpped Time Logger At Bottom 80 ~ TABLE TYPE : CURV DEFI ' ~ ' T ~' DE.P. DEPTH CHANNEL NAME T~NS Tension SP Spontaneous Potential SFLU SFL Unaveraged GR :Gamma Ray RHOB BUlk Density 8RHO Delta rho PHI Denslt~ Poroslty GR Gamma NPHI NEI]TRON ~OROSITY NRA, CALIBRATED THERMAL NsUTRON RATIO TNR RAW THERMAL NEUTRON RATIO AW CORRECTED NEAR THERMAL ~OUNTS TNPH THERMAL NEUTRON POROSITY LIS Tame Verification Listing Schlumberger Alaska Computing Center 24-JUL-1989 20:23 4 DEFI NPOR NEU N p . IT UTPUT FROM.. AN APPBI'CATION PR A CFTC CORRECTED FAR THERMAL COUNTS CNTC CORRECTED NEAR THERMAL COUNTS GP Gamma Ray TENS Tension GR Gamma Ray TENS Tension ** DATA FORMAT SPECIFICATION RECORD ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 ~20 4 66 5 66 6~ 0 5 2 68 3 6'6 0 16 66 1 0 66 0 ** SET TYPE - CMAN ** NAME :SERV UNIT SERVICE API APl aPI .API ~ L~ ~ NUMB ~ -U B SIZE REPR ID ORDER ~ LOG TYPE CLASS M:OD NUmB SAMP ELEM CODE DEPT FT ' 54913¢) O0 000 O0 .I 4 68 0000000000 IENS LB: 549130 O0 P OIL, MV 5491,3{0 O0 I L D D I,b GR P I.L ~Og FDC G/C3 54. t30 0 CALl FDC IN 5.49130 O, TENS: FDC LB 549130 O0 RNFD FDC CPS 549130 O0 RFfD fDC CPc 549~30 00 000 O0 000 O0 ooo oo 000 O0 1 000 O0 0 000 O0 0 000 O0 0 1 i 000 O0 0 I 1 000 O0 0 000 O0 0 000 O0 0 1 I i 4 68 000000000,0 LIS TaPe verii!cation Listing Schlumberger AlasKa Computing Center 24-JU5-1989 20:23 ID NFDC FDC CPS FFDC FDC CPS DRHO FDC G/C3 OPH! FDC PI! GR FDC GAP! NPHI CNL PU TNRA CN5 RTN~ CNL RCFT CNL CPS RCNT CNL C~S TNPH CNL PU NPOR CNL PU CFTC CNL CPS CNTC CNL CPS GR CNL GAPI TENS CNL E VICE APl API AP1 AP1 FILE NUMB UMB E ' E ORDER # LOG rYP CLASS NOD NtJMB SAM. P EL 549130 O0 000 O0 0 ! 549130 O0 000 O0 0 1 549130 O0 000 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 549130 O0 ~00 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 0 1 549130 O0 000 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 0 549130 O0 000 O0 0 1 549130 O0 000 O0 0 000 O0 0 000 O0 0 I R CSG GAPI 549130 O0 ENS CSG LB 549130 O0 COD I I 4 68 1. I 4 68 ! 1 4 68 1 I 4 68 1 1 4 68 1 1 4 68 I 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 ! 4 68 1 i 4 68 I 1 4 68 1 1 4 68 1 I 4 68 1 1 4 68 I i 4 68 (HEX) 0000000000 O00O000OO0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O00O0O0O00 0000000000 0OOOO000O0 0000000000 0000000000 0000000OO0 0O0O00O00O 0000000000 0000000000 DATA ** D~P C~Li GR 8158,000 TENS.DIL 3650.000 SP,DI5 -42 767 GR 80 DIL 52, .826 I~D. .FDC '438 ~E...S.FD~ 36~'0'000 RNFD,FDC : 1485 64o,81a c r'c n i CNL 726,636 C~TC,C~L ~2I 0130 GR.CNL 80 CSG -9991250 T£NS,~SG -999'250 D~PT D I5 CN.I~ CSG 8 o :ooo , oo.o s,.F c 775,500 ~FDCiFDC . 80'875 NPM~;CNL 67~,4tl CNTC,C~.L -999~250 TENS.CSG 000 RNFD 500 DRMO GR CN5 8O DEPT TENS,OIL FDC TENS,FDC FDC FFDC,FDC FDC NPH.I~CNL CFT CNL RCNT.CNL FTC CNL CNTC,CNL GR CSG- TE~S~G ~999.250 DIL FDC .CNL 8O 000 SFLU,DIL 2 500 RHOB.[DC 2 000 RFFD,~DC 1893 075 DPHI,FDC 25 065 RTNR,CNL 3 366 NPOR,CNL 34 500 TENS.CNL 3650 000 5FLU,DIL 875 RHOB,FDC 000 RFFD,FDC 109 DPHIiFDC 375 R~OB. 2 090 RFFD, 1002 027 DPSI ~.~DC 1! 762 RTNR~CNL 2 044 N~OR'CNL 375 TENS ~CNL 5 366 000 )o LIS TaPe Verification Listing Schlumberger AlasKa Computino Center 24-jUL-1989 20:23 PAGE: DEPT. 7900.000 TENS.DIS II~,DIb 3,0 ! 2 ILD, DIL CALl ~FDC 9,023 TENS.FDC NFDC,FDC 657,500 FFDC FDC GR~FDC 90.188 NPHIiCNL RCFT,CN~ 586,971 RCNT CNL CFTC.CNL 668,063 CN..C CNL GR,CSG -999.250 TENS.CSG DEPT, IL~,DII., hbI FOC FDC FDC GR FDC RCFT CNL CFTC CNL G~ D~T, ILM,DIL CALI,FDC NFDC~FDC GR~FDC CFTC~CNL FDC C~ R.~T CML CFTC CML GR CBG DEPT, IL~,DIL CTbI,FDC NFDC,FDC F GR..DC ~CFT,CNb 7800,000 TENS.DIL 1.915 ILO.DIS 9,508 TENS FDC 630.500 FFDC:FDC 131,250 MPHI,CNL 409,195 RCNT.CNL 493,340 CMTC,CNL -999.250 TEN$.CSG 7700.000 TENS 1,974 10.023 TENS 637.500 FFDC 112,563 463,521. RCNT .512,917 C~TC ..999'250 7500 54O -999 DIL FDC FDC , ,CNb CSG ,000 TEN$,DIb ;486 !LO'DIL ,000 F~DC;~'DC ,500 ;840 RCNT ~9] C~T~ C~ 1250 TENS CSG 740~ 5 (00 TENS 0 0 FFDC 50 MPHI 1!6 RCNT 850 CNTC ~N 250 TE, S O IL OIL FDC FDC CNL ,tNb .CNL ,CSG 000 TEN$,DIL 433 0'63 TENS,FDC 000 FFDC.FDC 750 NPHI.CN[~ 259 RCNT,CNb ~53 C~TC,C~n 250 5228,000 SP,DIL 3,018 GR,DIL 5228.000 RNFO,FDC 418'750 DRHO,FDC 5.905 TNRA,CNL 2176,690 TNPH,CNL 2084.52~ GR,CNL '999,250 -46 000 g0 188 1238 000 0 0 36,329 90,188 $FLU.DIL RHOB,FDC RFFD.FDC DPMI.FDC RTNR.CNL NPOR.CNL TENS'CNL 3,448 2,542 870.500 6,559 3,352 5228, 5292 1 5292 602 45 1752 g9 ,000 SP,DIL .845 GR.DIL 000 RN.FO,FDC 500 DRHO,FDC 059 TNRA.CN~ 337 TMPH,CML I GR,CN~ T 49,000 31.250 120~ 000 02~ 3 684 45 296 131 250 SFLU.DIL RHOB.FDC RFFD,;DC DPHI. DC RTNR.CNL NPOR.CNL TEN$.CN5 1188,000 4, 6 46,2~3 5292.000 5140 ! 5140 610 41. 1719 1751 -999 000 SP,DIL 49 GR,DIL O0 RNFD~FDC 500 DRHO,FDC 60I TNRA,CNL 2~6 TNPM,CNh 726 GR,CNL ,250 -43 000 SFLU.DIL 112 563 RHOB.FDC 1249 000 RFFD.FDC 028 DPHI.FDC 537 RTNR'CNL 40 321 NPOR.CNL II~ 563 TENS.CNL 2.I56 2.362 1261.000 1.7,4'70 3~678 40.i88 5140'000 52o : 687:~ 42~ !651~ 1667, '999, 000 BP DI5 -48,50, S:[ BU,DIL 347 GR. 9IL I74'1500 RHOBiFDC 000 RFFD,~ DC 1470,~00 000 RNFD,FDC 1339, 0 000 DRHO~FDC ' 696 ~TNR,CNb 44~096 923 T~RA,CN& 3'9~4 ~'PC)R; CN5 3~345 899 T'NPH, CML 43. 429 ' GR.CNL 174,5:00 IEN$,CN5 5200'000 250" 5060 -999 OOO SP,DIL -45 ,D!L .FDC 5OO:DRHO,FDC 0 179 T'NRA'CNb 3 25:2 TNP~;CNb 41 990 GR,CNL 220 250 500 SFLU DIL 3 990 FDC 2 32~ FDC 1350 00'.:: 270 ~PO , 750 '~ENS.CNL 485~,000 ;356 66 1840 ~817 954 999 250 SP FDC 1295 FDC 0 CNb 23 CNB 4 cab 1571 000 RFFD,FDC ' 1367', 000 034 DPHI~FDC 19'I32 4852 0 LIS Tape Verification L, lsttng Schlumberqer Alaska Computinq Center 24.-JUL.1980 20:23 PAGE) DEPT. 7300.000 TENS.DIL Ib,.DIb 3.221 iLD.DIL CALI,FDC 9,977 TENS.FDC NFDC,FDC 639,000 FFDC,FDC DFPT. ILM.DIL CALl FDC NFDC FDC GR FDC RCFT CNL CFTC CNL GR CSG DEPT. ILM,DIL CALI,FDC NFDC,FDC GP~FDC NL CSG D~PT, CALI,FDC MFDC.FDC RGR FDC CFT' ,CNL CFTC,CNL DEPT. CALI;FDC NFDC,FDC GR~FDC RCFT,CNb CFTC~CNL GR,CSG D~PT. L~.DIb CAL~,FDC NFDC,FDC GR FDC RCFT' 'CNL CFTC,CN~ 7200.0o0 4.992 9 86'7 604 000 103 625 554 657 625 744 -999 250 TENS.DIb ILD.DIL TENS,FDC FFDC.FDC NPHI,CNL RCNT.CNL CNTC,CNL TENS.CSG 7100 3 10 504, 574, ~999~ 000 TE~S.DIL 454 iLD, Dlb 078 TENS. FDC 500 FFDC,FDC 688 NP~I .CNL 346 RC ,. r,CNL 890 CNTC,CNL 250 TENS,CSG 7000, 4, ~0, !28, ~567~ '999~ 000 TE.8 054 ILO 477 TEN~ 500 FFDC . RCNT 423 CNTC 25O TENS DIL FDC .FDC CSG 6900 611 117 531 568 -999 TENS F 50O F.DC 875 NPHI 861 RCNT 928 CMTC 250 TENS FDC FDC CNL .CSG 637 55 -999 ,000 ,2!9 ,0'00 625 921 484 25O TENS ILD ~DC RCNT ,DIb .Dig ,FDC 'CNL 'CS(; 4912.000 SP.DIb 3,0~3 GR,DIL 4912,000 RNFD,FDC 551,500 DRHO.FDC 44.256 '"~RA,C, bM 1951,125 TNPH,CNL 1971.992 GR.CNL -999.250 -53.250 SFLU.DIL 3.565 116,81,3 RHOB.FDC 2,425 1240.000 RFFD.FDC 1132,000 0 050 OP~I,FOC 13,626 3:678 RTNR.CNL 3.905 43,055 NPOR.CNL 42,527 116.8~3 TENS.CNL 49~2.000 4780 O00 4:809 4780 0o0 5O2 500 36 466 2159 642 2143 45 -999 ~50 SP.OIb GR.DIL RNFD.FDC DRHO.FDC TNRA CNh TNPH:CNL GR,CNL -bO I03 1161 0 3 4O 103 625 RHOB:FDC 2."443 000 ~FFD, FDC 990,000 030 DPHI,FDC 12.559 244 RTNR,CNL 3 591 NPOR.CNL 39:2'5 625 ~EN .CNL 4780,000 4754.000 SP.DIb 3,175 ~R,DI~ 4764i000 RNfD.FDC 488~500 DRHO,FDC 4I~276 TNRA~CNL 2056,2~5 TNPM,CNb ~064,4.4 GR,CNL 999'250 -53 1 !3 1167 000 SFLU.DIL 4,738 688 RHOB,FDC 2 461 000 RFFD.FDC 976' .500 036 DPHI FDC 1~,476 140 NPgR.C~L 42;293 688 TENS;CNL 4764,000 4780 509 33 50 SP.DIb -63. GRjDIL i28j }{O,FDC 0, 'CNh ,CNL 39. GR;CNL 128, 0 0 RFFD.FDC 1050 10 DPM:I*FDC ~4 312 RTNR'CNL~ 3 294 NPOR~:CNL 40 750 TEN$.CNL 4780 000 106 ,000 DIL -68 , C N b 38 ,CNL 117 750 SFLU 8.75 RHOB O00RFFD 4544. 3 4544 510 35 1.974 1924 -999 000 173 GR;DIL 000 RNFD,F C 118 000 DRHO,FDC DI'L FDC 000 FDC 066 FDC CNL 625TEN$.CNL .323,473 105:1;000 I0,759 897 4544-000 LIS Tape Verification Listing Schlumberger A.las~a Computiqg Center 24-jOb-1989 20:23 PAGE: 8 DEPT NFDC GP RCFT CFTC 6700 000 TEN.., DI5 4:731 ILD,DIL FDC 10.375 TENS,FDC FDC 613 000 FFDC FDC FDC 78!563 NPHI!CNb CNL 949 877 RCNT CNL CNL 1014'051 C~TC.C~L CSG -999,250 TEN$,CSG DEPT, ILP,DIL ChS~,FDC NFD..FDC GP,FDC RCFT,CNL CFTC,CNL G~.CSG 6600,000 TENS,DIS 3.686 ILD.DIL 10,227 TENS.FDC 626.500 FFDC.FDC 83,188 NPI~I.CNL 705,698 RCNT,CNL 80~,272 CNTC,CNL -99 .250 TENS,CSG DEPT. 6500.000 TE~S.DIL 3 i94 ILD,DIL 9:781 TEN$:FDC ~D ~29~500 FFDC,F C B4,658 NPHI:CNL 660,391 ~CN~;CNL 749,874 CgTC,C~L "999,250 TEN$'CSG IL~,DIL ChLI,~DC NFDC,FDC GR,FDC CFTC;CNL GRiCSG 640~,000 TENS · 962 ILD RCNT ~'~' 842 C~TC '119, ~N 999, 250 TE.S ,FDC ,CN5 ,tNb .CSG NFDC 6300.000 TENS DIL '-895 FDC ,750 TENS FF 644 00 DC 114. 50 'NPHI C.L 474 RCNT CNL 538 CNTC CSG -999,250 TENS, FDC FDC CNL CSG D.:P~', CALI,FDC NFDC.FDC GR,FDC RCF'T~CNL CFTC:,CNL G~CS~ 620~,000 TENS '.800 ILD 638,500 ~ DC 462'914 ac~ 509'446 CNT -999.250 TENS DIL DI L FDC FDC C ~i :b SG 4528,000 SP.DIL 4,546 GR.DIL ~528,000 RNFD,FDC 549,500 DRHO,FDC 25;466 INRA.CNL 2747.0~5 T~PM,CNL 266~'935 GR,CNL '999,250 -63 78 1184 0 2 27 78 000 5~3 000 023 590 712 563 SFLU.DIL RHOB.FDC RFFD.FDC DPHI FDC RTNR:CNL NPOR.CNL TE~S.CNL 5.623 2 399 1106i000 15 206 2'853 25 86 4452,O00 SP,DIL 3,573 GR.DIL 4452.000 RNFD,FDC 653.000 DRHO.FDC 30,873 TNRA,CNL 2195.832 TNPH,CNL '999, 0 -72 000 83 188 1201 000 0 007 2 939 32 074 83 188 SFLb.DIL RHOB.FDC RFFD,FDC DPHI.FDC RTNR,CNL NPOR.CNL T~S CNL 1290 000 201449 3 064 4452.000 4428.000 SP.DIL ~3 051 GR,DIL 4428 000 RNFD.FDC 668 500 DRMO,FDC 35 318 TNRA'CNL 232014~6 TNPH,CND 2346~8 6 GRiCNL -999~250 84 1248 0 3 35 84 750 SFLU.DIL 688 RHOB,FDC 000 RFFD,FDC 005 DPHI,FD~ 174 RTNR,CNL 934 NPOR,C:NL 688' TENS.CNL 4.390 2,302 1283.000 35,498 4428; 000 4264,0~0 SP.DI5 '76 : 2'9 :i G'R;DIL 83 4264,000 RNFO~DC 1231 657;000 DR~O;~DC 0 ,5~7 !NRA,CN:b 3 ,65'1 7'NPH;CNL 35 ,962 GR'CN5 83 ,250 ' FDC , FDC 1321,000 FDC 20.170 3'55 36~4i4 CNL 4264°000 4080 -999 SP,DIL -84,500 SFSU,DIL 3'841 .~VC ,000 : RFFD.FDC ~155.'000 ~0 DRHO,FDC 0 05:2 ~PB!,FDC 14 12 · 524 RT~R'CNL 4 0I_ 904 TN~H,CNb 40,656 NPOR,CNL' 40 002 GR,CNL I14,250 TENS.CNL 4080 250 LIS Ta~e verification Listinq SchlUmberqer AlasKa Computina Center 24-JUL-1989 20:2] PAGE: DEPT, 6100,000 TENS.OIL · !LM,DIL 2,326 ILO,OIL C~LI,FDC 11.070 TENS,FDC NFDC,FDC 644,500 FFDC.FDC GR,FDC ~41.875 MPHI,CN~ RCFT.C~L 428 018 RCNT,CNL CFTC,CNL 505~828 CNTC.CNL GP.CSG -999,250 TENS,CSG DEPT ~000,000 TEN5 DI5 IL~' ~ '' ,DIL 1.899 I5D.DIL CALI,FDC 9,922 TENS,FDC NFDC,FDC 643,500 FFDC,FDC G~,FDC 133.625 NP~I CNL RCFT.CNL 451.483 RCNT~CN.L CFTC,CNL 5~2,020 CNTC,CNL GR,CSG -999.250 TENS,CSG DEPT, 5900, IL~,DIL 1 C~LI.FDC 9 NFDC~FDC 654 G~.FDC 1!3 RCFT,CNL ~84 CFTC,CNL 15 GR'CSG '999. DEPT, 5800 1 NFDC~'FOC 6~5 GRiFDC 123 RCFT CNL 473 CF' CNL 564 CSG -999 5700, DIb ~ FDC FDC 629 FDC 143 CNL CNL CSG -999 D~PT CALl NFDC 5.60~ DC 9 DC 6'24 FDC 90 ,CNL 761 000 TENS 653 438 TENS 500 FFDC 188 MPMI 677 RCNT 035 C~TC 250 TE~$ 000 TE ~$ 777 I'bD 219 :ENS 000 FFDC C TC 50 TENS 000 TEES NPHI N, 399 RC .~ 058 CNTC 250 TE S DIL DIb FDC FDC C N L DI OIL fDC C~ b ¢ lb CSG OIL FDC FDC C~b CNL CSG 4200.000 SP.DIL 2,406 GR,DIL 4~00.000 R~FD,FDC 623,000 ORHO,FDC 45,468 TNRA,CML 1705,104 TNPH,CNb 1810.552 GR,CNL -999,250 41bO,O00 SP,DIL 1,931 GR.DIL 41bO,O00 RNFD,FDC 629,000 DRMO,FDC 46,433 TNRA,CNL 1846,499 -TMPH,CNL !~26,606 GR,CN.b 99.250 -2I i41 1218 0 3 42 1.41 500 SFLU,DIL 8'75 RHOB.FDC 000 RFFD.FDC 032 OPHI,FOC 813 RT~R.CNL 312 NPOR.CNL 875 TE~S,C~L 1.898 2 357 1260 000 17 764 4 017 42 496 4200 000 4108,000 SP,DIL ,000 R~FD,~DC 691,500 DRHO,FDC 46,542 TMRA.CNL 1806 3!6 TNPH,CNL 999,250 -23,000 SFLU,DIL 133,625 RHOB.FDC 1208,000 RFFD,FDC 0,029 DPHI,FDC 3,792 RTNR,CNL 46,063 NPOR'CML 133,625 TENS.CNL 1,814 2.350 1266,000 18,1~2 4,1 0 47.138 4160,000 -16 766 5FLU.DIL 113 188 RHOB. I278 000 RFFD FDC . DC 022 DPHI,FDC 759 RTNR~CNL 43,148 NPOR,CNL 113. 88 TENSiCNL 1,420 2,305 1360'000 ;931 ;!71 43~990 4108,000 3950 39.'0 6i3 41 -999 OOO ~P 777 GR 000 RNFD 500DR'HO 855 TNRA 053TNPH 791 GR, 25O S ~ OIL -25,,594 cFL, U,Di 367 ~IL 123;56.] RHOB,~OC 330 [~DC 1237,000 : RFFD,FDC 135 FDC ' 0~010 DPBI.FDC I CNL 3,758 RTNR,CNL 43,886 CNL 4~, 088 NPOR;CNL 5'644 CNL i23,563 TENS,C~L 40401000 000 TENS,OiL 396i 834 IbD,Olb 359 TEN$,FDc 3964 500 FFDC~FDC 623 438 ~P~l,CSb ~2 677 R. CNr,CN~" 2362 458 CNTC,CN~ 250 TENS,CSG 000 SP DIb 765 GR DIb 000 RNFD FDC CNb 2bO - 3:0 550 00 RFF~DC 1215 019 ~P~I, 479 RTNR; 675 NPOR,CNL ,250 TENSgCN:.L 000 ~P,DIb '35,250 SFbU 81I ~R;OI5 90,438RHOB 000 RN~O;'[DC 1197~000 RFFD 500 5B5: INRA,CN~ 2~98:2 RTNR 454 TNPN~CNL 34~271 NPOR 9~2 GR~CNL 90~438 TEN6 250 FDC NI ,CNL 3964 LIS TaDe Verlf. icatio~ Listina $chlumberqer AlasKa Computinq Center 24-jUL-1989 20:23 PAGE: 10 DFPT, IL~.DIL C~LI FDC NFDC FDC GP FDC RCFT CML CFTC CML GR CSG DEPT, ILM,DIb CgLI,FDC NFD .FDC G~,FDC RCFT.CNL CFTC,CML G~'CSG DEPT. IL~,DIL CALI'FDC NFDC'FDC GR2FDC RCFT,CNL CFmC~CN~ GR~CHG D~PT, CALI FDC NFDC'FDC . RC CML CF DFPT FDC FDC FDC CNL GP CSG C~I;FDC NFDC'FDC RCFTC~b G~2CSG 5500,000 TENS,DID ],254 ILO.DID 9,477 TEMS.FDC 545,500 FFDC,FDC 88,313 NPHI.CML 632,239 RCNT.CNb 714,991 CNTC.C~L -999,250 TCNS.CSG 37'74 3 3774 655 35 2223 2293 -999 5400,000 TENS.DID 3'/20 2.420 ILO.DIL 2 10,055 TENS,FDC 3720 616.500 FFDC.FDC 6!2 105 688 NPHI,CNL 40 506~343 RCNT.CNL 2015 616,859 CNTC,CND 2057 -999.250 TENS,CSG -999 TENS.DID IbO,DIh TENS,FDC FFDC,FDC NPHI,CNL ~CNT,C~5 CNTC"C.~L T~N~ mSG 5300.000 3 149 9 102 631 000 120 188 03O 852 711 428 -999,250 5200,000 TE S '3 ~29@ ILD 62~,297 TEN~ .500 FFDC 102,000 NPHI 613;0~3 ~C~T 717' 988 C ~:~.C, -999,250 TENS DID .DID .FDC FDC CSG oo.ooo 9;3~ TE~S 518;000 ~DC 96;250 MPMI 7051698 RCNT 868;677 CMTC -999~250 ~ 000 TENS,DID 058 IbD, DID 641 TENS,FDC 500 FFDC,FDC 563 NPMI,C,,~b 308 RCNT,CNh 500~ 580 618 ,'9 9 9 3710 371~ 20'89 2184 -999 3654 -999 3744 3 189 .000 SP,DIL ,343 GR,DIL .000 RNFD,FDC ,000 DRRO,FDC ,946 TNRA,CNL ,661 TNPH.CNL ,0~2 GR,CNL .250 "34 250 SFbU,DI!. 3,105 88i313 RMOO,FDC 2,328 1221 000 RFFD,FDC 1341.000 0 023 DP~I,FDC 19,52~ 31183 RTNR,CNL 3.57 37 378 NPOR.CNL 37,780 88 313 TENS.CML 3774.000 ,000 SP .439 GR 000 RNFg 500 DRH 3 TNRA ~6 TNPH 44 GR 5O DID 38 500 SFDU.DIL 2 204 FDC 1194,000 RFFD,FDC 1198,000 FDC 0,008 DPHI.FDC 18.783 CML 3,467 RTNR CNb 3,845 CNL 39,017 NPOR:CNL 38'974 CNL 105,688 TENS,CML 3720,000 000 SP.DIL -43 204 GR,DIb 120 000 RNFD,FDC 1i94 000 DRHO,FDC ~ 750 TNRA.CNL ,CNL 35 .CNL 120 250 000 SFLU.DIL 3.000 ~88 RHO~,FDC 2.323 O0 RFF .FDC 1301,000 012 DPHI,FDC 19,840 I42 RTNR.CNL 3~30~ 487 MPOR,CNL 36,456 188 TENS.CNL 3710,000 GR '~45 102 121~ CNb 102 ,78:1 SFbU,DIL 3 ,000 RHOB~FDC 2 000RFFD,FDC 1224 015: :DPHI~FDC i8: 056 RTNR,CN5 3 705 NPOR~CNL 34 ~ · . .00 ~EN$'CNL 3720 000 SP, OIL -42 200 GR;D:Ib 96 000 RNFO, [DC 10! i 750 DR~O'cDC .-o 3'25 :: T~R~;CNb 3 C:. b 34 C~ 96 25O 750 SFLU DIL 2,554 (2" , ,UL 35,73,1 ]654. 000 46 84 ~DC 3~ 84 1429 22 3744 LIS Tape Verlflcation Listinq Schlumberger Alaska ComuutinO Center 24-dbL-1989 20:23 11, OEP?, 4900.000 TENS.OIL IL~,DIL 2.842 ILO.DIN CALI,FDC 9.227 TEN$,FDC NFQC.FDC 684,000 GR, FDC ~05. 31~ NPHI. CN5 RCFT,CNL 52b,428 CFTC.CNL 625.684 Ci~T CNL G~.CSG -999,250 TEN CSG DEPT. 4800,000 TENS,DIN !L~.DIL 3.358 ILD,DIL CALI.FDC 9,4~2 TENS FDC NFDC.FDC 635.500 FFDC~FDC GR.FDC 95,~38 NPHI.CNL RfFT,CNL 564.309 RCNT,CNL CFTC,CNL 660,369 CNTC,CNh GR.CSG -999.250 TENS,CSG DEPT IL~iDIL C~LI,FDC NFDC G~ RCFT,CNL CFTC,CNL G~.CSG C 61; DC NFDC~FDC DEPT NFDC GR DEPT IL~ OIL CALl FDC NFDC FDC FOC CNL 3384 2 33~4 730 4O 2i22 2074 -999 3400 3 3400 661 35 2072 2133 -999 4700,000 TENS.OIL 3280 ~,~51 ILD,DI~ 3 , .. 3280 52 TENS,FDC ~7~,000 FFDC,FDC 7~ lO ,375 NPHI,CNL 36'05'7 RCNT C L 1990 21,620 C~TC.C~L ~997 -999,250 TENS.CSG -999 460~,000 TENS, ,900 ILO. 66~,586 TENS .000 FFDC' 96,i25 NPHI, 502,365 RCNT, 91 C~' ,C .572, . 999, 50 TENS.' 4500 000 091 625 ooo 500 547 404 -999 250 ,000 SP,DiL 915 GR,OIh 000 ~NFD,FDC 000 DRHO,FDC 513 TNRA,CNL 99 TNPH,CN~ 26 GR,CNI, 250. -49.750 105.313 1329.000 0 040 .412 ~9.287 105.313 SFLU.DI5 RHOB.FDC RFFD.FDC DPHI,FDC RTNR,CNL NPOR.CNL TENS,CNL 2,791 1468. 0 21,170 3,478 37 312 3384:000 o]:ooo 962 11,242 699,000 I02,375 477,927 541,365 -999.250 000 8P.015 340 GR.DIL 000 RNFO,FDC 500 DRHO.FDC 234 T.NRA,CNL 759 TNPH,CNL ,540 GR,CN~ ;250 -49.781 95.438 1204 000 O!O12 3 140 37.796 95.438 SFLU.DIL RHOB.FDC RFFD.FDC DPHI.FDC RTNR,CNL ~POR.CN'L TENS.CNL 3 361 2:313 1268,~00 20. 05 3,~62 38' 21 3400.000 ,000 SP.DIb -52 000 RNFD,FDC 1305 500 DRHO,FDC 1.33 TNRA,CNL 663 T~PH,CNL 37 426 GR.CNL 250 813 SFLU.DIL 375 RHO~ FDC 000 RFFD~FDC 030 DPRI,FDC 456 RTNR.C~L 569 NPOR.CNL 375T:ENS.CNI. 2,75'0 1:41~ 290 000 2~ 828 55i 36 775 3280 000 DIb 3154,000 SP,DIh -54.000 SFLU,DIL 2,716 OIL 2~996 GR;DIL 96,125RHOB'FDC 2.267 FD~ 3154'000 RNFD, FDC 1237 ,FDC 1490 FDC 744.000 DR~O~FDC 0 ,~DC CNN 41, NRA,CN~ 430 'CNL 3, ~CNL 39, CNL i966' ~PH,CNL CNL 1953,417 GR,CNL 96'125 TENS.CNL 3154.000 CSG -999~250 FFDC, FDC NPH!, CNL RCNT;CNL TENS,CSG 3160 3 3160 1872 1978 -999 000 SP DIG -54 H Nb 43 N L, 9 3 750 SFLU.DIL 3.00'0 063 FDC 2,27! 000 FDC 14831000 CNL 45 CNL 3160 304~,000 SP,DIB -58:, ;092 GR*DI5 10:2~ 3044,000 RNFD,FDC 1348 778~500 DRHO;F~C 0 ~2,~b4: TNRA'C~b 3 1931. 30 TNP~CNL 42 ~963,222 GR,CNL 102 -9991250 632 RTNR,CNL 972 N. POR*CNL 375 TENS,CmL 3044 .0OO LiS Tape Verification Listing Schlumberger AlasKa Computing Center 24-j~f,-] 989 20:23 PAG~ DEPT, 4300.000 TENS,DIL IL~,DIL 3,$5g ILD.DIL CALI.FDC 9,313 T N FOG NFDC,FDC 653,500 FFDC,FDC G~,FDC 101.750 NPHI,CNL RCFT,CNL 516.569 RCNT.CNL CFTC,CNL 597 982 CNTC,CML G~,CSG -999:250 TEN$,CSG DEPT 4200 000 TENS.DIb Ib~' ' ,DIL 3,41.9 ILD.DIL CALI,FDC 9 477 TENS,FDC NFDC.FDC 683:000 FFDC,FDC GR,FDC 98,750 gPHI.CNL RCFT.CNL 484.109 RCNT.CNL CFTC,CNL 539,929 CNTC,CNL GR.CSG -999,250 TENS.CSG DFPT. 4100 IL~ DIL ~ C~LI" ,FDC NFDC,FDC 648 GR~DC 116 RC~T,CNL 441 CFTC,CNL .540 G ,C'S~ .999 .000 80 000 188 250 TE~S,DIL ILD,DIL TENS,FDC FFDC.FDC NPHI,CNb R~NT,CNL CNTC.CNL TENS.CSG D~PT, 400~ ILM,DIL CALI,FDC 71~ NFDC.FDC GR,FDC =90 RCFT;CNL 500 CFTC~CNb 577 G~,CSG '9gg 000 TEN~,DIb · ,063 T~NS,f[C °500 F DC.FDC ,375 NPH.I,C~ ~336 RCNT,CNL ~484 CNTC,CNL 1250 TENS.CSG DEPT NFDC GR DC .FOC FDC CNL CSG 3900 )00 TENS 7~4,000 . FDC 100.500 NPHI 549,054 RCNT 6~71450 CMTC -999~250 TENS ~DIb FDC FDC ,.tNb ',CN5 ,CSG 9 705 92 502 2934,000 SP,DIL 3'951 GR,OIL 2934,000 RNFO,FDC 740,500 DRHO.FDC 40.849 TN~A'CNL 1998,691 TNPH,CN~ 2023,279 GR,CNL -g99,250 -52.031 101 750 1201 000 0 009 3 438 40 312 101 750 SFLU.DIL RHOB.FDC RFFD,FDC DPMI.FDC RTNR.CNL NPOR CNL TENS~C~L 2950,000 3'554 2950 000 816 000 43 177 1865 219 1927 407 -999 250 SP,DIL -57 GR,DIL 98 RNFD.FDC 1337 DRHO,FDC 0 TNRA,CNL 3 TNPH.CNL 43 GR,CNL 98 500 SFBU,DIL 750 RNOB,FDC 000 RFFD.FDC 018 DPHI.FDC 57~ RTNR,CNL 208 NPOR.CNL 750 TENS,CNL 2840.000 3,490 2840~000 727 43 !790 1933 -999 SP.DIL -57.063 SFLU,DIL GR,t~IL 116.188 RHOO,FDC RNFD.~DC 1248.000 RFFD~FDC DRHO,FDC 9~008 DPHI.FDC TNRA'CNL 3,610 RTNR~N~ TNPM,CNb 43,230 NPOR,CN~ GR.CNL 116,185 TENS.CNL 2954 44 1997 ,FDC t3b~ ,FDC 012 T~RA,CNL 863 :: TNPH~CNL 673 GR,CNL 90 2,50 ]75 TEN$,CNL 2600,000 SP ~26006 O0 RNfD 316 T:NPH 4ql GR -999 250 DIL -58 78! SFLU DIL 100,50. : !~HOB FDC 1.411,000 RFFD , 041 DPHI · 407 RTNR ,CNL 39,414 NPOR .CNL 100,500 TENS D I L FDC FDC C N L CNL 2570 5 SP GR Nb G ,CNb 25 563 RHOB,FDC 000 RFFD'FDC 029 DPHI,FSC 510 544 NPOR;CNL 563 TENS,CNL 3,972 2,264 1540 000 23~38~ 3.636 2934' 3 249 1570 0 25 228 3 767 43 755 2950.000 2.629 146~ 27 2] 003 688 45 97 2840 60~ 2954 000 4 004: 4 984 225 2570 000 LIS Tape Verification bistiDq SChlumberger Alaska Computing Center 24-00b-1989 20:23 DEPT, 3700.000 TENS.DIL Ib~ DIL 4.844 linD.OIL CALI'FDC l.O 750 TENS FDC NFDC.FDC 663.000 FFDC FDC GR.FDC 84,938 NPHI~CNL RCFT,CNL q71,695 RCNT,CNL CFTC,CML 545.869 CNTC'CNL GR,CSG -999.250 TENS.CSG DEPT. 3600.000 TENS.DIL ILM.DIL 4.408 ILD.DIL CALI,F~C 1.0,641 TENS.FDC NFDC.FDC 691,000 FFDC.FDC GR FDC 97,250 NPHI CNb RCFT' ,C~L 464,804 RCNT:CNL CFTC,CNL 548.539 CMTC.CNL GR.CSG -999.250 TENS,CSG DEPT. ~500.000 TENS IL~,DIL 4,478 .ILD C~i~I,FDC ~4,461 TENS NFDC'FDC 700,500 FFDC FDC ~P; 92.625 RcfT;c~L 396,461 RCNT CF~;CNL 45~;604 CNTC G~,CSG 91.125 TENS Bib DIL FDC oo.ooo DIb 2999,~50 ILD'DIL FDC ~999~250 TENS~FDC FDC 2999;250 FFDC;FDC FDC .999;250 ~P~iiCNL C~I~ , 999;250 RCN~,CNL CNL -999,250 CMTC.;C~L CSG 42,281 TENS~CSG DEPT, ILM'DIb ChL!;FDC NFDC,FDC RCF~,CNL CFTC~CNL GR.CSG D~PT b~ DIL GR F~C RCFT CN]~ CFTC G~ ~200,000 TENS 2999;250 i999,250 T~N$ :999,250 ~DC 999~250 ~P~ -99~0 ~C~T -999.250 C~TC 51;031 2574,000 SP. DIL 5,162 GR.OIL 2574.000 RNFD.FDC 828,000 DRHO.FDC 857..98 GR,CNL 999.250 -67.063 SFLI~.DIL 4.536 FoC 1292:000 RFFP:FDC t68o.000 0,000 DPHI,FDC 26'693 40,5~1 ~POR.CNL 4 1~8 84.938 TENS.CNL ¢574'000 2364.000 SP,DI5 5 121 GR.DIL 2384:000 RNFO.FDC 784 500 DRHO,FDC 39:831 TNRA,CN~ t. 885.820 TNPH.C~L 1932,130 GR.CNL -999,250 -68 97 1309 0 3 41 97 250 SFGU.DIL 3,943 250 RMOB.FDC 2.264 000 RFED.FDC 1569,000 033 DPHI,FDC 23,374 657 NPOR,CNL 4 784 250 TENS.CNL 2384,000 2430,000 . 4,757 2430,000 850;500 44'406 1699,6~ 1738,2~,7 2~0,000 SP DIL GR RNFD FDC DRRO FOC TNRA CML TNPH,CNG GR.CNL 66.500 SFLU.DIL 4.097 92,625 RHOB FDC 2.0~0.5 47,000 RFFD FDC 1768.2 0,026 DPMI FDC 25.7~0 3,844 ~TNR CNL~ 4i041 44.817 NPOR CNL 44,86~ 92.625 TEN$.CNL 2430.000 -999 -999 -999 '999 -999 '999 -999 2350 , .,DIL -999.250 SF~U.DIL , .OIL -999;250 RHOBiFDC ,250 RNFD -999.2.50 RFFD,F'DC · 250 DRHO '999'250 DPHI,FDC ~0 ~NRA CNh -999.250 RTNR.CNL , 50 TNPH CNP -999.250 N~OR,CNL ,2bO GR,CN:b -999,250 TEN$'C~b .000 -999, 25O -999.:250 SP DIL -999 FDC 99 250 TNPH,CNb -999 250 GR,CNL -999 22'!0 000 250 SFL{.! DIL 250DPEX 250 RTNR 250 NPOR 250 TENS CNL '999,2'50 '99 FDC ~999,~.'u RN~rO,FD~ 250: DRMO FDC FD~ *999, . CN~ "9~9; .CNL ~999, CNL '9~9'250 GR.CNb CSG 2224~000 -999 FDC C N L ,CNL ,CNL 250 LIS TaPe Verification Listing SChlumberger AlasKa COmputind Center 24-do5-i989 20:2] PAGE: ¸!4 DEPT, 3100,000 TE~S,DIL IS~,DIL -999,250 IbD,DIL CALI,FDC -999,250 TENS,FDC NFDC,FDC -999,250 FFDC,FDC GP,FDC -999,250 NPHI,CNL RCFT,CNL -999250 RCNT,CNL CFTC,CNL -999:250 CNTC,CN5 GR,CSG 52,844 TENS,CSG -999. -999 -999 -999 -999 -999 -999 2184. 250 SP,DIL -999 250 GR,DIL -999 250 RNFD,FDC -999 250 DRHO,FDC -999 250 TNRA,CNL -999 250 INPH,CNL -999 250 GR,CNL -999 000 250 SFbU,DIL 250 RHOB,FDC 250 RFFD.FDC 250 DPH! FDC 250 RTNR:CNL 250 NPOR,CNL 250 TENS,CNL c~! NFDC GR. RCFT CFTC 3000,000 TEN$.DIL DIL -999,250 ILD.DIL FDC -999,250 ~NS.FDC FDC -999.250 _FDC.FDC FDC -999250 NPHI,CNb CNL -999~250 RCMT,CNL CNL -999,250 CNTC,CNL CSG 521656 TENS,CSG 999, :999. .!999, 999, 999, 999, 9~9, 21 O. 250 SP,DIL -999 250 GR,D!b -999 ~0 RNFD,F~C -999 0 DRHO,FDC -999 50 TNRA.CN~ -999 50 TNPH,CNL -999 ~50 G~,CN~ -999 000 250 ' U DIL 250 RHOB,FDC 250 RFFD,FD~ 250 DPHI,FD 250 RTNR,CNL 250 NPOR.CNL 250 TENS,CNL Ih~ DID CAL~ FDC NFDC [DC G~ ~DC RCFT CNL CFTC CNL GR,CSG 2900.000 TENS,DIL i 999,250 ISD.DIL 999,2502 TEN$,FDC ~ 999' 50 FFDC FDC -999~ 250 '4~. PHI',CN5 -999,250 . CN~,CN~ -999 ~ 250 CNTC*~NL -999 -999 -999 -999 -999 -999 -999 2080 ~50 SP.DIh '999 250 RMF~:FDC 999 250 I~RA' CNb 99 50 TNPH,C~b -999 50 G'R'CNL -999 .000 · ! · 250 $~Lt. DIL 250 RHOB:FDC 250 RFFD,FDC 250 DPH1.FDC 250 RTNR.CML DEPT, C4~I~FDC ~F~C~FDC ...FTiCNL CFT¢~C~ -999,250 ~'LD'DIL :999~250 T~NS FDC '~50 FfDC,FDC :999 ' 99:9,~50 NPHI,CNL '9991250 RCNT.CNL -999,250 C .TC,C b 49.43~ TENS.CSG -999,250 SP,DIL -999 '999.250 GR,DIL '999 :9.99,2.50 RNFD FDC MO.FDC :999,'250DR ,999,250 ,CNb -999 ,.!999~250 ,CNL' ' '999 T9~9,2~0 GR,CNL -999 2030,000 · DE PT NF FCC FDC CNL CML CSG 2700.000 TENS '99~2.50 ILD '99 ,250 TENS ;250 FFDC ;250 RcNT ;25O C~TC 47,000 TENS .DIL '999,250 SP,DIL -999.250SFbU.DIL ,[)lb ~999' ,DI~ -999,250 RHOB,FDC ,FDC ..999; ;FDC '999'250 RFFD*F'DC FDC -999; ,FDC 2999,250 ~DP~I,FDC CNL -999; ~NL '999'250 RT~R;CNL ' N~ -999'2~0 TNPH ,250~ NPOR ,C. b ,CNL -999 ~CNL ,~NL -999,2:'0 GR~CNL -999~250 ~!ENS.CN5 ,CSG i970,000 D~PT L !~ · DC ~600,000 Tg'$ DIL 999~250 ILl) ' { TEN FDC ~999,25.) ':. :i $ FDC -999'250 FFDC FDf -999,250 NPHI CNL -999;250 RCNT CNI.. -999'250 C~TC CSG 59~656 TENS DD1 L IL F[)C FDC C~b CNL c~ 999 GR,CNL -999 -999250 -999250 -999250 9 250 -999 250 -999 250 -999250 -999250 -999250 -999250 -999250 -999250 -999250 -999,250 -999,250 -999,250 ~5 ~999.2.0 '999250 ,250 250 '999.250 -999,250 '999~250 "999,250 LIS Tape Yerification Listing Schlumberger Alaska Computlnq Center 29-duL-198g 20:2J 15 DEPT, 2500,000 TENS,DIL ILM,DIL -999,250 ILD,{)IL C~L!,FDC -999,2S0 TEMS,FDC RCFT,FDC -999.250 NPBI,CNL CFTc.CNb -999.250 RCNT.CNL ,CML -999,250 CNTC,CNL GR,CSG 49.938 TEN$.CSG DEPT ~400,000 TENS,OIL NFDC,FDC 99,250 FFDC, DC GR,FDC -999,250 NPMI,CNb RCFT~CNL -999,250 RCNT,CNL CFTC,CNL -999~250 CNTC,CNL GP~CS(; 39.!25 TEN$.CSG D~PT, ILM DIL C~LI FDC NFDC FDC GP FDC CFT CNL FTC GP CS~ DEPT CALI NFDC 2300.000 -999.250 -999,250 -999,~50 -999. 50 -999,~50 -999,250 37,281 TENS DIb ILD OiL TENS FDC NPHI CML ~CNT CNTC CNL TE~$,CSG -999.250 SP,I.)II.~ -999 -999 250 GR DIL -999 -999:250 RNFD:FDC -999 -999,250 DRMO,FDC -999 -999.250 TNRA.CNL -999 -999 250 TNPH,CNL -999 -999:250 GR.CNL -999 1910.000 -999 -999 -999 -999 -999 -999 -999 1880 -999, -999, -999. -999, :999, 999, -999' 1865; DEPT. 2i00,000 TENS I5~, -999,250 ILD CALI~ '999,250 TENS NFDC,FDC '999,250 FFDC GR,FDC '999.250 NPMI RCFT;C~L -999,250 RCN~ CFTC,CNL -999~250 CNTC TE~S GR,CSG 43;06] '~ D~PT, L~DIb ALI,FDC -999 FDC,[DC -999 G~fDC -=999 RCFT,CNb -999 CFTC, -99~ GR.CSG 32 000 250 ILD TENS. 25_0 NPH I 250 RCNT 250 C~TC 313 TENS DIL '999, Diil :999, FDC 2'999; ~DC ~999, CNL .!999; 999; ~79o' 250 SP,DIL '999 250 GR.DIL -99~ 250 RNFD,FDC -99 250 DRHO.FDC -999 250 TNRA.CN5 -999 250 TNPH.CNL -999 250 GR.CNL -999 000 250 250 250 250 250 250 250 SFLU.DIL RHOB FDC RFFD:FDC DPHI.FDC RTNR,CNL ~POR.¢NL TENS.CNL 250 250 250 250 50 250 SP.DIL -999 250 50 GR,D!L -999 250 50 RMFD.FDC -999 ~50 50 DRHO,FDC -999 250 50 TNRA~CNL -999 250 50 PH CNL -999 TN , 50 GR,CNL -999 000 SFLO.DIL RMOB.FDC RFFD.FDC DPM!.FDC RTNR.CNL NPOR.CNL TEN$.CNL 2sO ~R.OZ~ 299. 250 RNFO,FDC . 999 250 DRHO~.FDC -999 2~0 TNRA CNh -999 ~250 TNPI~,CNL -999 250 GR.CNL -999. 000 SFLU .DIL RHOB,FDC RFFD~FDC DPHI,FDC RTNR ~ CNL 250 S?.DIL 2999 250 ~R,RI5 999 250 RN~D;~DC ~999 ~ ' TNRA*CNL :9gg 000 ' 50 RT~R,CNL 50 NPOR2CNL DIb -999. 250 SP DIL -999~250 GR FDC -999,25:0 RN~ D FDC -999. 250 DRHO C!~.~ -999,250 TNRA CN[~ '999.250 TNPH , CN~ ... 9.99 ~ 250 GR .CSG I740.000 250SFLU.DIL 250 RHOB.[DC 250 RFFD'fDC DPHI.,FDC RTNR.CNL 250 NPUR:.CNL 250 TENS.C~L DIL ~250 SFhU.D~L DIL 1250RMOB.FDC CNL 250 NPOR,CNL CNb -999 250 TENS.CNL -999.250 -999.250 -999.250 -999.250 -999,250 -999 250 -999:250 -999,250 -999.250 -99 -99~,250 -99 ,250 '999.250 '999.250 '999,250 '999'250 '999.250 '999'250 "999,250 '999~250 "999 '999~250 ~999.250 LIS Ta~e verification Listing $chlum erger Alaska Computing Center ~4-jUL-!989 20:23 PAGE: 16 DEP~ CALl NFDC GP CFTC GR , 1900.000 TENS.DI[~ ,OIL -999.250 ILO,OIL FDC -999,250 TEN$.FDC FDC -999,250 FFDC,FDC FDC -999.250 NPHI.CNL CNL :999,250 RCNT,CNL CNL 999,250 CNTC.CNL CSG 43.063 TENS.CSG OEPT CALl NFDC G~ RCFT , 1800,000 TENS,OiL ,OIL '999.250 ILO.OIL ,FDC '999.250 TENS,FDC .FDC -999,250 FFDC.FDC .~DC '999.250 NPHI,CNL , NL -999.250 RCNT.CNL ,CNL -999.250 CNTC.CNL .CSG 45.563 DFPT CALl NFDC RCFT cr~c 1700.000 ~Olh '999,250 .FDC '999'250 .FDC '999 50 _ ,50 CNL 999,250 CNL '999.250 CSG 50,375 TENS,OIL ILO,OIL TENS.FDC FFDC FDC MPMI CNL RCNT CNL CNTC CNh TENS CSG DEPT, !600,000 T~NS,DIL 1LM~DIL '999.2:50 LO.OIL CALI,~DC -999,250 ~ S FDC NFDC ~.~DC -999,250 FFDC.FDC ~ '* N GR;.~ 9C -999;250 NPHI C L RCFT iCNL -999,250 RC~T, CNL 'F C TC,CNL -99~;250 GR ~CSG 3 l, 125 TENS. CSG DEPT NF G~ 1500 DIL -999 FDC '999 CNL CSG 29 · 000 TENS.OIL 25~ ~LD'DI~ 250 TENS'FDC 50 F.DC~FDC 50 NPH'I~CNL 250 RCNT,CNL 250 CNTC;CNL 656 TENS.CSG ~N D~PT, ~400.000 TE $,DIL LM~ OIL 999,250 ILD,D~L 250 FDC NFDC.fDC ~999, flOC. G~,f DC 999,250 NPMI,CN~ RC~'T.CNL -999~25o RCNT~CNL CFTC CNL -999,250 ~NTC,CNb GR:CS~ 24' 563 ENS.CSG -999.250 SP,DiL ~999.250 GR,DIb -999.250 RNFD,FDC -999.250 DRHO,FDC -999.~50 TNRA.CNL ~999,250 TNPH,CNL 999'250 GR.CNL 1670.000 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SFLU.DIL RHOB.FDC RFFD.FDC DPhI,FDC RTNR,CNL NPOR,CNL TENS.CNL -999,250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 ~50 16bO O0 SP,DIb -999 250 SFLU.DIL GR,DIL -999}250 RHOB*FDC RNFD,FDC -999 250 RFFD.FDC DRHO'FDC -999 250 DPMI.FDC TNRA,CNL -999 250 RTNR.CNL TNPH.CNL -999 250 NPOR.CNL GR,CNL -999.250 TENS.CNL -999,250 SP,DI5 -999 -9991250 GR~DI~ -999 -999 250 RNFD.FDC -999 -999 250 DRHO,FDC -999 -999 ~50 TNRA'CML -999 -999 250 TNPH,CNL -999 250 GR~CNL -999 I$i ~000 250 SFLU. DIL 250 RMOB,FDC 250 RFFD;FDC 250 DPHI.FDC 250 RTNR,CNL -999 -999 50 RNFD,FDC 50 DRHO'FDC ,CNb ,CNL GR,CNL -999 -999 -999 -999 14bO 250 SP,DIL 250 ~GR;DIL 2:5:0 RNFQ~FDC 250 DRHO'FDC ~50 TNRA,CNL 50 ~ , NL o00 -999 250 SFbU,DIb 250 RMOB,FDC 250 RFFD.FDC ,,DC 250 OPHt. F ~ 25.~0 RTNR,C~L 250 ~!ENS~CNL ,250 SP, " -999 DIb ,250 GR~DIL -999 ~250 RN'FD'~DC -999 ;250 DRh~,~DC -999 ~2~0 TNRA~CN~ -999 ,250 TNPH,CML '999 ,2~0 GR,C~ u -999 50 SFLU.DIL 50 RHOB'FDC 250 TEN$.CNL '999,250 '999,250 -999,250 -999.250 -999 250 -999!250 -999 250 ~999,~0 999. 0 -999 250 -g 9:2 o -999 250 -999i250 -999 250 '999.25O -999,250 -999,25,0 -999 ' 2',50 -999; 250 2'50 -999 25O 250 25 25 -999 250 LIS Tape Veriticatlon Llstlnq Schlumber.~er Alaska Computlnq Center 24-OOb-1989 20: 23 17 DEPT. 130(.).000 TENS.DIL IL~,DIL -999. 250 IbP. DIL CALI.FDC -999.250 TENS.FDC NFDC,FD~ -999.250 FFDC.FDC GR~FDC -999.250 NPHI.CNL RCFT CNL -999.250 RCNT,CNL CFTC~CNL -999.250 CNTC,CNL GR.CSG 25.297 TEH$,CSG DE~. ~200,000 TENS,DIb I ,DIL -999.250 ILD,DIL D' CALI,FDC -999,250 TENS,F C NFDC.FDC -999.250 FFDC.FDC GR,FDC '999.250 NPHI,CNL RCFT,CNL -999,250 RCNT.CN~ CFTC,CNL -999,250 CNTC,CNL GR.CSG 40.469 TENS,CSG I~,D.IL CAL!~FDC NFDC,FDC ~R~FDC RC.FT CNL CFTC' G~,CS~ 1100,000 TENS :999,250 ILO DIL 999.250 TENS FDC -999,250 FFDC FDC -999,~50 NPHI C~L -999,250 R~NT~CNb -999;250 C~TC, CNL 31,375 TENS,CSG EP~, 1000,000 tL~{,DI'L -999,~50 C~LI'FDC -999,250 NFDC,FDC -999,250 ~cG~,FDC :999;250 G,.CSG 46;563 TENS IbP T E N S FFDC C~TC TEN S DIL FDC FDC CNb CML ~DIb 'FDC NFDC,FQC GR;FDC FT,CNL TC,CNL 991.000 .... ENS,DIL -999,250 I. LD~DIL 250 TENS~FDC -999,'999']50 FBDC;FDC -999, 50 NPMI,CNL -999,250 RC -999,2'50 CMTC 41,531 TENS.CSG END OF DA.,.A ** -999,250 SP.OIL -999.250 GR.OIL -999.250 RNFD.FDC 999,250 D~HO,FDC 2999,250 T~PA,CNb .. 05:000 -999.250 -999 250 -999' .250 -999.250 -999.250 -999.250 -999,250 SFLU.DIL RHOB,FDC ~FFD.FDC DPHI FDC RTNR[CNL NPOR.CNL TEMS.CNL 999,2b0 SP.DIL :999,250 GR,DIL -999,250 RNFO.FDC -999,~50 DRHO.FDC -999, 50 TNRA,CN~ -999.250 TNPH.CNL ;999,250 GR'CNL 330,000 -999,250 -999.250 -999 25O -999 250 -999 25O -999 250 -999 250 SFGU DIL RHOB:FDC RFfD.FDC DPHI,FOC RTNR,CNL NPOR.CNL TENS,CNL -999 -999 -999 -999 -999 -999 '999 1~65 250 SP.DIt, -g99 250 GR,DIL -999 250 RNFD,FDC -999 ~50 Og~O'FOC -999 50 TNRA~CNL '999 ~50 TNPH,CNL 999 50 GR~CNL :999 ,000 250 SFLU,DIL 250 RHOB,FDC 250 RFFD.FDC 50 DP~I,FDC 50 RTNR,CNL 250 NPOR,CNL 250TENS.CNL 999,250 SP,DI5 2999 999,~50 GR;DIL 1999 1999,2~0 RNFD~FDC 999 999.250 DRHO,FDC '999 -999'~b0 TNRA,CNL -999 :999'250 TNP~;CNL '999 , 999,250 GR,CNL -999 i!9.0,000 250 RTNR,CNL 250 NPOR ;CML 250 TEN$,CNL -999 1,195 DIL -999 DFIb '999 DC -999 .FDC -999 ~CNL '999 CN b 99 250 -999250 '999, 0 '999,250 '999.250 -999 250 -999 250 -999 250 -999 250 -999 2.50 '999,250 '999,250 '999.250 '999 '999 -999 -999 250 '999~ ~ ~999, LIS Tape Verification Listinq SChlumberger AlasKa Computing Center **** FILE TRAILER FILE NA.E : EDIT ,001 SERVICE : FL!C VERSION : DATE : 89/07/24 MAX RMC SIZE : t024 FILE TYPE : LO LAST FILE : 24 - J L! L - 1989 20:23 PAGE: **** FILE HEADER FILE NA~E : EDIT SERVICE : FbIC VERSION : O01A02 DATE : 89/07/24 MaX REC SIZE : 1.024 FILE TYPE : LO LAST FILE : TABLE TYPE : CONS CN ARCO A~ASKA, II.C. FN KUPARU,. PIN 50-103'20107'00 FEL W SLOPE FLETCHER/ 549I 30 154' 1.53. 113" ompany Name leld Name Well Name .API Serial Number ~ield Location Section T.own~ 1~ Rang County _ _ state or Province Witness's name servlce Order Number Permanent datum Log ~easured From [,IS Ta;)e ~erification Listing Schlumberger Alaska Computing Center 20:23 T~BLE TYPE : CUR¥ DEFI DEPT DE~TH CM~NM~h RHOB Bulk Density CALl Cali~er TENS Tens on RNFD Raw Near FDC Count Rate RFFD Raw Far FOC Count Rate DRHO Delta tho DPHI Density Porosity GR Gamma Ra NPH~ NEUTRON ~OROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO RTN~ RAW THERMAL NEUTRON RATIO RCFT RAW CORRECTED FAR THERMAL COUNTS RCNT RAW CORRECTED NEAR THErmAL COUNTS TNP~ THERMAL NEUTRON POROSITY r~Po~ NEUTRON POROSITY OUTPUT FROM AN APPLICATION T ¢ CORRECTED FAP Ti~ERMAt, COUNTS NTC CORRECTED NEAR THERMAL COUNTS R Gamma Ray ENS Tension PAGE~ 19 ** OATA FOR~4AT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 66 1 66 I~ 66 66 ~8 0 66 LiS Tape Verification bistlnq SChlumberger AlasKa Computln~ Center 24)OUL-I989 20:23 ** SET TYPE - CHAN ~, '''''NAME .... SER~'[~i~''''~'~''';'''X'i'';;SER I A I P .... I A;''FiC~'~3~3'~3'~[''~''''I R PR .... PROCESS''''''' ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) .................-........,...,,-..,,..-.--..,.--....-...................-.-.-... DEPT FT 549130 O. 0 O 1 1 4 68 ' 0000000000 RWOB FDH G/C3 549130 O0 000 O0 C~L! FDH IN 549130 O0 000 O0 TENS FDH LB 549130 O0 000 O0 RNFD FDH CPS 549130 O0 000 O0 RFFD FDH CPS 549130 O0 000 00 DRHO FDH G/C3 549130 OPM! FDH PU 549130 GR FDH GAPI 549130 O0 NPMI CNH PI] 549130 O0 TNRa CNH 549130 00 RTNR CNH 549130 O0 RCFT CNH CPS 5491]0 O0 RCNT CNH CPS 549~30 O0 TNP[~ CNN PU 549130 O0 NPOR CNM PU CFTC C~H CPS 549130 5 O0 .49130 00 CNTC C~H CPS 549130 O0 ~R' CNH GAPI 549130 O0 O0 000 O0 O0 000 O0 0 2 1 1 4 0 2 1 1 4 0 2 1 I 4 0 2 1 1 4 0 2 1 1 4 0 2 1 1 4 0 2 1 1 4 000 O0 0 2 1 I 4 000 O0 0 2 1 1 4 000 O0 0 2 1 I 4 000 O0 0 2 1 1 4 000 O0 0 2 I 1 4 000 O0 0 2 I i 4 000 O0 0 2 1 1 4 000 O0 0 2 1 i 4 000 O0 0 2 i i 4 ooo oo I 000 O0 ~ . 4 68 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 O000000OO0 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 000000000 000000000 PAGE{ 20 DATA CFTC 8i67 FD'H I607 FDH .CNH CN~ 86 O0 R~F~ 250 NPHI 48{ RCNT 573 CNTC. FDH FDH c~ RCFT,CN}.{ F' C- 'l'C. CNH 84 617 661 000 RHOB,FDH 000 RFFD~FD~ 375 NPHJ['CNH DEPT RNFD CFTC FDIa C~H CN H 8000,000 i191;000 78,000 897 ;024 1028,552 R },{ 0 B RFFD RCNT CNTC FDH FDH CNH CFTC FDH C'N~ 7900,000 1127; 000 93;!25 638~586 715;949 gOB,FDH FFD,FDM CNTC ~ 2 21 i:t7 ~D 916 CALl,i;. H 000 DRHO.FDH 280 272~ 105 GR 78 2019,505 TNPH CNH 217o,206 GR,.CNH 563 TE ~$,FDH 007 DPHI.FDH 2]8 ~N_R,CNH 707 NPOR,CNH 250 TENS':CNH g 82 TENS,FD~ 19 DPHI.FD}i 268 RTNR,C~B 873 NPOR,CNM 375 TENS,CNB 38 TENS 74 DPHI TNR POR 000 TENS DH 039 TENS,FOB 04:1 DPHI:, FDH 1'54 RTNR ,CN:H 720 NPORiCNH 125 TENS'CNH 2354,000 44;486 5384,000 ]7;426 · 8'644 5384,000 5092, 5168 000 LIS Tape veriflcation Listing SchlUmberger AlasKa Computing Center 24-0UL-1989 20:23 DFpT, 7800.000 RHOB.FDH RNFD,FDM 1251,000 RFf'D FDn GP,FDH 129,750 NPHI' RCF?,CMM 497,554 RCNT'CNH CFTC,CNH 536.752. CNTC*CNh DFPT. 7700,000 RHOS,FQH RNFD,FDH 1~22,000 RFFO,FD. GP,FD~ 1.1,188 NP~I,CN~ RCF~',CNB 405,317 RCNT CNh CFTC,CNg 473,216 CNTC:CNH DFPT. 7600.000 RHOB RNFD,FDH 1291.000 RFFD G~FDH 206,250 NPHI RC~T,CN~ 397,635 RCNT CF~C,CNH 445,066 CNTC DEPT, 7597, ]99 RHOB RNFD,FDH 1064,000 RFFD GIRl, FDH 219.125 NPH t RCFT~C~H 444,111 RCNT CFTC ~CNH 496 ~ 188 Ct~TC FDH FDH CNfi CNH . FDH ,FDP, . C N I,,! , CNH ,CNa 2,443 182,} 205 1821 140 2,373 1336 000 48 597 1687 4'74 1749 784 2,372 1282,000 45,G89 16~4,764 1661,04~ 2 372 1797 1803 427 CALl, DRHO, TNRA, TNPH, GR, F DH FDM CALI,FDH DRHO,FDH TNRA,CNH TNPH,CNH GR.CNN CALI,FDH DRHO,FDH TNRA, TNPH,CNH GR,C~H 9.430 0,076 3.529 40.380 129.750 9 828 0 065 3 903 45 052 111 !88 13 492 0 043 3 900 43 380 206 250 TENS,FDH DPH! FDH RTNR:CNH NPOR.CNH TENS,CNH TENS,FDH DPHi,FDH RTNR,CNH NPOR,CNH TENS.CNH TENS,FDH DPHI,FDH RTNR,CN~ NPOR,CN TENS,CNB CAL, I,FDH 12,055 TENS,FDH DRHO.FDH ~:018 DP~I.FDH TNRA,CNH 740 RTNR*CNH TNPH,CNM 42'593 NPOR*CNH GR,CNH 21. gl 125 TEN$~CNH 5108.000 1~,537 ,667 41,023 5108,000 5200,000 16,805 4,190 5200, 0 5280,000 43,702 5280,000 5128,000 16.879 5128;000 ** END OF DATA ~ **** FILE TRAILER **** ~ILE NAME ~DIT ,002 R$ION DATE : 89/07/24 .~AX REC SlZh . 1024 : LO **** TAPE TRAILER SERVICE NAM~ : EDIT ATE : 89/07/24 :~IGIN : FLIC NAME : 73404 :NUA. TION ~ : 1, PRE¥IO~S TAPE CO~ENI: : ARCO ALASKA, 1..'~C,'~' ~ ,ARCO KLPARUK 2K-7,API 50'i03'20107 LIS Tape Verification Listin~ Schlumberger AlasKa Com~:utin6 Center 24-JUb-1989 20:23 **** REEL TRAILER SFR¥ICE NA~E : EDI'r DATE : 89107124 OPIGIN : FLIC REEL NAME : 73404 CONTINUATI(]N ~ : PREVIOUS REEL : CO~ENT : aRCO ALASKA, INC,,ARCO KUPARUK 2K-7,API 50-~,03-201,07
