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192-090
Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-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 CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-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 T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' 192-090 T38905 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:54:40 -08'00' 192-090 T38905 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:55:11 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Re-enter Susp Well 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 7119'feet None feet true vertical 6301' feet None feet Effective Depth measured 6916'feet 6602', 6783'feet true vertical 6141'feet 5897', 6037'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6812' 6060' Packers and SSSV (type, measured and true vertical depth)6602' 6783' 5897' 6037' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 324-025 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer: SLB BluePack SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Staff RWO/CTD Engineer 6756-6772' (Squeezed), 6817-6842' 6016-6028' (Squeezed), 6064-6083' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 119' Well Shut-In measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-090 50-103-20181-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025586 Kuparuk River Field/ Kuparuk Oil Pool KRU 2M-12 Plugs Junk measured Length Production 1667' 7063' Casing 1706' 6288' 1706' 7102' 2742' 119'Conductor Surface Tie-Back 16" 9-5/8" 77' 2784' 2784' Burst Collapse 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 10:04 am, Apr 19, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.04.18 20:47:30-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle DSR-4/23/24 RBDMS JSB 041924 Page 1/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/1/2024 06:00 3/1/2024 09:00 3.00 MIRU, MOVE MOB P Pull sub off of well. Clean up around cellar. 3/1/2024 09:00 3/1/2024 16:00 7.00 MIRU, MOVE MOB P Move F/ 1B T/ Oliktok Y. 3/1/2024 16:00 3/1/2024 19:00 3.00 MIRU, MOVE MOB P Hold for field change out. 3/1/2024 19:00 3/2/2024 00:00 5.00 MIRU, MOVE MOB P Move F/ Oliktok Y T/ CPF 2. 3/2/2024 00:00 3/2/2024 03:30 3.50 MIRU, MOVE MOB P Move F/ CPF2 T/ 2B. 3/2/2024 03:30 3/2/2024 05:30 2.00 MIRU, MOVE MOB P Hold for Santos airport buses. . 3/2/2024 05:30 3/2/2024 09:30 4.00 MIRU, MOVE MOB P Continue to 2M pad 3/2/2024 09:30 3/2/2024 16:30 7.00 MIRU, MOVE MOB P On location. Crab rig over toward well row. Let traffic clear. Assess. Prep location. Lay herculite & matt's. Clear blown in snow around cellar. Crib up cellar box. 3/2/2024 16:30 3/2/2024 20:30 4.00 MIRU, MOVE MOB P Spot sub over 2M-12. Rig crew change out. Shim rig for level. 3/2/2024 20:30 3/3/2024 00:00 3.50 MIRU, MOVE MOB P Move in auxiliary equipment. R/U tiger tank and hard line. Completer acceptance checklist. 3/3/2024 00:00 3/3/2024 03:15 3.25 MIRU, WELCTL COND P Take on 10.1 PPG brine. Build 40 Bbls heated deep clean pill. R/U circ manifold. Blow through tiger tank hard line. PT w/ air. Take initial well pressures. T/IA/OA = 120/160/20. Rig accepted @ 0:00 Hrs. 3/3/2024 03:15 3/3/2024 03:30 0.25 MIRU, WELCTL SFTY P PJSM w/ rig crew on test lines and killing well. 3/3/2024 03:30 3/3/2024 04:00 0.50 MIRU, WELCTL PRTS P PT circ manifold & tiger tank line T/ 3500 PSI. 3/3/2024 04:00 3/3/2024 06:00 2.00 MIRU, WELCTL KLWL P Bleed free gas off of TBG F/ 60 T/ 0 quickly. Bleed gas off of IA F/ 0 T/ 0. Kill well w/ 32 Bbls 10.1 PPG heated, viscous, deep clean pill. Followed w/ xx Bbls 10.1 PPG brine pumping down TBG @ 4 BPM, xx PSI. Clean 10.1 PPG returns T/ surface. Total volume pumped =580 Bbls, Total volume returned =580 Bbls. 3/3/2024 06:00 3/3/2024 07:30 1.50 MIRU, WELCTL OWFF P Observe well for flowat open tubing and IA. 30 Min., Blow down all lines. R/D tubing line 3/3/2024 07:30 3/3/2024 09:00 1.50 MIRU, WHDBOP MPSP P Install BPV. PT 1000 PSI 10 min from below. R/D IA hose and circulating line 3/3/2024 09:00 3/3/2024 12:00 3.00 MIRU, WHDBOP NUND P PJSM Nipple down tree. Very uncoopertive. Steam flange. Pulled free. Load out tree from cellar 3/3/2024 12:00 3/3/2024 15:30 3.50 MIRU, WHDBOP NUND P Nipple up DSA. Nipple up stack on DSA. Install riser spool. TQ riser bolts. Air up boots, R/U trip lines 3/3/2024 15:30 3/3/2024 16:30 1.00 MIRU, WHDBOP NUND P PJSM for BOPE test, Start filling stack. At 100 PSI IA started flowing. S/D charge pump, IA stopped flowing. 3/3/2024 16:30 3/3/2024 21:00 4.50 MIRU, WHDBOP MPSP T Call out FMC. Pull slip over blanking plug. Inspect & redress blanking plug. Reinstall blanking plug. Fill stack w/ fresh water. Pressure up. Verify no communication to well bore past blanking plug. Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 2/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/3/2024 21:00 3/4/2024 00:00 3.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, UVBR's, w/ 3 1/2" 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. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Test gas detectors. Witness waived by AOGCC rep Brian Bixby 3/4/2024 00:00 3/4/2024 02:00 2.00 MIRU, WHDBOP NUND P Change LPR T/ 2 7/8" x 5 1/2" VBR's. 0.0 0.0 3/4/2024 02:00 3/4/2024 04:00 2.00 MIRU, WHDBOP BOPE P Continue Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested LVBR’s w/ 3 1/2" test joint. Test manual and HCR choke valves. Perform accumulator test. Initial pressure=2875 PSI, after closure=1650 PSI, 200 PSI attained =24 sec, full recovery attained =120 sec. UVBR's=5 sec, LVBR’s=5 sec. Annular=16 sec. Simulated blinds=5 sec. HCR choke & kill=1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test PVT and flow show. Witness waived by AOGCC rep Brian Bixby 0.0 0.0 3/4/2024 04:00 3/4/2024 07:00 3.00 MIRU, WHDBOP MPSP P B/D, R/D testing equipment. Suck out BOP stack. Pull blanking plug. Unabke to latch BPV on multiple attempts. M/U joint to top drive. RIH circulate / recip above BPV. Lay down joint. Pull BPV. 0.0 28.0 3/4/2024 07:00 3/4/2024 11:00 4.00 COMPZN, RPCOMP PACK P Make up landing joint. Back out LDS. See hanger unseat @ 100K pull. Pull hanger to floor. PUW=77K. Hook up hydraulic pump to control line. Able to pressure up to 5000 PSI. Cycle valve once. Block in 5000 PSI on line. Set in slips, Break down multi segment landing joint. Clear and clean rig floor 6,625.0 6,595.0 3/4/2024 11:00 3/4/2024 12:00 1.00 COMPZN, RPCOMP SLKL P R/U Slickline unit 6,595.0 6,595.0 3/4/2024 12:00 3/4/2024 16:30 4.50 COMPZN, RPCOMP SLKL P RIH w/2.6 X 8' to 1750' Clean. Run 2.5 X 12.4 drift clean to 3500'. Check SSSV pressure before going through valve. Holding pressure. Run 2.85 X 2' No Go to SSSV top @ 1767'. Run 2.85 X 5' hold open sleeve to SSSV @ 1767 Clean 6,595.0 6,595.0 3/4/2024 16:30 3/4/2024 17:30 1.00 COMPZN, RPCOMP SLKL P R/D Slick line 6,595.0 6,595.0 3/4/2024 17:30 3/4/2024 20:30 3.00 COMPZN, RPCOMP ELNE P R/U AK 6,595.0 6,595.0 3/4/2024 20:30 3/4/2024 22:00 1.50 COMPZN, RPCOMP ELNE P RIH with RTC, Log in hole. CCL. find SSSV @ 1769', Log down. Make cut @ 2494.3', Leaving 22.7' stub looking up. POOH with E-line 6,595.0 2,494.0 3/4/2024 22:00 3/4/2024 22:45 0.75 COMPZN, RPCOMP ELNE P On surface, Rig back eline 2,494.0 2,494.0 3/4/2024 22:45 3/4/2024 23:45 1.00 COMPZN, RPCOMP PULL P POOH w/ 3 1/2" EUE completion string F/ 2494' T/ 2392', PUW=55K. Overpull coming off bottom 80K fell off T/ 55K. Pipe free. 2,494.0 2,356.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 3/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/4/2024 23:45 3/5/2024 00:00 0.25 COMPZN, RPCOMP ELNE P R/U E-line w/ 2/5" x 7" IBP. 2,356.0 2,356.0 3/5/2024 00:00 3/5/2024 00:30 0.50 COMPZN, RPCOMP ELNE P R/U E-line w/ 2/5" x 7" IBP. 2,356.0 2,356.0 3/5/2024 00:30 3/5/2024 04:15 3.75 COMPZN, RPCOMP ELOG P E-line RIH w/ IBP. Set IBP COE @ 2472.6'. Inflate IBP. Pressure up appeared to shear off normally. Had to over pull & shear off @ bellville disconnect. POOH. 2,356.0 2,356.0 3/5/2024 04:15 3/5/2024 05:15 1.00 COMPZN, RPCOMP ELOG P R/D & release E-line. 2,356.0 2,356.0 3/5/2024 05:15 3/5/2024 05:45 0.50 COMPZN, RPCOMP RURD P Bleed PSI off of SSSV. R/U testing equipment. 2,356.0 2,356.0 3/5/2024 05:45 3/5/2024 06:00 0.25 COMPZN, RPCOMP PRTS P PT IBP T/ 1000 PSI for 10 Min. 2,356.0 2,356.0 3/5/2024 06:00 3/5/2024 06:15 0.25 COMPZN, RPCOMP PULL P POOH F/ 2,356' T/2,325', PUW=55K. 2,356.0 2,325.0 3/5/2024 06:15 3/5/2024 07:00 0.75 COMPZN, RPCOMP DISP P Displace will T/ seawater @ 5 BPM, 300 PSI. 2,325.0 2,325.0 3/5/2024 07:00 3/5/2024 07:30 0.50 COMPZN, RPCOMP OWFF P OWFF - 30 Min no flow. 2,325.0 2,325.0 3/5/2024 07:30 3/5/2024 08:00 0.50 COMPZN, RPCOMP SVRG P Service rig. 2,325.0 2,325.0 3/5/2024 08:00 3/5/2024 09:00 1.00 COMPZN, RPCOMP RURD P R/U sand hopper & trash pump from cellar T/ flow line. Suck off 10.1 PPG brine out of pits. 2,325.0 2,325.0 3/5/2024 09:00 3/5/2024 18:45 9.75 COMPZN, RPCOMP CIRC P Dump 25 bags of sand. Sucking out of IA, feeding down tubing. 2,325.0 2,325.0 3/5/2024 18:45 3/5/2024 19:45 1.00 COMPZN, RPCOMP CIRC P Circulate one tubing volume with cellar pump returns out IA and pumping up to pits Let sand clear tubing and settle on IBP Sim Ops: Start R/U slick line 2,325.0 2,325.0 3/5/2024 19:45 3/5/2024 20:00 0.25 COMPZN, RPCOMP PULL P PJSM for L/D TBG with pressure on control line POOH F/2,325' T/2,201' 52K UP 2,325.0 2,201.0 3/5/2024 20:00 3/5/2024 21:00 1.00 COMPZN, RPCOMP CIRC P Circulate tubing volume to clear sand and hold open sleeve profile in SSSV Rig up slick line 2,201.0 2,201.0 3/5/2024 21:00 3/5/2024 23:00 2.00 COMPZN, RPCOMP SLKL P R/U Slick line RIH W/2.85" drift/no go - tag up at 1,510' RIH set hold open sleeve @ 1510' in SSSV R/D Slick line 2,201.0 2,201.0 3/5/2024 23:00 3/6/2024 00:00 1.00 COMPZN, RPCOMP PULL P POOH L/D 3 1/@" TBG F/2,201' T/1,516' 49K UP 2,201.0 1,516.0 3/6/2024 00:00 3/6/2024 00:45 0.75 COMPZN, RPCOMP PULL P POOH F/1,516' T/1,342' At 1,342' see 3-5K over pull SSSV @ 615' Pick up one JT TBG secure control line RIH T/1,364' 49K UP 47K DN Recover 19 SS bands 1,516.0 1,364.0 3/6/2024 00:45 3/6/2024 02:00 1.25 COMPZN, RPCOMP BHAH P M/U BHA #1 GS spear (6.82') T/1,371' 1,364.0 1,371.0 3/6/2024 02:00 3/6/2024 03:15 1.25 COMPZN, RPCOMP PULD P RIH on 3 1/2" TBG F/1,371' T/2,392' 54K UP 54K DN Tag sand @ 2,392'- set DN 5K 1,371.0 2,392.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 4/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/6/2024 03:15 3/6/2024 04:00 0.75 COMPZN, RPCOMP CIRC P Make up X/over and 1 JT DP Set DN 10K - pump at 1.5 BPM 675 PSI Pick up release off bait sub Top of bait sub @ 1026.45' 2,392.0 1,026.0 3/6/2024 04:00 3/6/2024 04:45 0.75 COMPZN, RPCOMP RURD P L/D 1 JT DP and X/over, blow down top drive 1,026.0 1,026.0 3/6/2024 04:45 3/6/2024 05:45 1.00 COMPZN, RPCOMP PULD P POOH L/D TBG 1,026.0 15.0 3/6/2024 05:45 3/6/2024 06:15 0.50 COMPZN, RPCOMP BHAH P Lay down BHA#1 15.0 0.0 3/6/2024 06:15 3/6/2024 06:45 0.50 COMPZN, CSGRCY MPSP P Set test plug in tubig head for opening up lower ram cavity 0.0 0.0 3/6/2024 06:45 3/6/2024 08:15 1.50 COMPZN, CSGRCY OTHR P Change lower pipe rams to fixed 7" 0.0 0.0 3/6/2024 08:15 3/6/2024 12:15 4.00 COMPZN, CSGRCY BOPE P Make up 7" test jt // Test 7" rams and Annular 250/3500 // Unable to get good test fluid leaking past test plug // Pull test plug and re-seat // Test good test // Rig down test equipment // Blow down surface lines // Pull test plug 0.0 0.0 3/6/2024 12:15 3/6/2024 14:30 2.25 COMPZN, CSGRCY NUND P Drain stack // Nipple down BOPs and stand on stump // 0.0 0.0 3/6/2024 14:30 3/6/2024 15:30 1.00 COMPZN, CSGRCY CUTP P Clean up around well and prep for grow and stretch ops Remove 2 1/16" valves, LDS, and flanges from tubing spool 0.0 0.0 3/6/2024 15:30 3/6/2024 17:00 1.50 COMPZN, CSGRCY CUTP P Break bolts on tubing spool, R/U Hydro tight to grow casing 0.0 0.0 3/6/2024 17:00 3/6/2024 21:45 4.75 COMPZN, CSGRCY CUTP P Grow 7" casing with Hydro tight First jack with Hydro tight = #442,800 Total growth = 2.70' Monitor casing for growth for 30 min R/D Hydro Tight 0.0 0.0 3/6/2024 21:45 3/6/2024 22:45 1.00 COMPZN, CSGRCY CUTP P Remove TBG spool from 7" casing R/U cutter and cut off 7" casing below pack off to be able to spear casing 0.0 0.0 3/6/2024 22:45 3/7/2024 00:00 1.25 COMPZN, CSGRCY CUTP P M/U BHA #2 7" casing spear Spear 7" casing, pick up to 205K on hook Stretch 7" casing 1.77' Set slips as per FMC Total grow/strecth = 4.47' Release spear and L/D 0.0 0.0 3/7/2024 00:00 3/7/2024 00:15 0.25 COMPZN, CSGRCY CUTP P Release spear and L/D 0.0 0.0 3/7/2024 00:15 3/7/2024 01:00 0.75 COMPZN, CSGRCY CUTP P Rig up cutter, cut off exess casing Cut off excess casing - cut length = 5.08' 0.0 0.0 3/7/2024 01:00 3/7/2024 01:45 0.75 COMPZN, CSGRCY RURD P Clean up in cellar area, spot spacer spool behind rig, bring in 11" DSA and spacer spool into cellar 0.0 0.0 3/7/2024 01:45 3/7/2024 02:45 1.00 COMPZN, CSGRCY NUND P N/U 11" 3K x 11" 5K DSA 0.0 0.0 3/7/2024 02:45 3/7/2024 04:30 1.75 COMPZN, CSGRCY NUND P Break off DSA on BTTM of BOP, pick BOP up Remove 13 5/8" x 11" DSA, set BOP back down on pedastal N/U 11" 5K x 13 5/8" DSA 0.0 0.0 3/7/2024 04:30 3/7/2024 05:00 0.50 COMPZN, CSGRCY NUND P N/U 13 5/8" spacer spool 0.0 0.0 3/7/2024 05:00 3/7/2024 07:00 2.00 COMPZN, CSGRCY NUND P N/U BOP stack and tighten all studs up 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 5/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/7/2024 07:00 3/7/2024 10:30 3.50 COMPZN, CSGRCY NUND P Install 20" x 13 5/8" flow box riser Install riser and hook up all lines Pull RKB verrify height on rams and bag 0.0 0.0 3/7/2024 10:30 3/7/2024 12:00 1.50 COMPZN, CSGRCY PRTS P Test break on stack 0.0 0.0 3/7/2024 12:00 3/7/2024 12:30 0.50 COMPZN, CSGRCY BHAH P Pick up BHA# 2 // 5-7/8" string reamer drift run 0.0 13.0 3/7/2024 12:30 3/7/2024 14:00 1.50 COMPZN, CSGRCY PULD P Single in hole on drill pipe drifting hole to 5-7/8" // Pick up 30 jts drill pipe total 13.0 950.0 3/7/2024 14:00 3/7/2024 15:00 1.00 COMPZN, CSGRCY CIRC P Circulate well ensure good fluid // Flow check well no flow // Blow down topdrive 950.0 950.0 3/7/2024 15:00 3/7/2024 15:45 0.75 COMPZN, CSGRCY TRIP P TOOH // Pu Wt 50K 950.0 0.0 3/7/2024 15:45 3/7/2024 16:00 0.25 COMPZN, CSGRCY BHAH P M/U BHA #4 over shot for bait sub T/4' 0.0 4.0 3/7/2024 16:00 3/7/2024 18:00 2.00 COMPZN, CSGRCY PULD P RIH F/4' T/1,019' 50K UP 50K DN Note: At 210' and 620' see 5-7K drag 4.0 1,019.0 3/7/2024 18:00 3/7/2024 18:30 0.50 COMPZN, CSGRCY FISH P Slack off T/1,028', set DN 10K, P/U lean, attempt 3 times Circulate at 5 BPM 163 PSI just above fish @ 1,028' Slack off set DN 5-15K no pump pressure increase Slow pumps down to 3 BPM, rotate over fish @ 20 RPM, slack off engage fish P/U 60K 1,019.0 2,395.0 3/7/2024 18:30 3/7/2024 19:30 1.00 COMPZN, CSGRCY TRIP P Blow down top drive, fill trip tank POOH F/2,395' T/1,366' 2,395.0 1,366.0 3/7/2024 19:30 3/7/2024 20:00 0.50 COMPZN, CSGRCY BHAH P Release overshot, break off and laydown, remove bait sub from 3 1/2' TBG 1,366.0 1,366.0 3/7/2024 20:00 3/7/2024 21:00 1.00 COMPZN, CSGRCY RURD P Change out handling equipment for 3 1/2" TBG, R/U HES spooler for control line 1,366.0 1,366.0 3/7/2024 21:00 3/7/2024 22:00 1.00 COMPZN, CSGRCY PULL P POOH L/D 3 1/2" TBG F/1,366' T/686' Revover 11 SS bands, 30 total bands recovered 1,366.0 686.0 3/7/2024 22:00 3/8/2024 00:00 2.00 COMPZN, CSGRCY RURD P R/D HES spooler and clear off rig floor Load BHA #5 components in shed Monitor well on TTtake .86 BBL 686.0 686.0 3/8/2024 00:00 3/8/2024 01:00 1.00 COMPZN, CSGRCY PULL P POOH L/D 3 1/2" TBG F/686' Cut JT = 8.80' 686.0 0.0 3/8/2024 01:00 3/8/2024 03:00 2.00 COMPZN, CSGRCY RURD P Clean and clear floor, R/D TBG equipment, Change out handling equipment to 3 1/2" DP Clear pipe shed of 3 1/2" TBG, get shed ready to pick up BHA 0.0 0.0 3/8/2024 03:00 3/8/2024 04:30 1.50 COMPZN, CSGRCY BHAH P M/U BHA #5 6 1/8" string mills T/220' 0.0 220.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 6/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/8/2024 04:30 3/8/2024 07:45 3.25 COMPZN, CSGRCY TRIP P RIH F/220' T/2340' At 561' take 5K mill depths 558', 549' - pick up clean slack back off 2K drag At 570' take 7K mill depths 567', 558' - pick up clean slack back off 3-5K drag At 616' take 5K mill depths 613', 604' - pick up take 5K over, S/O back thru take 5-10K DN 613' - 616' At 620' - 625' take 5-10K - pick up take 5K over, S/O back thru take 5-10K At 815' - took 5-10K - pick up take 5K over, S/O back thru take 3-5K 50K UP 45K DN 220.0 2,340.0 3/8/2024 07:45 3/8/2024 08:15 0.50 COMPZN, CSGRCY CIRC P Circulate to ensure fluid clean 2,340.0 2,340.0 3/8/2024 08:15 3/8/2024 09:00 0.75 COMPZN, CSGRCY TRIP P Blow down TD and stand pipe TOOH F/ 2340' 50K Up 2,340.0 220.0 3/8/2024 09:00 3/8/2024 10:00 1.00 COMPZN, CSGRCY BHAH P Lay down BHA# 5 220.0 0.0 3/8/2024 10:00 3/8/2024 10:30 0.50 COMPZN, CSGRCY CLEN P Clean up and prep for e-line ops 0.0 0.0 3/8/2024 10:30 3/8/2024 12:30 2.00 COMPZN, CSGRCY ELNE P Pick up E-Line equipment for CBL 0.0 0.0 3/8/2024 12:30 3/8/2024 14:30 2.00 COMPZN, CSGRCY ELOG P Power up tools, RIH T/2300' CBL up to find TOC TOC @ 1907' 0.0 0.0 3/8/2024 14:30 3/8/2024 15:00 0.50 COMPZN, CSGRCY ELNE P Rig down E-Line 0.0 0.0 3/8/2024 15:00 3/8/2024 15:30 0.50 COMPZN, CSGRCY SVRG P Service rig , service drawworks and Top drive 0.0 0.0 3/8/2024 15:30 3/8/2024 16:30 1.00 COMPZN, CSGRCY CLEN P Clean up floor and prep to pick up BHA 0.0 0.0 3/8/2024 16:30 3/8/2024 17:15 0.75 COMPZN, RPCOMP BHAH P Pick up BHA # 6 MSC 0.0 5.0 3/8/2024 17:15 3/8/2024 18:45 1.50 COMPZN, RPCOMP TRIP P RIH T/1,627' 55K UP 60K DN 5.0 1,627.0 3/8/2024 18:45 3/8/2024 19:30 0.75 COMPZN, RPCOMP CPBO P Pump @ 1 BPM 125 PSI Locate 7" casing collars @ 1,643', 1,685' - set DN 5K 1,627.0 1,695.0 3/8/2024 19:30 3/8/2024 19:45 0.25 COMPZN, RPCOMP CPBO P Slack off 10' below collar at 1,685' T/1,695' Rotate @ 80 RPM 6.7 - 6.8K free TQ, pump at 1.8 BPM 370 PSI TQ while cutting 6.8 - 6.9K, TQ fall off to 6K Turn off rotary, slack off set down 3K on knifes, P/U 9" pulled 3K over Cut 7" CSG @ 1,695' 1,695.0 1,695.0 3/8/2024 19:45 3/8/2024 20:45 1.00 COMPZN, RPCOMP CIRC P Circulate out gas and artic pack 2.8 BPM 890 PSI Dump 95 BBLS 3.5 BPM 1440 PSI 5 BPM 3180 PSI 1,695.0 1,695.0 3/8/2024 20:45 3/8/2024 21:15 0.50 COMPZN, RPCOMP OWFF P L/D single, blow down top drive Flow check 1,695.0 1,695.0 3/8/2024 21:15 3/8/2024 22:15 1.00 COMPZN, RPCOMP TRIP P POOH F/1,668' T/5' 1,695.0 5.0 3/8/2024 22:15 3/8/2024 22:30 0.25 COMPZN, RPCOMP BHAH P L/D BHA, clean and clear rig floor 5.0 0.0 3/8/2024 22:30 3/8/2024 23:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7, casing spear T/15' 0.0 15.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 7/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/8/2024 23:00 3/9/2024 00:00 1.00 COMPZN, RPCOMP RURD P Slack off stab spear into 7" casing Rig up lines to circulate, blow air thru all lines to insure clear flow path, line to tiger tank froze up. Bring up GBR tongs to floor 15.0 34.0 3/9/2024 00:00 3/9/2024 00:30 0.50 COMPZN, RPCOMP RURD P Continue to rig up circulating lines, R/U LRS test LRS line to 1500 PSI Bring up GBR tongs 34.0 34.0 3/9/2024 00:30 3/9/2024 01:00 0.50 COMPZN, RPCOMP SFTY P PJSM on circulating OA with LRS, hot water 34.0 34.0 3/9/2024 01:00 3/9/2024 03:45 2.75 COMPZN, RPCOMP DISP P Pick up on 7" casing 75K UP, Close bag Flood lines to open top tank, test to 1000 PSI - good test Pump 88 BBLS 170° diesel at 2 BPM 40 PSI ICP 200 PSI FCP Pump 130 BBLS 120° freash water 4 BPM 300 PSI Pump 25 BBL Hivis pill Chase with 233 BBLS 8.6 PPG seawater 5 BPM 450 PSI 34.0 34.0 3/9/2024 03:45 3/9/2024 04:15 0.50 COMPZN, RPCOMP OWFF P Monitor for pressure, open bag, flow check Blow down lines, top drive, drain stack, rig down circulating lines R/U GBR tongs 34.0 34.0 3/9/2024 04:15 3/9/2024 05:00 0.75 COMPZN, RPCOMP RURD P Blow down lines, top drive, drain stack, rig down circulating lines R/U GBR tongs 34.0 34.0 3/9/2024 05:00 3/9/2024 09:30 4.50 COMPZN, RPCOMP PULL P POOH F/1,695' Lay down single DP, cut JT 7" and spear 75K UP Lay down spear and cut jt , cut jt length 34.40' Cut jt 17.30' 1,695.0 0.0 3/9/2024 09:30 3/9/2024 10:45 1.25 COMPZN, RPCOMP CLEN P Clean up floor and change elevators rig down GBR equipment 0.0 0.0 3/9/2024 10:45 3/9/2024 13:30 2.75 COMPZN, RPCOMP BHAH P Remove BHA's from shed that were used in retrieving 3.5" tubing and cutting 7" // Bring in BHA componants for drift of 9-5/8" and tie in of casing 0.0 0.0 3/9/2024 13:30 3/9/2024 15:00 1.50 COMPZN, RPCOMP BOPE P Pressure test casing head 11" 3000 psi break 250/3000 psi 5 min each, good test // Rig down test equipment 0.0 0.0 3/9/2024 15:00 3/9/2024 15:30 0.50 COMPZN, RPCOMP MPSP P Pull test plug and install wear ring // 9" ID 0.0 0.0 3/9/2024 15:30 3/9/2024 17:30 2.00 COMPZN, RPCOMP BHAH P Pick up drift BHA # 8 // 8-3/8" string mills 0.0 16.0 3/9/2024 17:30 3/9/2024 19:30 2.00 COMPZN, RPCOMP TRIP P RIH F/16' T/1,695' 58K UP 63K DN Tag 7" casing stump at 1,695' W/3K DN 16.0 1,695.0 3/9/2024 19:30 3/9/2024 20:15 0.75 COMPZN, RPCOMP CIRC P Circulate @ 8 BPM 560 PSI Pump 26 BBL Hi vis sweep around Dump 107 BBLS due to strung out artic pack contaminated seawater 1,695.0 1,695.0 3/9/2024 20:15 3/9/2024 20:45 0.50 COMPZN, RPCOMP OWFF P L/D Single T/1,680' Blow down top drive, flow check 1,695.0 1,680.0 3/9/2024 20:45 3/9/2024 21:45 1.00 COMPZN, RPCOMP TRIP P POOH F/1,680' T/16' 1,680.0 16.0 3/9/2024 21:45 3/9/2024 22:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 8 16.0 0.0 3/9/2024 22:15 3/9/2024 23:00 0.75 COMPZN, RPCOMP BHAH P M/U BHA #9, 8 1/2" mills with flex joint between them. 0.0 31.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 8/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/9/2024 23:00 3/10/2024 00:00 1.00 COMPZN, RPCOMP TRIP P RIH F/31' T/1,045' 49K UP 54K DN 31.0 1,045.0 3/10/2024 00:00 3/10/2024 01:00 1.00 COMPZN, RPCOMP TRIP P POOH F/1,045' T/31' 1,045.0 31.0 3/10/2024 01:00 3/10/2024 01:45 0.75 COMPZN, RPCOMP BHAH P Change out BHA to stiffen up BHA #10 8 1/2" mills with flex joint between T/123' 31.0 123.0 3/10/2024 01:45 3/10/2024 03:30 1.75 COMPZN, RPCOMP TRIP P RIH F/123' T/1,045' 55K UP 60K DN Note: 1 HR time change ahead 123.0 1,045.0 3/10/2024 03:30 3/10/2024 04:15 0.75 COMPZN, RPCOMP TRIP P POOH F/1,045' T/123' 1,045.0 123.0 3/10/2024 04:15 3/10/2024 05:15 1.00 COMPZN, RPCOMP BHAH P C/O BHA, for BHA #11 double stacked 8 1/2" mills T/113' 123.0 113.0 3/10/2024 05:15 3/10/2024 06:45 1.50 COMPZN, RPCOMP TRIP P RIH F/113' T/1,695' 75K UP 70K DN 113.0 1,695.0 3/10/2024 06:45 3/10/2024 07:45 1.00 COMPZN, RPCOMP CIRC P Circulate SxS PP 524 psi @ 136 SPM 1,695.0 1,695.0 3/10/2024 07:45 3/10/2024 09:15 1.50 COMPZN, RPCOMP TRIP P TOOH for dress off shoe Up Wt 1,695.0 113.0 3/10/2024 09:15 3/10/2024 10:30 1.25 COMPZN, RPCOMP BHAH P Lay down BHA# 11 113.0 0.0 3/10/2024 10:30 3/10/2024 11:00 0.50 COMPZN, RPCOMP SVRG P Change out tong pull back line 0.0 0.0 3/10/2024 11:00 3/10/2024 12:00 1.00 COMPZN, RPCOMP RGRP T Change out tong pull line, bad bearing replacement 15.0 0.0 3/10/2024 12:00 3/10/2024 12:45 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 12 dress off bha 0.0 15.0 3/10/2024 12:45 3/10/2024 13:45 1.00 COMPZN, RPCOMP TRIP P Trip in hole on stands of drill pipe to dress off stump 15.0 1,690.0 3/10/2024 13:45 3/10/2024 14:30 0.75 COMPZN, RPCOMP MILL P Dress off top of casing down to 1698' // TOC 1695' // Pump sweep // Pump S x S hole clean for tooh 1,690.0 1,698.0 3/10/2024 14:30 3/10/2024 15:45 1.25 COMPZN, RPCOMP TRIP P TOOH to run 7" tie back string // PU WT 55K // Lay down mill 1,698.0 0.0 3/10/2024 15:45 3/10/2024 16:45 1.00 COMPZN, RPCOMP OTHR P Pull wear bushing 0.0 0.0 3/10/2024 16:45 3/10/2024 19:45 3.00 COMPZN, RPCOMP RURD P Rig up GBR to run 7" Hyd 563 string with Tq Turn // Swap elevators and prep floor for casing run Bring up space out pups, blow down lines, get pipe shed in order to run casing 0.0 0.0 3/10/2024 19:45 3/10/2024 20:15 0.50 COMPZN, RPCOMP SFTY P PJSM with all hands on running 7" casing 0.0 0.0 3/10/2024 20:15 3/10/2024 23:15 3.00 COMPZN, RPCOMP PUTB P Run 7" 26# L-80 Hyd 563 casing as per detail T/1,693' M/U 7.77' pup, slack off T/1,698' latch up CSG patch on 7" CSG stump 73K UP 76K DN Set DN 30K T/50K on hook P/U 60K over T/135K to confirm latch TQ turn 7" HYD 563 connections M/U TQ = 9400FT/LBS Patch has 2.91' of swallow 0.0 1,698.0 3/10/2024 23:15 3/11/2024 00:00 0.75 COMPZN, RPCOMP PRTS P R/U to test 7" casing patch, pressure up to 1000 PSI 1,698.0 1,698.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 9/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/11/2024 00:00 3/11/2024 00:30 0.50 COMPZN, RPCOMP PRTS P Test 7" Casing/Patch T/1000 PSI F/10 min Rig down test equipment, blow down lines 1,698.0 1,698.0 3/11/2024 00:30 3/11/2024 00:45 0.25 COMPZN, CEMENT RURD P Drop "bomb" 4.82" OD M/U top drive, P/U T/75K Pressure up T/720 PSI open cementer 1,698.0 1,698.0 3/11/2024 00:45 3/11/2024 01:30 0.75 COMPZN, CEMENT CIRC P Circulate make sure brine even in/out 8 BPM 77 PSI 1,698.0 1,698.0 3/11/2024 01:30 3/11/2024 02:30 1.00 COMPZN, CEMENT OWFF P Blow down top drive, drain stack and trip tank, pull riser Perform 30 min no flow at OA in cellar 1,698.0 1,698.0 3/11/2024 02:30 3/11/2024 04:45 2.25 COMPZN, CEMENT NUND P Break stack at 11" 3K flange Pick up to 135K on hook 60K over Install FMC slips, slack off set slips 1,698.0 1,698.0 3/11/2024 04:45 3/11/2024 06:45 2.00 COMPZN, CEMENT NUND P Set stack back down, tighten bolts up on 11" 3K flange Install riser air up boots 1,698.0 1,698.0 3/11/2024 06:45 3/11/2024 15:45 9.00 COMPZN, CEMENT WAIT T Wait for warmer weather // -45° Ambiant -77° Wind Chill is below min temp for cement ops 1,698.0 1,698.0 3/11/2024 15:45 3/11/2024 20:45 5.00 COMPZN, CEMENT RURD P Spot up CMT trucks, R/U cementers, install CMT head Load rinsate pills into trip tank, pill pit, open tank and cuttings box Blow air thru all lines Wait on all vac trucks to arrive on loction 1,698.0 1,698.0 3/11/2024 20:45 3/11/2024 21:15 0.50 COMPZN, CEMENT SFTY P PJSM, circulating OA with warm water and cementing OA 1,698.0 1,698.0 3/11/2024 21:15 3/11/2024 22:00 0.75 COMPZN, CEMENT DISP P Break circulation with warm water from cement unit, shut in valve on open top tank Test hard line and cementing manifold to 1000 PSI, good test bleed off, shut in cement line on rig floor, test lines to 3000 PSI, good test bleed off Pump140° water, pump 120 BBLS at 5 BPM 576 PSI 1,698.0 1,698.0 3/11/2024 22:00 3/11/2024 23:30 1.50 COMPZN, CEMENT CMNT P Perform cement job - Cement wet @ 21:46 HRS Pump 10 BBLS fresh water spacer with red dye Pump 87 BBLS 15.3 PPG Class G Lead CMT @ 3 BPM 125 PSI Drop closing plug Kick out with 10 BBLS water from cement unit Chase with 38.2 BBLS 8.6 PPG seawater @ 3.5 BPM 866 PSI Slow pump to 3 BPM for last 15 BBLS ICP = 780 FCP = 900 PSI Bump plug @ 53.2 BBLS 905 STKS, PSI up to 2500, see cementer tool close at 1900 PSI, hold for 5 min, bleed off confirm cemeter closed CIP @ 23:12 HRS 1,698.0 1,698.0 3/11/2024 23:30 3/12/2024 00:00 0.50 COMPZN, CEMENT RURD P Blow down all lines R/D down cement head and lines Flush stack and lines with cement rinsate pills 1,698.0 1,698.0 3/12/2024 00:00 3/12/2024 01:00 1.00 COMPZN, CEMENT WWWH P R/D down cement head and lines Flush stack and lines with cement rinsate pills 1,698.0 1,698.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 10/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/12/2024 01:00 3/12/2024 06:45 5.75 COMPZN, CEMENT WOC P Wait on cement to get to 100 PSI compressive strength CIP @ 23:12 HRS 3-11-24, 100 PSI = 8 HRS 36 Min = 8:48 AM 3-12-24 Prep cellar area for splitting stack and cutting casing, clean clear rig floor. Pull riser, blow all lines down, grease choke manifold, HCR's and manual valves on BOP 1,698.0 1,698.0 3/12/2024 06:45 3/12/2024 07:45 1.00 COMPZN, CEMENT RURD P Open lower pipe rams, clean out any cement C/O rams to 2 7/8" x 5 1/2" 1,698.0 1,698.0 3/12/2024 07:45 3/12/2024 13:45 6.00 COMPZN, CSGRCY NUND P Pick up stack, cut 7" casing with Wachs cutter Break stack apart and set back 1,698.0 0.0 3/12/2024 13:45 3/12/2024 16:15 2.50 COMPZN, CSGRCY NUND P Install 7" pack off, N/U TBG head // Good test on packoffs 3000 psi 15min 0.0 0.0 3/12/2024 16:15 3/12/2024 16:45 0.50 COMPZN, CSGRCY PRTS P Test 7" pack off and 11" 3K flange break to 3000 PSI F/10 min 0.0 0.0 3/12/2024 16:45 3/12/2024 19:45 3.00 COMPZN, CSGRCY NUND P N/U 7 1/16" x 11" 5K , 11" 5K x 13 5/8" DSA's. N/U BOP tighten all bolts, install riser hook up all lines. Set test plug. 0.0 0.0 3/12/2024 19:45 3/13/2024 00:00 4.25 COMPZN, CSGRCY BOPE P Flood lines. Purge air from system. Obtain shell test. Begin Weekly BOP test w/ 3 1/2" Test Joint to 250/3500 psi on all components. 0.0 0.0 3/13/2024 00:00 3/13/2024 06:00 6.00 COMPZN, WELLPR BOPE P Complete weekly BOP test w/ 3 1/2" Test Joint to 250/3500 psi on all components. Test BOPE at 250/3500 PSI for 5-min each, Test annular, UVBR, and LVBR with 3 1/2" test joint. Test blinds rams. Choke valves #1 to #13, upper/lower top drive IBOP. Test 3 1/2" IF FOSV and dart valve. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual/HCR kill valves & manual/HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2,000 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3050 PSI, After closure = 1700 PSI. 200 PSI attained = 22 sec. Full recovery attained = 116 sec. UVBR's = 4 sec, LVBR’s = 4 sec. Annular = 17 sec. Simulated blinds = 4 sec. HCR choke & kill =1 sec each. 4 back up nitrogen bottles average = 1,900 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sean Sullivan. 0.0 0.0 3/13/2024 06:00 3/13/2024 07:45 1.75 COMPZN, WELLPR RURD P Blowdown lines. Drain Stack. Pull Test Plug. Set Wear Ring. Kick out 7" cut joint w/ pup. Load Yellow Jacket tools. 0.0 0.0 3/13/2024 07:45 3/13/2024 08:15 0.50 COMPZN, WELLPR BHAH P MU BHA #13 (cement millout). 0.0 220.0 3/13/2024 08:15 3/13/2024 10:00 1.75 COMPZN, WELLPR TRIP P TIH and lightly tag TOC @ 1,655'. 220.0 1,655.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 11/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/13/2024 10:00 3/13/2024 13:30 3.50 COMPZN, WELLPR MILL P Mill through plug and cementer F/ 1,655' T/ 1683' Up Wt= 73 Dn Wt=69 PP= 220 psi PR= 5 bbls/min Rot= 50 TQ= 4500 Unable to make progress past 1683' TOOH check bit 1,695.0 1,683.0 3/13/2024 13:30 3/13/2024 15:00 1.50 COMPZN, WELLPR TRIP P TOOH 1,683.0 0.0 3/13/2024 15:00 3/13/2024 16:15 1.25 COMPZN, WELLPR BHAH P Swap bit to Rock bit 6-1/8" 0.0 0.0 3/13/2024 16:15 3/13/2024 16:45 0.50 COMPZN, WELLPR SVRG P Tape up service loop 220.0 220.0 3/13/2024 16:45 3/13/2024 18:00 1.25 COMPZN, WELLPR TRIP P TIH to 1,683' w/ BHA #14 ( 6 1/8" roller cone bit) 0.0 1,683.0 3/13/2024 18:00 3/13/2024 21:30 3.50 COMPZN, WELLPR MILL P Obtain parameters. Up Wt = 72. Dn Wt = 76, PP = 257 psi, PR = 5 bbls/min, Rot = 70, TQ = 5K ft-lbs. Continue milling through ES Cementer and opening bomb to 1,690'. SD pumps and rotary. Dry drifted clean through ES cementer interval. TIH and tag top of sand @ approx 2,397'. Broke through sand bridge to 2,416'. Set 7K down. Dry drill on top of sand to break up debris. Dry drill to 2,418'. PUH. Bring pumps online. Wash down to 2,419'. 1,683.0 2,419.0 3/13/2024 21:30 3/13/2024 22:00 0.50 COMPZN, WELLPR CIRC P Circ BU. 2,419.0 2,419.0 3/13/2024 22:00 3/14/2024 00:00 2.00 COMPZN, WELLPR SLPC P PUH. Slip and Cut Drill Line. 2,419.0 2,408.0 3/14/2024 00:00 3/14/2024 00:30 0.50 COMPZN, WELLPR SLPC P Continue to Slip and Cut Drill Line. Function Test Crown Saver. 2,408.0 2,408.0 3/14/2024 00:30 3/14/2024 02:00 1.50 COMPZN, WELLPR TRIP P TOOH w/ BHA #14. 2,408.0 220.0 3/14/2024 02:00 3/14/2024 03:00 1.00 COMPZN, WELLPR BHAH P L/D BHA #14 (6 1/8" roller cone). Recovered metal debris in boot basket. 220.0 0.0 3/14/2024 03:00 3/14/2024 04:00 1.00 COMPZN, WELLPR BHAH P MU BHA #15 (RCJB). Performed Out of hole well control drill. 0.0 42.0 3/14/2024 04:00 3/14/2024 05:30 1.50 COMPZN, WELLPR TRIP P TIH w/ RCJB to 1,685'. String mill set down in cementer 42.0 1,685.0 3/14/2024 05:30 3/14/2024 06:30 1.00 COMPZN, WELLPR REAM P Ream out cementer with string mill // Drift good 1,685.0 1,685.0 3/14/2024 06:30 3/14/2024 07:30 1.00 COMPZN, WELLPR TRIP P TIH w/ RCJB to top of sand @ 2,419' 1,685.0 2,419.0 3/14/2024 07:30 3/14/2024 08:45 1.25 COMPZN, WELLPR WASH P PUH. Obtain parameters. Clean milling debris off top of sand. Wash down to 2428'. Blow down TD, Flow check well 2,419.0 2,428.0 3/14/2024 08:45 3/14/2024 10:00 1.25 COMPZN, WELLPR TRIP P TOOH w/ BHA #15 (RCJB Run 1). 2,428.0 0.0 3/14/2024 10:00 3/14/2024 10:45 0.75 COMPZN, WELLPR BHAH P L/D BHA #15. Recovered Chunks of metal // clean out baskets 0.0 0.0 3/14/2024 10:45 3/14/2024 12:15 1.50 COMPZN, WELLPR TRIP P TIH w/ BHA # 16 (RCJB Run 2) 0.0 2,428.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 12/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/14/2024 12:15 3/14/2024 13:30 1.25 COMPZN, WELLPR WASH P PUH. Obtain parameters. Clean milling debris off top of sand. Wash down to 2432'. Pump pressure spike to 2000 psi , unable to make it down to top of plug Blow down TD, Flow check well 2,428.0 2,432.0 3/14/2024 13:30 3/14/2024 14:30 1.00 COMPZN, WELLPR TRIP P TOOH to inspect BHA 2,432.0 0.0 3/14/2024 14:30 3/14/2024 15:15 0.75 COMPZN, WELLPR BHAH P Found opening plug "bomb" in RCJB, Make up BHA for run in hole 0.0 0.0 3/14/2024 15:15 3/14/2024 15:45 0.50 COMPZN, WELLPR CLEN P Floor wet and slick, clean up floor for trip in hole 0.0 0.0 3/14/2024 15:45 3/14/2024 17:30 1.75 COMPZN, WELLPR TRIP P TIH w/ BHA# 17 (RCJB Run 3). 0.0 2,432.0 3/14/2024 17:30 3/14/2024 18:00 0.50 COMPZN, WELLPR WASH P PUH. Obtain parameters. Pump Rate = 8 BPM @ 1,661 psi. RPM = 10, Free Torque = 1.8K. Clean milling debris off top of sand. Wash down to 2,447'. 2,432.0 2,447.0 3/14/2024 18:00 3/14/2024 18:30 0.50 COMPZN, WELLPR OWFF P Blow down TD, Flow check well 2,447.0 2,447.0 3/14/2024 18:30 3/14/2024 19:45 1.25 COMPZN, WELLPR TRIP P TOOH to inspect BHA 2,447.0 42.0 3/14/2024 19:45 3/14/2024 20:15 0.50 COMPZN, WELLPR BHAH P L/D RCJB. Recovered chunk of rubber and small metal chunks/pieces. 42.0 0.0 3/14/2024 20:15 3/14/2024 21:00 0.75 COMPZN, WELLPR BHAH P MU BHA #18 (RCJB Run 4). 0.0 42.0 3/14/2024 21:00 3/14/2024 22:00 1.00 COMPZN, WELLPR TRIP P TIH w/ RCJB to sand top @ 2,447'. 42.0 2,447.0 3/14/2024 22:00 3/14/2024 22:15 0.25 COMPZN, WELLPR WASH P PUH. Obtain parameters. 30 RPM, Free Torque = 3K. Pump Rate = 7 BPM @ 1513 psi. Wash down to 2,455' cleaning debris off top of sand plug. 2,447.0 2,455.0 3/14/2024 22:15 3/14/2024 22:30 0.25 COMPZN, WELLPR CIRC P Circ BU. 2,455.0 2,455.0 3/14/2024 22:30 3/14/2024 23:00 0.50 COMPZN, WELLPR OWFF P Blowdown TD. OWFF 2,455.0 2,455.0 3/14/2024 23:00 3/15/2024 00:00 1.00 COMPZN, WELLPR TRIP P TOOH w/ BHA #18 to inspect for debris. 2,455.0 42.0 3/15/2024 00:00 3/15/2024 00:45 0.75 COMPZN, WELLPR BHAH P L/D RCJB. Recovered shroud of opening bomb. 42.0 0.0 3/15/2024 00:45 3/15/2024 01:30 0.75 COMPZN, WELLPR BHAH P MU BHA #19 (RCJB Run #5) 0.0 42.0 3/15/2024 01:30 3/15/2024 03:00 1.50 COMPZN, WELLPR TRIP P TIH w/ RCJB to sand top @ 2,455'. 42.0 2,455.0 3/15/2024 03:00 3/15/2024 03:15 0.25 COMPZN, WELLPR WASH P Obtain parameters. 6 BPM @ 2,000 psi. Wash down to 2,456', cleaning debris off top of sand plug. Circ BU. 2,455.0 2,456.0 3/15/2024 03:15 3/15/2024 03:30 0.25 COMPZN, WELLPR OWFF P Blowdown TD. OWFF. 2,456.0 2,456.0 3/15/2024 03:30 3/15/2024 05:00 1.50 COMPZN, WELLPR TRIP P TOOH w/ BHA #19. 2,456.0 42.0 3/15/2024 05:00 3/15/2024 06:00 1.00 COMPZN, WELLPR BHAH P L/D RCJB. Recovered no material. Clean. 42.0 0.0 3/15/2024 06:00 3/15/2024 06:30 0.50 COMPZN, WELLPR BHAH P MU BHA #20 (Baker IBP Pulling Tool). 0.0 14.5 3/15/2024 06:30 3/15/2024 08:00 1.50 COMPZN, WELLPR TRIP P TIH w/ BHA #20 to sand top @ 2,455'. 14.5 2,455.0 3/15/2024 08:00 3/15/2024 12:00 4.00 COMPZN, WELLPR CIRC P Unload 8.6# from pits. Load new 10.1# brine. Circ STS to load well with 10.1# brine. 2,455.0 2,455.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 13/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/15/2024 12:00 3/15/2024 15:30 3.50 COMPZN, WELLPR WASH P Wash down to top of plug @ 2,467' // Stack and pressure up @ 2462' // Unable to wash down further // Reverse circ B/U // Still unable to latch into IBP 2,455.0 2,467.0 3/15/2024 15:30 3/15/2024 17:00 1.50 COMPZN, WELLPR TRIP P TOOH w/ BHA #20. 2,467.0 14.5 3/15/2024 17:00 3/15/2024 17:30 0.50 COMPZN, WELLPR BHAH P L/D BHA #20 (IBP Pulling Tool). 14.5 0.0 3/15/2024 17:30 3/15/2024 18:00 0.50 COMPZN, WELLPR BHAH P MU BHA #21 (Hydraulic Overshot) 0.0 14.0 3/15/2024 18:00 3/15/2024 19:00 1.00 COMPZN, WELLPR TRIP P TIH w/ BHA #21 to IBP top @ 2,453'. 14.0 2,453.0 3/15/2024 19:00 3/15/2024 19:30 0.50 COMPZN, WELLPR WASH P Obtain parameters. PUW = 67K. SOW = 72K. Pump rate = 0.5 BPM. Pump Pressure = 215 psi. Wash down to IBP @ 2,464'. See pressure indicator. Set 3K down. Swallow IBP with hydraulic overshot. PU to confirm good latch. 2,453.0 2,464.0 3/15/2024 19:30 3/15/2024 20:00 0.50 COMPZN, WELLPR MPSP P PU 6K to release. Did not release. Set 3K down and reattempt. PU 6K. Did not release. PU 7K. IBP released. Allow element to relax. PU to collar. Blowdown Top Drive. 2,464.0 2,449.0 3/15/2024 20:00 3/15/2024 20:30 0.50 COMPZN, WELLPR OWFF P OWFF. 2,449.0 2,449.0 3/15/2024 20:30 3/15/2024 22:00 1.50 COMPZN, WELLPR TRIP P TOOH w/ BHA #21 (hydraulic overshot) and IBP fish. No pump out sub. Pull wet. 2,449.0 14.5 3/15/2024 22:00 3/15/2024 22:30 0.50 COMPZN, WELLPR BHAH P L/D BHA #21 and IBP. IBP in good condition. Recovered opening bomb debris on top of IBP. 14.5 0.0 3/15/2024 22:30 3/15/2024 23:00 0.50 COMPZN, WELLPR RURD P RU testing equipment. Flood lines. Purge Air. Prep to test 7" casing down to CA-2 plug. Close Blinds. 0.0 0.0 3/15/2024 23:00 3/15/2024 23:15 0.25 COMPZN, WELLPR PRTS P PT 7" casing to 2500 psi against CA-2 plug @ 6,671'. Charted for 15-min. Passed. 0.0 0.0 3/15/2024 23:15 3/15/2024 23:30 0.25 COMPZN, WELLPR RURD P Bleed off. Open Blinds. Blowdown lines. RD testing equipment. 0.0 0.0 3/15/2024 23:30 3/16/2024 00:00 0.50 COMPZN, WELLPR BHAH P MU BHA #22 (YJ 3 1/2" Overshot). 0.0 0.0 3/16/2024 00:00 3/16/2024 00:30 0.50 COMPZN, WELLPR BHAH P Cont. to MU BHA #22 (YJ 3 1/2" Overshot). 0.0 210.0 3/16/2024 00:30 3/16/2024 01:30 1.00 COMPZN, WELLPR TRIP P TIH to 2,455'. Set down 5K. Pushing debris/junk. Clean pickup. Cont. TIH seeing 1-3K bobbles. Set down again at 2,457'. PU. Rotate string 1/2 turn. TIH to 2,494' with no issues. 210.0 2,494.0 3/16/2024 01:30 3/16/2024 02:00 0.50 COMPZN, WELLPR WASH P Obtain parameters. PUW = 75K. SOW = 75K. Pump rate = 2 BPM. Pump Pressure = 60 psi. 2,494.0 2,494.0 3/16/2024 02:00 3/16/2024 03:00 1.00 COMPZN, WELLPR FISH P TIH to set down at 2,531'. Set 5K down @ 2,531'. PUH. Rotate at 10 RPM. Free Torque = 1K. TIH to 2,531'. Scoop up stub. Fully locate @ 2,534'. Set 7K down. Slight pressure indicator of 30 psi. PU to confirm latched. PU to 140K and broke over to 105K. Moving pipe at 105K. Set slips. Breakout and blowdown Top Drive. 2,494.0 2,534.0 3/16/2024 03:00 3/16/2024 07:30 4.50 COMPZN, WELLPR TRIP P Crew C/O. TOOH w/ 3 1/2" Tubing fish from pre-rig cut @ 6,625' to 4,301', standing back DP. 6,625.0 4,301.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 14/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/16/2024 07:30 3/16/2024 08:30 1.00 COMPZN, WELLPR BHAH P L/D BHA #22 (YJ Overshot). 4,301.0 4,091.0 3/16/2024 08:30 3/16/2024 15:30 7.00 COMPZN, WELLPR TRIP P Cont TOOH laying down 3 1/2" Tubing from 4,091' to surface. Cut jt 17.53' // Bottom of jt damaged 2.75' split down middle 4,091.0 0.0 3/16/2024 15:30 3/16/2024 17:00 1.50 COMPZN, WELLPR CLEN P Rig down liner equipment, change elevators, prep floor for running/picking up drill pipe // Prep BHA for fishing run 0.0 0.0 3/16/2024 17:00 3/16/2024 18:30 1.50 COMPZN, WELLPR BHAH P Crew C/O. MU BHA #23 (Overshot). 0.0 210.0 3/16/2024 18:30 3/16/2024 20:00 1.50 COMPZN, WELLPR TRIP P TIH on stand of drill pipe T/ 2,437' 210.0 2,437.0 3/16/2024 20:00 3/17/2024 00:00 4.00 COMPZN, WELLPR PULD P Continue TIH picking up singles DP from pipe shed to 6,047'. 2,437.0 6,047.0 3/17/2024 00:00 3/17/2024 01:00 1.00 COMPZN, WELLPR PULD P Continue TIH picking up singles DP from pipe shed to 6,605'. Set 5K down approx. 10' early after RKB corrections. N3 RKB = 29.1'. Parker 245 RKB = 39'. 6,047.0 6,605.0 3/17/2024 01:00 3/17/2024 02:45 1.75 COMPZN, WELLPR FISH P Screw in TD. Obtain parameters. PUW = 124K. SOW = 115K. Pump Rate = 5 BPM @ 1,000 psi. 2.5' of swallow on Overshot before grapple. Wash down to 6,605'. Set 5K down. PUH. Rotate string 1/2 turn. TBIH. Set down at same. PUH. 6 BPM @ 1,400 psi. Rotate string @ 30 RPM. Free Torque = 3.8K. TBIH to 6,605'. See weight bobbles. Set 2K down. WT. fell off. Slowly worked down to 6,606' seeing torque ranging from 4.8-6K. PUH. Drift down to 6,606.3'. Mark pipe. Continue making attempts to rotate down over fish top. Slowly work down to 6606.6' rotating at 15 RPM. PUH. Clean up weight. No overpull. Adjust to 20 RPM. 6 BPM @ 1,400 psi. Work down to 6,607.5'. Set 3-5K down. Rotate slowly to capture fish. Repeat as set down WT dropped off. PUH slowly. See 10K overpull then slipped off. Continued attempts to latch fish. Worked down to final depth of 6,608'. PUH. Saw slight overpull and looked like 1-2K WT gain but acted like it was slipping off fish. Backoff and blowdown Top Drive. 6,605.0 6,607.6 3/17/2024 02:45 3/17/2024 03:15 0.50 COMPZN, WELLPR OWFF P PUH. OWFF for 30-min. 6,607.6 6,510.0 3/17/2024 03:15 3/17/2024 06:15 3.00 COMPZN, WELLPR TRIP P TOOH w/ BHA #23 (5 3/4" OD Overshot). 6,510.0 210.0 3/17/2024 06:15 3/17/2024 07:00 0.75 COMPZN, WELLPR BHAH P L/D BHA #23. No marks on overshot // Retrieved 1' chunk of tubing folded up in shoe // 210.0 0.0 3/17/2024 07:00 3/17/2024 08:00 1.00 COMPZN, WELLPR BHAH P Pick up BHA# 24 (6 1/8" x 3 1/2" Burn shoe) to dress off top of stump 0.0 210.0 3/17/2024 08:00 3/17/2024 12:00 4.00 COMPZN, WELLPR TRIP P TIH to top of fish @ 6607' 210.0 6,607.0 3/17/2024 12:00 3/17/2024 13:15 1.25 COMPZN, WELLPR WASH P Get perameters:Pu Wt 124K // So Wt 115K // Pump 1.5 bpm @ 587psi // Start washing over stump @ 6607.5' 3K wob Tq 6640 PP 627psi 6,607.0 6,607.0 3/17/2024 13:15 3/17/2024 17:00 3.75 COMPZN, WELLPR TRIP P Blow down TD // TOOH w/ BHA #24. 6,607.0 210.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 15/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/17/2024 17:00 3/17/2024 18:00 1.00 COMPZN, WELLPR BHAH P Lay down and inspect BHA# 24. Minimal wear. Crew C/O. 210.0 0.0 3/17/2024 18:00 3/17/2024 19:15 1.25 COMPZN, WELLPR BHAH P MU BHA #25 (6 1/16 x 4 5/8" ID Burnshoe). 0.0 217.0 3/17/2024 19:15 3/17/2024 22:45 3.50 COMPZN, WELLPR TRIP P TIH to tubing stub @ 6,607.5'. 217.0 6,506.0 3/17/2024 22:45 3/18/2024 00:00 1.25 COMPZN, WELLPR SLPC P Slip and cut Drill Line. 6,506.0 6,506.0 3/18/2024 00:00 3/18/2024 01:00 1.00 COMPZN, WELLPR SLPC P Finish Slip and Cut. 6,506.0 6,506.0 3/18/2024 01:00 3/18/2024 03:45 2.75 COMPZN, WELLPR FISH P Screw in TD to Joint #69. TIH. Back out of TD. PU Joint #70. Screw in TD. Obtain parameters. PUW = 126K. SOW = 115K. 5.0 BPM @ 959 psi. Rotation = 40 RPM. Free Torque = 5K. Slowly TIH and burn over fish @ 6,607.5'. See fish top. Weight bobble. Cont. TIH swallowing fish to 6,612.2'. Set 3K down. Torque = 5.2K. Repeat process. Set 5K down. Continue to set down @ 6,612' (4.8' of swallow to inner mill). Seeing torque increase but little mill off. 6,506.0 6,612.2 3/18/2024 03:45 3/18/2024 05:15 1.50 COMPZN, WELLPR CIRC P PUH. Pump 30 bbl hi-vis sweep. Circ BU. 6,612.2 6,612.2 3/18/2024 05:15 3/18/2024 05:45 0.50 COMPZN, WELLPR OWFF P OWFF. 6,612.2 6,612.2 3/18/2024 05:45 3/18/2024 09:00 3.25 COMPZN, WELLPR TRIP P TOOH w/ BHA #25 (4.625" burn shoe) 6,612.2 210.0 3/18/2024 09:00 3/18/2024 09:45 0.75 COMPZN, WELLPR BHAH P L/D BHA #25. 210.0 0.0 3/18/2024 09:45 3/18/2024 10:15 0.50 COMPZN, WELLPR BHAH P BHA# 26 (3.5" dressoff shoe) 0.0 218.0 3/18/2024 10:15 3/18/2024 13:00 2.75 COMPZN, WELLPR TRIP P TIH to top of fish @ 6607' 218.0 4,500.0 3/18/2024 13:00 3/18/2024 13:30 0.50 COMPZN, WELLPR SVRG P Service rig // Grease blocks and drawworks 4,500.0 4,500.0 3/18/2024 13:30 3/18/2024 14:30 1.00 COMPZN, WELLPR TRIP P Continue trip in hole to top of fish 6607' 4,500.0 6,607.0 3/18/2024 14:30 3/18/2024 15:30 1.00 COMPZN, WELLPR WAIT T Highline issues CPF 2 line wend down // Work on getting power restored to rig // 15:30 rig back on HL 6,607.0 6,607.0 3/18/2024 15:30 3/18/2024 17:30 2.00 COMPZN, WELLPR MILL P Dress top of fish F/ 6608' T/ 6613' Up Wt = 126K Dn Wt= 115K PP 480psi @ 4bpm 80rpm @ 8000 tq TQ while milling 8400 // 1' in erattic pipe movement and tq, pick up 10K overpull 20' up kill rot stack out @ 6609.9' // Kick on rotary continue milling over stump // @ 16:28 wt fall off indicate over stump, continue down T/6613' // Kill rot pick up 20K overpull ( 145K ) SO T/ 6609' 15K wob // Rot 60 rpm work down T/6612' // Continue to clean up stump for Overshot run down T6613' 6,607.0 6,612.0 3/18/2024 17:30 3/18/2024 18:00 0.50 COMPZN, WELLPR OWFF P OWFF. Crew C/O. 6,612.2 6,612.2 3/18/2024 18:00 3/18/2024 21:30 3.50 COMPZN, WELLPR TRIP P TOOH w/ BHA #26 (3 1/2" burn shoe) 6,612.2 210.0 3/18/2024 21:30 3/18/2024 22:15 0.75 COMPZN, WELLPR BHAH P L/D BHA #26 210.0 0.0 3/18/2024 22:15 3/18/2024 23:00 0.75 COMPZN, WELLPR BHAH P MU BHA #27 (3 1/2" overshot) 0.0 218.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 16/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2024 23:00 3/19/2024 00:00 1.00 COMPZN, WELLPR TRIP P TIH w/ BHA #27 to midnight depth of 2,560'. 218.0 2,560.0 3/19/2024 00:00 3/19/2024 01:45 1.75 COMPZN, WELLPR TRIP P Cont TIH w/ BHA #26 to just above tubing stub @ 6,526'. 2,560.0 6,526.0 3/19/2024 01:45 3/19/2024 02:15 0.50 COMPZN, WELLPR FISH P Screw in TD. Obtain Parameters. PUW = 126K. SOW = 114K. Pump Rate = 4 BPM @ 546 psi. TIH to top of fish @ 6,608'. See 1-2K weight bobble at top of fish. Cont. to swallow fish to 6,612.8'. Set 8k down. PUH to 140K (15K over). Set back down on fish to 6,615.1' (7' swallow). Set down 10K. Press. bumped up to 700 psi. PU to 160K (34K over). Hit 1 Jar Lick. Set back down on fish to 6,615.1'. PU to 126K and seals pulled out of packer. Still have pressure indicator (fish on). 6,526.0 6,615.1 3/19/2024 02:15 3/19/2024 03:45 1.50 COMPZN, WELLPR CIRC P PUH. Circ STS (X2) @ 5.5 BPM and 1272 psi. 6,615.1 6,606.0 3/19/2024 03:45 3/19/2024 04:15 0.50 COMPZN, WELLPR OWFF P OWFF. 6,606.0 6,606.0 3/19/2024 04:15 3/19/2024 06:00 1.75 COMPZN, WELLPR TRIP P TOOH w/ BHA #27 (3 1/2" Overshot) and fish. 6,606.0 3,482.0 3/19/2024 06:00 3/19/2024 07:00 1.00 COMPZN, WELLPR RGRP T Work on link tilt system 3,482.0 3,482.0 3/19/2024 07:00 3/19/2024 09:45 2.75 COMPZN, WELLPR TRIP P TOOH w/ BHA #27 (3 1/2" Overshot) and fish. 3,482.0 218.0 3/19/2024 09:45 3/19/2024 11:15 1.50 COMPZN, WELLPR BHAH P L/D BHA #27. Seal assembly in tact // 218.0 0.0 3/19/2024 11:15 3/19/2024 13:45 2.50 COMPZN, WELLPR CLEN P Clean up rig floor start BOP test prep // Pull wear ring // Flush stack for BOP test 0.0 0.0 3/19/2024 13:45 3/19/2024 16:30 2.75 COMPZN, WELLPR RURD P Rig up BOP test equipment install test plug 0.0 0.0 3/19/2024 16:30 3/19/2024 22:30 6.00 COMPZN, WELLPR BOPE P Perform weekly BOP test w/ 3 1/2" Test Joint to 250/3500 psi on all components. Test BOPE at 250/3500 PSI for 5-min each, Test annular, UVBR, and LVBR with 3 1/2" test joint. Test blinds rams. Choke valves #1 to #13, upper/lower top drive IBOP. Test 3 1/2" IF FOSV and dart valve. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual/HCR kill valves & manual/HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2,000 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3050 PSI, After closure = 1700 PSI. 200 PSI attained = 23 sec. Full recovery attained = 109 sec. UVBR's = 4 sec, LVBR’s = 4 sec. Annular = 23 sec. Simulated blinds = 3 sec. HCR choke & kill =1 sec each. 4 back up nitrogen bottles average = 2,050 PSI. Test gas detectors, PVT and flow show. Witnessed by AOGCC rep Kam StJohn 0.0 0.0 3/19/2024 22:30 3/20/2024 00:00 1.50 COMPZN, WELLPR RURD P R/D test equipment, Drain stack Blow down choke & kill.Pull test plug 0.0 0.0 3/20/2024 00:00 3/20/2024 00:30 0.50 COMPZN, WELLPR RURD P Set wear ring - Run in LDS 0.0 0.0 3/20/2024 00:30 3/20/2024 01:00 0.50 COMPZN, WELLPR RURD P P/U three additional drill collars for milling packer, strap 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 17/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/20/2024 01:00 3/20/2024 02:30 1.50 COMPZN, WELLPR BHAH P P/U BHA #22. 6.125 packer mill. P/U three drill collars from shed. Two stands out of derrick 0.0 314.4 3/20/2024 02:30 3/20/2024 06:30 4.00 COMPZN, WELLPR TRIP P Trip in well F/314' T/ 6,627' 314.4 6,627.0 3/20/2024 06:30 3/20/2024 07:00 0.50 COMPZN, WELLPR OTHR P Blow down tiger tank line ensure lines are open for packer gas if needed 6,627.0 6,627.0 3/20/2024 07:00 3/20/2024 07:30 0.50 COMPZN, WELLPR SVRG P Service valve in pits 6,627.0 6,627.0 3/20/2024 07:30 3/20/2024 09:30 2.00 COMPZN, WELLPR DISP P Displace well to 12.5# Water based polymer mud // Take 10.1 returns to truck to blend for 12.5# // Pmp 89spm ( 10 bpm ) @ 3800 psi // 6,627.0 6,627.0 3/20/2024 09:30 3/20/2024 12:00 2.50 COMPZN, WELLPR COND P Condition mud for milling 6,627.0 6,627.0 3/20/2024 12:00 3/20/2024 17:00 5.00 COMPZN, WELLPR MILL P Get SPR Mill packer F/ 6,627' T/ 6631 Pump 5 bbls/min @ 1000psi // Rot 80 rpm @ 8100 tq // Up Wt 127K Dn Wt 111K // Engage top of packer, pumped off bottom and pop-offs blown // Re-pin pop-offs circulate well confirm SPRs // Re engage fish 6,627.0 6,631.0 3/20/2024 17:00 3/20/2024 17:30 0.50 COMPZN, WELLPR CIRC P Fluid level dropping after packer free, PUH to 6625, Lost 10 BBls in 5 min. Shut trip tank. 6,625.0 6,625.0 3/20/2024 17:30 3/20/2024 18:00 0.50 COMPZN, WELLPR CIRC P Restart pump, Travel down to 6655', No sign of packer, Circ BU 1.5 times 5 BPM @ 1120 PSI. No signs of gas 6,625.0 6,655.0 3/20/2024 18:00 3/20/2024 19:00 1.00 COMPZN, WELLPR OWFF P Observe well for flow 30 minutes. No flow, Lay down working joint and 15' pup. RIH to 6756' 6,655.0 6,756.0 3/20/2024 19:00 3/20/2024 20:00 1.00 COMPZN, WELLPR MILL P Kelly up, Dry mill on packer 70 RPM. 7.6zk zfree torque. Bring pumps online 4 BPM @ 811 PSI. Pressure up to 1300 PSI soon as stinger enters packer 6,655.0 6,755.0 3/20/2024 20:00 3/20/2024 20:30 0.50 COMPZN, WELLPR CIRC P PUH to 6755. Circ BU 7 BPM @ 2000 PSI. Set down on packer @ 7656 6,755.0 6,756.0 3/20/2024 20:30 3/21/2024 00:00 3.50 COMPZN, WELLPR TRIP P POOH 6756 to 776'. PUW=135K off bottom 6,756.0 776.0 3/21/2024 00:00 3/21/2024 00:30 0.50 COMPZN, WELLPR TRIP P Continue trip out of well. PUW=50K 776.0 315.0 3/21/2024 00:30 3/21/2024 02:00 1.50 COMPZN, WELLPR BHAH P Lay down BHA # 22. 3 stands DC. Break and clean boot baskets, Clean rig floor 315.0 0.0 3/21/2024 02:00 3/21/2024 02:30 0.50 COMPZN, WELLPR BHAH P M/U BHA #23, Packer spear 0.0 315.2 3/21/2024 02:30 3/21/2024 06:30 4.00 COMPZN, WELLPR TRIP P TIH & Spear packer // Good spear @ 6740' // 315.2 6,740.0 3/21/2024 06:30 3/21/2024 07:30 1.00 COMPZN, WELLPR CIRC P Attempt to circ through spear // Spear appears to be packed off in tubing unable to circ down DP 6,740.0 6,740.0 3/21/2024 07:30 3/21/2024 09:30 2.00 COMPZN, WELLPR TRIP P TOOH 10 stands pulling slow to not swab 6,740.0 5,700.0 3/21/2024 09:30 3/21/2024 11:00 1.50 COMPZN, WELLPR CIRC P Drop opening dart for circ out sub // unable to pump it down wait for dart to fall on seat // pump open circ sub circ B/U 5,700.0 5,700.0 3/21/2024 11:00 3/21/2024 16:00 5.00 COMPZN, WELLPR TRIP P TOOH to lay down fish // Slow pulling spead due to swab effect, CA-2 plug still in tubing tail no circ point below packer // @ 2200' increased swabbing while pulling stands // Stop to circ B/U // 5,700.0 2,200.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 18/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/21/2024 16:00 3/21/2024 16:30 0.50 COMPZN, WELLPR CIRC P Circulate B/U ensure well clean 2,200.0 2,200.0 3/21/2024 16:30 3/21/2024 22:00 5.50 COMPZN, WELLPR TRIP P Continue out of hole with packer and spear BHA, Frequent flow checks. POOH slowing, swabbing 2,200.0 315.0 3/21/2024 22:00 3/22/2024 00:00 2.00 COMPZN, WELLPR BHAH P Lay down BHA # 23 and fish Recovered 10.88' of packer 315.0 0.0 3/22/2024 00:00 3/22/2024 00:30 0.50 COMPZN, WELLPR BHAH P Clean and clear rig floor 0.0 0.0 3/22/2024 00:30 3/22/2024 02:00 1.50 COMPZN, WELLPR BHAH P M/U BHA #24 6.125 clean out 0.0 336.0 3/22/2024 02:00 3/22/2024 06:00 4.00 COMPZN, WELLPR TRIP P Trip in well, BHA #24 336.0 6,630.0 3/22/2024 06:00 3/22/2024 10:00 4.00 COMPZN, WELLPR SLPC P Cut and slip drill line 6,630.0 6,630.0 3/22/2024 10:00 3/22/2024 16:00 6.00 COMPZN, WELLPR REAM P Get perameters for reaming F/ 6630' T/6915' Pump 7 bpm @ 2000 psi // Rot 56 rpm @ 6500 ft/lbs // Rot Wt 110K Stall @ 6783' // work past spot @ 6783 - 6785 started loosing fluid ~10bbl/hr // Continue reaming down stand T/ 6841' **STALL** // Work mills past tight spot T/6844' ( Torque swings from 6k to 8k ) hole clean up @ 6844' // Continue in hole T/ 6915' 6,630.0 6,915.0 3/22/2024 16:00 3/22/2024 17:00 1.00 COMPZN, WELLPR CIRC P Circulate S x S ensure hole clean for running completion // Work string while circulating to ensure perfs clean . Work pump up to 10 BPM @ 3720 PSI. Sand in returns, Circ until clean returns 611 BBls 6,915.0 6,915.0 3/22/2024 17:00 3/22/2024 17:30 0.50 COMPZN, WELLPR P OWFF, Blow down top drive 6,915.0 6,915.0 3/22/2024 17:30 3/22/2024 22:30 5.00 COMPZN, WELLPR TRIP P TOOH racking stands in derrick for move PUW=140K 6,915.0 315.0 3/22/2024 22:30 3/23/2024 00:00 1.50 COMPZN, WELLPR BHAH P Lay down BHA# 24 inspect mills. Mills show slight wear on nose. Some debrie in boot basket 315.0 0.0 3/23/2024 00:00 3/23/2024 00:30 0.50 COMPZN, RPCOMP BHAH P Continue laying down Cleanout BHA. Load ut to ground 0.0 0.0 3/23/2024 00:30 3/23/2024 03:00 2.50 COMPZN, RPCOMP BHAH P Clean and prep floor for running completion, Jet stack. Pull wear ring. Double check jewelry order and items. RHC plug in nipple. 230 Jtsin ODS shed. 5 spares behind jewelry. Rig down spinners. Rig up power tongs. Ensure FOSV has proper X-O 0.0 0.0 3/23/2024 03:00 3/23/2024 03:18 0.30 COMPZN, RPCOMP SFTY P PJSM to run 3 1/2" completion 0.0 0.0 3/23/2024 03:18 3/23/2024 06:00 2.70 COMPZN, RPCOMP PUTB P M/U 3 1/2" completion 0.0 1,084.0 3/23/2024 06:00 3/23/2024 06:30 0.50 COMPZN, RPCOMP SVRG P Service tubing tongs // Adjust to bite on pipe 1,084.0 1,084.0 3/23/2024 06:30 3/23/2024 16:00 9.50 COMPZN, RPCOMP PUTB P Pick up and run 3.5" EUE 8rd completion // Change out Jt 135 due to bad collar replaced with same length jt " C " 31.10' // Continue to run in hole with completion // 1,084.0 6,774.0 3/23/2024 16:00 3/23/2024 16:30 0.50 COMPZN, RPCOMP THGR P Pick up tubing hanger and land in tubing hanger // Up Wt 87K Dn Wt 77K 6,774.0 6,800.0 3/23/2024 16:30 3/23/2024 17:00 0.50 COMPZN, RPCOMP ELNE P Rig up e-line for gamma corrilation 6,800.0 6,800.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Page 19/19 2M-12 Report Printed: 4/18/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/23/2024 17:00 3/23/2024 20:00 3.00 COMPZN, RPCOMP ELOG P RIH with e-line // Log K1 and corrilate to completion // consult with town engineer for space out /+32'/ POOH with e-line 6,800.0 6,800.0 3/23/2024 20:00 3/23/2024 20:30 0.50 COMPZN, RPCOMP ELNE P Rig down e-line 6,800.0 6,800.0 3/23/2024 20:30 3/23/2024 22:00 1.50 COMPZN, RPCOMP THGR P P/U tubing hanger with landing joint. Lay down hanger. Add 31.5' joint. M/U tubing hanger. Land hanger, run in LDS. Lay down landing joint. 6,800.0 6,800.0 3/23/2024 22:00 3/23/2024 23:00 1.00 COMPZN, RPCOMP WWSP P Run in set BPV. Test to 1000PSI/10 min. Unable to get over 650 PSI. No fluid coming up past BPV. Well drinking. Hold 600 PSI / 10 minures 6,800.0 6,800.0 3/23/2024 23:00 3/24/2024 00:00 1.00 COMPZN, WHDBOP RURD P Blow down surface lines. R/D test equipment 6,800.0 6,800.0 3/24/2024 00:00 3/24/2024 08:00 8.00 COMPZN, WHDBOP NUND P ND stack. Remove bell nipple and swing out of cellar. Remove double spool. M/U stack to DSA spool. Stab onto BOP rack 6,800.0 0.0 3/24/2024 08:00 3/24/2024 10:00 2.00 COMPZN, WHDBOP RURD P Rig up circulating manifold for CI and Freeze protect 0.0 0.0 3/24/2024 10:00 3/24/2024 11:45 1.75 COMPZN, WHDBOP PRTS P Pressure test lines with LR // Pressure test tree // Pull BPV 0.0 0.0 3/24/2024 11:45 3/24/2024 14:30 2.75 COMPZN, WHDBOP DISP P Pump 10.1 CI down IA taking returns up tubing // 3 bpm @ 925 psi 0.0 0.0 3/24/2024 14:30 3/24/2024 14:45 0.25 COMPZN, WHDBOP OTHR P Drop Ball and rod. Rig up sensators tubing & IA2 0.0 0.0 3/24/2024 14:45 3/24/2024 17:00 2.25 COMPZN, WHDBOP PRTS P Set packers 3600psi // Roll into 30 min Tubing test Pressure up 3840 psi 15 min 3750psi 30 min 3720 psi good test // Lower tubing to 1500psi // Pressure up IA 2880 psi 15 min 2820 psi 30 min 2820 psi good test 0.0 0.0 3/24/2024 17:00 3/24/2024 18:00 1.00 COMPZN, WHDBOP PRTS P PT hardline to TT 0.0 0.0 3/24/2024 18:00 3/24/2024 20:00 2.00 COMPZN, WHDBOP DISP P PJSM, pump diesel FP, 80 BBls, Final pump pressure 600 PSI 0.0 0.0 3/24/2024 20:00 3/24/2024 21:00 1.00 DEMOB, MOVE RURD P U-Tube freeze protec one hourt, R/D LRS 0.0 0.0 3/24/2024 21:00 3/24/2024 22:30 1.50 DEMOB, MOVE RURD P Blow down circ lines and surface lines. Rig down circ equip 0.0 0.0 3/24/2024 22:30 3/25/2024 00:00 1.50 DEMOB, MOVE RURD P Work RDMO checklist 0.0 0.0 3/25/2024 00:00 3/25/2024 03:00 3.00 DEMOB, MOVE MOB P Complete RDMO check list. Warm up moving system. Pull rig off 2M-12 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 3/25/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,916.0 2M-12 4/12/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install post RWO GLD. Pull plug, tag 2M-12 4/12/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Tagged cmt obstruction @ 6780 RKB W/2.65 cent & 2.5 Bailer 4/10/2013 haggea NOTE: WAIVERED WELL: IA x OA COMMUNICATION 2/17/2004 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 119.0 119.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.8 2,783.7 2,783.5 36.00 J-55 BTC 7" Tie-Back String work over 2024 7 6.28 39.0 1,705.9 1,705.9 26.00 L-80 HYD 563 PRODUCTION 7 6.28 39.0 7,102.4 6,288.3 26.00 J-55 AB-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.1 Set Depth … 6,812.4 String Max No… 3 1/2 Set Depth … 6,060.0 Tubing Description Tubing - Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.6 37.6 0.00 Hanger 6.982 3 1/2" FMC Gen 4 Tubing Hanger, TC-1A-EN (H BPV Profile) FMC TC-1A- EN 2.952 2,478.4 2,478.3 0.19 Mandrel – GAS LIFT 6.005 3-1/2" x 1-1/2" MMG (w/ 1.5" DV and RK Latch. (SN: 24135-15) SLB MMG 2.920 3,875.9 3,857.0 21.78 Mandrel – GAS LIFT 5.849 3-1/2" x 1-1/2" MMG (w/ 1.5" DV and RK Latch. (SN: 24135-13) SLB MMG 2.920 4,810.1 4,641.4 37.48 Mandrel – GAS LIFT 5.955 3-1/2" x 1-1/2" MMG (w/ 1.5" DV and RK Latch). (SN: 23762-08) SLB MMG 2.920 6,541.1 5,850.5 40.75 Mandrel – GAS LIFT 6.002 3-1/2" x 1-1/2" MMG, EUE (2,000 psi SOV, RKP Latch). (SN: 24135-12) SLB MMG 2.920 6,601.5 5,896.5 40.14 Packer 5.992 3-1/2" x 7" BluePack RH Max VAM TOP B/P (3,500 psi), SN: C23P- 1913 SLB BluePac k 2.894 6,782.7 6,036.7 38.63 Packer 6.000 3-1/2" x 7" BluePack RH Max VAM TOP B/P (3,500 psi), SN: C23P- 0281 SLB BluePac k 2.894 6,804.8 6,054.0 38.58 Nipple - X 4.499 2.813" X-Nipple (SN#: 5011991-18) HES X-Nipple 2.813 6,811.9 6,059.6 38.56 Wireline Guide 4.499 3-1/2" WLEG, 9.3#, L-80, EUE HES WLEG 3.010 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) 39.6 39.6 0.00 EMERGENCY SLIPS Set FMC slips on 7" casing FMC 3/11/2024 7.000 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) 2,478.4 2,478.3 0.19 1 GAS LIFT GLV RK 6.00 5 1,215.0 4/12/2024 SLB MMG 0.250 3,875.9 3,857.0 21.78 2 GAS LIFT GLV RK 5.84 9 1,195.0 4/11/2024 SLB MMG 0.250 4,810.1 4,641.4 37.48 3 GAS LIFT GLV RK 5.84 9 1,190.0 4/11/2024 SLB MMG 0.313 6,541.1 5,850.5 40.75 4 GAS LIFT OV RK 6.00 2 0.0 4/11/2024 SLB MMG 0.250 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) 1,690.2 1,690.2 0.30 Collar - Stage 8.240 CMTR,TYPE H ES-II, HYD 563 L- 80 Halliburto n HES II CMTR 4.370 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,756.0 6,772.0 6,015.9 6,028.4 C-4, A-5, 2M-12 10/21/2001 6.0 APERF 2.5" HSD, PJ Chgs; 60 deg ph 6,817.0 6,842.0 6,063.6 6,083.1 A-3, 2M-12 12/21/1992 4.0 IPERF SWS 4 1/2" Csg Gun, 180 deg. phasing; Oriented 10 deg. CCW F/ High Sid Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,756.0 6,772.0 6,015.9 6,028.4 CEMENT SQUEEZE SQUEEZED C-SAND PERFS 2M-12, 4/18/2024 12:33:20 PM Vertical schematic (actual) PRODUCTION; 1,703.0-7,102.4 IPERF; 6,817.0-6,842.0 Nipple - X; 6,804.8 BALL & ROD; 6,798.0 Packer; 6,782.7 APERF; 6,756.0-6,772.0 CEMENT SQUEEZE; 6,756.0 ftKB Packer; 6,601.5 Mandrel – GAS LIFT; 6,541.1 Mandrel – GAS LIFT; 4,810.1 Mandrel – GAS LIFT; 3,875.9 SURFACE; 41.8-2,783.7 Mandrel – GAS LIFT; 2,478.4 7" Tie-Back String work over 2024; 39.0-1,705.9 7" Casing Cement; 39.0 ftKB CONDUCTOR; 42.0-119.0 Hanger; 37.6 KUP PROD KB-Grd (ft) 45.51 RR Date 9/9/1992 Other Elev… 2M-12 ... TD Act Btm (ftKB) 7,119.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018100 Wellbore Status PROD Max Angle & MD Incl (°) 50.96 MD (ftKB) 5,348.88 WELLNAME WELLBORE2M-12 Annotation Last WO: End Date 3/25/2024 H2S (ppm) 90 Date 12/5/2018 Comment SSSV: TRDP STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2M-12 JBR 04/12/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 3-1/2" Test joint used. 11 Accumulator bottles 1000 psi precharge. BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold". FSV Misc: EUE FOSV. Test Results TEST DATA Rig Rep:Henry/BezoldOperator:ConocoPhillips Alaska, Inc.Operator Rep:Chase Erdman / Jim Newell Rig Owner/Rig No.:Nordic 3 PTD#:1920900 DATE:3/19/2024 Type Operation:WRKOV Annular: 250/3500Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS240320133146 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 3184 Sundry No: 324-025 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 1 P Inside BOP 1 P FSV Misc 1 P 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8" x 5-1/2 P #2 Rams 1 Blinds P #3 Rams 1 2-7/8" x 5-1/2 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 2 2-1/6"P System Pressure P3050 Pressure After Closure P1725 200 PSI Attained P23 Full Pressure Attained P109 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P23 #1 Rams P4 #2 Rams P3 #3 Rams P4 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Al Hansen To:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC) Cc:Company Man, Nordic 3 Subject:Nordic 3 BOP test form Date:Tuesday, March 5, 2024 3:31:11 AM Attachments:Nordic 3 BOP AOGCC 03-03-24.xlsx Al Hansen Rig Manager Rig 3 907-440-6928 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. .580 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:3 DATE: 3/4/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1920900 Sundry #324-025 Operation: Drilling: Workover: xxx Explor.: Test: Initial: xxx Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3184 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 1P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5 1/2"P Flow Indicator PP #2 Rams 1 CSO Rams P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5 1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2875 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1650 P Check Valve 0NA200 psi Attained (sec)24 P BOP Misc 2 2 1/16" 5000 P Full Pressure Attained (sec)120 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 x 2000 P No. Valves 12 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 1P Annular Preventer 16 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 hrs HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-3-24/07:18 hrs Waived By Test Start Date/Time:3/3/2024 20:30 (date) (time)Witness Test Finish Date/Time:3/4/2024 4:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nordic Test BOPE with 3 1/2" test joint, Accumulator system pressure adjusted up to 3,000 PSI 3/5/24 Henry/Twedt CPAI Newell/Barr KRU 2M-12 Test Pressure (psi): gmanager.rig3@nordic-calista.com ic3.Companyman@conocophillips Form 10-424 (Revised 08/2022) 2024-0304_BOP_Nordic3_KRU_2M-12 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ 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 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk River Field 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7119 3184 None Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Elliot Tuttle Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 2M-12 Other: Replace Tubing N/A Kuparuk River Field elliott.tuttle@conocophillips.com CTD/RWO Engineer Size Kuparuk River Oil Pool 6301' Plugs (MD): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 6647'MD/5931'TVD SSSV: 1807'MD/1807'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25659, ADL 25664 192-090 P.O. Box 100360, Anchorage, AK 99510 50-103-20181-00-00 ConocoPhillips Alaska, Inc Proposed Pools: J-55 TVD Burst 6683' MD 119' 2784' 119' 2784' 16" 9-5/8" 73' 2738' Perforation Depth MD (ft): 6756-6772 6817-6842' 7056' 6016-6028' 6064-6083' 6288'7" 6670'6805 6054' 2/18/2024 3-1/2" Packer: Baker F-1 Permanent SSSV: Camco TRDP-4A 7102' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Kayla Junke at 12:57 pm, Feb 15, 2024 Revised 324-025 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.14 20:36:40-09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle VTL 02/26/2024 BOP test to 3500 psig Annular preventer test to 2500 psig X DSR-2/15/24A.Dewhurst 16FEB24 X ADL0025586 10-404 ($8JLC 2/20/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.02.20 09:25:40 -09'00' RBDMS JSB 022024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 14, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2M-12 (PTD# 192-090). This is a revised submission due to material procurement issues. A tubing run plug deployed through the 3 1/2" tubing is planned rather than an Eline set plug as commonly practiced. Well 2M-12 was drilled and completed in 1992 by Parker 245. It was initially an A-sand Kuparuk producer, but then became an A and C-sand Kuparuk producer in 2001. In 2007 the C sand was cemented off due to poor performance. May of 2017 a brush and flush was performed noting heavy weight swings. A Caliper was then run noting corkscrewed tubing due to subsidence (near surface). The well was moved to RWO to repair the well. If you have any questions or require any further information, please contact me at +1 907-252-3347 The tubing will be pulled. The 7" casing will be grown/stretch and drift will be verified. If no drift possible, then the subsided PC casing will be removed, replaced and cemented in. Once drift of PC has been addressed, the production packer will be removed so that the C sand can be isolated with the new upper completion. New GL completion will be run with 2 packers, straddling the C sand cemented perforation. Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN= Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.02.14 20:37:09 -09'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: CTCO,Cmt Sqz, N2_ Development Exploratory 3. Address: 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: 5,474; Total Depth measured 9,170 feet 5,534; 8,597 feet true vertical 8,283 feet ~8,530 feet Effective Depth measured 5,474 feet 5,374 feet true vertical 4,992 feet 4,902 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" & 1-1/2" 6.4/L-80 & 2.75/J-55 5,955 & 2,944 (MD) 5,414 & 2,858 (TVD) 5,374 MD Packers and SSSV (type, measured and true vertical depth)Baker Prem Pkr 4,902 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3,450psi 6,870psi 8,160psi 895' 894' Burst Collapse 1,950psi895' TVD measured Packer Plugs Junk measured Length measured true vertical STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-109 50-283-20088-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0032930 Ivan River / Undefined Gas Pool Ivan River Unit 41-01 00 0 8280 98 9-5/8" 7" 3,335' 8,266' 3,498' 9,152' 4,750psi 7,020psi 0 Gas-Mcf MD 0 Size 165' Intermediate 20" 13-3/8" 165' Production Liner 3,498' 9,152' Casing Structural 165'Conductor Surface 0 Jake Flora, Operations Engineer 323-596 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 719 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 jake.flora@hilcorp.com 907-777-8442 N/A Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.30 19:25:51 - 09'00' Noel Nocas (4361) Rig Start Date End Date 11/4/23 11/17/23 11/04/2023- Saturday Mob equipment to location Spot in & rig up equipment. Transport & load water. BOP test as per sundry 250 psi low / 3000 psi high. Fluid pack coil and PT CTC to 3500 psi. M/U BHA = 2. 13" CTC 2. 13" DFCV 2. 13" Bidi Jars 2. 13" Disco 2. 13" Circ Sub 2. 13" Motor 2. 20" 4 bladed junk mill. BHA OAL = 23. 77'. Stab on well. Function test motor - good. RIH w/YJ FCO BHA - Motor & Mill. At 4600' ctm PUW 20k RIW 11k. Tank straps: FW 475 bbls Return 36 bbls. RIH w/YJ FCO BHA - Motor & Mill. At 4600' ctm PUW 20k RIW 11k. Tank straps: FW 475 bbls Return 36 bbls. 4800' ctm. Online down coil taking returns up tbg. Circ 2500 psi WHP 25 psi. Establish 1:1 returns. Cleanout 4800' - 5400'. Wiper trip. RIH. Circ 2600 psi WHP 35 psi. 1 bpm 1:1 returns. Tag Cmt Retainer 5528' ctm. Wiper trip up above top open perf 5446'. RIH. Re-tag Cmt retainer @ 5528' ctm (+6' correction) PUH to 5394' ctm / 5400' Corrected MD. 5400' - 23. 77' BHA = 5376. 23' MD. Flag pipe yellow. Corrected EOP at flag = 5376. 23'. PUH. At 5000' shut in CTBS. Injectivity test: . 5 bpm WHP went up to 1000 psi. Off pump. WHP slowly dropping. No injectivity to pump cement through retainer. 11/05/2023 - Sunday PJSM Discuss daily operations. Pull out of hole from 3000' to 0' bump up Lay down bit & motor assembly Pick up wash nozzle. Run in hole to 3000'. Work string from 3000' to 3500' unload hole with N2 flowing thru choke. Run in hole to tag @ 5490' Kick in N2 & fluff hole with 300 scf/min to induce kick. Work string from 5000' to 5490' while pumping N2. Pull out of hole with jet nozzle to pick up motor & pit assembly. Pick up motor assembly & millRun in hole with motor & mill (2. 20" mill) to tag @ 5485'. Kick in pump @ 1 bbl/min wash down from 5485' to 5534'. Work pipe from 5000' to 5485'. Circulate hole clean. Run in hole to tag @ 5534'. Zero pipe & flag pipe @ 5474'. Establish injection rate 1 bbl/min with 550 psi. Pull tubing out of hole to pick up CICR. Discuss plan forward w/OE. RIH w/N2 nozzle to 3000' and unload well w/N2. Tagged high @ 5490'. POOH and M/U motor & mill (2. 20"). Clean out to PBTD @ 5534' flagged coil @ 5474' and established injectivity 1 bbl/min @ 550 psi. POOH w/BHA. M/U YJ CICR BHA and RIH w/YJ Cast Iron Cmt Retainer. At flag 5474 - 14 correction for shorter BHA = 5460 COE. Adjust counter. On set depth Launch ball online down coil 1 bpm. Confirm ball rolling. Circ 1900 psi @ 1 bpm. At 35 bbls away ball still not seated. Ball seated. Coil pressured up to 2371 psi. No indication of shear. Bleed coil off. Pressure up coil to 3500 psi. No Stack 8k down retainer set. Unable to pump through it. Pull up to unsting from retainer 35k. Pressure up coil to 700 psi PUH 50 and tag CICR @ 5474. PUH and attempt to pump down coil pressured up to 3000 psi. Inject down CTBS @ 1 Round up N2 transport to blow down reel. Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name IRU 41-01 50-283-20088-00-00 192-109 w/N2 nozzle to 3000' and unload well w/N2. Tagged high @ 5490'. POOH and M/U motor & mill (2. 20"). Clean out to PBTD @ 5534' flagged coil @ 5474' and established injectivity 1 bbl/min @ 550 psi. POOH w/BHA. M/U YJ CICR BHA and PUH 50 and tag CICR @ 5474. PUH and attempt to pump down coil pressured up to 3000 psi. Inject down CTBS @ 1 RIH w/YJ Cast Iron Cmt Retainer. At flag 5474 - 14 correction for shorter BHA = 5460 COE. Adjust counter. On set depth Flag pipe yellow. Corrected EOP at flag = 5376. 23'. PUH. At 5000' shut in CTBS. Injectivity test: . 5 bpm WHP went up to 1000 psi. Off pump. WHP slowly dropping. No injectivity to pump cement through retainer. RIH w/YJ Cast Iron Cmt Retainer. At flag 5474 - 14 correction for shorter BHA = 5460 COE. Adjust counter. On set depth psi WHP 35 psi. 1 bpm 1:1 returns. Tag Cmt Retainer 5528' ctm. Wiper trip up above top open perf 5446'. RIH. Re-tag Cmt retainer @ 5528' ctm (+6' correction) PUH to 5394' ctm / 5400' Corrected MD. 5400' - 23. 77' BHA = 5376. 23' MD. Rig Start Date End Date 11/4/23 11/17/23 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name IRU 41-01 50-283-20088-00-00 192-109 11/07/2023 - Tuesday 11/08/2023 - Wednesday PJSM, Disscuss daily plan to mob cement equipment from Ivan river to Beluga barge landing. Mob all remaining equipment to barge landing 11/09/2023 - Thursday PJSM, Discuss clean out operations & traveling to location in wintery conditions, Crew travel to location, Pick up tool assembly on injection head & stab onto well, Make up 4 (2. 26" mill) blade mill on 2-1/8" motor. Run in hole to tag @ 5335', Spot in & rig up pump, Clean out cement from 5335' to 5474'. Drop CIRC ball (. 56") with 3500 psi to open circ sub with 3200 psi, switch from fluid to N2. Blow hole dry. Pull out of hole while blowing N2 recovered (48 bbls) per strap lock in 1400 psi, Bump up & secure well, Bleed down reel. PIck up injector head from BOP, break down tools. Rig down & move equipment to barge landing. 11/15/2023 - Wednesday 11/16/2023 - Thursday PJSM, Discuss daily operations, Crew travel to location, PJSM, Attempt to nipple up dual string adaptor leaking, Replace o-rings & metal ring & test-good, Pick up 2' gun 6 spf GR/CCL, Pressure test lubricator 250 low/ 3000 high-good, Bump up pressure with N2 to 1800 psi, Run in hole to correlate tag CIBP @ 5456', Send in Log and correlate good on depth, Run back in hole with 2' x 2" 6 spf to shoot 5450'-5452', 5 min 1800, 10-1800, 15-1800,(plug wet) Pull out of hole pick up 8' x 2" gun 6 spf, 7 gram, Run in hole to perf from 5446' to 5454', 5-1800, 10-1800, 15-1800, Pull out hole & rig down, Secure well. PJSM, Discuss daily operations, Crew travel to location, Check wellhead pressure SITP-1300, Pick up 5' strip gun & run in hole to 5428' & shoot from 5454-5449,(5-1300, 10-1300, 15-1300) Pull out of the hole, Secure well winds to high to continue perfing, Rig down. 11/17/2023- Friday PJSM, Discuss daily operations, Crew travel to location, Pick up lube & 5' strip gun, Make up lube to wellhead & pressure test-good, Attempt to run gun thru wellhead (hand spang) (break off lube and check tools multiple times), Work string thru wellhead, Remove strip gun & make modifications, Make up tools & attempt to run in the hole (Unable to pass max OD 2. 13"), Pull off well, Remove gun and go thru wellhead (Max OD 1. 69") no issues, Make up gauge ring (Max OD 2. 05") Run in hole no issues, Pull out & pick up 5' strip gun attempt to run in hole-no pass, Call town & discuss, Decsion made to rig down & move to H-pad. Secure well & turn over to production. 5335', Spot in & rig up pump, Clean out cement from 5335' to 5474'. Drop CIRC ball (. 56") with 3500 psi to open circ sub 8' x 2" gun 6 spf, 7 gram, Run in hole to perf from 5446' to 5454', 5-1800, 10-1800, 15-1800, Pull out hole & rig down, Run back in hole with 2' x 2" 6 spf to shoot 5450'-5452', 5 min 1800, 10-1800, 15-1800,(plug wet) Pull out of hole pick up hole to 5428' & shoot from 5454-5449,(5-1300, 10-1300, 15-1300) Pull out of the hole, Secure well winds to high to _______________ __________________________________________________ Updated by DMA 11-30-23 SCHEMATIC Ivan River Unit IRU 41-01 Completion Ran 8/10/11 PTD: 192-109 API: 50-283-20088-00-00 TD =9,170 PBTD = 8,597 Sterling / Beluga RT-THF:24 KB 7 @ 9,152 ST B1U 14 3 16 517 19 15 18 12 3 4 7 RKB: 51 AMSL 13-3/8 @ 895 9-5/8 @ 3,498 20 @ 165 1 13 9 10 11 0 2 Tyonek ST A3 8 6 ST X2 ST A1 5 Tagged fill @ 8,851(7/22/09) CBL Top:5,000 R RA Fill cleanout to 5800(8-4-23) CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20Conductor 94# Surface 165Driven 13-3/8Surface 68#, K-55 Surface 895 Butt / 12.415212 bbl / Cmt to Surface 9-5/8Intermediate 47#, N-80 Surface 144 Butt / 8.681281 bbl / Cmt to Surface47#, S-95 144 3,498 Butt / 8.681 7Production 29#, N-80 Surface 9,152 Butt / 6.184 171 bbl / Cmt to 5,000 Tubing Detail 2-7/8Production 6.4#, L-80 Surface 5,955 IBT-Mod/2.441 1-1/2Heater 2.75#, J-55 Surface 2,99410RD Fluid: Propelyne Glycol JEWELRY DETAIL No. Depth Length ID OD Item 1 24.20 0.55 2.441 12.00 Dual Tubing Hanger, 2-7/8 x 2-3/8 12 5M National (2-7/8 & 2-3/8 8RD lift threads) 2 5,327 4.03 2.310 3.920Sliding Sleeve, Halliburton XD 3 5,374 8.38 2.870 5.980Premier Packer 4 5,428 1.30 2.313 3.220 Baker X Profile (2.313 Min ID) 5 5474CICR Cement retainer (11/5/23) 6 5,534Cement Retainer (9/17/23) 7 5,595 1.41 2.257 2.880Mechanical-release 8 5,728CIBP (9/16/23) 9 5,916 0.70 2.441 3.958Ported Sub 10 5,955 0.94 3.670 4.950WLEG 11 +/-8,530 32.77- - Dropped TCP Assembly 12 8,597 2.00- -Cement Retainer capped w/ 269 cement (Est) 13 8,613-2.441 3.500Cut tubing stub 14 8,629 4.78 3.250 5.968 Baker 3H Packer w/ mill out extension (Min ID thru Anchor Latch Seal Assembly) 15 8,643 0.67 2.441 3.500 Baker RA Sub 16 8,650 1.24 2.2503.500" Baker R Profile w/ No-go 17 8,659 0.63 2.441 3.687Baker Ported Sub w/ glass disc 18 8,693 0.82 2.441 3.687Tubing Tail 19 8,895 (est) 183 3.687FISH: Baker TCP Drop Off Guns PERFORATION DETAIL ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) Ft Condition Sterling X2 5,446 5,454 4,669 4,975 8Perfed 11/15/23 - Open Sterling A1 5,494 5,501 5,010 5,017 7Perfed 9/22/23 - Squeezed ST-A3 5,544 5,551 5,054 5,0607 Perfed 9/9/22 Isolated ST-B1U 5,671' 5,678' 5,165' 5,172' 7 Perfed 2/4/21 Isolated Sterling/ Beluga 5,977 5,9875,434' 5,443' 5 spf 4-5/8 TCP (11/2/11) 73-4 Sd 7,768' 7,796' 7,019' 7,044' 6 spf 2 HC, 60 deg phase (6/29/12) Iso 7,954 7,9747,186' 7,204' 6 spf 2 HC, 60 deg phase (6/28/12) Iso Tyonek 8,710 8,7257,868' 7,882' 12 spf Perfed 1/26/93 Isolated 8,745 8,7687,900' 7,920' 12 spf Perfed 1/26/93 Isolated 8,783 8,8037,934' 7,952' 12 spf Perfed 1/26/93 Isolated 8,815 8,8757,963' 8,017' 12 spf Perfed 1/26/93 Isolated 2M-12 RWO Procedure Kuparuk Producer PTD #192-090 Page 1 of 3 Completed Pre-Rig Work 1. MIT-OA to 1800 psi (passed) – 12/12/23 2. T-PPPOT, T-POT, IC-POT, (Passed) and IC-PPPOT tests (Failed), FT LD’s (passed) - 12/12/23 3. 2500psi CMIT (passed) Confirm plug/packer with Drawdown Test (DDT) (on-going) – 12/14/23. Remaining Pre-Rig Work 4. Obtain TxIA DDT, OA DDT 5. Make tubing cut @ 6625’ RKB, if drift allows 6. Lockout SSSV if possible. Install hold open sleeve as needed. 7. Prepare well for rig 48-72 hrs before rig arrival. Rig Work MIRU 1. MIRU Nabors Nordic 3 on 2M-12. (No BPV will be set due to risk assessment done on Nordic 3.) 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 250/3500 psi. Test annular 250/3500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~6625’ RKB). 6. If not all tubing comes due to subsidence, then work additional sub-steps below to clear buckled 7”, then pull remaining completion. a. RU Eline while holding on to tubing. i. Cut tubing an additional time as needed to create plug space. b. RIH with IBP through tubing and set in 7” casing. PT plug to confirm. i. No Eline set plugs available, RI with plug on 1 ¼” CS Hydril through false floor and inside 3 ½” tubing (Work string out of size range for BOP). Have triple connect on kick jnt throughout operation as means to pump kill/ isolate well throughout operation (similar to inner string operation on Screened Lateral). ii. Set 2nd IBP if necessary. c. Dump sand on plug. Set tubing down on sand gently. 7. If all tubing does pull free, and drift of 7.0” casing looks good. Then commence with only grow and stretch portion subsidence on the existing 7” casing. Then go to “Remove 3 ½” x 7” Production Packer” step. Pull Subsided 7.0” Casing 8. Set storm packer or plug in 7” casing and PT to confirm as barrier. a. Set additional IBPs or RBPs in 7.0” casing and dump sand as necessary. 9. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. b. Shell test 3000 psi rated flanges on wellhead to 3000 psig when flanges are exposed to test pressure as soon as practical. 10. Pull storm packer or plug. Condition fluid as needed. 11. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. 2M-12 RWO Procedure Kuparuk Producer PTD #192-090 Page 2 of 3 12. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry as needed. 13. Pull 7.0” casing down to cut (~1600’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. b. If any 3.5” tubing was left downhole. Pull 3.5” tubing to clear wellbore for tie-back running. Bore out 9-5/8” and run 7.0” Tie-Back Subsidence 14. PU mills and bore out 9-5/8” as necessary to obtain drift for new 7.0” tie-back. a. As drift is regained, pull any additional 7.0” or 3.5” tubing as needed to get 7.0” removed down to cement in OA. 15. Run new 7.0” tie-back casing with overshot. 16. Test casing to 2500 psig. 17. Cement OA to surface. 18. Split stack and land slips, cut excess casing and install IC packoffs. Installed tubing spool and terminate 7.0”. Land stack and MU to casing flange. a. Shell test flange break. 19. Mill plugs in cementer. 20. Circulate out sand on IBP or any lower plug. Pull plugs. a. Pull any remaining 3.5”. b. Perform cleanout run down to stub if needed Remove 3 ½” x 7” production packer 21. Weight up to KWF 22. Mill on/ Remove 3 ½” x 7” Production packer push to bottom a. Close annular and circulate out packer gas, weight up if required 23. Fish packer out of hole 24. Cleanout across cemented C sand perforation and A sand perforations. a. Log across if needed Install New 3-½” Completion and ND BOP, NU Tree 25. MU 3 ½” completion with overshot, packers, nipples, and GLMs. RIH with completion. 26. Once on depth, close annular on 3 ½” tubing and rig up E-Line with pressure control a. Log packers on depth, RD Eline b. Space out tubing hanger c. Land tubing in hanger, RI LDs, test packoffs to 5000psi 27. Circulate in CI fluid at opportune time as needed. After CI is in place, set packers. 28. Pressure test tubing to 3000 psi for 30 minutes and chart. 29. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 30. Confirm pressure tests, then shear out SOV with pressure differential. 31. Install BPV. Test. 32. ND BOPE. NU tree. PT tree. 33. Pull BPV. 34. Freeze protect well, and set BPV if necessary. 35. RDMO. ND BOP, NU Tree 36. Confirm pressure tests, then shear out SOV with pressure differential. 37. Install BPV. 38. ND BOPE. NU tree. 2M-12 RWO Procedure Kuparuk Producer PTD #192-090 Page 3 of 3 39. Pull BPV, freeze protect well, and set BPV if necessary. 40. RDMO. Post-Rig Work 41. Pull BPV 42. Pull any remaining plugs. Install GLD. Turn over to operations General Well info: Wellhead type/pressure rating: FMC Kuparuk Gen IV, 11” 3M top flange on Casing spool. 7-1/16” 5M top flange on Tubing spool Production Engineer: Natalie Dye Surveillance and Reservoir Engineer: Kevin Wiggs Estimated Start Date: 2/18/24 Workover Engineer: 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. Confirm subsidence issues and drift. Repair 7” subsidence with cut/pull/replace of tops section of 7” casing as needed. Remove production packer and run new 3.5” completion straddling the C sand perforations. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failed N/A CMIT-TxIA Passed to 2500psi – 12/13/23 MIT-OA Pass to 1800 psi on 12/12/23 IC POT &PPPOT Failed – 12/12/23 TBG POT &PPPOT PASSED – 12/12/23 MPSP: 3184 psi using 0.1 psi/ft gradient Static BHP: 3789 psi @ 6050 TVD measured on 5/4/18 – well has lost drift and plug cannot be removed, 2M-03 is shut in currently and tracks pressure well with 2M-12, plan to take SBHP from 2M-03 prior to rig up. 2M-12 Proposed RWO Completion - Workstring inside tubing 3 1/2" IF Box, to be made up to Ball Valve 2.5" Inflate plug, to be set in 7" casing 3 1/2" EUE to be made up to Production tubing 1 1/4" CS Hydril to be made up to Workstring Triple Connect Surface Casing Production/Intermediate Casing Conductor C-Sand Perfs 6756' - 6772' (cement squeezed) A-Sand Perfs 6817' - 6842' Top of Arctic Pack estimated @ 1760' RKB 2M-12 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 119 119 16 15.06 62.58 H-40 Welded Welded Surface 2784 2784 9.625 8.921 36 J-55 BTC BTC Production/ Intermediate 7102 6288 7 6.276 26 J-55 BTC BTC Tubing 6682 5958 3.5 2.992 9.3 L-80 EUE8rd Mod EUE8rd Mod New Tubing 6626 5915 3.5 2.992 9.3 L-80 EUE8rd Mod EUE8rd Mod PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 2481' RKB 3880' RKB 4817' RKB 6427' RKB 3-1/2" x 7" Packer C Sand Perforations @ 6756' to 6772' RKB 3 1/2" x 7" Packer 2.813" X-landing nipple at xxxx' RKB (2.813" min ID) 3 1/2" WLEG PROPOSED 7.0" Tie-Back 7.0", 26# L80, HYD563 to Surface 7.0" Cementer 7.0" Sealing Overshot Remaining Completion in the hole during 7" Subsidence Repair Tubing Cut @ ~6626' RKB (planned cut depth) GBH-22 Seal Assembly @ 6646' RKB (2.985" ID) BKR F-1 Perm Packer @ 6647' RKB (4.00" ID) D nipple @ 6671' RKB (2.75" ID) -CA-2 Plug installed SOS @ 6682' RKB Surface Casing Production/Intermediate Casing Conductor C-Sand Perfs 6756' - 6772' (cement squeezed) A-Sand Perfs 6817' - 6842' Top of Arctic Pack estimated @ 1760' RKB Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est 37' of Rat hole, leaving 49' of Open Perfs) 6,805.0 5/4/2018 2M-12 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: (Secure) Set plug & Gas Lift 11/17/2019 2M-12 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 119.0 Set Depth (TVD) … 119.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.8 Set Depth (ftKB) 2,783.7 Set Depth (TVD) … 2,783.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 39.0 Set Depth (ftKB) 7,102.4 Set Depth (TVD) … 6,288.3 Wt/Len (l… 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.5 Set Depth (ft… 6,683.1 Set Depth (TVD) (… 5,959.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.5 37.5 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,806.7 1,806.7 0.36 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 6,646.2 5,930.8 39.79 SEAL BAKER GBH-22 LOCATOR SEAL ASSEMBLY w/XO & SBE (5" OD, ID 4") 2.985 6,647.0 5,931.4 39.79 PACKER BAKER F-1 PERMANENTPACKER 4.000 6,670.5 5,949.5 39.51 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,682.2 5,958.5 39.34 SOS BAKER SHEAR OUT SUB, ELMD @ 6673' per SWS PERF Record (10-21-01) 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,667.0 5,946.8 39.56 2.73" Baited Pulling Tool Catcher Assembly 2.73" Bait Sub (13"), XO (belongs to unit 765), & 2.5" gutted JD (31" OAL) 11/17/201 9 0.000 6,670.0 5,949.1 39.51 2.75" CA-2 Plug Set 2.75" CA-2 Plug (28" OAL) 11/17/201 9 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,756.0 6,772.0 6,015.9 6,028.4 C-4, A-5, 2M-12 10/21/2001 6.0 APERF 2.5" HSD, PJ Chgs; 60 deg ph 6,817.0 6,842.0 6,063.6 6,083.1 A-3, 2M-12 12/21/1992 4.0 IPERF SWS 4 1/2" Csg Gun, 180 deg. phasing; Oriented 10 deg. CCW F/ High Sid Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 6,756.0 6,772.0 6,015.9 6,028.4 Cement Squeeze 2/15/2007 SQUEEZED C-SAND PERFS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,782.9 2,782.7 MACCO SPM-1A 1 GAS LIFT DMY BK2 0.000 0.0 11/17/2019 2 4,505.0 4,398.8 MACCO SPM-1A 1 GAS LIFT DMY BK2 0.000 0.0 9/17/2019 3 5,605.0 5,184.9 MACCO SPM-1A 1 GAS LIFT DMY BK2 0.000 0.0 9/17/2019 4 6,073.6 5,507.0 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 9/17/2019 5 6,362.5 5,717.0 MACCO SPM-1A 1 GAS LIFT DMY BK2 0.000 0.0 6/8/1999 6 6,594.5 5,891.2 CAMCO MMG-2 1 1/2 GAS LIFT OPEN Open 0.000 0.0 11/17/2019 Notes: General & Safety End Date Annotation 2/17/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 4/10/2013 NOTE: Tagged cmt obstruction @ 6780 RKB W/2.65 cent & 2.5 Bailer 2M-12, 11/18/2019 8:03:02 AM Vertical schematic (actual) PRODUCTION; 39.0-7,102.4 IPERF; 6,817.0-6,842.0 CEMENT SQUEEZE; 6,756.0 ftKB APERF; 6,756.0-6,772.0 SOS; 6,682.2 NIPPLE; 6,670.5 2.75" CA-2 Plug; 6,670.0 2.73" Baited Pulling Tool Catcher Assembly; 6,667.0 PACKER; 6,647.0 SEAL; 6,646.2 GAS LIFT; 6,594.5 GAS LIFT; 6,362.5 GAS LIFT; 6,073.6 GAS LIFT; 5,605.0 GAS LIFT; 4,505.0 GAS LIFT; 2,782.9 SURFACE; 41.8-2,783.7 SAFETY VLV; 1,806.7 CONDUCTOR; 42.0-119.0 HANGER; 37.5 KUP PROD KB-Grd (ft) 45.51 Rig Release Date 9/9/1992 2M-12 ... TD Act Btm (ftKB) 7,119.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018100 Wellbore Status PROD Max Angle & MD Incl (°) 50.96 MD (ftKB) 5,348.88 WELLNAME WELLBORE2M-12 Annotation Last WO: End DateH2S (ppm) 90 Date 12/5/2018 Comment SSSV: TRDP • i ‘91_-09 0 2`62:6'6 WELL LOG TRANSMITTAL �— DATA LOGGED 4/2.0/2017 M.K.BENDER PROACTIVE DINOSTIC SERVICES, INC. AG RECEIVED To: AOGCC Makana Bender JUN 13 2017 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 AOGCC (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952S Ep JUN 2 22e17, 1) Caliper Report 29-May-17 3N-19 1 Report /CD 50-029-23056-00 2) Caliper Report 27-May-17 2M-12 1 Report /CD 50-103-20181-00 Signed : /'2Ld. 4Z4$zL/<�' Date : Print Name: _ t PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CaMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\T'ransmittalSheets\ConocoPhil Iips_Transmit.docs *RECEIVED Vq(1.--0 0 JUN 13 2017 Memory Multi-Finger Caliper AOGCC LogResults Summar y Company: ConocoPhillips Alaska, Inc. Well: 2M-12 Log Date: May 27, 2017 Field: Kuparuk Log No.: 14826 State: Alaska Run No.: 1 API No. 50-103-20181-00 Pipe Description: 3.5 inch 9.3 lb. J-55 ABM-EUE Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 6,675 Ft. (MD) Pipe Description: 7 inch 26 lb. J-55 AB MOD Top Log Interval: 6,675 Ft. (MD) Pipe Use: Casing Bottom Log Interval: 6,793 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is depth correlated to a Halliburton Production Profile Log dated May 27, 2013. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage and any possible I.D. restrictions from 500 feet to 1,400 feet. The caliper recordings indicate buckling throughout the 3.5 inch tubing. An overlay of centered and un-centered caliper recordings from 500 feet to 1,400 feet, highlighting the buckling is included in this report. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. The caliper recordings indicate the 7 inch casing logged appears to be in good to poor condition with respect to internal corrosive and mechanical damage, with a maximum recorded wall penetration of 50% in an area of general corrosion in joint 3 (6,739 ft), and cross-sectional wall loss of 18% at 6,742 feet. Outside of the perforation intervals, no other significant wall penetrations or areas of cross-sectional wall loss are recorded throughout the casing logged. No significant I.D. restrictions are recorded throughout the casing logged. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 19%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 9%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS : Joint Corrosion 50 3 6,739 Ft. (MD) Outside of the perforation interval, no other significant wall penetrations (> 18%) are recorded throughout the casing logged. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : Corrosion 18 3 6,742 Ft. (MD) Outside of the perforation interval, no other significant areas of cross-sectional wall loss (> 3%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the casing logged. T. Leckband C. Waldrop J. Fama Field Engineer(s) Analyst(s) Witnesses) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • cE PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2M-12 Date : May 27, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings From 500 Feet to 1,400 Feet. Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) MEMMNIMMEIEMENNINIMI 2.5 3.5 1.500 0° 0° 90° 180° 270° 0° 0° 0° 90° 180°270° 0° Maximum I.D. I 2.5 inches 3.5 Minimum I.D. I 2.5 inches 3.5 Maximum Radius : 1.25 inches 1.75 Minimum Radius 1.25 inches 1.75 l AWL dr 'wc?... 550 - 1- Ji,. • . ..••...•. • g n 600 irtq .... • •. .. 650 4091. iii ............ ,. ) ,..... '......... y.t 700 r• • • ismorimis 750 sminimmiiimg ■■■WM.■■■■ ■■■■M®■ ■■■ ■E■EM EMMIEN■ soo ■■�■k ■■■■■ ■■■■L1■■■■■ ■■■■ !■■h,,,sommummun,,_ ■■ ®�■ INMEN 850 _.. . ■■■ ass■■■■ - i, -. nommommo wilmoricommun ■ MOO ■ ■■ 900 mr■ ■■s■■ ■i■■ ■■■■NIEMIN■E Iti ■■■■11■r■■■ 00. ■■■■ENI■■■■■ I ■■■FxIM■■■■ 950 Mil■■�kT■■liEl IMENIEFiiiiiillfrii ■■■110 ■■■■1000 `iIZIt mommourammom■■m■ i mum ■■■■IU■■■M■ 11111011111111MMEM ■■111EE■■E 1 050 ■■I■■E � ■ ■■■■■ ■ ■LE ■■ M■® i■®■M■■ I ■ 1100 1110 • .......... .......... I ..; . I i .... . l•".. ....., : — • '. - 1........ -;' , ...........• ............ ......‘ — ......... . 1150 —4:.:-.::.., .......- .. ..................._,.. r........ ......, ,.„....s, :ir. t —1200 .. _ .. ....., .v::1 ,...................... '4::•........... ........ ..... ..... ........ V....... .....,. *E.tr• ---...Ai ..... .........tt.P N......... 1250 117 I "...)_ riegfia.:.:.. •ss. .t:t , 49i I ,s 11 .....s....... A t. .. a. ....,.............. ............. . ....It ....:..> <::: 1300 .......41 , lir .., el I , '.....".•••... ............... ,i.:1:::,r. <.... PI ,1 1350 ..„ , ..... .. ........... ......... ............. ........ , ........... : ........:••''' .11. ..nii... 4.. ....., ,........ f.) E e•• A 4I Minimum Radius 1.25 inches ...,....... 1.75 Maximum Radius 1.25 inches 1.75 Minimum I.D. I I 2.5 inches 3.5 Maximum I.D. I I 2.5 inches 3 5 Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) t 2.5 3.5 1:500 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° • 0 Correlation of Recorded Damage to Borehole Profile IPipe 1 3.5 in (67.4'-6,674.8') Well: 2M-12 Pipe 2 7. in (6,674.8'-6,792.5') Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 27, 201 7 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 170 V"iS _ 25 t �, 827 50 , " 1,602 • 75 2,395 GLM 1 -- --- 0 100 3,175 - �= c Z • 0 125 3,950 4114111111110 GLM 2 150 4,734 .1111110, GLM 3 175 5,510 GLM 4 GLM 5 200 --2; 6,294 GLM 6 mil 1 --- 6,675 4 6,754 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=4 • Perforations • i PDS Report Overview (14 . Body Region Analysis Well: 2M-12 Survey Date: May 27,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf J-55 ABM-EUE Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 ABM-EUE 2.992 in. 67 ft. 6,675 ft. Penetration (%wall) Damage Profile(%wall) 250 Penetration body 1011111 Metal loss body 0 50 100 0.1 _ 200 150 100 50 48 A 0 0 to 20 to 40 to over 20% 40% 85% 85% a Number of joints analyzed(total=219) 219 0 0 0 GLM1 94 Damage Configuration(body) 30 20 GLM 2 (10:00) 143 10 GLM 3 (9:30) 0 GLM4(11:00) 192 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 5 (10:00) GLM 6(1:00) Number of joints damaged(total=54) 24 2 28 0 0 Bottom of Survey=209.7 • • ili PDS Report Joint Tabulation Sheet Well: 2M-12 Survey Date: May 27, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 ABM-EUE Tubing 2.992 in. 0.254 in. 67 ft 6,675 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 67 0 0.01 6 2 2.95 Pup 1 70 0 0.03 11 5 2.93 1.1 101 0 0.02 7 1 2.92 Pup Lt. Deposits. 1.2 107 0 0.02 7 1 2.95 Pup 2 113 0 0.03 10 3 2.92 Lt. Deposits. 3 144 0 0.03 10 4 2.92 Lt. Deposits. 4 174 0 0.03 11 5 2.92 Lt. Deposits. ■ 5 205 0 0.05 19 7 2.89 Shallow Line Corrosion.Lt. Deposits. 6 235 0 0.04 15 5 2.90 Shallow Pitting. Lt.Deposits. ■ 7 267 0 0.03 13 4 2.91 Lt. Deposits. ■ 8 298 0 0.03 10 4 2.93 Lt. Deposits. ■ 9 329 0 0.03 11 5 2.91 Lt. Deposits. ■ 10 360 0.04 0.04 14 3 2.93 ■ 11 391 0.04 0.04 15 5 2.88 Shallow Pitting. Lt.Deposits. iii 12 422 0.04 0.03 13 3 2.92 Lt. Deposits. ■ 13 454 0.05 0.04 15 3 2.90 Shallow Line of Pits.Lt. Deposits. ■ 14 485 0.06 0.04 15 3 2.89 Shallow Pitting. Lt.Deposits. ■ 15 516 0.04 0.03 13 4 2.91 Lt. Deposits. ■ 16 547 0.04 0.03 13 4 2.90 Lt. Deposits. ■ 17 579 0 0.03 11 2 2.92 Lt. Deposits. ■ 18 610 0 0.04 14 3 2.90 Lt. Deposits. ■ 19 641 0.04 0.03 13 4 2.91 Lt. Deposits. 20 672 0 0.02 9 3 2.91 Lt. Deposits. 21 703 0 0.03 10 4 2.95 22 735 0 0.02 8 2 2.94 23 766 0 0.04 15 6 2.90 Shallow Line of Pits.Lt. Deposits. 24 796 0 0.03 10 2 2.90 Lt. Deposits. 25 827 0.04 0.04 15 4 2.89 Shallow Line of Pits.Lt. Deposits. ■ 26 858 0 0.04 15 5 2.91 Shallow Line of Pits.Lt. Deposits. i 27 889 0 0.04 15 5 2.90 Shallow Line of Pits.Lt. Deposits. 28 920 0 0.03 11 3 2.90 Lt. Deposits. ■ 29 952 0 0.03 13 3 2.94 • 30 983 0 0.05 18 7 2.90 Shallow Pitting. Lt.Deposits. 1 31 1014 0 0.03 13 3 2.92 Lt. Deposits. ■ 32 1045 0 0.04 15 6 2.90 Shallow Line of Pits.Lt. Deposits. 33 1076 0 0.04 14 7 2.94 1 34 1107 0 0.03 11 3 2.92 Lt. Deposits. ■ 35 1138 0 0.03 12 4 2.94 • 36 1169 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 37 1200 0 0.04 14 2 2.91 Lt. Deposits. • 38 1232 0 0.03 12 2 2.93 Lt. Deposits. ■ 39 1262 0 0.04 15 4 2.92 Shallow Pitting. Lt.Deposits. ■ 40 1293 0 0.03 13 3 2.90 Lt. Deposits. ■ 41 1325 0 0.04 15 7 2.90 Shallow Pitting. Lt.Deposits. 42 1355 0 0.04 15 4 2.91 Shallow Pitting. Lt.Deposits. ■ 43 1386 0 0.04 14 4 2.93 Lt. Deposits. a 44 1417 0 0.04 14 4 2.92 Lt. Deposits. ■ 45 1448 0 0.03 13 4 2.92 Lt. Deposits. ■ 46 1479 0 0.04 16 5 2.92 Shallow Line of Pits.Lt. Deposits. ■ 47 1510 0 0.04 17 5 2.92 Shallow Line of Pits.Lt. Deposits. IPenetration Body Metal Loss Body Page 1 • S illi 41.1410., PDS Report Joint Tabulation Sheet Well: 2M-12 Survey Date: May 27, 201 7 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 ABM-EUE Tubing 2.992 in. 0.254 in. 67 ft 6,675 ft. Joint It.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 48 1541 0 0.03 13 4 2.92 Lt. Deposits. 49 1571 0 0.04 14 4 2.93 Lt. Deposits. 50 1602 0.05 0.05 19 5 2.91 Shallow Line Corrosion.Lt. Deposits. 51 1633 0.04 0.05 18 6 2.90 Shallow Line Corrosion.Lt. Deposits. a 52 1664 0.05 0.05 19 9 2.92 Shallow Pitting. Lt.Deposits. i 53 1695 0.05 0.03 13 4 2.92 Lt. Deposits. 54 1726 0 0.03 10 2 2.93 Lt. Deposits. • 55 1755 0.04 0.04 16 4 2.92 Shallow Pitting. Lt.Deposits. 56 1786 0 0.03 13 3 2.93 Lt. Deposits. 56.1 1817 0 0.02 9 2 2.95 Pup 56.2 1827 0 0 0 0 2.81 Camco TRDP-4A SSSV 56.3 1833 0 0.02 9 2 2.93 Pup Lt. Deposits. 57 1844 0 0.03 13 4 2.91 Lt. Deposits. ■ 58 1875 0 0.03 11 4 2.91 Lt. Deposits. 59 1904 0.04 0.03 13 3 2.93 Lt. Deposits. 60 193 4 0 0.04 . 14 3 2.94 • 61 1966 0.05 0.04 15 3 2.90 Shallow Pitting. Lt.Deposits. ■ 62 1997 0.04 0.04 14 6 2.90 Lt. Deposits. • 63 2028 0 0.03 12 3 2.95 64 2059 0 0.03 11 2 2.92 Lt. Deposits. 65 2090 0.05 0.03 11 2 2.90 Lt. Deposits. N 66 2121 0.04 0.04 17 4 2.93 Shallow Corrosion. • 67 2151 0.05 0.04 17 7 2.91 Shallow Corrosion. Lt.Deposits. a 68 2183 0 0.04 14 3 2.91 Lt. Deposits. • 69 2214 0 0.03 10 2 2.92 Lt. Deposits. 70 2242 0 0.02 9 2 2.94 71 2274 0 0.02 9 3 2.92 Lt. Deposits. 72 2305 0 0.04 14 3 2.91 Lt. Deposits. 73 2335 0 0.04 16 7 2.92 Shallow Line of Pits.Lt. Deposits. a 74 2366 0 0.03 12 2 2.92 Lt. Deposits. • 75 2395 0.06 0.04 16 4 2.88 Shallow Line of Pits.Lt. Deposits. 76 2426 0 0.04 14 5 2.92 Lt. Deposits. 77 2457 0 0.02 9 3 2.90 Lt. Deposits. • 78 2486 0.04 0.03 13 4 2.91 Lt. Deposits. • 79 2517 0 0.04 15 5 2.92 Shallow Pitting. Lt.Deposits. ■ 80 2549 0.04 0.04 14 5 2.92 Lt. Deposits. s 81 2580 0.04 0.03 11 2 2.93 • 82 2611 0 0.04 14 3 2.91 Lt. Deposits. 83 2642 0 0.03 13 4 2.91 Lt. Deposits. 84 2673 0 0.03 13 4 2.91 Lt. Deposits. 85 2704 0.05 0.04 14 2 2.91 Lt. Deposits. • 86 2735 0 0.03 13 2 2.92 Lt. Deposits. m 87 2766 0.04 0.03 11 3 2.91 Lt. Deposits. 87.1 2797 0 0 0 0 2.89 GLM 1 (No Deviation) 88 2804 0.04 0.03 13 4 2.92 Lt. Deposits. 89 2835 0.05 0.04 16 6 2.90 Shallow Line of Pits.Lt. Deposits. a 90 2865 0 0.04 15 5 2.90 Shallow Line of Pits.Lt. Deposits. ■ 91 2895 0 0.03 11 2 2.94 92 2926 0 0.03 12 3 2.93 Lt. Deposits. 93 2957 0 0.03 13 3 2.90 Lt. Deposits. IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: 2M-12 Survey Date: May 27, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 ABM-EUE Tubing 2.992 in. 0.254 in. 67 ft 6,675 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 94 2988 0 0.03 13 3 2.91 Lt. Deposits. ■ 95 3019 0 0.03 13 4 2.91 Lt. Deposits. • 96 3050 0 0.04 15 5 2.93 Shallow Pitting. Lt.Deposits. ■ 97 3081 0 0.03 11 4 2.92 Lt. Deposits. • 98 3112 0 0.04 14 5 2.90 Lt. Deposits. u 99 3143 0 0.04 16 4 2.92 Shallow Pitting. Lt.Deposits. ■ 100 3175 0 0.03 11 2 2.91 Lt. Deposits. • 101 3206 0 0.03 13 3 2.90 Lt. Deposits. ■ 102 3237 0 0.04 16 4 2.88 Shallow Pitting. Lt.Deposits. 103 3268 0 0.02 9 2 2.94 104 3299 0 0.03 13 6 2.91 Lt. Deposits. • 105 3331 0 0.03 12 4 2.90 Lt. Deposits. ■ 106 3361 0.04 0.04 15 6 2.89 Shallow Line of Pits.Lt. Deposits. 107 3393 0 0.03 11 3 2.92 Lt. Deposits. ■ 108 3424 0 0.03 13 4 2.90 Lt. Deposits. • 109 3455 0 0.04 14 3 2.91 Lt. Deposits. • 110 3485 0 0.03 13 4 2.92 Lt. Deposits. ■ 111 3516 0 0.04 15 5 2.87 Shallow Line of Pits.Lt. Deposits. • 112 3547 0.05 0.03 13 4 2.92 Lt. Deposits. ■ 113 3578 0 0.04 14 4 2.90 Lt. Deposits. ■ 114 3608 0 0.03 11 5 2.93 Lt. Deposits. 115 3640 0.05 0.03 13 3 2.88 Lt. Deposits. • 116 3671 0 0.04 14 2 2.92 Lt. Deposits. 117 3702 0 0.03 12 2 2.90 Lt. Deposits. • 118 3733 0 0.03 12 2 2.91 Lt. Deposits. • 119 3764 0 0.03 12 5 2.91 Lt. Deposits. • 120 3795 0.04 0.03 13 2 2.93 Lt. Deposits. ■ 121 3826 0 0.04 14 3 2.91 Lt. Deposits. ■ 122 3857 0 0.03 12 2 2.93 Lt. Deposits. • 123 3888 0 0.03 11 3 2.92 Lt. Deposits. • 124 3919 0 0.03 11 2 2.92 Lt. Deposits. 125 3950 0 0.03 13 4 2.91 Lt. Deposits. • 126 3981 0 0.04 15 2 2.91 Shallow Pitting. Lt.Deposits. ■ 127 4012 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 128 4043 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 129 4074 0 0.03 12 2 2.92 Lt. Deposits. • 130 4105 0 0.03 12 3 2.88 Lt. Deposits. ■ 131 4136 0 0.04 14 2 2.91 Lt. Deposits. • 132 4168 0 0.03 11 2 2.93 Lt. Deposits. 133 4199 0.04 0.03 11 3 2.90 Lt. Deposits. ■ 134 4230 0 0.03 10 2 2.93 • 135 4261 0 0.03 13 3 2.91 Lt. Deposits. • 136 4292 0 0.04 14 5 2.90 Lt. Deposits. 137 4323 0 0.02 9 3 2.90 Lt. Deposits. r 138 4354 0 0.03 10 2 2.90 Lt. Deposits. ■ 139 4385 0 0.03 12 2 2.93 Lt. Deposits. a 140 441 7 0 0.03 13 3 2.93 Lt. Deposits. • 141 4448 0 0.03 12 5 2.90 Lt. Deposits. ■ 142 4479 0.05 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. 142.1 4510 0 0 0 0 2.90 GLM 2(Latch C 10:00) Penetration Body Metal Loss Body Page 3 • • Report Joint�� PDS p to T abulation Sheet Well: 2M-12 Survey Date: May 27, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 ABM-EUE Tubing 2.992 in. 0.254 in. 67 ft 6,675 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 143 4518 0 0.04 15 6 2.92 Shallow Pitting. Lt.Deposits. 144 4548 0 0.04 15 6 2.92 Shallow Pitting. Lt.Deposits. u 145 4580 0 0.03 13 5 2.93 Lt. Deposits. ■ 146 4612 0 0.04 15 4 2.93 Shallow Pitting. Lt.Deposits. ■ 147 4643 0.04 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 148 4672 0 0.03 11 3 2.91 Lt. Deposits. ■ 149 4703 0 0.03 13 2 2.90 Lt. Deposits. ■ 150 4734 0 0.03 11 2 2.90 Lt. Deposits. ■ 151 4765 0 0.03 13 3 2.90 Lt. Deposits. ■ 152 4796 0 0.03 13 3 2.90 Lt. Deposits. ■ 153 4827 0 0.03 13 3 2.89 Lt. Deposits. ■ 154 4858 0 0.03 13 2 2.90 Lt. Deposits. ■ 155 4890 0 0.03 13 4 2.87 Lt. Deposits. ■ 156 4921 0 0.03 10 4 2.92 Lt. Deposits. ■ 157 4953 0.04 0.04 15 3 2.92 Shallow Pitting. Lt.Deposits. 158 4983 0 0.02 9 3 2.90 Lt. Deposits. 159 5015 0 0.04 15 4 2.91 Shallow Pitting. Lt.Deposits. ■ 160 5046 0 0.04 14 2 2.92 Lt. Deposits. ■ 161 5077 0 0.04 15 2 2.91 Shallow Pitting. Lt.Deposits. ■ 162 5108 0 0.03 12 4 2.94 • 163 5139 0.04 0.04 14 3 2.91 Lt. Deposits. • 164 5171 0 0.04 14 6 2.90 Lt. Deposits. a 165 5202 0 0.04 14 4 2.92 Lt. Deposits. 166 5233 0 0.02 9 3 2.94 167 5264 0 0.03 13 2 2.92 Lt. Deposits. ■ 168 5293 0 0.04 15 5 2.90 Shallow Pitting. Lt.Deposits. ■ 169 5324 0 0.03 11 4 2.91 Lt. Deposits. ■ 170 5354 0 0.03 11 3 2.91 Lt. Deposits. ■ 171 5386 0 0.03 13 4 2.91 Lt. Deposits. • 172 5417 0 0.03 11 4 2.93 • 173 5448 0.04 0.03 11 3 2.91 Lt. Deposits. ■ 174 5479 0 0.04 14 3 2.91 Lt. Deposits. ■ 175 5510 0 0.03 11 3 2.92 Lt. Deposits. ■ 176 5541 0 0.04 14 3 2.90 Lt. Deposits. ■ 177 5572 0.05 0.04 15 6 2.92 Shallow Line of Pits.Lt. Deposits. 177.1 5604 0 0 0 0 2.92 GLM 3(Latch C@ 9:30) 178 5610 0 0.04 14 4 2.91 Lt. Deposits. • 179 5641 0.04 0.03 11 2 2.94 ■ 180 5672 0 0.03 13 3 2.90 Lt. Deposits. ■ 181 5704 0 0.03 12 5 2.91 Lt. Deposits. ■ 182 573 5 0 0.03 11 3 2.95 • 183 5766 0 0.03 11 2 2.91 Lt. Deposits. 184 5797 0 0.02 9 3 2.93 Lt. Deposits. 185 5828 0 0.04 15 5 2.93 Shallow Line of Pits. ■ 186 5859 0 0.04 15 6 2.90 Shallow Pitting. Lt.Deposits. , 187 5890 0 0.02 9 3 2.93 U 188 5921 0 0.04 14 1 2.90 Lt. Deposits. ■ 189 5949 0 0.03 11 2 2.91 Lt. Deposits. ■ 190 5980 0 0.03 13 2 2.94 ■ 191 6011 0 0.03 13 2 2.94 IPenetration Body Metal Loss Body Page 4 • 1111 PDS Report Joint Tabulation Sheet Well: 2M-12 Survey Date: May 27, 201 7 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 ABM-EUE Tubing 2.992 in. 0.254 in. 67 ft 6,675 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 192 6038 0 0.03 11 4 2.91 Lt. Deposits. 192.1 6069 0 0 0 0 , 2.93 GLM 4(Latch C@ 11:00) i 193 6076 0.04 0.04 17 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 194 6107 0.04 0.04 17 5 2.91 Shallow Line of Pits.Lt. Deposits. ■ 195 6138 0 0.04 14 2 2.93 • 196 6169 0 0.03 12 3 2.91 Lt. Deposits. ■ 197 6201 0 0.03 12 3 2.95 198 6232 0 0.02 9 3 2.95 199 6262 0 0.04 15 3 2.94 Shallow Line of Pits. II 200 6294 0 0.02 9 2 2.94 • 201 6325 0 0.04 14 4 2.88 Lt. Deposits. 201.1 6357 0 0 0 0 2.91 GLM 5(Latch C@ 10:00) 202 6364 0 0.02 9 3 2.90 Lt. Deposits. 203 6394 0 0.03 10 3 2.91 Lt. Deposits. • 204 6425 0 0.03 12 2 2.87 Lt. Deposits. • 205 6456 0.05 0.04 15 5 2.91 Shallow Pitting. Lt.Deposits. ■ 206 6488 0.04 0.04 15 4 2.95 Shallow Line of Pits. ■ 207 6519 0 0.03 13 2 2.92 Lt. Deposits. III 208 6550 0 0.03 11 4 2.91 Lt. Deposits. 208.1 6581 0 0.01 6 0 2.97 Pup 208.2 6587 0 0 0 0 2.87 GLM 6(Latch @ 1:00) 11 208.3 6595 0 0.03 10 0 2.91 Pup Lt. Deposits. 209 6601 0 0.02 9 2 2.90 Lt. Deposits. 209.1 , 6632 0 0.02 7 1 2.94 Pup 209.2 6639 0 0 0 0 2.96 Baker GBH-22 Seal Assembly 209.3 6652 0 0 0 0 2.95 Baker F-1 Perminent Packer 209.4 6653 0 0.02 . 9 0 2.95 Pup 209.5 6661 0 0 0 0 2.74 Camco D Nipple No Go 209.6 6663 0 0.03 13 3 2.91 PUP Lt.Deposits. 209.7 6675 0 0 0 0 2.92 SHEAR OUT SUB IPenetration Body Metal Loss Body Page 5 • • PDS Report Overview t+ /� Body Region Analysis Well: 2M-12 Survey Date: May 27,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf J-55 AB MOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf J-55 AB MOD 6.276 in. 6,675 ft. 6,793 ft. Penetration(%wall) Damage Profile(%wall) 10 min Penetration body 61011 Metal loss body 0 50 100 1 8 6 4 2 2 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=4) 2 0 1 0 3 Damage Configuration (body) 10 8 6 4 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=2) 0 1 1 0 0 Bottom of Survey=4 = Perforations • • ili PDS ReJoint Tabulation �� �� ort p Sheet Well: 2M-12 Survey Date: May 27,201 7 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf J-55 AB MOD Casing 6.276 in. 0362 in. 6,675 ft. 6,793 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 6675 0 0.04 10 1 6.21 Lt. Deposits. R ii 2 6712 0 0.07 18 3 6.22 Marker Joint Shallow Line of Pits.Lt. Deposits. - 3 6731 0.06 0.18 50 18 6.24 Marker loint Corrosion. 4 6754 0 0.65 100 36 6.16 PERFORATIONS Lt. Deposits. I Penetration Perforations Body Metal Loss Perforations 'Penetration Metal Loss Body Page 1 • cr11_, • PDS Report Cross Sections Well: 2M-12 Survey Date: May 27,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf J-55 AB MOD Analyst: C.Waldrop Cross Section for Joint 3 at depth 6,738.839 ft. Tool speed=48 Nominal ID=6.276 Nominal OD= 7 •z Remaining wall area=89% Tool deviation=33° 1 11) Finger= 12 Penetration=0.180 in. Corrosion 0.18 in.=50%Wall Penetration HIGH SIDE= UP • • IIII PDS Report Cross Sections lANOS Well: 2M-12 Survey Date: May 27,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf J-55 AB MOD Analyst: C.Waldrop Cross Section for Joint 3 at depth 6,741 .890 ft. Tool speed=48 Nominal ID=6.276 Nominal OD=7 Remaining wall area=82% � �� Tool deviation=34° / 7 \ \ ii 1 / N 41/ Finger= 13 Penetration=0.115 in. Corrosion 18%Cross-Sectional Wall Loss HIGH SIDE=UP • • Mir KUP PROD 2M-12 ColnocoPhillips a6iMi�i well attributes Max Angle 8 MD TO Alaska,Inc. AFeCIW) Feed Nana weaves statue Ma 11 en I1tKa) Act atm 0160) c 0,,,„;„...,,,,,, 501032018'32 KUPARIJK RIVER UNIT PROD x196 5.:489 .88 7,110 Comment-•• Ceenf H2slppml Clete Annolatr0n eine Dale 80-ISO III) Mg Ranee Gate 0.010,1089017 9.00 Ne 558V TROP 1 Last WC. 45.51 9.y 392 Ver ac .• r 58000A5On owwbl llt88) End Deb Anesenteltoe. Loot Mc4 0y 5000 Dara Last Tag:SLA 6.790.0 4,9.2013 Rev Reeser:TAG.NOTE - --- .,a 2_ ..,:�ae�r aTa 1• t 'Lasing Strings 111 II � G0dpdun 00 ppm 00 IM) Tap)TtKel sot oeptn111661 set Oven/PVC)..PRAM p,..Ore% Top Throne yie CONDUCTOR 16 15:'152 42.0 119.0 62.58 H-40 WELDED Cuing 0.0 0)00 00 IMI 101001 Top 11)50) sat Depth;01661 sot 0eptn)TV01...Wt1LOn ll...Crane rop-Mead ' SURFACE 5518 8.521 41.2 2'32 7 2,763.5 36.00 J-55 ETC Carnes Deealptlan 00)n) ID(10) Tap/rtKo) lot coptn 171601 sot Gwen 4700)....nvteue,p,..GIROS Tap TORSO .. � ..,..PRODUCTION 7 $.275 39.0 2 4 2 285.3 26.'x10 4.55 AE-1.400- Tubing Strings P , 700909 Deeenptnn team Ata..10 pm Top 4(x601 re4C ptn:It...tot Owen)TVCB t.W1I ) Orono Top Connection t TU BINS 3112 2.992 37.5 _.c..0 1 5,959.2 9.30 4-35 ABM-EUE _ j Completion Details anD Tcp11166) Top 0,31IltORI Top 100)'1 EMIL. corn No m16) I 37.5 37.5 0:00 HANGER FMC GEN IVTUBING HANGER 3.340 ^+�oasucToe so-,19o.n- H 1,808.7 1,5'06.7 0.'36 SAFETYVLV CNACOTROP-4A SAFETYVALVE 2.812 6,546.2 3930.6 39.79 SEAL BAKER GBH-T2 LOCATOR SFA/APeEMBLYwrX0& 2.985 4;i SHEER O 6.5+)7.0 5,531.4 '39.79 PACKER BAKER F-1 -t PERMERM ANENTPACKER 4.000 STT 1M,1ASST 6.670.5 5.949.5 39.51 NIPPLE CAMCOO NIPPLE NO GO 2.750 5.5E2.2 5958.3 39.34 SOS 3AK£R SHEAR OUT SUE.009006672j per SWS 3.013 F<ERF Record(16-21-01) Perforations 8 Slots 1E174:,-;)-01 snot Dene Tdp)Twl him IT.41 /Metal Top)rtKa) SRI ittK6) 1ttK 01 )71661 2000 Sot. I) Typo Conn 6.736.0 6,772.0 6,015,9 6,020.4 C-4.A-5,200- :,'21.2001 6.0 SPERF 2.5"H90-PJ Chess;60 12 deg ph 6,817.0 6.842.0 5.063.6 6,083.1 A-3,214-12 '.121/1992 4.0 IPERF SW54 VTCsg G.K., sure*901 hl-aiT.00it t 1 1' & 08 Oriented tdeg.CCW e.e,2.7d 9- Ft H)gR Sid Cement Squeezes rtna Tap)TVOI etre Dela) I Top lettep elm 1 ) 11[50) 21160.) flea Start Oats coin 6,750.0 6.772.0 T Cement Squeeze 2/15/2007 SQUEEZED C-SAND PERES vs RR:4Ao:-e Mandrel Inserts St onl 01 TaTop IT`/01 VvevaLRLakePert se. Tfl0 Run pp/Ka) 111661 Mine Mabel 0008 dery Type Type 400) Ipel Nun Dae Cern OAS La6T.sSOS 1 0- 2,785.9 2.7327 `(ACCO SP0A-1A 1 GAS LIFT GLV 862 0.156 1,239.0 8/18/2009 2 4.505.0 1 L447.00 5/14-1A 1 GAS LIFT GLV BK2 0.156 1,254.0 8/182009 0 5.605.0 -" ACCO SP14-1A 1 GAS LIFT GLV 8*C2 0.188 1,289.0 9J1812009 000.Lor:c.CT2E - 4 6,073.6 5._.-' .0:CCO S'PM-SA l GAS LIFT OV BK 0.230 0.0 972812012 5 6,352.5 57'..: 100 5044-15 1 GAS LIFT MAY BK2 0.000 0.0 6/811999 6.534.5 5,891.22 ZIAMCC 040132 1172 GAS LIFT DMV RK 0,000 0.0 8/182009 G.11,S.S.0 I I Notes: ,nLcr6acNotes:General&Safety 0 Cho OHIOnctdtron _.'0.20' NOTE'.WAIVERED'WE IA CACO01MiJNICATI0N NOTE.Yew Scnsnet0 w:APIs.5chvnat<c9.0 4'1_. _ _ NOTE:Tagged cent obstrvca)on X 6780 RIG te:2.65 ce^x 82.59.1'0- 868 Lem Baal II PACKER:6AaT.0 `. 50600,6.8703 I 606:6.6/23i APEFS.CRS 06.Tre t i f EMS,6a1TA 5420 E -- VIACEJC KIM 856-7,1004 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN r-i Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED .E]' Logs-of various kinds . [] Other Complete COMMENTS: n Scanned by: Dianna Vincent Nathan Lowell · , TO RE-SCAN Date: Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Deaz Mr. Maunder: • RECEIVED JAN ~ $ 200 Alaska Oii & Gea Canac, Gomrr~~~i,~~ Anchorspe o ~f ~ (%`~"` Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annulaz space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ,. Penry ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Da+A 06/14/07 Schlumberger Ie¡ é). - óC:¡ ò sCANNED JUN· 2 1 2007 NO. 4300 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~.~ 0 iOOl Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Œ 04/05/07 Sc~IUßI'el'g8P RECEIVED NO. 4205 .-~;"< . . .~~~^~.:#"'~'~:~" ..~: -1' ~.~~~. - _;,;. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 ~ 011 &. Gas Cons. Commission Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 þ..? R 1 () '2.007 scANNEt> 10 d - Cffò Field: Kuparuk WeU Job# Log Description Date Color CD BL 2M.12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1 H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H·02 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331- N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J·160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . . RECEIVED nc on¡np 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 . 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 192-090 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20181-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 146', Pad 105' GL . 2M-12 - 8. Property Designation: 10. Field/Pool(s): ADL 25586, 'ALK 2672 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7119' I feet true vertical 6301' I feet Plugs (measured) Effective Depth measured 6885' feet Junk (measured) true vertical 6117' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 119' 119' SUR. CASING 2743' 9-518" 2784' 2784' PROD. CASING 7058' 7" 7099' 6286' Perforation depth: Measured depth: 6817'-6842' true vertical depth: 6064'-6083' ŠCANNEO MAR 2 () 2007 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6685' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'F-1' PERM. pkr= 6648' Cameo 'TRDP-4A' SSSV= 1808' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6756'-6772' I reatment descriptions inCluding volumes used and final pressure: 8 bbls behind pipe, 3200 #squeeze pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubino Pressure Prior to well operation 96 , 346 2834 -- 248 Subsequent to operation 169 40 2002 -- 255 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0- Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. J hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact John Peirce @ 265-6471 Printed Name John P~ Title Wells Group Engineer Signature /¿ '?7.c::""- Phone Date :3-g-67 Prenared bv Sharon AlIsu~Drake 263-4612 Form 10-~ Revised -:1004 "c. :::--- RB. BFl, MAR 1 9 2007 .41> "J0/~ 0<>7 17 Submit o· inal nly . STATE OF ALASKA MAR 0 9 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Con C '. REPORT OF SUNDRY WELL OPERATIONS A h s. omtnIsslon ORIGINAL A h\o ~~~7 . 2M-12 Well Events Summary . DATE Summary 11/5/06 TAGGED @ 6933' RKB W /2.2" CENT AND SAMPLE BAILER 11/6/06 PUMPED 17 BBLS OF 6 PPA SLURRY CONTAINING 3400 LBS. OF 20/40 MESH SAND OVER THE A SAND PERFS. FOLLOWED UP SAND PLUG WITH 10 BBLS FRESH WATER AND 26 BBLS OF DIESEL FREEZE PROTECT. STOPPED PUMPING 5 BBLS BEFORE SAND HIT PERFS. FLOWLINE FREEZE PROTECTED WITH 20 BBLS METHANOL. 11/16/06 TAGGED SAND PLUG @ 6771' RKB. TARGET FOR SAND TOP: 6782 - 6792'. ATTEMPTED BAIL EXCESS SAND. IN PROGRESS. 11/17/06 BAILED SAND FROM 6778' TO 6782' RKB. CORRECTION TO JEWELRY LOG DEPTHS INDICATE 20' MORE FT. TO BAIL. IN PROGRESS. 11/18/06 BAILED ON SAND PLUG, LOST l' OF HOLE. PUMP UNAVAILABLE TO MAINTAIN PRESSURE ON WELL. LAST TAGGED @ 6779' RKB. 11/21/06 TAG & BAIL ON SAND PLUG ON @ 6775' RKB. IN PROGRESS 11/22/06 BAILED FROM 6775' RKB TO 6779' RKB, IN PROGRESS 11/23/06 BAILED 4' OF HARD PACKED SAND FROM 6779' RKB TO 6782' RKB, IN PROGRESS 11/24/06 BAILED 4' OF SAND FROM 6782' RKB TO 6786' RKB 11/29/06 TAGGED TOP OF SAND AT 6777.4', DUMPED 8 GAL (5 FEET) OF CLASS G CEMENT / ON TOP OF SAND, CEMENT TOP AT 6772.4' 12/11/06 LOGGED A PRODUCTION PROFILE TO CHECK FOR LEAK IN CEMENT PLUG ABOVE PERFS AT 6817' - 6842'. WELL PRODUCING 3092 BWPD, 12 BOPD, 3248 MSCFPD ./ TOTAL GAS, AND 971 MSCFPD GAS LIFT; P = 256 PSI, T = 130 DEGF. TOOL STOPPED IN OPEN PERFS AT 6765,7' ABOVE CEMENT PLUG TOP. STATION LOG AT MAX DEPTH OBSERVED 84% OF TOTAL PRODUCTION AT TD. MAIN ENTRY AT 6754', 16% OF TOTAL PRODUCTION. DEFT SHOWED LOWEST HYDROCARBON ENTRY AT TD. LARGE GAS ENTRY AT 6754'. NO CROSSFLOW DETECTED WITH THE WELL SHUT IN. WELL BROUGHT ON PRODUCTION AFTER WE MOVED OUT. 2/12/07 Mill cement plug down to 6760' CTMD (6780' RKB) w/ 2.5" Hailey underreamer equiped " with 6.18" blades. Heavy sand and cement across shakers in MI Skid, maintained 1: 1 returns throughout job, with minor increases in pit levels at times. 2/13/07 TAGGED PLUG 6818' RKB, STARTED DUMP BAILING, 2.5 BAGS SAND DUMPED. IN PROGRESS. 2/14/074 BAGS OF SAND DUMPED INTO WELL, FILLING UP TO 6811 RKB. IN PROGRESS. 2/15/07 DUMPED SAND STARTING @ 6811' RKB, FILLED TO 6803' RKB. JOB COMPLETE. 2/16/07 PERFORMED C SAND CEMENT SQUEEZE. SQUEEZED 8 BBLS BEHIND PIPE. ACHIEVED 3200# SQUEEZE PRESSURE. JETTED OUT EXCESS CEMENT FROM TUBING AND CLEANED OUT SAND PLUG FROM ON TOP OF A SAND. JETTED THROUGH HARD CEMENT/SAND INTERFACE @ 6803' CTMD. CLEANED DOWN TO 6950' CTMD, EST. 108' OF RATHOLE. WELL FREEZE PROTECTED W/50 BBLS OF DIESEL. 2/24/07 TAG @ 6885' RKB. EST 43' RAT HOLE. RECOVERED BAILER OF SAND. OBTAIN BHP SURVEY @ 6800' RKB=4024 psi @ 157 deg F. JOB COMPLETE. / ¡/ Scblull~el'gll' RECEI\/E[) 12/19/06 1 ~- NO. 4077 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: 8eth nEe 2 120m) .-~()Ü &. Ga,1! Coos. GOffin Ani;"Of~¡e ,,:, ~ (~ J. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ¡'>~~·¡~J~-:"'¡¡Î "'&I}~U 14d -0'10 Field: Kuparuk Well Job# 8L Color CD Log Description Date 1 R-03A (REDO) 11483497 INJECTION .PROFILE 11/30/06 1 1 8-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-088 11538771 PRODUCTION PROFILE 12/12/06 1 3H-108 11534187 PRODUCTION PROFILE 12/08/06 1 1J-136 11534188 USIT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1 F-1 0 11534192 INJECTION PROFILE 12/12/06 1 1 Y -27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A S8HP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1 F-05 N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Sc~lIIIIbepgep NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ."'.If'Ii<.". ;a...i~..,¡J.i"~r';¡j] ~'W:flo1i..rlÌ~~ ~. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1L1~ -Cf1Ò Field: Kuparuk Well Job# Log Description BL Color CD Date "0 ''::/ 1 E-1 82 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-1Q5L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04106 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-1j 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy ofthis transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e 2M-12 (PTD 1911310) report of SCP The current T/I/O is SI/2900/1250. The well is also waivered for IAxOA communication. Attached is a 90 day TIO plot and schematic. Please let me know if there are any questions. «2M-12 TIO 90 day plot 4-2-06.gif» «2M-12.pdf» Marie McConnell Problem Well Supervisor 659-7224 __ 'Content-Description: 2M-12 TIO 90 day plot 4-2-06.gif '2M-12 TIO 90 day plot 4-2-06.gif Content-Type: image/gif Content-Encoding: base64 __ __ __ 1 of 1 4/4/2006 10:08 AM 2M-12 4'IQ 90 day plot 4-2-06.gif (GIF Imag~1240x770 pixels) 1 of 1 4/4/2006 10:09 AM Pi-[.-LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 November 9, 2001 Cammy Oechsli-Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2M-12 (192-090) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation operations on 2M- 12 If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Group Team Leader Phillips Alaska Inc. MM/skad RECEIVED NOV 2, 7 2001 ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3, Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5163' FNL, 5090' FEL, Sec. 27, T11 N, RSE, UM 5. Type of Well: Development __X Exploratory __ Stratigraph ic __ Service__ (asp's 488029, 5948986) 6. Datum elevation (DF or KB feet) RKB 146 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2M-12 At top of productive interval 1296' FNL, 1279' FEL, Sec. 33, T11N, RSE, UM At effective depth At total depth 1474' FNL, 1415' FEL, Sec. 33, T11N, RSE, UM (asp's 486425, 5947399) 9. Permit number / approval number 192-090 / 10. APl number 50-103-20181 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 7119 feet 6301 feet Effective depth: measured 6945 feet true vertical 6164 feet Casing Length Size CONDUCTOR 119' 16" SUR. CASING 2638' 9-5/8" PROD. CASING 6953' 7" Plugs (measured) Junk (measured) Cemented 211 sxAS I 590 sx PF E, 430 sx Class G 210 sx Class G Measured Depth 119' 2784' 7099' True verticalDepth 119' 2784' 6286' Perforation depth: measured 6756' - 6772', 6817' - 6842' true vertical 6016' - 6028', 6064' - 6083' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 6685' MD. Packers & SSSV (type & measured depth) BAKER 'F-1~ PERM. @ 6648' MD. CAMCO 'TRDP-4A' MOD @ 1808' MD. RECEIVED 0ti & Gas Cms. Commission 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 614 Subsequent to operation 733 Representative Daily Average Production orlniection Data Gas-Md Water-Bbl 1198 1269 2184 1937 Casing Pressure Tubing Pressure 228 230 15. Attachments Copies of Logs and Surveys run _ Daily Report 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 Michael Mooney Form 10-404 Rev 06/15/88 · Title Staff Engineer Questions? Call Mike Mooney 263-4574 Date ;;// ~ ~/'~/ Prepared by Sharon Al/sup-Drake 263-4612 0RIG1HAL,,0.s SUBMIT IN DUPLICATE Date Comment 2M-12 Event History 10/16/O 1 10/21/01 TAGGED @ 6945' RKB; DRIFTED TBG W/2.5" HOLLOW CARRIER TO 6800' WLM. [TAG, PERF] PERFORATED C4 SAND @ 6756'-6772' USING 16' OF 2.5" HSD, PJ CHGS, 6 SPF. MADE JEWELRY LOG, WELLBORE DISPLACED W/65 BBL DIESEL, LEFT WELL SI. [PERF] Page I of I 11/8/01 THE MATERIAL UNDER THIS COVER HAS BEEN, MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P'L M ATE R IA L TH I~S MA E E W UNDER R K E R C:LORIkMFILM.DOC (_~s..r 'T'e s-r' I ICt OFILMED sssv J~' ' GLM DV or GLV ' Fluid Level · ~ Found @ ~_~2_~- Fd~ KUPARUK FLUID LEVEL REPORT Well 2:~_..- ~ ~-- Date//-~~/~ ~ %:10 CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman Fluid Level Shot Down: Casing _._.~/Tubing CSG Press During Shot =--------# TBG Press During Shot-- ~.~---# Reason For Shooting FL: To Determine O,p, erati%l Valve Well Status: On Continuous GL Operating CSG Press = ____.__ # GL Rate (If Available) = ~ MCFD On Intermittent GL On Time = ------ Min. Off Time=_____ Hr._____ Min. Delta Time From End Of On Cycle =-~--- .~.__.~ No GL Min. Comments: PERMIT DATA 92-090 5892 92-090 5430 92-090 SURVEY 92-090 DAILY WELL OP 92-090 407 92-090 HLDT %OGCC Individual Well Geological Materials Inventory T DATA_PLUS T 5794-7000 HLDT T 2727-7119 OH/CDR/HLDT R 0.00-7119 R 09/05-12/22/92 R COMP DATE: 12/22/92 L 6200-6980 92-090 CET L 5749-7001 92-090 CET L 5794-7001 92-090 CDR/FIELDPRINT L 2801-7119 92-090 CDR-DC L 2801-4766 Page: 1 Date: 11/16/94 RUN DATE_RECVD 1 11/22/93 1 11/02/92 11/02/92 01/22/93 01/22/93 11/20/93 11/20/93 1 10/12/92 COMP 09/21/92 05/14/93 Are dry ditch samples require~? ~ y~ no And received? yes Was the well cored?~ Vt yes ~~s & description received? Are well tests require~s"~r~o Received? yes no Well is in compliance In~t i-al no yes no ARCO Alas~<a, inc. Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 11, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~;.'..--. ;~3 2M-01 Stimulate ~.,'~.--~. 2M-05 Stimulate ~?~.- ;.~ot 2M-08 Stimulate of~._~¢ 2M-12 Stimulate ¢I;~..~i 2M-27 Stimulate ¢lz.-?o 2M-28 Stimulate ,~-loff 2M-32 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA~r¢, OIL AND GAS CONSERVATION COMMIb~.,,.3N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other .... 6. Datum elevation (DF or KiWi 2. Name of Operator J 5. Type of Well' Development ., X ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 114' FSL, 189' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1296' FNL, 1279' FEL, SEC 33, T11N, R8E, UM At effective depth 1423' FNL, 1373' FEL, SEC 33, T11N, R8E, UM At total depth 1476' FNL, 1413' FEL, SEC 33, T11N, RSE, UM 71 1 9' feet 6301 ' feet 12. Present well condition summary Total Depth: measured true vertical 147' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2M-12 9. Permit number/approval number 10. APl number 5o-10~-20181 I1 1. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 7 01 1 ' feet Junk (measured) true vertical 621 6' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 121' 16" 211 SXASI 2784' 9 5./8" 7099' 7" measured 6815' -6840' true vertical 6062' 6082' 590 SX PF E 430 SX CLASS G 210 SX CLASS G Tubing (size, grade, and measured depth) 3 1/2" 9.3# J-55 L-80 @ 6685' Packers and SSSV (type and measured depth) Baker F-1 @ 6649', Camco TRDP-4A-M©D @ 1808' Measured depth 121' 2784' 7099' True vertical depth 121' 2784' 6286' 113. Stimulation or cement squeeze summary Intervals treated (measured) Refer to attached summary Treatment description including volumes used and final pressure 14. Pressure Re~)resentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Prior to well operation Subsequent to operation (Stabilized) 2462 1 1 75 0 1150 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢t~ '(~ ,, ~//~' Tit,e Senior Engineer Form 10-404 Rev 06/15/88 psi Service 247 psi Date SUBMIT IN DUPLICA-I E March 20, 1993 2M-12 GSW DATAFRAC W/DS 140D. PUMP 3 SLK WTR PI/SI'S & GSW MINIFRAC @ 25 BPM. DATA AS FOLLOWS: STEP VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC PI/SI#1 150 4682 1660 3950 .72 1585 PI/SI#2 50 4613 1725 4025 .73 1551 PI/SI%3 10 4719 1700 3925 .72 1682 PI/SI%4 300 4049 1770 3920 .73 842 EFFICIENCY CALC. AT 51% BY C MATCH, 55% BY EFF. CURVE, 49 % BY G FUNCTION. SMART COMP INCORRECTLY READ DESIRED ADDITIVE RATES FOR L-10 AND ACTIV 1 & 2 FOR QC BARS. EVERYTHING ELSE WORKED OK. GSW FRAC W/DS 140D. PUMP 300 BBL PAD @ 25 BPM, LAST WHTP=4150 PSI. PUMPED 25.0 MLBS 16/20 CL IN 1 & 2 PPA STAGE & 214.4 MLBS 12/18 CL IN 4-14 PPA STAGES. SCREENED OUT IMMEDIATELY PRIOR TO 14 PPA STAGE REACHING PERFS, PEAK WHTP=8000 PSI. TOTAL SLURRY (WITH PAD) 1580 BBLS. PAD SLURRY RATIO 0.19. TOT PROP: DESIGN=299.8 MLBS, IN FORM=217.3 MLBS W/12.7 PPA @ PERFS. ESTIMATE 22.2 MLBS LEFT IN WELLBORE. TOT FLUIDS: WATER=1862 BBL, DSL(FLA)=50 BBL, ADD'S=35 BBL. (COOPER/CRABTREE/WALKER) ARCO Alaska, Inc. Date: November 19, 1993 Transmittal #: 8932 RETURN TO: ARCO Alaska, InC. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO- 1119 P.O. Box 100360:' Anchorage, AK 99510-0360 Transmitted here' with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ...F~t~~G~~~R-Dat~- 2M-12 ~ LIS Tape and Li~ing: 11-09-93 93507 ~ 5~ HLDT Depth Shi~-3 passes and Lat Avg. 5~q- 7~' 2M-32 c~ LIS Tape and Listing: !1-11-93 93505 ~ ~ ~HLDT Depth Shi~-5 passes and Lat Avg. 2M-04 c~ LIS Tape and Listing: 11-12-93 93508 ~~. HLDT Depth Shi~-3 passes and Lat Avg. 2M-08 c~ LIS Tape and Listing: 11-12-93 93506 ~SHLDT Depth Shi~-3. passes and Lat Avg. ~o~t ~o ' ~2M-08 ~LIS Tape and Listing: 8-12-93 93301 DIT~LDT/CNTG/LDWG Format Receipt Acknowledged: ~~.~;'~ ~~~ Date: DISTRIBUTION: Bob Ocanas R~c¢\~J~ . ARCO Alaska, Inc. Date: May 07, 1993 Transmittal #: 8732 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the folloWing Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~'~"~I H-16 H-16 H-19 H-19. ~--' [50/1 H-17 ,,.~ ~_ %.1H-17 M-o ~-'r~-O- -PM- 12 , M-04 ~M-14 Cf~M-08 ,..~& 2M-02 ~"~~M-02 CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth Corrected 1/8-10/93 2671-7510 Corrected 1/8-10/93 2671-7510 Corrected 12/13-16/92 5364-8990 Corrected 12/13-16/92 5364-8990 Corrected 1/2-5/93 4981-8185 Corrected 1/2-5/93 4981-8185 Corrected 10/25-29/92 3347-9800 Corrected 9/6-8/92 2801-4766 Corrected 9/23-26/92 4260-12370 Corrected 7/14-17/92 3664-9811 Corrected 11/3-7/92 4253-12151 Corrected 8/31 to 9/3/923437-10003 Corrected 8/31 to 9/3/923437-10003 Receipt Acknowledged: DISTRIBUTION: D&M Drilling ,4/aska 011 & Gas Cons. Commission Anchorage VendorPackage(Johnston) NSK State of Alaska(+Sepia) Kathy Worley(Geology) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , , , I Status of Well Classilicalion of Service Well OIL [~] GAS F'"'] SUSPENDED r'~ ABANDONED r'~ SERVICE [--'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-90 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-103-20181 4 Location of well at surface ~ ............... ' .... ~ ..... "~'- : ' 9 Unit or Lease Name 114' FSL, 189' FWL, SEC 27, T11N, RSE, UM i '~ ~; ~ YE~Iq'ED' ! KUPARUK RIVER 1296'FNL, 1279'FEL, SEC33, T11N, RSE, UM!;-';'~',-~,~ , ~ . ..-~/'~L 2M-12 At Total Depth :z~',.~.~ ........ i~ ,~~r 11 Field and Pool 1476' FNL, 1413' FEL, SEC 33, T11 N, RSE, UM KUPARUK RIVER FIELD 5 Eievation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 147', PAD 105' GLI ADL 25586, ALK 2672 · 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Deplh, it offshore 116 No. of Completions 09/05/92. 09/08/92. 12/21/92.I NA feat MSLI' 1 , 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Suwey 20 Depth where SSSV set 21 Thickness ot permafrost MD, 6301'TVD 7011'MD, 6216'TVD YES [~ NO F--] 1808' fea~MD 1400' APPROX 7119' 22 Type Elact~ic or Other Logs Run CDR,CDN, GR, CET, HLDT, GYRO 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE w-r. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 121' 24' 211 SX ASI 9-5/8" 36# J-55 SURF 2784' 12-1/4" 590 SX PF E, 430 SX CLASS G 7' 26fl J-55 SURF 7099' 8-1/2' 210 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inten/al, size and number) SIZE IDEPTH SET (MD) PACKER SET (MD) 3-1/2' 9.3~ J-55/L-80 6685' 6648' 6815'-6840' W/4-1/2" CSG GUN ~ 4 SPF MD 6062'-6082' T VD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHoKE SIZE I GAS-OIL RATIO I TEST PERIOD W Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY. APl (corr) Press. 24-HOUR RATE ~ 28 'CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or waler. Submit core chips. Form 10-407 r, Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSESDE , ,, 29. 30. GEOLOGIO ~ FORMATION TESTS , , NAME Include interval tested, pressure data, all fluids recoverd and gravily, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. = KU PARU K C TOP 6756' !6016' NA (UPARUK C BO'FI'OM 6774' 6030' KUPARUK A TOP 6774' 16030' KUPARUK A BOTTOM 6934' $155' 31. LIST OF A'I-rACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATION& PAGE: I WELL: 2M-12 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER FIELD: KUPARUK RIVER LEASE: API: 50-103-20181 PERMIT: APPROVAL: ACCEPT: 09/05/92 12:09 SPUD: 09/05/92 04:09 RELEASE: 12/21/92 06:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC I 09/05/92 (374) TD: 674'( 0) 09/06/92 (375) TD: 2801'(2127) 09/07/92. (376) TD: 3739'( 938) 09/08/92 (377) TD: 6689'(2950) 09/09/92 (378) TD: 7119' ( 430) DRILL & SURVEY M~: 9.1 VIS: 76 MVE RIG F/2M-02 TO 2M-12. ACCEPT RIG @ 0030 HRS 09/05/92. SET IN & NU 20" DIVERTER SYSTEM & FUNCTION TEST SAME. MAKE UP BHA. LOAD MWD & ORIENT SAME. CHANGE OUT STABILIZER SLEEVES. SPUD @ 0430 HRS 09/05/92. DRILL 12.25" HOLE F/121'-374'. SURVEY W/MWD. CMT CSG 9-5/8"@ 2783' MW: 9.6 VIS: 55 DRILL 12.25" HOLE F/374'-1557'. SURVEY W/MWD. SERV RIG. DRILL F/1557'-2801'. SURVEY W/MWD. CBU. WIPE HOLE T/1200'. HOLE FREE, NO FILL. CIRC & COND FOR 9-5/8" CSG. POOH. DN LOAD MWD. LD BHA. RU GBR TONGS. RUN 9-5/8" CSG TO 2783.66'. RU HOWCO. CIRC & CON/) MUD PRIOR TO CMT JOB. CEMENTING CSG @ REPORT TIME. DRILL, LOG, & SURVEY 9-5/8"@ 2783' MW: 8.7 VIS: 31 CMT CSG. CMT W/590 SX PF E CMT & 430 SX CLASS G CMT. CLEAN UP AFTER CMT JOB. LD LANDING JT. SET OUT DIVERTER. MU 11" 3M SPEED HEAD. NU BOPE. TEST ALL TO 300 & 5000 PSI. HAD LEAK. HCR ON CHOKE FAILED, CHANGED OUT & RETESTED-GOOD. INSTALL WEAR BUSHING. MU BHA, LOAD MWD, INSTALL RA SOURCES. RIH. DRILL PLUGS & FC. CIRC CLEAN. TEST CSG TO 2000 PSI. DRILL CMT & SHOE @ 2787'. DRILL 10' NEW HOLE TO 2811'. CIRC CLEAN. PERFORM PIT. DRILL HOLE F/2811'-3739'. SURVEY W/MWD, LOG W/LWD. DRILL, LOG, & SURVEY 9-5/8"@ 2783' MW: 9.1 VIS: 35 DRILL F/3739'-4764'. SURVEY W/MWD, LOG W/LWD. COULD NOT BUILD ANGLE PROPERLY W/TURBINE, STEERING 35 LEFT TOOL WALKING TO RIGHT. CIRC MIX PILL. POOH, FREE. LD TURBINE, PICK UP AKO. RIH TO SHOE. SERVICE TOP DRIVE. RIN. HIT BRIDGE @ 4722'. WASH & REAM TO BTM. DRILL HOLE F/4764'-6689'. SURVEY W/MWD, LOG W/LWD. CBU @ 6200 7"@ 7099' MW:10.3 VIS: 37 DRLG F/6689'-7119'. CIRC & COND HOLE. WELL FLOWING. WT. UP F/10.2 TO 10.3. PULL 10 STDS. MONITOR WELL. POOH TO SHOE. SERVICE TOP DRIVE. RIH. WASH 45' TO BTM. NO FILL. CIRC & COND TO RUN 7". SPOT 35 BBL BARATROL PILL. POH 7 STDS. PMP DRY JOB. POOH. LD DP,, HWDP, & DC. DOWNLOAD LWD. LD BHA F/INSPECTION. PULL WEAR RING. RU TO RUN 7". RUN 7" TO 2700'. CBU. RUN 7" TO 4420'. STARTED LOSING RETURNS. CBU. RUN 7" TO 6200'. CBU. WELL : 2M-12 OPERATION: RIG : PARKER 245 PAGE: 2 09/10/92 (379) TD: 7119' ( 0) 12/21/92 (381) TD: 7119 PB: 7011 12/22/92 (382) TD: 7119 PB: 7011 RIG RELEASED 7"@ 7099' MW:10.2 VIS: 0 CBU @ 6200'. RUN 7" 26# J-55 BTC-MOD CSG & SET SHOE @ 7099'. CIRC & COND MUD. CIRC & COND MUD, PACKING OFF-CSG HUNG UP FROM BTM 20' UP. NO REUTRNS-WORK PIPE FREE. REGAIN RETURNS. HOOK UP HALLIBURTON & CMT. TEST LINES TO 4000 PSI. CMT CSG W/210 SX CLASS G CMT. PU STACK & SET SLIPS. ND. MAKE FINAL CUT 7"-INSTALL PACKOFF & NU TREE. TEST PACKOFF TO 3000 PSI-OK. INJECT 80 BBLS H20 & 80 BBLS DIESEL. RIG RELEASED 09/09/92 22:30 HRS. RIH W/3-1/2# COMP ASS¥ 7"@ 7099' MW: 0.0 MVE RIG F/ 2M-09 TO 2M-12. ACCEPT RIG @ 18:30 HRS 12/20/92. ND & REMVE FMC TREE. INSTALL TEST PLUG. NU BOPS. MU 7" ANN VALVE ON WELL, PREHEAT BOPE BEFORE TESTING. TEST BOP TO 3500 PSI F/15 MIN. PULL TEST PLUG. TEST 7" ANN TO 3500 PSI. LOSS OF 50 PSI. BLEED OFF. RU SWS EQUIP. MU PERF GUNS & PERF F/681~'-684Q'. POOH. MU JB & 6" GAUGE RING. RIH TO 6810'. POOH. MU BAKER SETTING TOOL & PKR. RIH W/SAME. SET PKR W/TBG TAIL @ 6674' POOH. RD SWS. RU TO RUN 3-1/2" TBG. MU & RIH W/BA~ER SEAL ASSY & COMP EQUIP. RIG RELEASED 7"@ 7099' MW: 0.0 SERV RIG-SAFETY MEETING. CONT RIH W/3-1/2" COMP ASSY. MU SSSV. ATTACH CONTROL LINE & TEST SAME TO 5000 PSI. RIH. TAG PKR. SPACE WELL OUT. MU TBG HGR. ATTACH CONTROL LINE & TEST TO 5000 PSI. LAND TBG. RILDS. PRESS ANN TO 1000 PSI. CLOSE SSSV. BLED TBG TO 500 PSI TO TEST SSSV. TEST TBG TO 2500 PSI. TEST ANN TO 2500 PSI. SHEAR BALL @ 3800 PSI W/2500 PSI ON TBG. LD LJT. SET BPV. ND BOP. NU FMC GEN VI 5000 PSI TREE. SSSV CLOSED, REPAIR & OPEN SAME. TEST PACKOFF TO 5000 PSI AND TREE TO 250 & 5000 PSI. PULL BPV. OPEN SSSV. PMP 12 BBLS DIESEL DNANN TAKING RETURNS OUT TBG. PMP 4 BBLS DIESEL DN TBG @ I BPM @ 1750 PSI. SET BPV. SECURE WELL. SICP=0 SITP=0 RIG RELEASED 18:30 HRS 12/21/92. SIGNATURE: (drilling ~pe~nt DATE: q 9...-°to SUB - S URFA CE DIRECTIONAL SURVEY ~'~ UIDANCE ~ ONTINUOUS ~-~ OOL Company Well Name Field/Location ARCO ALASKA, INC. 2N-12 (114' FSL, 189' i~L, SEC 27, T11N, R8E, U~) KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92585 Logqed BV: J. FORNICA Date 26-SEP-92 Computed By: R. KRUI~ELL SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2M-12 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 26-SEPT-g2 ENGINEER' JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMLFTH OF SOUTH 45 DEG 53 MZN WEST COMPUTATION DATE' 15-0CT-92 PAGE 1 ARCO ALASKA, INC. 2M-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 26-SEPT-g2 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 2O0 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -146 O0 IO0 200 300 400 5O0 599 699 799 899 O0 -46 O0 O0 54 O0 O0 154 O0 O0 254 O0 O0 354 O0 99 453 99 99 553 99 99 653 99 99 753 99 0 0 N 0 0 E 0 12 N 43 28 W 0 14 N 40 50 W 0 13 N 4O 19 W 0 17 N 39 35 W 0 18 N 37 57 W 0 20 N 32 41W 0 8 N 23 23 W 0 4 N 18 24 W 0 7 S 51 53 W 0 O0 0 09 0 10 0 06 0 03 -0 03 -0 13 -0 23 -0 30 -0 28 0 O0 0 17 0 O0 0 O0 0 O0 0 O0 0.29 0. O0 0. O0 0.27 0 O0 N 0 O1 N 0 30 N 0 62 N 0 95 N 1 38 N 1 86 N 2 23 N 2 41N 242N 0.00 E 0.13 W 0,42 W 0 68 W 0 96 W 130 W 1 62 W 1 84 W I 92W I 95 W 000 N 0 0 E 13 N 86 51W 52 N 54 52 W 92 N 47 49 W 35 N 45 12 W 89 N 43 13 W 47 N 41 6 W 90 N 39 35 W 08 N 38 32 W 11 N 38 52 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 99 O0 1099 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 O0 1899 853 99 99 953 99 99 1053 99 99 1153 99 98 1253 98 98 1353 98 98 1453 98 98 1553 98 97 1653 97 97 1753 97 0 19 S 52 53 W 0 19 S 32 6 W 0 22 S 11 28 W 0 27 S 7 8 W 0 30 S 10 54 W 0 26 S 2 8 W 0 29 S 6 45 W 0 19 S 8 44 E 0 21 S 1 32 E 0 18 S 1 56 W 0 13 0 64 1 13 1 66 2 33 2 97 3 51 3 99 4 38 4 78 0.08 0.04 0, O0 0 O0 0 26 0 O0 0 24 0 O0 0 O0 0 O0 2 16 N 1 80 N 1 29 N 0 61N 0 24 S 1 O1S 1 80 S 2 42 S 3 04 S 3 62 S 2 28 W 2 64 W 2 83 W 2 91 W 3 O1 W 3 15 W 3 15 W 3 21 W 3 15 W 3 15 W 3 14 N 46 30 W 2O N 55 4O W 11 N 65 27 W 97 N 78 12 W 02 S 85 31W 31 $ 72 13 W 63 S 60 14 W 02 S 52 56 W 38 S 46 3 W 79 S 41 1W 2000 O0 1999 97 1853 97 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2099 O0 2199 O0 2299 O0 2399 O0 2499 O0 2599 O0 2699 O0 2799 O0 2899 97 1953 97 2053 97 2153 97 2253 97 2353 94 2453 87 2553 80 2653 74 2753 97 97 97 97 97 94 87 80 74 0 9 S 12 3O E 0 11 S46 24 E 0 19 S 23 52 E 0 19 S 23 21 E 0 18 S 25 23 E 0 13 S 59 14 E 2 10 S 32 29 W 2 13 S 33 45 W 1 59 S 44 2 W 1 56 S 53 49 W 5 06 5 13 5 23 5 43 5 62 5 68 7 26 11 04 14 74 18 12 0 O0 0 35 0 O0 0 14 0 O9 0 15 0 59 0 13 1 38 0 15 4 02 S 4 28 S 4 70 S 5 23 S 5 73 S 6 O8 S 7 66 S 10 91S 13 96 S 16 07 S 3 15 W 2 99 W 2 73 W 2 50W 2 27 W 2 02 W 2 68 W 4 80 W 7 O0 W 9 65 W 5 11 $38 2 W 5 5 5 6 6 8 11 15 18 22 S 34 55 W 43 S 30 9 W 80 S 25 30 W 16 S 21 37 W 41 S 18 21W 12 S 19 18 W 92 S 23 44 W 61 S 26 37 W 75 S 30 59 W 3000 O0 2999 68 2853.68 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 3099 O0 3199 O0 3298 O0 3398 O0 3496 O0 3593 O0 3690 O0 3785 2 17 54 2953.54 3 22 31 3053.31 4 17 88 3152.88 6 5 04 3252.04 8 45 41 3350.41 11 42 91 3447.91 13 52 50 3544.50 16 7 82 3639.82 19 9 O0 3879.23 3733.23 22 43 S 53 21W S 49 10 W S 46 57 W S 45 46 W S 45 6 W S 44 59 W S 45 13 W S 45 52 W S 47 20 W S 48 26 W 21 61 26 82 33 55 42 71 55 61 73 52 95 74 121 58 151 78 187 38 1 88 0 73 1 51 2 40 4 03 2 98 2 22 2 64 3 32 4 05 18 14 S 21 46 S 26 03 S 32 35 S 41 51 S 54 10 S 69 84 S 87 94 S 108 132 12 50 W 16 21 28 37 49 65 66 S 106 55 S 132 22 03 S 34 35 W 55 W 27 49 W 33 13 W 42 21W 55 95 W 73 63 W 95 08 W 121 05 W 151 48 W 187 10 S 37 38 W 75 S 39 33 W 87 S 41 1W 74 S 41 53 W 63 S 42 43 W 84 S 43 13 W 66 S 43 43 W 83 S 44 18 W 41 S 44 59 W COMPUTATION DATE' 15-0CT-92 PAGE 2 ARCO ALASKA, INC. 2M-I2 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- 26-SEPT-92 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3970 03 3824 03 26 44 4100 4200 4300 4400 45OO 4600 4700 4800 4900 O0 4058 O0 4145 O0 4231 O0 4314 O0 4394 O0 4474 O0 4553 O0 4633 O0 4711 15 3912 42 3999 04 4085 25 4168 81 4248 14 4328 31 4407 44 4487 42 4565 S 50 19 W 15 29 8 S 51 47 W 42 29 39 S 52 39 W 04 32 31 S 52 37 W 25 35 0 S 53 13 W 81 37 14 S 53 55 W 14 37 38 S 55 40 W 31 37 16 S 57 20 W 44 37 10 S 59 0 W 42 40 12 S 58 ! W 229 15 276 18 324 72 375 98 431 489 549 609 668 729 O1 73 92 97 3O 4O 4.02 0 71 2 43 2 53 3 46 I 34 1 66 4 17 3 08 2 45 159 80 S 164.23 W 229 15 S 45 47 W 189 219 250 283 319 354 388 419 452 41S 201.04 W 276 30 S 239.65 W 324 62 S 280.70 W 376 98 S 324.99 W 431 32 S 372.53 W 490 63 S 422.13 W 551 42 S 473.01 W 612 48 S 524.15 W 671 30 S 577.42 W 733 21 S 46 42 W 85 S 47 32 W 30 S 48 14 W 59 S 48 51W 65 S 49 24 W 32 S 49 58 W 05 S 50 36 W 33 S 51 20 W 48 S 51 56 W 5000 O0 4786 65 4640 65 42 4 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4858 O0 4926 O0 4990 O0 5053 O0 5117 O0 5181 O0 5247 O0 5315 O0 5384 68 4712 17 4780 15 4844 29 4907 31 4971 69 5035 87 5101 79 5169 O0 5238 68 45 54 17 49 19 15 50 42 29 50 41 31 49 58 69 49 50 87 47 19 79 47 9 O0 46 23 S 57 32 W S 55 39 W 861 S 48 16 W 935 S 45 12 W 1012 S 43 38 W 1089 S 41 16 W 1166 S 41 11W 1242 S 40 23 W 1317 S 40 36 W 1390 S 40 47 W 1463 793 86 97 22 05 58 21 48 14 21 03 2 31 4 24 6 77 0 62 4 49 0 26 0 59 0 63 0 23 3 06 487 43 S 633.15 W 799 04 S 52 25 W 525 570 624 679 736 793 85O 906 961 56 S 691.05 W 868 72 S 749.29 W 941 06 S 804.59 W 1018 04 S 859.27 W 1095 18 S 910.60 W 1170 70 S 961.07 W 1246 43 S 1010.06 W 1320 28 S 1057.68 W 1392 72 S 1105.36 W 1465 lg S 52 45 W 89 S 52 42 W 24 S 52 12 W lg S 51 41W 96 S 51 3 W 44 S 50 27 W 40 S 49 54 W 85 S 49 24 W 16 S 48 59 W 6000 O0 5454 53 5308 53 44 35 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5525 O0 5598 O0 5671 O0 5744 O0 5819 O0 5895 O0 5972 O0 6050 O0 6128 96 5379 O9 5452 04 5525 73 5598 50 5673 37 5749 30 5826 28 5904 64 5982 96 44 12 09 43 29 04 42 52 73 42 7 50 41 8 37 40 9 30 39 7 28 38 35 64 38 5 S 40 13 W 1533 60 S 39 59 W 1603 S 39 35 W 1672 S 39 6 W 1740 $ 38 34 W 1807 S 38 0 W 1872 S 37 27 W 1937 S 37 25 W 2000 S 37 6 W 2062 S 36 4O W 2123 22 10 O5 14 95 44 62 52 87 0 16 0 6O 0 75 0 58 1 12 0 93 0 73 1 26 0 32 1 25 1015 64 S 1151.36 W 1535 31 S 48 35 W 1069 1122 1175 1227 1280 1331 1382 1432 1481 16 S 1196.45 W 1604 40 S 1240.76 W 1673 30 $ 1284.11 W 1740 95 S 1326.52 W 1807 09 S 1367.63 W 1873 63 S 1407.48 W 1937 35 S 1446.30 W 2000 19 S 1484.20 W 2062 89 S 1521.47 W 2123 56 S 48 13 W 10 S 47 52 W 77 S 47 32 W 63 S 47 13 W 25 S 46 54 W 58 S 46 35 W 67 S 46 18 W 53 S 46 1W 88 S 45 45 W 7000.00 6207.50 6061.50 37 53 7100.00 6286.43 6140.43 37 53 7119.00 6301.42 6155.42 37 53 S 36 39 W 2184.49 S 36 39 W 2245.10 S 36 39 W 2256.61 0. O0 0. O0 O. O0 1531.16 S 1558.13 W 2184.54 S 45 30 W 1580.43 S 1594.77 W 2245.23 S 45 16 W 1589.79 S 1601.73 W 2256.76 S 45 13 W ARCO ALASKA, INC. 2M-12 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 15-0CT-92 PAGE 3 DATE OF SURVEY: 26-SEPT-92 KELLY BUSHING ELEVATION: 146.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 1000 2000 3OO0 4000 5000 6000 7000 7119 0.00 -146 O0 0 0 O0 999.99 853 99 0 19 O0 1999.97 1853 97 0 9 O0 2999.68 2853 68 2 17 O0 3970.03 3824 03 26 44 O0 4786.65 4640 65 42 4 ENGINEER: JEFF FORMICA VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E S 52 53 W 0 S 12 30 E 5 S 53 21W 21 S 50 19 W 229 S 57 32 W 793 S 40 13 W 1533 S 36 39 W 2184 S 36 39 W 2256 O0 5454.53 5308 O0 6207.50 6061 O0 6301.42 6155 53 44 35 50 37 53 42 37 53 0 O0 0 O0 N 13 06 61 15 86 60 49 61 0 O0 0 O8 0 O0 1 88 4 02 2 31 0 16 0 O0 0 O0 2 4 18 159 487 1015 1531 1589 16 N 2 02 S 3 14 S 12 80 S 164 43 S 633 64 S 1151 16 S 1558 79 S 1601 28 W 3 15 W 5 50 W 22 23 W 229 15 W 799 36 W 1535 13 W 2184 73 W 2256 0 O0 E 0 O0 N 0 0 E 14 N 46 30 W 11 S 38 2 W 03 S 34 35 W 15 S 45 47 W O4 S 52 25 W 31 S 48 35 W 54 S 45 3O W 76 S 45 13 W COMPUTATION DATE' 15-0CT-92 PAGE 4 ARCO ALASKA, INC. 2M-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 26-SEPT-92 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 146 O0 246 O0 346 O0 446 O0 546 01 646 Oi 746 Oi 846 O1 946 Oi 0 O0 -146 O0 146 246 346 446 546 646 746 846 946 O0 0 O0 O0 100 O0 O0 200 O0 O0 300 O0 O0 400 O0 O0 500 O0 O0 600 O0 O0 700 O0 O0 800 O0 0 0 N 0 0 E 0 15 N 46 Si W 0 16 N 37 5i W 0 14 N 39 38 W 0 19 N 38 ii W 0 21 N 34 7 W o 18 N 31 29 W 0 7 N 23 37 W 0 i N 3 i2 E 0 14 S 51 56 W 0 O0 0 10 0 08 0 05 0 O0 -0 06 -0 18 -0 26 -0 32 -0 15 0 O0 0 O0 0 O0 0 O0 0 i2 0 11 0 15 0 ii 0 09 0 17 0 O0 N O13N 044 N 0 76 N 1 i4N 1 58 N 2 07 N 2 32 N 2 44 N 233 N 000 E 0 26 W 0 54 W 0 80 W 1 llW 145W 1 7SW 188W 1 92 W 2 06 W 0 O0 N 0 0 E 29 N 63 29 W 70 N 50 37 W 11 N 46 31W 59 N 44 16 W 15 N 42 25 W 71 N 40 19 W 98 N 39 4 W ii N 38 13 W ii N 41 27 W 1046 Oi 1046 O0 1146 1246 1346 1446 1546 1646 1746 1846 1946 900 O0 O1 1146 O1 1246 O1 1346 02 1446 02 1546 02 1646 03 1746 03 1846 03 1946 oo iooo oo oo ilOO oo oo 1200 oo oo 1300 oo oo 1400 oo O0 1500 O0 O0 1600 O0 O0 1700 O0 O0 I800 O0 0 17 S 48 47 W 0 16 S lg 28 W 0 22 S 5 18 W 0 29 S 7 22 W 0 27 S i2 45 W 0 28 S 3 35 E 0 21 S 9 19 W 0 22 S 6 3 E 0 19 S I 11E o 15 s I 36 W 0 37 0 87 1 36 ! 96 2 65 3 2O 3 79 4 14 4 56 4 94 0.00 0.02 0.21 0.16 0. O0 0.17 0.46 O. 14 0.03 0. O0 201 N 1 59 N 1 O1 N 0 24 N 0 61 S 1 36S 2 14S 2 69 S 3 32 S 3 84 S 246 W 2 75 W 2 87 W 2 96 W 3 10 W 3 14 W 32i W 3 16W 3 14 W 3 16 W 3 18 N 50 44 W 18 N 59 57 W 04 N 70 38 W 97 N 85 25 W 16 S 78 56 W 42 S 66 37 W 85 S 56 20 W 15 S 49 35 W 57 S 43 28 W 97 S 39 25 W 2046 03 2046 O0 1900 O0 2146 2246 2346 2446 2546 2646 2746 2846 2946 03 2146 03 2246 03 2346 03 2446 04 2546 og 2646 17 2746 23 2846 29 2946 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 11 S 29 30 E 0 17 S 33 27 E 0 21 S 23 32 E 0 20 S 24 9 E 0 15 S 27 i8 E 0 45 S 14 45 W 2 14 S 32 48 W 2 ii S 34 14 W 1 57 S 52 i6 W 2 0 S54 lW S 11 5 14 5 32 5 52 5 68 5 82 8 99 12 77 16 32 19 69 00l 0 17 0 O0 0 17 0 oi 3 57 0 O0 0 14 0 10 0 09 4 iS S 4 43 S 4 94 S 5 47 S 5 94 S 6 34 S 9 15 S 12 37 S 14 99 S 17 O1S 3 10 W 2 86 W 2 62 W 2 39 W 2 15 W 1 96 W 3 65 W 5 80 W 8 20 W 10 93 W 5 18 s 36 45 W 5 5 6 6 9 13 17 20 28 S 32 49 W 59 S 27 57 W 97 S 23 34 W 32 S 19 56 W 63 S 17 11W 85 S 21 46 W 66 S 25 6 W O8 S 28 41W 22 S 32 44 W 3046 38 3046 O0 2900 O0 3146 3246 3347 3448 3550 3653 3758 3864 3973 56 3146 85 3246 45 3346 65 3446 76 3546 79 3646 Gl 3746 iS 3846 21 3946 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 3 6 S 50 39 W O0 3 53 S 47 0 W O0 5 17 S 46 19 W O0 7 24 S 44 25 W O0 10 23 S 45 34 W O0 12 51 S 44 46 W O0 i5 3 S 45 34 W O0 17 47 S 46 $1 W O0 21 21 S 48 4 W O0 25 41 S 49 45 W 23 80 29 76 37 46 48 29 63 75 84 36 109 13 138 46 173 95 217 32 0 80 1 O0 1 97 2 13 2 51 1 93 1 95 3 17 3 70 4 04 19 51 S 23 44 S 28 70 S 36 29 S 47 21 S 61 80 S 79 25 S 99 59 S 123 152 14 24 W 18 24 32 43 57 75 96 60 S 122 19 S 73 W 30 35 W 37 08 W 48 02 W 63 59 W 84 17 W 109 28 W 138 45 W 173 14 W 217 24 iS S 36 7 W O0 S 38 38 W 64 S 40 19 W 44 S 41 28 W 87 S 42 20 W 47 S 42 59 W 22 S 43 29 W 53 S 44 2 W 98 S 44 44 W 33 S 45 33 W ARCO ALASKA, INC. 2M-12 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 15-0CT-92 PAGE 5 DATE OF SURVEY: 26-SEPT-92 KELLY BUSHING ELEVATION: 146.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DE. PTH DEPTH DEPTH DEG MIN DEG MIN 4086 10 4046 O0 3900 O0 29 2 ENGINEER: JEFF FORMICA O0 4000 O0 29 40 O0 4100 O0 32 56 O0 4200 O0 36 15 O0 4300 O0 37 35 O0 4400 O0 37 25 O0 4500 O0 37 40 O0 4600 O0 41 10 O0 4700,00 45 14 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 51 41W 269.46 S 52 39 W 325.04 S 52 44 W 385.53 S 53 7 W 453.52 S 54 41 W 528.53 S 57 5 W 604.46 S 58 46 W 677.75 S 57 49 W 758.54 S 56 11 W 849.24 S 46 18 W 958.59 S 44 13 W 1080 67 67 4146 78 4246 03 4346 48 4446 78 4546 87 4646 64 4746 89 4846 S 41 19 W 1200 S 40 25 W 1315 S 40 42 W 1422 S 40 14 W 1525 S 39 52 W 1622 S 39 16 W 1716 S 38 34 W 1808 S 37 48 W 1895 S 37 28 W 1979 4200 4317 4439 4564 4690 4815 4945 5081 5230 66 4946 O0 4800.00 50 5 5388 48 5046 O0 4900.00 50 5544 59 5146 O0 5000 O0 49 57 5697 24 5246 O0 5100 O0 47 22 5844 43 5346 O0 5200 O0 47 8 5988 02 5446 O0 5300 O0 44 37 6127 91 5546 O0 5400 O0 44 1 6265 78 5646 O0 5500 O0 43 3 6401 72 5746 O0 5600 O0 42 6 6535 11 5846.00 5700 O0 40 49 6665 99 5946.00 5800 O0 39 34 23 11 64 23 54 89 28 75 30 6794.53 6046.00 5900.00 38 36 6922.05 6146.00 6000.00 38 0 7048.78 6246.00 6100.00 37 53 7119.00 6301.42 6155.42 37 53 S 37 7 W 2059.15 S 36 36 W 2137.29 S 36 39 W 2214.06 S 36 39 W 2256.61 1 13 2 46 2 33 2 78 1 74 2 98 3 34 I 68 3 99 4 25 3 44 0 18 0 87 0 40 0 18 0 83 0 61 1 13 1 02 1 48 0.25 1.81 0.00 0. O0 185 22 S 195 74 W 269 48 S 46 35 W 219 256 297 342 385 424 468 518 586 50 S 239 44 S 288 59 S 343 24 S 404 36 S 468 50 S 532 13 S 602 29 S 680 58 S 766 92 W 325 35 W 385 16 W 454 34 W 529 30 W 606 43 W 680 66 W 763 36 W 855 46 W 965 18 S 47 33 W 89 S 48 21W 23 S 49 4 W 74 S 49 45 W 47 S 50 33 W 95 S 51 26 W 12 S 52 10 W 29 S 52 42 W 16 S 52 34 W 672 60 S 853 11 W 1086 36 S 51 45 W 761 848 930 1009 1084 1157 1228 1298 1365 83 S 933 88 S 1008 99 S 1078 22 S 1145 06 S 1208 23 S 1269 85 S 1327 26 S 1381 24 S 1433 12 W 1204 74 W 1318 89 W 1425 93 W 1526 92 W 1623 38 W 1717 24 W 1808 77 W 1895 20 W 1979 62 S 50 46 W 39 S 49 55 W 05 S 49 13 W 99 S 48 38 W 78 S 48 7 W 71 S 47 39 W 77 S 47 12 W 99 S 46 47 W 38 S 46 23 W 1429.47 S 1482.14 W 2059.16 S 46 2 W 1492.79 S 1529.58 W 2137.30 S 45 42 W 1555.19 S 1576.00 W 2214.14 S 45 23 W 1589.79 S 1601.73 W 2256.76 S 45 13 W COMPUTATION DATE: 15-0CT-92 PAGE 6 ARCO ALASKA, INC. 2M-12 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASINO DATE OF SURVEY: 26-SEPT-92 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114' FSL ~ 189' FWL, SEC27 TllN RSE U ! vi MEASURED DEPTH BELOW KB 'TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2784 O0 6756 O0 6774 O0 6774 O0 6934 O0 6949 99 7011 O0 7099 O0 7119 O0 2783 81 6015 go 6029 96 6029 96 6155 42 6168 03 6216 18 6285 64 6301 42 2637 81 5869 90 5883 96 5883 96 6009 42 6022 03 6070 18 6139 64 6155 42 13 53 S 1410 30 S 1419 26 S 1419 26 S 1498 70 S 1506 60 S 1536 58 S 1579 94 S 1589 79 S 6.62 W 1467.61W 1474.41W 1474 41W 1533 97 W 1539 83 W 1562 16 W 1594 40 W 1601 73 W COMPUTATION DATE' 15-0CT-92 PAGE 7 ARCO ALASKA, INC. 2M-i2 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 $/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING DATE OF SURVEY: 26-SEPT-92 KELLY BUSHINO ELEVATION: 146.00 FT ENGINEER: JEFF FORMICA ********~*** STRATIGRAPHIC SUMMARY SURFACE LOCATION = 114' FSL · 189' FWL, SEC27 TllN RSE UM MEASURED DEPTH BELOW KB 'TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2784.00 6756.00 6774.00 6774.00 6934.00 6949.99 7011.00 7099.00 7119.00 2783 81 6015 90 6029 96 6029 96 6155 42 6168 03 6216 18 6285 64 6301 42 2637 81 5869 90 5883 96 5883 96 6009 42 6022 03 6070 18 6139 64 6155 42 13 53 S 1410 30 S 1419 26 S 1419 26 S 1498 70 S 1506 60 S 1536 58 S 1579 94 S 1589 79 S 6 62 W 1467 61W 1474 41W 1474 41W 1533 97 W 1539 83 W 1562 16 W 1594 40 W 1601 73 W FINAL WELL LOCATION AT TI): TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7119.00 6301.42 6155.42 2256.76 S 45 13 W r ~ DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA, INC. KUPARUK RIVER WELL 2111~- 1 2 COUNTRY RUN ONE ~T. u~? FEET WELL' 2t4-12 (114' FSL, 189' FWL, SEC 27, T11N, R8E, UN) HORIZONTAL PROJECTION ~',ELL ' 2~- 12 (114' FSL, 189' FWL, SEC 27, T11tt, R8E, U~) VERTICAL PROJECTION -1000 -~500 0 0 5OO lO00 1.~00 2O00 , ,. ,~, ,'',., · VERTICAL-..SECTION, ~.. 25OO PERMIT// C~ - ~0 WELL NAME ~L~, c~fY~--- 1'2,,. COMPLETION DATE I~-_./~_t4:/'Z~ CO. CONTACT' ~ I~Q Check off or list data as it is received.*list received date for'407, if not required list as NR '40'i' 'i'~ ...... }'"]~'Z~j~ drillin'§'hi'story" b/ Surreal []'wellteSts''' D I core dcscripti°~l~ : ,;Cored,.!n',tc~a!s,,,.,', co, re,,analys,is, 1~)~ , d~,,ditCh interVals ..... , , digital data i ii J Jiii iiii jllJii ! i ijl_ iiii i ii i ii ii !1 ii . i ii i ii i i i I iii ii I i i i i i i II IIII i ii iiiii iii i i ii i .J i .11 ii i iii i ii ii i ii ........... ! ............................ I, ,! iiii iii I II I I I I ! II .... LOG TYPE .......... RUN ...... IN:rEI:IVALS ....... SCALE" , NO. _, (to the,,,n, carcst f,,ooq (inchllO0'} i ii ii iii iii iJ II LJ i I I1~ I ii iiii , i i .il I II I I I I II I I II I 3) ............................ ....... _.. i .11 till id iii . i I I i i ii i ...... : ................ iii ,1 ,,, I i i ii iii iiiii ..... J .... i l_ _ i I . i ii iii i i ii ii , ifil ii111 i I iii Ill I I J I I Il I Il I I I I 131 ...... ........................ , ,, , ii I II I i ii t II I IIII II 1__- Ill_ , I i , i 11 _ ...... : ._' .... .... ,, . ................... :?,,~ ......... ~'~ ~t'~'.."'! _!l_ ........... ii , ,,, , ,i ii i I I ........... i ii ,1, ARCO Alaska, Inc. Date: October 30, 1992 Transmittal #: 8586 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-12j~'~' LIS Tape and Usting 10-10-92 92545 2 M 3 0/~ 5'~/~/ LIS Tape and Usting 0 9 - 1 9 - 9 2 9 25 28 2M 2 7~ 5-~?~-LIS Tape and Usting 09-19-92 92471 2 M 0 6 .~ .r~?3j LIS Tape and Usting 0 9- 1 8 - 9 2 9 24 8 6 2M 09#J-dg~/LIS Tape and Usting 09- 1 8-92 92511 2M 02E.~$.C"LIS Tape and Usting 1 0-06-92 92539 Receipt?'~ Acknowledged' --~/~'-~-~"-~Date' R._~.~.~ I V E D._ DISTRIBUTION: NOV 0 2 1992 Alaska 0ii & G~s Cons. Commission Anchorage Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: October 30, 1992 Transmittal #: 8585 RETURN TO: ARCO Alaska, inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ¢~)"¢3 2M-04 ¢3-¢'0 2M-12 ¢).-093 2M-02 Sub-Surface Directional 1 0- 0 6 - 9 2 Survey Sub-Surface Directional 0 9 - 0 7 - 9 2 Survey Sub-Surface Directional 0 9 - 2 6 - 9 2 Survey Sub-Surface Directional 1 0- 0 7- 9 2 Survey Sub-Surface Directional 0 8- 2 5 - 9 2 Survey Sub-Surface Directional 0 8 - 2 4 - 9 2 Survey Receipt Acknowledged:-- DISTRIBUTION: D&M State of Alaska (2 copies) 92610 92546 92585 92547 92518 92519 ~'~ .C'. 3~- Dato.--RE-C-E-I-¥ E D NOV 0 2 1992 AJaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: October 9, 1992 Transmittal #: 8572 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2 M - 1 2 Cement Evaluating Log 9 - 2 6 - 9 2 5 7 9 4 - 7 0 01 Acknowledge' ~-~--- Date' State of Alaska(+sepia) Receipt Drilling RECEIVED NSK OCT 1 2 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: September 18, 1992 Transmittal #: 8551 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. Please acknowledge receipt · 2M-12 C[~ ~ 9/6-8/92 2783-71 1 9 Receipt Acknowledged' DISTRIBUTION: D&M Drilling Date: RE..CE.IVED SEP 2 1 1992. Alaska 011 & Gas Cons. Commission Anchorage Vendor Package(Johnston) NSK State of Alaska(+Sepia) AI.~ ~ OIL AND GAS CONSERVATION COMk ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Change approved program Operation Shutdown Re-enter suspended well Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Abandon Suspend Alter casing _ Repair well 99510 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, AnChorage, AK RKB 14.7 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 114' FSL, 189' FWL, Sec. 27, T11N, RSE, UM At top of productive interval 1320' FNL, 1290' FEL, Sec. 33, T11N, R8E, UM At effective depth At total depth 1509' FNL, 1484' FEL, Sec. 33, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical (Well has not been drilled) 71 1 6' feet Plugs (measured) 6288' feet feet Junk (measured) feet None 8. Well number 2M-12 9. Permit number 92.-90 10. APl number 50-1 03-20181 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 8 O' Surface 2 7 6 7' Intermediate Production 7 1 1 6' Liner Perforation depth: measured Size Cemented 1 6" 200 CF 9-5/8" '280 Sx Perm E & ~'~.'~ ,j1"~..~,..430 Sx Class G 7" 160 Sx Class G 175 Sx AS I true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Measured depth True vertical depth 121' 121' 2767' 2767' 7116' 6288' Arctic Pack RECEIV£D S E P - 1 199?- Alaska 0il & Gas Cons. o0mmiSs'~0n Anchorage ~13. Attachments Description summary of proposal _ Change.approved surface casin9 prior to spud from 1 14. Estimated date for commencing operation September 5, 1992 16. If proposal was verbally approved Detailed operation program X__ BOP sketch _ 0-3/4", 45.5 ppf, J-55 to 9-5/8", 36 ppf, J-55. 15. Status of well classification as: Oil __ Gas __ Suspended _ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title ¢¢.,. )~r~; )"//',,,~ · - - FOR COMMISSION USE OI~LY ../,,,,J ¢'--¢../,'~ Date IConditions of approval: Notify Commission so representative may witness /Y','~ IApproval No. Plug integrity __ BOP Test _ Location clearance__ .,,pproved ~op~"~'.~._~ Mechanical Integrity Test _ Subsequ~quire 10- 'Returned / Approved by the order of the Commis _ . Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT I'1~ 'IzI~II:SLI~-ATE B . , . . . . . , 10. 11 12 13 14 15 16 17 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-12 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (2767')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7116') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure wello Clean location and release rig. RECE V D S E P - ! 199 - Alaska Oil & Gas Cons. Anchorage i ARCO ALASKA, Inc. Structure : Pad 2M Well : 12 Field : Kuparuk River Unit Location : North Slope, Alaska - 0 _ 2So _ $oo~ 75o~ 100~ - ! 75O- 2O0O_ 225~. 25o~_ 3000. 32so_ 35oi 3750~ 4250~ 450~. 47S0. SO0~ RKB ELEVATION: 14.7' 6.00 <-- West I~oo t6oo ~40o 12oo iooo ~1~ &OD ~ 200 o I I I I I I ! t I I 1 SURFACE LOCATION: SEC. 27, T1 8/ PERMAFROST ~O=l 397 T/ UGNU SNDS ~D=1~37 T/ W SAK SNDS ~D=2007 ~/ TARGET ~'C~G PT TVD=2767 ~D=5987 K-lO ~D=2837 TMD=6712 DEP=2060 KOP TVD=2967 TMD=2967 DEP=O ~ TD LOCATION: ~ SOUTH 1434 1509' FNL, 1484' FEL~ WEST 1479 SEC. A~ MODIFIED CSG PT TVD=3275 TMD=3276 DEP=25 12.00 18.00 BUILD 3 DEG / 1OO' 24.00 30.00 36.00 4-2.00[0C TVD:4245 TMD:4-368 DEP:491 K--5 TVD:4327 TMD=44-77 DEP=$64. S 45.88 DEG W 2060' (TO TARGET) AVERAGE ANGLE 42.02 DEG RECEIVED s E P - 1 1992 Alaska Oil & Gas Cons. Oommissio~ Anchorag~ soft T/ ZONE A T'VD:6006 TMD=6737 DEP=2077~ 8/ KUP SNDS TVD=6139 TMD=6916 DEP=21g 6~s~ TI) / LOGGING PT TVD=6888 TMD=7116 DEP=233t 0 250 $00 750 1000 1250 I $00 ! 750 2000 2250 2500 SCALE ! : 125.O0 Vertical Section on 225.88 ozimuth with reference 0.00 N, 0.00 E from slot ~12 - T/ KUP SNDS TVD=5987 TMD=6718 DEP=2060 CaOTgO wr , ~o.~s For: B MATHEI~S .O,e,l~ ~LOTTED : 24-~UG-92 ~ ~RENC[ IS 12 ~RS~ ~2. ~C~X~S ~E ~ ~ REFERENCE SLOT ~ ~R~C~ ~PT~ ~E REFE~NC[ JE~H[~. ~EASTMAN m m 250 I I, ARCO ALASKA, Inc. Structure : Pad 21wi Well: 12 INCLUDES PROPOSED 1F/4U/7/SV Field : Kuporuk River UnH Location : North Slope, Aleako W e s f '~'-' ' 200 150 100 50 0 50 : 5o. oo 100 1000 O0 1200 1400 ~ ooo 1800 1000 1 200 1400 O0 1 000 1 200 1000 ~00 s E P -- 1 ~U92 Anchorage 100 _ 0 _ 50 _100 _150 _200 _250 _300 I I V Casing Design ! Cement Calculations 1-Sep-92 INPUT WELL INFORMATION Well Number: Surface Csg MD: Surface Csg TVD: MD: TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice (1, 2, 3, or 4): Production Casing Choice (1 or 2): Production Casing Frac. Pressure 2M-12 2,767 ft 2,767 ft 7,116 ft 6,288 ft 2,007 ft 6,712 ft 5,987 ft 10.2 ppg ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 3,500 psi PRESSURE INFORMATION Maximum anticipated surface pressure Estimated BH pressure at top of target zone CEMENT CALCULATIONS Surface Casing Cement: Surface lead: TVD surface shoe {(13.5*0.052)-0.11}*TVDshoe Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = -I Top West Sak, TM D Design lead bottom 500 ft above the Top of West Sak Annular area Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Cement volume required Surface tail: TMD shoe = (surface TD - 500' above West Sak) * (Annulus area) = Length of cmt inside csg = Internal csg volume = Cmt required in casing = RECEIVED Total cmt = Excess factor = Cement volume required = S E P - 1 !992 Yield for Class G cmt = Alaska 0il & Gas Cons. 60mmissiO~ Cement volume required =l Anchorage 2,767 ft 1,638 psiI 10.2 ppg 5,987 ft 3,276 psi 3176 psiI 2,007 ft 1,507 ft 0.3132 cf/If 472 cf 15% 543 cf 1.97 280 sxI 2,767 ft 395 cf 8O ft 0.4340 cf/If 35 cf 429 cf 15% 494 cf 1.15 430 sxI Casing Design / Cement Calculations Production Casing Cement: Production tail: CASING DESIGN TMD = Top of Target, TM D = Want TOO 500' above top of target = Annulus area (9" Hole) = (TD-TOC)*Annulus area = Length of cmt wanted in csg = Internal csg volume = Cmt required in casing = Total cmt = Excess factor = Cement volume required = Yield for Class G cmt = Cement volume required =[ TENSION - Minimum Design Factors are: T(_ob)=l,.5 and T(js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = 9.6ppg*.052*TVD Surf. Cas.*X-sect. Area Casing Rated For: MD surface shoe = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =l Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = 9.6ppg*.052*TVD Surf. Cas.*X-sect. Area Casing Rated For: MD surface shoe = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Prod.*X-sect. Area Casing Rated For: TMD = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =J Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Prod.*X-sect. Area RECEIVED S E P - 1 1992 Alaska 0il & Gas Cons. C0rnrnissio~ 2 Anchorage Casing Rated For: TMD = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =J 1 -Sep-92 7,116 ft 6,712 ft 6,212 ft O. 1745 158 cf 80 ft 0.2148 17 cf 175 cf 15% 201 cf 1.23 160 sxJ 564000 lb 2,767 ft 36.00 Ib/ft 99612.0 lb 14164.3 lb 85447.7 lb 6.6J 639000 lb 2,767 ft 36.00 Ib/ft 99612.0 lb 14164.3 lb 85447.7 lb 7.51 415000 lb 7,116 ft 26.00 Ib/ft 185016.0 lb 25177.4 lb 159838.6 lb 2.61 490000 lb 7,116 ft 26.00 Ib/ft 185016.0 lb 25177.4 lb 159838.6 lb 3.11 Casing Design / Cement Calculations BURST- Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 1 -Sep-92 3520 psi 1638.1 psi 2.11 Production Casing: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ 4980 psi 6835 psi 2910 psi 3925 psi 1.3J COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Internal Pressure = Design Factor =1 2020 psi 0.530 Ib/ft 1468 psi 0 psi 1.41 Production Casing 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Internal Pressure = Design Factor =1 4320 psi 0.530 Ib/ft 3335 psi 0 psi 1.3J RECEIVED $ EP - 7 7992 /~la$1(a OJJ & Gas Cons. Commission Anchorage Casing Design / Cement Calculations 1-Sep-92 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength 1161OOO lb 979OOO lb 639OOO lb 931000 lb Body Strength 1086000 lb 916000 lb 564000 lb 715000 lb Collapse 4750 psi 3090 psi 2020 psi 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section I 7.000 6.276 26 L-80 7.5491 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength 667000 lb 490000 lb Body Strength 604000 lb 415000 lb Collapse 5410 psi 4320 psi Burst 7240 psi 4980 psi RECEIVED ~lask. a Oil & Gas Cons. uommiss~o,; Anchorage .JPARUK RIVER UNI'. 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS ~S DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16% 2000 PSI BALL VALVE 4. 20" - 2000 PSi DRILLING SPOOL WITH TWO 10" OUTLETS. SEP '~ "'~e~ .Alaska. Oil & Gas Cons. Commissior~ Anchora~le 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER E DF 3/10/92 13 5/8" 5000. BOP STACK 7 6 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 4 I3 ~K~P STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLDFOR 10 MINUTES, BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE lINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16'- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR & Gas Co~s. Commission Anchorage Alaska 2M-'? 2... RE:ViSEi:I::,~ Prudhae B,"~ 9/3192 M. Minder Casing Iht Iht [:)eso Desc Desc~ "f'ensior~ Size BoEom Top I....ength Lbs Grade 'l"h r~,:.:~ad I....bs 't A 16 '121 4,1 80 6~, 5 H.,.40 Weld 2A 9~625 Z767 41 Z76"7 36 J.,.55 SA 7 6288 4.1 7116 ~6 J..,55 BTC 0 4.A 0 0 0 0 0 0 0 0 5A 0 0 0 0 0 0 0 0 6A 0 0 0 0 0 0 0 0 'TA 0 0 0 O 0 0 0 0 8A 0 0 0 0 0 0 0 9.A 0 0 0 0 0 0 0 10A 0 0 0 0 0 0 0 lB 4.[iii 5B 6B 1 Mud Wieght PPg 10.0 9.6 0.(3 0.0 0.0 0.0 0.0 0.0 0.0 I."'lyd GrAdi ¢...,.nt psi/ft 0.520 0.4.99 0.5~90 0.000 0.000 0.000 0.000 0.000 0.000 0.000 M~ Press Minimum psi Yield 1384. 164.0 352(3 3580 3'1 "76 4~)90 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Tension F~/L..b s 5 99.612... 185.016 0 0 0 0 0 0 0 Strength K/L~s 0 715 4.15 0 0 0 0 0 0 0 I::h.'e.~ s ur'e Bot.-PSI Resist. 63 6'70 1381 2(32(.'3 3335 4.320 O 0 0 0 0 0 0 0 0 0 0 0 0 0 :k WALTER J. HICKEL, GOVERNOR · ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 1, 1992 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-12 ARCO Alaska, Inc. Permit No: 92-90 Sur. Loc. ll4'FSL, 189'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc. 1509'FNL, 1484'FEL, Sec. 33, RllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF: ALASKA ALJ-,oKA OIL AND GAS CONSERVATION COMMISo~ON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work' d~'{'[i X R'e~:ill [] '~ f~"Type of Well E~:pl0r'atory [] '~{~atigraphic Test "¢'~' ..... Development 6ii X Re-Entry F'~ Deepen ['-] Service D Development Gas r"] Single Zone X Multiple Zone 2.. Name of"0p~ralor ............ 5, DatUm Elevation (D~'or KB) i 0'. ' I~ield and Pool ' ' ' . AR.CO Alaska, Inc. RKB 147', Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 10,0360, ,Anchorage, AK 99510-0360 ADL 25586, ALK 2672 4. LocalJon of well at sudace ' ' 7. Unit or property Name 1 1. TYpe B~n'd ('~ee 2o AAC 25.025) 114' FSL, 189' FWL, Sec. 27, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1320' FNL, 1290' FEL, Sec. 33, T11N, R8E, UM 2M-12 #UG630610 At total depth 9. Approximate spud date Amount 1509' FNL, 1484' FEL, Sec. 33, T11N, R8E,' UM 9/1 0/92 $200,000 12. Distance t° nearest "~. Distanc"e"to' nearest well 14. Numb~' ~i"'ac'res in property 15. Proposed depth (ME) and WDi ...... property line 2M~ 11 7116' MD 1484 @ TD leet 24' @ 540' MD feet 2560 6288' TVD leer 16:'''' ~i'o be c~m'pleied f"or deviate-d ~'lls ........ 1~. Anticipate~l pr~s'~'~re (see 20 AAC'2'5.035(e)(2)) ....... Kickoff depth 2967 feet Maximum hole angle 42.02° Maximumsudace 1638 ,$i, At total deoth (TVD~ 31 76 '18. Casing program ................ ,, ' '" Setting.',iD,e'pth ..... size Specifications 'Top BOttom Quantity of cement Hole ca, sing 'Weight Grade ...... Coupling "~.'~gth ' Md TgD ~ ' TV~)' ' (include s!,a,,,ge (Jata) '24" .... 16" 62.5# H-40 Weld 80' 41'.... 41' 121' 121' . _+200 CF ........... 13.5" . 10.75'' 45.5#' j:~5 BTc ~7'6'7',' 41, 41,'"' 276~,' 2767," 320 Sx Permafrost E & ' HF'ERW 500 Sx Class G 8.5" 7" 26.'0'# J-55 BTCMOE 3276' 41' 41' ' 3276' ''~275' ~ HF-ERW .... 8.5" 7" 26.0# J-55 BTC ~840' 32'~6, 3'275, 7i'i6, 62'8'8, 16(~ Sx ClaSs G " .... H'¢-ERW ............. Top 500' ;hove Kuoar'uk 19. To be c~)~pleted for Redrili,'Re-entry, and Deeper; ~)erations, ' ............. Presenl well condition summary Total depth: measured f e et Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vedical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface Intermediate AU6 2 7 1992 Liner Pedoration depth: measured ,t~bska Oil & Gas Cons. Commission true vedical Anchorage ~i Attachments .... FiTi~g fee 'X .... Property plat ' '~" BO'P Sket~l~'")~' '' Diverter Sketch' X "' Drillir~g progr~ X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report BI 20 AAC 25.050 requirements X 21. i I~rebY certify that the fo~'~oing' i~;'true and"~0rrect 't(~ the' ~(~i'0f' 'my 'kn(~wledge ........ Signed /~///~~ Title Area... Drillincj E nglineer Date ........... Cbmmission Use O~ly' ' · /' 'Permit' Number' ' I APl number ........... I Apprq-~al date '" ;; ..~ I See cover lette;'f'or .... ?.z- , .zo/?/ ,,, 7-1- other req. rements Conditions of approval Sam'~)ies required r-]" Yes ~ No" Mud lo.q required r-1 ~,;s ~ No ...... Hydro.qen sulfide measures BI Yes ~ No Directional survey required /~ Yes E] No Required workin.q pressure for BOPE r-] 2M ffi 3M E] 5M ["] 10M B i5M Of her: Originat o',~,n~3d.::: By Approved by David W. uuhnston by order of .......... Commission, e,r ....... the c.o,m,mission ... Date '~. "" -- _ Form 10-401 Rev. 7-24-89 Submit in triplicate PERMIT TO DRILL 20 AAC 25.005 -,.~.~.. Type. of Work Drill 'X Redrill D 11~ Type of Well Exploratory F'J Stratigraphic Test J-'J Devei0~me~i 0ii/..',X '%.~ Re-Enln/ F'J Deepen r"] Service J'-] DevelopmenlGas r'J Sin,clleZone X Mullil:)le~Zo~e ~'., N~'r~.of oPerator "' 5. Datum Elevation (DF or KI~) 10. Field and Pool ARCC~,~laska, Inc. RKB 1.47',...Pad !05' GL teel Kuparuk River Field 3. AddreSs %,% 6. Properly Designalion Kuparuk River Oil Pool P. O. Box 1'Q0360, Anchoracje, AK 99510,-.0360 ADL 25586, ALK 2672 4." ' Localion ol well ai"sudace 7. Unil or properly Name 1 i. Type Bond (see 20 AAC 25.O2S)' 114' FSL, 189' FW~';'.Sec. 27, T11N, R8E, UM Kup. aruk River Unit Statewide At lop of productive interval (~,...TARGET) 8' Weld number Number 1320' FNL, 1290' FEL, Sed?~..33, T11N, RSE, UM . 2M-.12 #UG630610 Al lolal deplh '%-~.,? 9. Approximate spud dale Amounl 1509' FNL, 1484' FEL, Sec. 33, '%.11N, R8E, UM 9/1 0/92~ $200,000 12. Distance l° nearest 13. Dislance I0~ nearest well ' ' 14. Number of acres in prOperly 1~5. Proposed deplh (MD and TVD) property line 2M- 1 1 '*,, ../"; ; ( 7116' MD 1484 @ TD feel 24' @ 540' MD,. feet /' 2~,60 ? .... "-6288' TVD leel 16. TO be completed for' deviaied wells ..... "%.~ ' 17. AnliciPaled preSscre (see 20/A~C 2s,035(e)(2)) .... mu hole an le ~ o Max~mumsurface~ o~si8 At to)tel dec)Ih CTVDi Kickoff depth 2967 feel Maxi m .q ', 42.02 ' i ~?~163~ .;'"' 3176 '~ 18.' ~:asing Program ' "'' ' %~ [ ' Se~n~/I~ep~h/ !w.....' ...... size Specificalions ~"%. ! ' Top ~ ~ _,.J~olt°m Quanlif)/of cement Hole Casing Weight Grade C~pling Lenglh ,:'~.. MD TV• k MI~ 'TVD (Include sla~'e' cJata1 2~4" 16" 62.5# H,40 Weld 80,,. "~"t' 41' ~,21' 121' +200 CF '13.5" '" 10.75" 45'5# J-55 BTc 2767' 41%i 4i' 2%67' '2~67' "~0 Sx Permafrost E & HF.ERW: ~-. . ~,, 500 Sx Class G 8.5. 7. 26.0# J-55 BTCMOE 3276" 41' '~4,1' 3276' 3275' 8.5" ¢" 2'e.o# J-55 CEITC 3840' 3276' 32¢5' 7116' 6288' 160SxClas'sG .... ,,/ HF-ERW " ;',~, '" ~"'~ ToF; ...... 500"ab°ve'Kuparu'k ' 19. To be completed for Redrill, Re-e~g(rY, and ~)~ep'en Operalions. \~ . Present well condition summar~~ ,~ Total depth: measure~l feet Plugs (me~s..ured) true ,'¢~rlical ieel "~-'-. Efleclive deplh: measured ~i feel Junk (measured),:~ /{rue vedical feet . ~ ~. ~ ¢' ~ Measured depth True Vertical depth Casing Length Size Cemented Structural ~' ~' ':'~. Conductor' Surface ~ Production ~-'"~ ' 2 7 ~. ? Ceasured Alaska 0il & Gas Cons; CommisSion Perforation depth: vertical :i /rue Anchorage ~,~ / ~ .. 20': Attachments ~.Eilidg fee X Pr(~Periy plat 0 BOPSketch X Diverle, Sketch X Drilling program X Drilling fluid program X Time vs deplh plot [] Refraction analysis [] Seabed report r-J 20 AAC 25.050 requiremenls X 2'1".' I hereby certify lh,'~l Ihe foregc~ing is true and correc'{ 'io lhe best' of my knowledge Si.ned ///~///~~ Title Area D,rilli,n~l, En~l in e er , , , Date ~1~/~'-- ~.. '" ' , , / .... Co~mis~ion Use Only/ ~' Perm, Number J APl number J Approval del J See cover ,eUer for ~- ?~ 50- /~.,e- ~_ 0/~, ?/ ..... ?-" /- Y~:;~ other requiremenls , Conditions of approval Samples required 0 Yes ~ "o Mud Io.~ required E] Yes ~ No Hydro.aensulfide measures [] Yes ,J~ NO Directional survey required ~ Yes Fi No Required working pressure for BOPE 0 2M [~ 3M 0 5M BI tOM 0 15M Olher: Original Signed By Approved by , , C0m, missioner the commission , Dale ,, Form 10-401 Rev, 7-24-8g ARCO ALASKA, II'lC. Structure : Pad 2M Well : 12 Field : Kuporuk River Unit Location : North Slope, Alaska 2000_ 2250. 250O- . 2750. · 3250- - 3500- 3750_ - 400~ 425~ ~500- 4750- - 5000- 5250_ - 5500- - 5750- - 6000- RKB ELEVATION: 147' B/ PERMAFROST TVD=1397 T/ UGNU SNDS TVD=1437 T/ W SAK SNDS TVD=2007 B/ W SAK SNDS TVD=2567 10 3/4"C$G PT TVD=2767 K-lO TVD=2837 KOP TYD=2967 TMD=2967 DEP=O 6.00 12.00 <-- West BOO ! 600 14,00 1200 1000 BOO 600 4-00 200 0 [ I ,I I I I I I I I I I I I I I I I I I ~ I -- SURFACELOCATION: ] / 2o0 ~,~' ~L, ~a9' FWL | / SEC. 27, T1 400 O~ 600 ~ ~ oo o 2oo ~ / I TARGET LOCATION: I .... ~/ I 1 320' FNL, 1290' FEL[ I SEC' 33'T'1N' RSE I Boo TARGET TVD=5987 TMD=6712 DEP:2060 TO LOCATION: I SOUTH 1434 1509' FNL, 1484'FEL WEST 1479 AB MODIFIED CSG PT TVD:3275 TMD=3276 DEP=25 SEC. 213, ¥1~N, RSE 18.00 BUILD 3 DEG / 100' 24.00 30.00 36.00 42.00 EOC TVD=4245 TMD=4368 DEP=491 K-5 TVD=4327 TMD=4477 DEP=564 S 45.88 DEG W ;2060' (TO T^RGET) AVERAGE ANGLE 4;2.02 DEG REEEIVED AU G 2 1 1992 Alaska Oil & Gas Cons, 6ommissiOn Anchorage T/ ZONE A TVD=6006 TMD=6737 DEP=2077: B/ KUP SNDS TVD=6139 TMD=6916 DEP=21 - T/ KUP SNDS TVD=5987 TMD=6712 DEP=g060 TI) / LOGGING PT TVD=6;~88 TMD=7116 DEP=;E331 25 0 500 750 1000 1250 1500 1750 2000 2250 2500 SCALE 1 : 125.00 Vedical Section on 225.85 azimuth with reference 0.00 N, 0.00 £ from slot #12 I!RREATED BY JONES For: B MATHE]~S ATE PLOTTED : 24-AUG--02 LOT REFERENCE IS ~2 VERSION #2. OORDINATES ARE IN FEET REFERENCE SLOT #12. ARCO ALASKA, Inc. 250 Structure: Pad 2M Well : 12 INCLUDES PROPOSED 1F/4.U/7/SV Field : Kuparuk River Untl Location : Norfh Slope, Alaska 200 150 100 50 0 50 : 50.00 100 1000 1200 .000 14-00 1000 1800 1000 1 200 1 4-00 1000 I I 100 50 O0 O0 1000 1200 AUG Alaska Oil & Gas Cons. 'Anohorage _ 0 _ 50 _100 _150 _200 _25O _3OO I I V ,.UPARUK RIVER UNI, 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED AU G 2 7 1997. 1. 16" CONDUCTOR Alaska 0il & Gas Cons, commiSsion-- 2. SLIP-ON WELD STARTING HEAD Anchorage 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/9'2 7 13 5/8" 5000 PSI BOP STACK .ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 4 I3 i2 , BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE T_~_O 3_QQQP_SI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11"-3000 PSI X 13-5/8"- 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR REC£ VED AU G 7 Alaska Oil & Gas Oons. Anchorage Casing Design / Cement Calculations 26-Aug-92 INPUT WELL INFORMATION Well Number: Surface Csg MD: Surface Csg TVD: MD: TVD: Top of West Sak, TM D: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice (1, 2, 3, or 4): Production Casing Choice (1 or 2): Production Casing Frac. Pressure 2M-12 2,767 ft 2,767 ft 7,116 ft 6,288 ft 2,0O7 ft 6,712 ft 5,987 ft 10.2 ppg 3,500 psi PRESSURE INFORMATION Maximum anticipated surface pressure Estimated BH pressure at top of target zone CEMENT CALCULATIONS Surface Casing Cement: Surface lead: Surface tail: TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe Anticipated Mud Weight Top of Target Zone, TVD 100 psi Overbalance Top West Sak, TM D Design lead bottom 500 ft above the Top of West Sak Annular area Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Cement volume required TMD shoe (surface TD - 500' above West Sak) * (Annulus area) RECEIVED AU G ?- 7 1997. Alaska Oil & Gas Cons. Anchorage Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required 2,767 ft 1,638 psiJ 10.2 ppg 5,987 ft 3,276 psi 3176 psiI 2,007 ft 1,5O7 ft 0.3637 cf/If 548 cf 15% 630 cf 1.97 320 sXJ 2,767 ft 458 cf 8O ft 0.5399 cf/If 43 cf 501 cf 15% 577 cf 1.15 500 sxJ Casing Design / Cement Calculations Production Casing Cement: Production tail' CASING DESIGN TMD Top of Target, TMD Want TOC 500' above top of target Annulus area (9" Hole) (TD-TOC)*Annulus area Length of cmt wanted in csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required TENSION - Minimum Desiqn Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = 9.6ppg*.052*TVD Surf. Cas.*X-sect. Area MD surface shoe = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = 9.6ppg*.052*TVD Surf. Cas.*X-sect. Area Casing Rated For: MD surface shoe = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy =Mud Gradient*.052*TVD Prod.*X-sect. Area Casing Rated For: TMD = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =l Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Prod.*X-sect. Area AU 6 2 7 1992 Alaska 0il & Gas Cons. L;omrn'C,s~oo Anchorage Casing Rated For: TMD = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =! 26-Aug-92 7,116 ft 6,712 ft 6,212 ft 0.1745 158 cf 80 ft 0.2148 17 cf 175 cf 15% 201 cf 1.23 160 sxJ 715000 lb 2,767 ft 45.50 Ib/ft 125898.5 lb 17965.3 lb 1 O7933.2 lb 931000 lb 2,767 ft 45.50 Ib/ft 125898.5 lb 17965.3 lb 107933.2 lb 8.61 415000 lb 7,116 ft 26.00 Ib/ft 185016.0 lb 25177.4 lb 159838.6 lb 490000 lb 7,116 ft 26.00 Ib/ft 185016.0 lb 25177.4 lb 159838.6 lb 3.11 Casing Design / Cement Calculations BURST- Minimum Design Factor = 1.1 Surface Casing: Burst - Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 26-Aug-92 3580 psi 1638.1 psi 2.2i Production Casing: 1. Design Case - Tubing leak while well is SI Inside pres--Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.gppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =l 4980 psi 6835 psi 2910 psi 3925 psi COLLAPSE - Minimum Desiqn Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Production Casing 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Internal Pressure = Design Factor =[ Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Internal Pressure = Design Factor =l 2090 psi 0.53O Ib/ft 1468 psi 0 psi 1.4J 4320 psi 0.530 Ib/ft 3335 psi 0 psi 1.31 RECEIVED AUG 2 7 1992 Oil & Gas Cons. Commissio[~ Anchorage Casing Design / Cement Calculations 26-Aug-92 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength 1 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 4320 psi 4980 psi RECEIVED AUG 2 7 1992 Alaska Oil & Gas Cons. OommJssior~ Anchorage DRILLING FLUID PROGRAM Well 2M-12 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-120' 5-15 15-40 10-12 9-10 10% _+ Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.2 10-18 8-12 35-50 2-4 4-8 4-5 9-10 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1638 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-12 is 2M-11. As designed, the minimum distance between the two wells would be 24' @ 540' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175+ sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. Adjust FV to 50-80 sec/qt below gravel beds. RECEIVED Alaska Oil 8, 6as Cons. Cornrrlission Anchorage ~M,,, 1 ~.XL.J Al .as 2M.~ 1 ?**. Prudhoe: 8131192,,. M. Minder IA 3A 5A 6A "?A 8A 9A '? 0A Casing Size 16 10.'75 '7 0 0 0 (,1 0. 0 (:,1 Iht [.3otto rn 1.2.,1 2'76 '7 6288 0 0 0 0 0 0 (:,1 Iht Top 4.1 4,1 4.1 0 0 0 0 O (,1 L.ength 80 P...'76 '7 7116 0 0 0 0 0 0 0 Lbs 4.5.5 26 0 (,1 0 0 0 0 Grade H.,.4,0 J,,.55 J.,.55 0 0 0 0 0 0 D e s e, 'T'hread Weld 8TC 13"1"C: 0 C1 0 0 C) 0 0 Tension Lbs 0 0 0 0 0 0 (,1 0 0 0 38 4.8 5[.3 6B 8[,3 9B 013 Wieght PPg 10.0 9.6 10,2 0,0 0,0 0.0 (.1.0 0.0 0.0 0.0 Gradient psi/ft 0,52O 0,4.99 0.530 0.000 0.000 0,000 0.000 0.000 0.000 0.000 Surf,~oe psi 384. '176 31 '76 0 0 0 0 Minimum Yidd 't 64.(:,1 4.980 0 0 0 0 0 0 0 Tendon K/Lbs 5 'f 25.8985 I' 85,016 (,1 0 0 0 0 0 Strength K/L.~s 0 '715 4.15 0 0 0 0 0 0 0 Bot.,,PSI 1('381 3335 0 0 0 0 0 0 0 C:ollap s e Resist. 6'70 2.,.090 4"320 0 0 0 0 O. 0 0 ?/ ~h ITEM (1) Fee (2) Loc (3) Admi n APPROVE DATE [2 thru 8] ' (4) Casg [14 thru 22] (5) BOPE [23 thru 28] ** CHECK LIST FOR NEW WELL PERMITS ** Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated $ is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease n~rnber appropriate .......................................... 13. Does well have a unique name & n~rnber ................................ 14. Is conductor string provided ......................................... 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wellbore ................... 21. Is old wellbore abandonment procedure included on 10-403 .............. 22. Is adequate wellbore separation proposed ............................. 23. Is a diverter system required ........................................ 24. Is drilling fluid program schematic & list of equipment adequate ..... 25. Are necessary diagrams & descriptions of diverter & BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to %o~ psig ..... 27. Does choke manifold comply w/API RP-53 (May 84) ...................... 28. Is presence of H2S gas probable ...................................... Lease $ Well NO REMARKS ,2- Other /~'.PC___ ~ [29 thru 31] (7) Contact [32] geo19gY' eng i neet i nq' DWJ _~. MTM/~/ RAD ~ ~t" \ RP_C~.~ BEW ~ JDH~. LAG ~l'~ 29. 30. 31. 32. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressur.e zones ................... Are seismic analysis data presented on shallow gas zones .... · ......... If offshore loc, are survey results of seabed conditions presented... Name and phone ngrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' rev 08/18/92 jo/6.011 O -rz ~0 cn--I 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. * ~LASKA COMPUTING CENTER * ****************************** COMPANY NAME : ~CO ~L~SK~ INC. WELD N~ME : 2~-~2 FIELD NAME : KUPA~tJK BOROUGH t NORTH SI, OP~ STATE : ALASKA APl NUNBER : 50-~03-20181 ~EFE~EMCE NO : 93507 RECEIVED ~OV 2 2 199~ Alaska Oil & ~as Cons. AnChorage C°r~l$$iorf Tape Verification Listinq SchlumberJer Ala$K~a Co~put, inq Center DATE : 93/11/il ORICIN : FLIC ~E[, ~A~E : 93507 CONTIN!J~TION # ~ CON~E:NT : ARCO ALASKA, !NC., KUPARUK RIVER, ~-12, 50-10]-20181-00 DATE : 93/t!/11 O~I~IN : FLIC CONTiNU~TIOM # : l CO~ENT : ARCO ALASKA, INC., KUPARUK RIVE~, 2M-!2, 50-103-2018%-00 KUP~UK RIVER CASED HOL~ WIR~LIN~ LOGS WELL NANE~ APl NUMBER: LOGGING CO~PANY: T~P~E C~EATIO~i DATE: JnB OP~ATO~ WITNESS: SURFACE LOCATION TnWNSgi'P: FML: FSL: FEL: ELEVATION(FT FROM ~SL KELLY D~ICK FLOOR: GROUND L~V~L: WELL CA~ING ~ECORD 2N'12 5010320181 ARCO AbA~gl INC., ,,I'NOV-g3 93507 JEFF FORMICA BUFFORD BEPR 27 ~46 00 146!00 ~05 O0 1ST ST~IMG ~ND ST~IMG ]RD STRIMG ~PODUCTION STRI~G CURVE SHI~T DATA - ALL PASSES TO STANDARD(~EASURED DEPTH) OPEN HOLF~ CASING DRILLERS CASING [:~IT SIZE (IM) SIZE (IN) D~iPTH (FT) WFIGgT CLB/FT) 7.000 7099.0 ~6.00 PAGE: Schlumberger AlasK~ Computtnq center LD~., TOOL COD~: ~ET bDWG CURVE CODE: GR RUN NU~BE~: 1 D ~TE LOGGED: ~6-SEP-93 LO~GIMG CO~PANY~ SCHLU~BE~GE~ ~EL,b SERVICES ----------EOU'IVALEMT UMSHIFTED G~CH RE~ARKS: · THE CET AND ?H~ HLDT ~ERE RUN I~ cOmBINATION AND NO DEPTH SHIFTING wAS REOU!R~D, $ PAGE: **** FIL~ HEADER FIL~ NA~E : EDIT ,001 SERVICE ~ FbIC V~R~ION : 00!C0! DAT~ : F~L~ TYP~ ~ LO bAST FILE FILE HEADER FILE NUMBER: 1 EDITED CURVES DePth shifted and clipped curves for each PaSS ~D separate files, 0,5000 PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LD~G TOOL CODE HI.,DT START DEPTH 6967.0 STOP, DEPTH ~779,0 5779,0 CURVE SHIFT DATA - PASS TO DASS(MEASUR~:D DEPTH) BASELINE CURVE FOR SHIFTS LD~G CURVE CODE: ~RCH PaSS ~U~BER: 1. .......... EQUIVALENT U~SHIFTED D~PTH BASELINE DEPTH GRCH HLDT RENARKS: THE CFT A~D THE HLDT gERg RUN IN COMBINATION, NO DEPTH CORRECTIFDK; WAS R~QUIR~D. THE GRCH.CE? ~ I~CLUD~D, HOWEVER, THIS IS THE ~AHE CURVE ~$ GRCH.HSDN FOR LIS TaPe Verif~cation [~isttmg SChlt~mberger Alaska Computing Center P~S$ 1, $ # PAGE~ ** D~TA FOR~:AT SPECIF.IC~TION ~ECO~D ** ** SET TYPE P~P~ COD~ V~bUE ~ 66 0 2 66 3 73 4 66 5 66 6 7 65 9 65 1! 66 36 ~.3 66 0 i~ 65 FT ~5 66 68 !6 66 1 o 66 0 ** SMT TYPE - CHAN ** .......... ..,,,,..--.........-....----...--.-.-...-,.,,--.-----..-----.-----------,--- ID ORDER # bOG TYPE C1,~$S ~OD NUmB S~P EI~F~ CODE [HEX) DFPT FT O0 000 O0 0 1 ! 1 ~ 6~ 0000000000 ~.o~ HSO~ C/C] O0 000 O0 0 t ~ ~ 4 ~ oooooooooo o~o ~SDw ~/C~ Oo 000 O0 0 t ~. ~ 4 ~ oooooooooo pe~ ~s~ ~/~ oo ooo oo o t t t 4 ~ oooooooooo T~S ~so~ ~ oo ooo oo o ~ t ~ 4 ~ ooeooooooo ~c~ .so~ ~x oo coo oo o t ~ ~ ~ 6~ oooooooooo c~c.~ c~ ~) oo ooo oo o ~ ~ 1 ~ ~ oooooooooo DE~T, ?008,500 ~NO~,NSDN -~99.2~0 DRHO,MSDN -999,250 . TENS HSDN ~05~,000 23.672 iS Tape ~eriflcation Listing ~chlumberger Alaska Comput~.,n~ Center i!-NOV-1993 22~03 D~PT. ~779:~00 ~HO~.HSDN -g~ ~0 DRHO.HSDN' -999..250 T~NS,USD~ .870 O0 GRCH'~:SON ";:' : 5 GRCN,C.ET 65,875 PEF.~SDN 20.938 F!SE NA.~E : EDIT .001 VERSIO~ : O01C0l DAT~ : g)/!!/ll ~AX ~EC SIZE : 1024 F!L~ TYP~ : LO LAST FIL~ FILE NA~g t EDIT .002 8ERVIC~ · FL!C V~RSION : 001C01 DaT~ : 9.3/1!/11 ~AX REC SIZE : !0~4 FIL~ TYPE : LO FILF ~U~: 2 EDIT~:D CURVES DePth sh~fted and cli. DPed curves for each PaSS ~n separate files, 0.5000 # FILE SU.MA~Y LOWG TOO[, COD~ ~LDT START DEPTH 6998.0 STOP DEPT~ 6185,0 b185.0 CURVE SHIFT DATA - PASS TO PASS(~EASURED DEPTH) B~SEI, I~E CURVE FOP SHIFTS LOW~ CUPVE CODK~ G~CH --- ........ ~O~{IVAL~NT ~NSHIFTED DEPTH .......... ~ASELI~ DEPT~ G~CH HLDT $ ~E~ARKS: THE CET AND THE HLDT WERE RUN l~ COMBINATION, ~0 DEPTH LIS Tape Verification !..;istinq Schlumberger AlasKa ComDutin0 Center CORRECTION 'AS R~:Q[]IRED, bis FORMAT DATA ii-NOV'-!993 22:03 . ,.* DATA FORMAT SPECIFICATION RECORD ** ** SET.TYPE - 64ED ** TYPE REPR CODE VILUE ! 66 0 2 66 0 3 73 24 4 66 1 o 11 66 42 t2 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ~ ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB MI.INB SIZE REPR PROCESS '''''''''''''''''''''''''''''''''''''''''''''''''''''''''D~PT ~T 00 2 I .... ] '''''''''~'''''~;~;3;3'~'4 8 .. 0 RHOB HSDN G/C] 00 000 00 0 2 ! ! 4 68 0000000000 DRHD HSDN G/C~ 00 000 00 0 2 1 I 4 68 0000000000 PFF HSDN 8N/E 00 000 O0 0 2 ! ! 4 6~ 0000000000 T~NS HSDN LB 00 000 00 0 2 1 ! 4 68 0000000000 GRCH HSDN GADI 00 000 00 0 2 I 1 4 68 0000000000 ** DATa DEPT, 7025.000 RHOB,HSDN -999,250 DRHO,HSDN -999,250 PEF.HSDN 2870,000 GRCH,HSD~ -999,250 6185 000 RHOB,HSD~ ~99 250 D HO,HSDN -999.250 DEF,HSDN ~995,000 GRCH,HSD~ =999.~50 20,938 22.672 LIS TaPe Verification Listing SchlumbergerAlaska Computin~ Center I~-NOV-!993 22:0] **** FILE TRAILER **** FILM NAME : EDIT ,002 SERVICE : wblC VERSION : O01COI b~ST FILE : **** FILE HEADER **** FI5~ NAME : EDIT ..003 SERVICE : Fb!C VERSION : o0ICOI D~TE : 93/!1/11 ~IX REC S!Z~ : 1024 FILE TYPE : bO L~ST FILE F!bM HEADER FIbF NUMBER: EDITED CURVES DeDt~ ~h~fted and Cl~.PDed curves ~or eacD Dass 0.5000 DEPTH INCREMENT: FILM SUmmARY LOWG TOO!, CODE HLDT START DEPTH 6~54.0 699~.0 STOP 6185,0 CURVE SHIFT DATA - PASS TO PASS{MEASURED DEPTH) BAS~L!NE CURV~ FOR SHI~TS LDWG CURV~ CODE: GRCH D~SS ~U~S~R: 1 ...... ----EQUIVALENT {.}~SHIFTED DEPTH .......... BASELINE DEPTH G~CH HbDT REHARKS: THE CET AMD THE HL!)T WERE RUN I~) CONBINATION, NO DEPTH CORRECTIO~-~ WAS REOU!RED, $ ~lUmberqer iasK Computlnq Center ** DATA OR,AT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYP~ R~P~ CODE VAbUE 1 66 0 2 ~6 0 3 73 24 4 66 5 66 6 73 7 65 ~! 66 42 I~ 69 13 66 0 !4 65 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** , , ID ORDER # BOG TYPE CLASS MOD NUMB SA~P ~LE~ CODE (HEX) D~PT ~T O0 000 O0 0 3 1 t. 4 68 0000000000 RHOB HSDN G/C3 O0 000 O0 0 3 ! ! 4 68 0000000000 OqWn HSDN G/C3 00 000 00 0 ) 1 ! 4 68 O0O0000000 P~F ~SO~ ~N/E O0 000 00 0 3 ! ! 4 68 0000000000 TFNg NSDN LB O0 000 O0 0 3 ! I 4 68 0000000000 G~CW HSDN GAPI O0 000 O0 0 3 1 i 4 68 0000000000 ** DATA ** D~PT. 7026,000 RHOM.HSDN '999,~50 TENS,HSDN ~915.O00 G~CH.NSDN -999,250 DRHO,HSDN -999.250 PEF.HSDN 28,984 ** E~D OF PATA ** [,IS Tape Ver]ficatt, on Listing Schlumberger A]as~a'cOmpOt.img Center **** FILE [~A~ : EDIT ,003 VERSION D.~T~ ~ 93/!I/! ~, ~AX ~EC SIZE ~ I0~4, FILE TYPE LAST F!bE **** FIbE '{EAt)ER **** FILE NA~E : EDIT .004 SERVICE : FL!C VERSIO~ { OO1CO~ [)-RTE : 9]/11/11 ~X REC 8tZ~Z ~ !0~4 FI'hE TYPE : hO AVERAGED CURVES of edited static baseline vasses for all other curves. DEPT~ I~CRE~ENT 0.5000 LDWG TOOL CODE PASS NUMBERS ~E~A~S: THIS FI%E CONTainS THE LATERAL AVERAGED CURVES. LIS FOR'~AT DATA ** DATA FORHAT SPECIFICATION PECORD ** ** SET TYPF - 64gB ** TY~E ~EPg CODE VALUE 1 66 0 2 66 0 ~ 66 5 66 LtS TaOe veriff, catfon Listing $Chltlmber~er AlaSKa Co~putl, n~ Center PAGE: 7 65 9 65 ~ 66 64 !2 6~ !4 65 FT 15 66 G8 !G GG 0 G6 ** SET THPE - Cga~ ** -,--,---------,,,,-,------------------------,--,,,,---,-,--,------------------------,--- NA ~'~ S~RV · .~RVICE API AP! API A ! N M []MB ~IZE ~EP~ P~OC~S ID ORDER ~ ~OG TYPE CLASS ~OD N[IMB SAMP ~bE~ CODE (HEX) D~? rT 00 000 O0 0 4 ~ ! 4 6~ 0000000000 R~OB HL~V G/C] O0 000 00 O 4 I I 4 68 0000000000 DmHO HLAV G/C3 00 000 00 0 4 I ! 4 6~ 0000000000 G~C~ ~SDN GAP? 00 000 00 0 4 I I 4 6~ 0000000000 DEPT. 700~.500 RHO:~.HLAV -999.250 DRH0.HLAV D~PT. 5779.000 R~OB.H[,AV -g99.~50 DRHO.~LAV -qgg.250 GPC~.HSDN -999.250 GRCH.~SDN 62.000 65.875 FIL~ NA~ : EOIT .O04 $~RV.[CE VERSION : 001C0~ FIL? TYPE : LAST FI[,E LIS Taue Veri~icatlon Listing S. cnlUmMerger A.las~a Comput~.~g Center FII.,~ NAi~ ~ EDiT ,005 V~RSION : 00~.C01 DA. TM : 93/1!/11 ~X R~C SIZe: : 1024 F~b~ TY~ ~ bO LAST FI Lg : F!5~ NUMBER 5 Ct)ryes and loq header data for each DaSS l~ separate PASS NUMBER DEPTH INCREMENT{ 0,5000 VENDOR TOOL.CODE START DEPTH ~CN 7008.5 HbDT 700~,5 $ LOG HEADER DATA ~ATE LOGGEQ: SOFTWARE VERSION: TI~E LOGGER TD D~!LLER TO LOGG~(FT): TOP bOG INTERVAL BOTTOW LOG INTERVAL [MT): LOGG{~]G SPEED (FPHR): D~PTN COnTrOL IJSF~ (YES/NO): STOp O~PTU 5770.0 5779.0 WLDT MLOT HLDT HLDT $ TOOL STPING (TOP TO BOTTOM) V~NDCE TOOL CODE TOOL TYPE HI, Dr TEl, MEETlY CARTRIDGE MLDT gLDT HLDT C~T CET CASING COLLAR LOG gG~EHOLE AMD C~SI~G DATA OP~]g HOLE BIT SIZE (IN): DRILLERS CASING DEPT~ LOGGERS CAS!NG DEPTH (FT]: files; raw background PaSS in !asr f~ 26'SEP-92 CP 32,6 1300 26-SEP-92 7~19.0 006,0 ~794,0 7001.0 900.0 TOOL T C-B 0 HLDC-AA WL~V-A~ !9 ~L~S-BA 20 CEEC-~ 832 CESS-A 763 CaL-YA 0~8 SGC-SA TCC-~ 839 2783.0 LIS TaPe V'eri. f:ication Listino SChlumbergerAiaska ComPutin~ Center BOREHOLE CONDITIONS FLUID TYPg: FLUID DENSITY (LB/G): SURFACE T~MPE~ATURE (DEGF): BOTTO~ HOLE TEH~ERAT!.]RE (DEGF): FLUID S~LIMITY FLUID bEVEL (FT)~ FLUID RATE AT ~ELLHEAD W~T~R CUTS (PCT): GAS/OIL RATIO: C~OKE NEUTRON TOOL TOOL TYPE CEPITHER~b OR THERMAL): MATgIX: MATRIX DENSITY: HOLE CORRECTION (IN): BbUELINE COUNT RATE NORMALIZATION IN OIL Z~ME BASE NORMALIZING WINDOW (FT)~ BLUEbINE COUNT RAT~ SCAL~S SET BY FI, ELD ENGINEER F~R COUNT Ar~ ~ow SCALE WA~ COUNT RATE HIGH 8CAL~ NE,~R COUNT RATE LOW SCALE (CPS): N~AR COUNT RAT~ HIGH $CA~E TOOL STANDOFF (IN): !0,20 NEITHER SANDSTONE 2..65 SPACER: * THERE DO~S NOT APPEAR TO BE A ~ICROANN!,!LUS CH R8 CLASS "G", 70 DEG MIX, 2~0 SX, ~5,6 PPG, ~,22 YIELD, $ LIS FO~AT DATA ** D~TA FORMAT SPEC!FIC~TI(DN RCCORD ** ** SET TYD~ - 64E~ ** T..YDE ~PR CODE~ V'AL[i~; I 66 0 2 66 0 3 7] 96 LIS Taue Yeri.ficatin~ Listin 8chlt!mberger AlasKa ComPutln~ Center II-.NOV-1993 22.:0] PAGE: 12 4 66 5 66 @ 68 0 5 9 11 66 1] 66 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** D~PT FT O0 000 O0 0 5 hSR~ Hhl G/C~ O0 000 O0 0 5 SSRw ~b~ G/C3 O0 000 O0 0 5 PEFL 4Lt O0 000 O0 0 5 P~FS ~L! O0 000 O0 0 5 PEF ~Li O0 000 O0 0 5 LSWl ~5! CPS O0 000 O0 0 5 ~SW~ H5! CPS O0 000 O0 0 5 LSW3 ~51 C~8 O0 000 OO 0 5 LSW4 ~bl CPS O0 000 O0 0 5 LSW5 ~L1 CPS O0 000 O0 0 5 $$~ ~bl C~$ O0 000 O0 0 5 SSw~ ~Lt CPS O0 000 O0 0 5 SSW3 ~bI CPS O0 000 O0 0 5 SSW~ ~bl CPS O0 000 O0 0 5 SSW5 ~bl CPS O0 000 O0 0 5 ~09 ~b~ G/C] O0 0oo O0 0 5 D~HO .bl G/C3 O0 000 O0 0 5 ~ ~b! DE~ O0 000 O0 0 5 C~ aL1 ~t~R O0 000 O0 0 5 T~N$ NL1 L~ O0 000 O0 0 5 C~L! gbl IN O0 000 O0 0 5 G~ ~L1 GAPI O0 00o O0 0 5 C~L ~hl V O0 00o O0 0 5 SIZE REPR PROCESS CODE 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6B 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 68 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 6~ o000000o00 4 6~ 0000000000 4 6~ 0000000000 4 68 0000000000 4 6g 0000000000 4 6~ 0000000000 4 6~ 0000090000 4 68 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 68 0000000000 4 6~ 0000000000 ** DAT~ ** LIS ?a~e verification ~is:in~ SchlUmbergerAlasKa Computt. ng Center DEPT 7008 500 L$.~,~ 3..~h 1 tO~.g 0oo ,Hbl R~O~, ~t l,~g4 DR~O 'HLI T~NS.~I ]050,000 C.~LI~L1 -NOV- 993 22 03 , t : 2] 48O 672 74~ 500 4876 000 -0,587 8,500 SSRH.HLI LSW!.HL! 5SWb. HLI SSW,4,,~L1 GR,H51. 3-3~4 PEFb 729.500 5SW!,~bl 1921.000 SSWb.~Lt 17~.875 CS.HL1 62.000 C'Cb'~L1 23,672 523,500 5~0.500 217-500 !182'000 -0,014 $~VlCE : V~R$ION : 00it01 D~T~ : 9]/II/!I ~X REC SYZ~ : !024 FILE TYPE : bO bAST FI!,~ **** FILE HEADER **** FILE NA~E : Ei)IT ,006 SERVICE VERSION : o01C0~ DATE : 93/1!/!1 ~X REC S!Z~ : lO24 FILE TYPE LAST FIL~ : Curves and PAS~ NUVg~R: D~DTH INCRemENT: CH ,.. 6185.0 NLDT 7025.0 6185.0 bOG H~AD~R DAT~ DATE LOGGED~ S~FT~A~E V~RS!ON~ TD DRILLER files; raw background pass in last fi, ~6-SEP-92 C? 32,6 1]00 26-8EP-92 7~19 0 7006~0 5794.0 LIS TaPe Yerification !.,isting Schlumberger Alaska ComPuting Center 22:0] PAGE: 14 BOTTOM [,OG IMTFRVA!~ (FT)~ DEPTN CO~TPOI, USeD (YES/MO): ?00~ .0 900 0 TOOL STR!~G (TOP TO BOTTOm) V~SDOR TOOL COD~ TOOL TYP~ TOOL NUMBER '"'-'-"-'"'-' HLDT T~:,~- CARTRIDGE TCC-B 420 gbOT H'Li)T HLDC-AA 20 HLDT HbDT HBDV-AA HbO? HbDT HbDS-BA HbDT CET CE~C-A HLDT C~T CESS-A 763 MLDT C~SING CObLAR LOG C~L-YA H~DT Ga~M~ RAY SGC-$~ 27! HbDT TCC-B 839 $ gOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT)~ LOGGERS CASING DEPTH (FT): BOREHO!,E CONDITIONS FLUID TYPE: FLUID DENSITY SURFACE T~MPERATUR~ ~DEGF): BOTTO~ HOI.,~] TEMPERAT RE FLUID SALINITY FLUID LEVEL FLUID RATE AT W~TER CUT8 G~S/OIL RAT~O: CHOK~ 27~3.0 NEUTRON TOOL TOOL TYDE (£P!TH~:RM~L O~ THERMAL): ~ATR!× DENSITY: HOL~ CODR~CTIO~ BRIN~ 10,20 157.0 NEITHER SANDSTONE 2,65 BLUEL~NE COUNT RATE NORgALIZATIDN IN OIL ZONE TOP NORgALIZ!NG W!NDO~ (FT): BASE NORMALIZING WINDOW (FT)~ DLUELiNE COUNT RATE SC~LRS SET BY FIELD ENGINEER WqR COUNT RATf LOW SCALE (CPS): mAR COUNT RATE HIGH SCALE (CPS): NEaR COUNT RATE LOW SCALE (CPS): NEaR COUNT RATE HIgH SC,~LE (CPS): # REMARKS: TOOL ST~DOFP (IN): ********************************************************** LIS Tape Verification Li~st:l. ng Schlumberger Alas<a Computing Center , , , * THERE DOES MGT ~PPMAR TO BE A MICROAN~UBUM CH R8 , CLASS "G", 70 DMG MIX, 210 SX~ 15,6 PPG, !,22 YIELD, L~S FOR~T DAT.A PAGE, ** DATA FORMAT SPECIFI ....... ,.t!ON RLCOR[ ** **. SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 96 4 66 5 66 ? 65 8 6~ 0,5 9 65 FT 1.1 66 12 68 13 66 0 !4 65 ~T 15 66 68 16 66 1 0 66 ** SET ?YPE = ''''"''~'~ ..... ''''' ..... ''°'''' ...... 7'''~i'~;'~'''''''' ..... '''''''''''''''''''''''' Na~ F {INIT SEPVTCE ami .~P! aP i L, ~UMR NHMR SIZE REPR PRO.ESS ID ORDER # h..~ TYPE CLASS MOD NUMB Sg~P ELEM CODE {HEX) ...................... ..... . ..... . ........ ...... .... ....... .... ........................ DEPT FT O0 000 O0 0 6.. 1 ~ 4 68 0000 . 00000 0 LSRH HL2 G/C3 O0 000 O0 0 6 1 1 4 68 0000000000 SSRH ~L2 G/C3 O0 000 O0 0 6 i ! 4 6R 0000000000 PEFL HL2 O0 000 O0 0 6 I ! 4 6~ 0000000000 PEF~ ~L~ O0 000 O0 0 6 1 ! 4 68 0000000000 P~F ~L2 O0 000 O0 0 6 ! I 4 68 0000000000 b$~l ~L2 CPS O0 000 O0 0 6 1 1 4 68 0000000000 L~W2 ~b2 CPS O0 000 O0 0 6 I 1 4 68 0000000000 LSW3 ~L2 CPS o0 000 O0 0 6 1 I 4 6~ 0000000000 bSW4 ~L~ CPS O0 000 O0 0 6 1 1 4 68 0000000000 LAWS ~L2 CPS O0 000 o0 0 6 ! 1 4 6~ 0000000000 SS~! HL2 CPS O0 000 O0 0 6 I 1 4 6~ 0000000000 $SW2 ~b2 CPS OO 000 O0 0 6 ! ! 4 6~ 0000000000 bis Tame Verification Llstino Schlumberger A...asKal Compu.tind Center PAGE: 16 ID OROE~ # bOG TYP $$W~ ~h~ CPS oo Oo SSW~ HL2 CPS o0 O0 SSW$ HL~ CPS O0 O0 RM'OB Mb2 G/C3 oo O0 D~HO Hb2 G/C3 oo 000 R~ H~2 DEG O0 000 C8 Mb2 F/HR O0 TM~S ~2 LB O0 000 C!LI HL2 IN O0 000 GR qb2 G~PI O0 O00 CCh Mb2 V 00 000 [INIToE" '~VTCF~ ......IDI !PI' I iPI ?ILE NUMB NUN E Cb= O0 o 6 i oo 0 6 I 1 OO 0 6 t t O0 0 6 1 O0 0 6 I 1 OO 0 6 1 i. oo 0 6 1 I oo 0 6 1 1 OO o 6 I I O0 0 6 1 1 O0 0 6 I 1 SiZE REPR PROCESS CODE (HEX) 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 68 0000000000 4 6~ 0000000000 ** DAtA ** 7025,000 22.125 603,000 1675,O00 2.190 2870,000 TENS LSi~4,~L2 SSW3'HL2 DRHO,.HL2 C:RLI,HL2 6185.OO0. ~..',eRH,. 'HL2 HL2 29'969 PEF.HL2 HL2 469.000 bSW4,~b2 HL2 1499,000 SSW3oHL2 ~b~ 2.241 DRHO,HL2 HL2 2995.000 CALI.HL2 ** E~D OF DATA .2~.71.3 SORH,Hb2 4 ~,250 t,.SWS,~h2 46 ,000 $SW4,Hb2 '0,524 RB,HL2 8,500 GR'Hb2 2.797 SS~q. ML2 22.672 LSW1.Hb2 361i~50 LSWS,Hb2 4148.000 SSW4.NL2 '0.557 RS Hb~ 3.457 PEFL.ML2 134'625 bSW~,H, b2 404,000 1953,000 88W5,~L2 99~063 t, SW~*H.b2 338,500 SSWl 1830.000 SSWS:Hb2 185.875 C$.~b2 89,375 CCL.Hb2 529~000 209'375 000 22.672 199.500 463.250 190.625 915 000 **** FILE TRAILER **** F!L~ NA~E : EDIT ,006 SERVICE : FLIC VERSION ~ 00lC01 DATE : 9]/11/11 ~X REC SIZY : 1024 FIbM TYPE ~ LO bAST FIL~ LIS TaPe verification Listin~ Schlumberger AlasKa Co~putin~ Center !I-NOV-1993 22:03 PAGE: 17 F!LC NAME : EDIT ,007 S~RV!C~ ! FLIC VERSION ! 001C0! ~aX REC SIZE : 10~4 F~LE TYPE : LO LAST FILE ~ Curves and log header data for each ~ass in separate DEPT~ I~CREMMNT: 0.5000 F~LE ~Stl~ARY VENDOR TOOL CODE START DEPTH GRCH 7026.0 ~[,DT 7026'0 LOG ~EADER DATA DAT~ bOGGED: SOFTWARE VERSION: TI~E LOGGER ~N TD D~IL[,ER TD LUGGE~fFT): TOP bOG INTERVAL BOTTO~ LOG I~TERVAb (ET): ~,0GG!Ng SPEED (FPHR): DEPTH CO~T~OL {ISMD (YES/MO): STOP DEPT~ 6!a5,o 61~.5,0 files; raw backoroumd Pass l.n .last fi 26'$EP"92 CP 32.6 1300 26'SEP'92 7119,0 7006.0 5794.0 700~,0 900.0 TOOL ST~I~G (TOP TO BOTTOM) VENDO~ TOOL CODE TOOL TYPE TOO[, NUMBER ...... .......... .... ~[,r)T EL~T~Y CARTRIDGE TCC-~ WL!)T HLDT Hk, DC-AA 20 HLDT ~LDT NbDV-A~ 19 ~LDT hLDT ~LDS-BA ~0 MLD~ CET CEEC-A MLDT CET CESS-A 76~ ~[,9T C~S!NG C[)LLA~ bOG CAL-YA 028 ~LDT ~AM~A RAY SGC-SA 271 ~LDT TCC-B $ CASING DATA DR!LLEPS CASING CASING DEPTH 278],0 Schlumber~er ~l, as~a Co~utinO' Center ll-NOV,,i. 993 22:03 BOREgOLE CONDITIONS FbU!D TYPE: FLUID DENSITY S.JR~CE TE~PE~ATU~ (DEGF): FLUID LEVEL FLUID ~ATE AT WELLHEAD (BP~): WATER C!,!T~ (PCT): G~S/Oib RATIO: CNOKE NEUTRON TOOL TOOL TYPE (EP!THE~AL OR ~TRIXI MATRIX DENSITY: HOLE CORRECTION fiN): ~I, UEL!NE COUNT RATE NORmALIZaTION IN OiL ZONE TOP MORMlblZ!MG WIND~ (FT)I BLUELINE COUNT RATE SCALES SET SY FIELD ENGINEER FAR COUNT ~ATE bOW SCALE ~P COUNT PATE HIGH SCALE (CPS)I !~E;AR COUNT RATE L~W SCALE NEAR COUNT RATE HIGH SCALE (CP$)~ TOOL .ST~NO£!FF fiN): 10,~0 157,0 NEITHER $~.MDS:TONE 2,65 ********************************************************** , , * THERE DOES NOT APPEAR TO OM ~ ~ICROANNUbUS CH R8 * CLASS "G" 70 I)FG MIX, 210 SX, 15.6 ..... ' ......... ~, 1,22 YIELD, $ LIS ~OR~AT D~TA PAGE: 18 ** DATA FOP?AT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE RD~E.E COD 1 66 n 2 66 0 ~ 7] 96 LIS Tame Veri~lcation blstfnq SChldmberoer AlasKa ComDutin0 Center 22:03 PAGE: Ig TYPE REPR 9 65 11 66 !~ 66 14 65 15 66 16 66 o 66 0,5 0 1 1 LSRH HL3 G/C3 D~F$ HL3 PEr Hb3 bSW~ ~b3 CPS bSW~ HL3 CPS LSW3 ~L] CPS LSW4 HL3 CPS LSW5 HL3 CPS SSW~ HI, 3 CPS $$w~ ML~ CPS $$W~ HL3 CPS $Sw5 Nb3 CPS RHO8 ~b3 G/C3 ~B NL~ DEG T~$ HL] GR "53 G~P! CCh HL3 V **,..KET ?YPE - tHaN ** ID ORDER ~ LOG T YPE CLA oo 000 O0 o O0 000 O0 0 OO o00 O0 0 O0 o0o O0 0 oo 000 O0 O0 000 O0 o O0 000 oo 0 oo 0oo O0 0 O0 000 oo O0 0o0 O0 0 oO 000 O0 0 oo 0oo oo 0 OO 000 oo 0 O0 000 O0 o O0 00o O0 0 O0 000 OO O 00 o00 o0 0 o0 0o0 0o o O0 OoO 00 0 O0 000 00 0 O0 000 00 0 O0 000 oo o 00 0oo oo 0 OO 0o0 OO 0 7 I 1 4 68 0000000000 7 ! 1 4 68 0000000000 7 ! ! 4 68 0000000000 7 1 I 4 6R 0000000000 7 I I 4 6~ 0000000000 7 1 ! 4 68 0000000000 7 1 I 4 68 0000000000 7 1 1 4 6~ 0000000000 7 I t 4 68 0000000000 7 1 1 4 68 0000000000 7 ! 1 4 68 0000000000 7 1 I 4 68 0000000000 7 1 I 4 6g 0000000000 7 I 1 4 68 0000000000 7 1 1 4 6~ 0000000000 7 I I 4 6~ 0000000000 7 1 I 4 68 0000000000 7 ! 1 4 68 0000000000 7 I I 4 68 0000000000 7 1 1 4 68 0000000000 7 { I 4 6~ 0000000000 7 I 1 4 68 0000000000 7 1 1 4 68 0000000000 7 i t 4 68 0000000000 ** DaTA ** bis Tape V~erif!.cation SC~.lumber~er Aiaska Comptlt.!r~q Center ii-NOV-1993 22:0~ 2O ')~P~ 7026.000 DKFS, '.b3 ~5,844 P~LFi~b3 bSwL.~5~ 442,500 bSW4.~b3 SSW~.HL~ 1~95'000 R~O~'~b) 2,205 DR~O 2 al6 SSRi.t,Hb3 3.686 PEF~.ML3 9'7.!25 bSW2.HL3 ]24.000 SSWl.Hb3 1726.000 $SWL.HL3 194.875 424.750 !88,000 9~5.000 -0,047 END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT ,007 SERVICE ~ FL!C VERSION g O01COl DATE : 9]ttl/11 MAX REC SIZE : 1024 FIL~ TYPE : LO bAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE ~ 9]/I1/1,! T~PM NA~E : 9]507 CO~iNUATION # : P~EVIOU8 TAPE COMMENT : ARCO ALASKA, INC., KUPARI:/K RIVER, ~-12, 50-~03-2018~-00 **** REEL TRAILER SERVICE N~E : EDIT DATE : 9]/11/11 ORIGIN ~ ~L~C ~EI,~ NA~E : 93507 C~NTINt. IATIUN # : P~EVIOUS ~EEL CO~ENT : aRCO * AbASKA COMPUTINg CENTER , ******************************* ******************************* COMPANY NAM~ : ARCD AbASKA, INC, WELL NAME : FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH STAT~ : ALASKA AP! NUMBER : 50-103-2018~-00 REFERENCE NO I 92545 RECEIVED NOV 0 Z 1992 Alaska Oil & Gas Cons. Commission Anchorage bis TaPe Yeri:ficatlon Listing Schlumberger Alaska Computfno Center I0-0CT-1992 I0:30 PAGE: · ~** REEL NEAD~ **** SERVICE NA~E : EOIT DATE : 92/10/10 ORIGIN : FLIC REEl, NAME : 92545 CONTIM~ ,~U~TION # : PREVIOUS REEL : CO~EN'T : ARCO ALASKA, iNC,,KUPARUK RIVER UNIT,2M-l~,50-103-20181-O0 **** TAPE HEADER **** SERVICE NAME : EDIT DAT~ : 92/1.0/10 O~XGI~ : FLIC T~P~ NA~E : 92545 CONTINUATION # PREVIOUS TAPE CO~E~T : ARCO ASASKA, INC,,KUPAROK RIVER UNIT,~M-12,50-103-20181-O0 P~RUK RIVE~ U~IT ~WD/~AD API NUMBER: r~E~ATOR~ L GG!NG COMPANY: JOB DATA JOB NUMBER: LOGGING ENGINEER~ OPERATOR WlTNESS~ SURFACE LOC~TION SECTION: TOWNSNIP: ~ANGE: WNL: ~Sb: FwL: FLEVATION(FT FRO~ MSL O) KELLY BUSHING: DERRICK FLOOR: G~OUNO LEVMb: # WELL CASING RECORD !ST STRING 2ND STRING BIT RUN I BIT RUN 2 92545 92545 PERRY PERRY AUGLEN AUGLEN 'BIT RUN3 27 11N 114 189 146.00 146.00 105.00 OPEN HOLE CASING DRILLERS 8IT SIZE (IN) SIZE (IN) DEPTH (FT) '' ..... ' ...... CT;~; ......27;;T''''0 Schlumberaer AlaSka ¢omputinq Center REM...RKS: FIELD ENGIN~E:R'B REMARKS: **********~LWD RUN BIT TO RES: 65-3', BIT TO GR: 75 7' BIT RUN ONE FROM: 2801' "4766' ' BIT TO RES: 33.9', BIT TO GR~ 94 32' BIT RUN TWO F~OM: .4766':':-' 7119 MATRIX DENSITY = 2'65G(G/~:C) SAND. FLUID DEMMIT:Y = 1.0 RES. SA. MPLE RATE = 20 ROTATIOn!AL BUL~ DENSITY F~OCESSING USED. BARITE ADDED TO MUD SYSTEM. DOWNHObE SOFTWARE: V4.0C $ $ !0-0CT-1992 ~0:30 **** FIbE HEADER **** F!L~ NA~E : EDIT ,001 SERVICE : V~R$ION : 001A07 DAT~ ~ 92/10/10 ~AX REC SIZE : !0~4 FILE TYPE :: LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED ~ERGED MWD Dept~ shifted and cl~Pped curves; all bit ru~s merged. DEPTH INCREMENT 0.5000 FILE SUMMARY KR[I TOOL CODE START DEPTH ~w~ ~ o1._ $ B!S~LINE CURV~ FO~ SHIFTS: GE CURVE SHIFT D~TA (~EASURED DEPTH) HAS,LINE DEPTH 88888.O 602~.0 6q19,5 69~2,5 6871.0 6860.0 6847.5 STOP DEPTH ------ .... EOUIVALE~T UNSHIFTED DEPTH ..... ----- NWD 6923,0 691~.5 6~vO.O 6858.0 6852.0 6~46.0 SchlUmberger Alaska 'Computing Center IO'OCT'I9g2 I01:30 PAGE: 6840,5 835,5 ~831,0 6~19 § 6796,0 6794~0 677~'5 674 ,0 6725 67 0,5 6662,5 6642'5 6630,0 6568.5 6554'$ 6548,0 6506,5 6481,5 6475,5 6474,5 6470'5 6468'0 6464,5 6461,5 456,0 .439,5 6434,0 6420'0 6417,5 6407,0 64015 6376!'5 6361 0 6340 5 632!'5 6262.0 62420 6197:5 t00,0 $ MERGED DATA SOURCE KRU TOOL CODE CDR $ # REMARKS: 6839,0 6834.0 6828'5 6818 0 6798:0 6794,5 6792,0 6773,0 6740,0 6723,5 6714,5 6708 0 6677:5 6660,5 6640.0 6626'5 6566-.0 6552 6503-5 6479,0 6474.5 6473,0 6468 6462 6452.5 6437~5 6431.0 6418,0 6415,5 6404.5 6398.5 6374.5 6356.5 6335.5 6317,5 6258.0 6~38.0 6195.0 97.5 BIT RUN NO. MERGE TOP O! 2783.0 02 4766.0 7119.0 THE DEPTH SHIFTS ABOVE REFLECT FWD GR TO CASED HOLE GR FRO~ CET/HLDT RAN ON 26-SEP-92. ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT. $ SchlUmberger Alaska Computind Center PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE -~64EB.** TYP~ REPR~CODE V~bUi i 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 9 65 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** HAME SERV {INIT SERVICE API APl APl API FihE NUMB NUMB SIZE REPR P~OCESS · ID: . O~DER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) D~PT FT 548246 O0 000 O0 0 I 1 ! 4 68 0000000000 R~ ~WD OHMS 548246 O0 000 O0 0 { I 1 4 68 0000000000 RP ~WD OMMM 548246 O0 000 O0 0 1 I 1 4 68 0000000000 ROP MW9 F/HR 548246 O0 000 O0 0 1 1 1 4 6~ 0000000000 G~. MWD GAPI 548246 O0 000 O0 0 I ! I 4 68 0000000000 mm~mmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmm~mmmmmmmmmmmm~mmmmmmmmmmmm~mmm~mm~mmmmm ** DATA DEPT, 7116.000 RA.MWD -999.250 RP.MWD -999,250 ROP.MWD ~,MWD -999,250 DEPT. 7000,000 RA.MWD 2,907 RP,MWD 2,901 ROP.MWD GR.MWD 80.683 DEP?, 6500,000 RA,MWD 2.!19 RP,MWD 2,066 ROP,~WD G~,~WD 234,0~6 185.442 214.178 320.391 bis SchiumberOer Aias~ ¢omputl, ng Center G~,~WD. 109,750 D~PT. 5000,000 RA,)4WD G~,MWD 74,7~7 ~PT, 4500'000 G~,MWD 113':843 . . DEPT. 3000,0.00 RA.~WD ~.~ 71.069 D~PT, 2743,000 ~A.~WD ** END OF DATA **** FILE FIL~ NA~E ~ EDIT ,001 S~RVICE : FLIC VERSION : 001A07 D~T~ ~ 92/10/10 ~aX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT ,00~ SERVICE : FLIC VER$ION : 001A07 DATE : q2/10/10 ~AX REC SIZE : 1024 FILF TYPE : LO LAST FILE : FIL~ HEADER FIL~ NUMBER RAW MWD lO-OCT'! 992 Io{30 3-.462 RPi. MWD 4,848 2'771 2,742 RP,MWD 2,907 RP.MWD 3.303 RP.NWD 3,2~4 0,~33 RP,MWD 3',336 ROP,pWD ~.66! 3'o~1 ~o~.~wu 7.79~ ROP-MWD i25,006 215,261 227,837 414,822 292.061 ~27,574 708,'379 -999,250 5 $chlumberqer Alaska Computing Center I0-OCT-1992 XO:30 Curves and log header data for each bit run In separate f~les, BIT RUN NUMBER: DEPTH INCREMENT: 0,5000 # FILE vEnDOR TOOL CODE START DEPTH 2801.O LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN~OLE SOFTWARE DAT~ TYPE (~E~ORY OR TD D~ILLER (FT)~ TD LOGGER(FT): TOP LO~ I~TE~¥AL (FT): BOTTO~ LOG INTERYAL RIT ~OTATIO~AL SPE~D ~OLE IN~LI~ATION (D~) ~AXINU~ ANGLE~ . CDR RESISTIVITY $ BOREHOLE AND C~SING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS ~UD TYPE: ~UD DENSITY ~UD VISCOSITY MUD CHLORIDES FLUID LOSS g~XI~U~ RECORDED TEMPERATURE (DEGF): RESISTIVITY (ON,M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): ~UD AT PAX CIRCULATING T~MPERRTURE: MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: ~ATRIX DENSITY: HOLE CORRECTION TOOL STANDOFF (IN): STOp DEPTH 4766.0 06-$EP-92 FAST 2,3D V4,0 4766.0 47660 4766.0 TOob NUMBER RC,$~22 8.500 2783.0 LSND 10,30 145.0 3.290 3,350 6B.0 6~.0 SANDSTONE 2.65 ~,500 SChlUmberger AlaSka Com, putino Center 10-0CT-1992 10:30 EW~ FREOUENCY (HZ): ********** BIT RUN ONE FR~ '280I- 4766' ' MATRIX D~NSITY.- 2.65 (G_CC) SAND, FLUID DENSITY RES.~ SAMP'LE RATE ROTATIONAL: BULK D~NSITY PROCESSING USED,:~ BARITE ADDED TO ~UD SYSTE~, DOWNHO5~ $OFTWARE~ V4,0C $ 5!8 FORMAT DATA PAGE: DATA FORMAT :SPECIFICATION RECORD ** mmmmmmmmmmmmmm~m CODE VALUE 0 0 ~0 1 0 5 **'SET TYPE- 64EB TYPE REPR ! 66 2 66 4 66 5 66 6 7~ 7 65 9 65 11 66 12 68 I3 66 0 14 65 FT 15 66 68 16 66 i 0 66 ! ~m~m~m~m~m~m~mm~mm~mm ** SET TYPE D~PT FT 54824 ATR LWl OH~ 54824 PSR Lw1 OH~ 54824 ROP~ LWl F/MR 54824 GW LW! GAPI 54824 CHAN ** LOG TYPE CLASS UOD NUMB SA{P ELE~ CODE (HEX) O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 I 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 O00000000O O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 ! 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm LIS TaPe ueri/ication ListinO SchlUmber0er Alaska Computlno Center t0-0CT-1992 I0:30 ** DATA DEPTi. 4765,500 ATR,LWl -999.250 GR,LW{ -999'250 DEPT 4500.000 ATR.LW! 2,327 PSR,LWl ~:LWl 10i.603 4000.000 ATR.LW1 2.933 PSR.LWl G~. DEPT 35~0o000 ATR*LW1 3.290 PSR.:LWI~ D~PT~ 3000'000 ATR'LW! 3,0~7 PSR.LWi D~PT ~727,000 ATR'LWl -999.~50 P$~.LW1 END OF OAT.A ** '999.250 ROPE.LW! 2'.,213 ROPE.LWl ~'635. ROPE.LWl 3.036 ROPEoL~I 2'*547 ROPE.LWl '999.250 ROpE'L~I PAGEs 239.523 403'989 334,320 323,397 735,249 -999,250 **** FILE TRAILER FILE NA~E : EDIT .002 V~RSION : 001AO7 DATE ~ ~AX AEC SIZE ~ 1024 FILE TYPE : LO LAST FILE : **** FILE ~EADER **** FILF HA~E : EDIT .003 SERVICE : FL!C VERSION ~ O01a07 DATE : 92/10/lo ~gx AEC SIZE : I0~4 FILE TYP~ : LO LAST FILE : F!L~ gEADER FILE NUMBER 3 RAW MWD Curves and log header data ~or each bit run in separate files. BIT RUN NUMBER: ~ DEPTH INC~E~E~T: 0.5000 FILE SU~HARY ~IS Tape Verlftcat~on Listing ,Chlu~berge~AlasKa computing Cen..ter !0-0CT-!992 10:30 VENDOR TOOL CODE START DEPTH sTOp DEPTH CDR 4766 7!!9,0 $ LOG HEADER DATA DATE bOGGED: ~OFTWA~E SURFACE SOFTWARE VERSION: DOWNHObE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD D~ILLER (FT): TD LiOGGER(FT): TOP bO~ INTERVAL (FTI: BOTTO~ LOG~.INTERVAL (FT): BIT ~OTAT:XONAL SPEED (RP~): ~OLE INCLINATION (DEG) gINI~U~ ANGLE~ MAXI~U~ ANGLE~ TOOL STRING (TOP TO BOTTOM) ¥~NDOR TOOL CODE TOOL TYPE CDR ~SISTI¥ITY BOREWOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): ~RILbERS CASING D~PTH~ 80REHOLE CONDITIONS MUD TYPE: DENSITY (LB/G): MUD VISCOSITY PH~ CMLORIDES FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE CDEGF): . RESXSTIVITY (OH~M) AT TEmPERATUrE(DEGF): MUD AT ~EASURED TEMPERATURE ~UD AT ~AX CIRCULATING TEMPERATURE: MUD FILTRATE AT (~T): ~U~ CAKE AT NEUTRON TOOL ~AT~!X DENSITY: HOLE CO~RECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): ~MA~KS: ********** LwD RU, 2 ********** S,T_ TO ~S$: 3].9', SIT TO BTT RUN ~WO F~OM: 4766' ' 7~19 08'$EP'92 FAST 2,3D V4,0 MEMORY t19.011~.o ?66 0 ~mmm~m~m~mmm'~,m~mMm~ RGS022 5083?O bSND 10,30 145.0 ~.~o 3.350 SANDSTONE ~.65 8,500 68.0 68.0 Schlumberger ,llasEa Computt,~O Center 10., 0 C ?= i 99 ~ I 0: 3 0 MATRIX DgMS!TY : 2.65 (G/CC} SAND, FLUID DENSITY RES.~ SAMPLE RATE = 20 SEC'i: ROTATIONAL BULK DENSITY PROCESSING: USED, BARITE ADDED TO MUD 'SYSTE~, DOWNHOLE SOFTWARE~ V4.0C $ FORMAT DATA PAGE: lO D~TA FOR'MAT SPECIFICA. TiON RECORD SET TYPE - 64EB ** TYPE REPR CDD'E VALUE; I 66 0 2 66 0 3 73 20 4 66 5 66 6 73 7 65 8 68 0 5 9 6s il 66 51 I~ 68 14 65 FT 15 66 68 16 66 0 66 1 mmmmmmmmmm~mmmmmmmmmm#mmm~mmm ** SET TYPE - CHIN mm~mmmmm~mmmmmm~mmmmmmmmmmmmmmmmmmmmmm~Nm~mmmmmmmmmmmmmmm~m~mmmmmmmmmmm~mm~mmmm~mmmm NAME SERV [INIT KERVICE APl API APl: AP1 FILE NUMB NUMB SIZE R£PR PROCESS ID ORDER # hOG TYPE CLASS MOD NUNB SAMP ELEM CODE (HEX) D~PT FT 54~246 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHM~ 548246 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OHM~ 54~246 O0 000 O0 0 3 1 i 4 68 0000000000 ROPE LW2 F/HR 54~246 O0 000 O0 0 3 1 1 4 68 0000000000 GR bw2 GAPI 548246 O0 000 O0 0 3 1 1 4 68 0000000000 mm~m~m~m~m~mm~mm~m~mm~mm~m~mm~m~mm~m~m~m~m~mmm~~m~m~mm~mm~m~~m ** DATA ** L~IS Ta~e verif:[cat:[on bistlng 5Ch~LUmberger Alaslca Computtn~ Center %0-0CT=~992 10~30 :.: DEPT : 7119,000 ATR.LW2 -999.250 PSR.LW2 -999.250 G~:LW2 '999,250 D~PT. 6500,.000 ATR'LW2 ~ 116 P$R bW'2 2,272 DEPT" 6000,000 ATR'~ LW2 3 428 PSR. LW2 3.259 G~.LW~ 89.965 DEPT' 5500.000 AT~'LW2 4,897 P':SR, LW2 4'807 ~,5w2 108.175 D~PT 5000.000 ATR'~W2 2,890 PsR.5w2 2.836 DBPT:' 4679.500 ATR.bW2 -999.250 PSR.LW2: -999 250 G~.LW2 130,915 ' **' E~O OF DATA ROPE.LW2 ROpE.LW2 ROP~.LW2 ROPE.Lw2 PAGE~ 1 1 185,442 19],563 287.995 116.729 . 193.550 -999.250 F~LE NA~E : EDiT .003 SERVICE : FLIC V~RSION : O01A07 DATE: : 92/I0/~0 ~X R~C SIZE : !024 F~LE TYPE ! LO LAST FILE FIL~ NA~E SERVICE DATE FILE TYPE LAST FILE HEADEP **** EDIT ,004 FLXC 001~07 92/10/I0 1024 LO FILE HE,DER FILE NUMBER RAW C!~RVES Curves'a~d lo~ PASS MU~BER: DFPTH IMC~E~ENT: 4 header data -.500o for each pass in separate files; raw background pass in last file ichlumberger Alaska Computinq Center !0-OCT-1992 10:30 PAGE: 12 START DEPTH 6978,0 VENDOR TOOL CODE ~LDT $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION,: Ti~E L~GGER ON BOTTOM: TD DRILLER ?D LOGGE~(FT): TOP LOG INTERVAL (FT): 8OTTOM ~OG INTERVAL LOGGING SPEED (FPHR): D~PTH CONTROL USED (YES/NO): TOOL STRING (TOP TO VENDOR TOOL CODE HLDT HLDT CET C~T CCL GW STOP DEPTH 6194 · 0 BOTTOM) TOOL TYPE T.~LFMET~Y CARTRIDGE HLDT CARTRIDGE HIGH VOLTAGE HLDT SONDE CET CARTRIDGE CET SONDE COLLA~ LOCATOR GAM~A RAY DOWN'HOLE TELEMETRY BOREHOLE AND CASING DATA OPEN HOLE BIT $~ZE (IN): DRILLERS CASING DE~TH LOGGERS CASING DEPTH BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE {EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: 26-SEPT-92 CP 32,6 !30o 711go0 7006,0 6194,0 6978,0 900.0 TOOL NUMBER HLDC-AA 19 HLDVmAA HLDS-BA 20 CEEC-A CESS-A 763 CAL-YA 028 SGC-SA 271 GCPC-B 7~7 GCFC-A 701 GCIO-.A 40 TCC-~ 839 7099.0 7099.0 BRINE 10,20 157.0 SANDSTONE 2.65 £S Tape vertftcatton bls[tnq .-hlumberger AlasKa Computing Center i0-0CT-1992 10:30 CORRECTION BLUELTNE COUNT RATE NO.RM~LIZATION IN O!b ZONE TOP MO~M'ALIZlNG WINDOW (FT): BASE NOR'MAbIZ!MG WINDOW BLUELIME COUNT RATE SCALES SET BY FIELD ENGIMEER FAR COUNT RATE LOW SCALE (CPSs): FAn COU~T ~TE ~GH SC~bE (CP~: NEAR COUNT RATE bOW SCAL~ (CPS) NEAR COUNT RATE HIGH SCALE (CP)I TOOL STANDOFF . RAM THREE PASSES ~ 900 FPH$*****~ ************************* COMP'UTIMG CENTER EEMAR. KS: THE HLDT DATA IS PRESENTED IN THIS FILE TO ACCOMPANY THE MWD RE$ISITIVITY DATA {AS NO CDN WAS RUN WITH THE CDR). PASSES 2 & 3 OF THE'HLDT WERE DEPTH CORRECTED TO ~ATCH P.~S$ ~.o THEM THE PA~SES WERE AVERAGED TO YIELD THE DATA PRESENTED HERE. $ LIS FORMAT DATA 1¸3 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** --..------,,,,......-.....-.-- ?YP~ CODE VALI)E mmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmm I 66 0 2 66 0 5 66 6 73 7 65 11 66 36 12 68 13 66 14 65 FT 15 66 68 16 66 1 0 66 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm I0-0CT-~.992 ~0:30 1¸4 ** SET,TYPE - CHAN ** m mmmmm~mM~mmmmwmmmmmmmmmmmmmm~tmemmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm{~;emmmmmm~mmmm ~ s~Rv O~T SE~VXC£ ~pI A~I ~P~ ~P~ F'~.,~ ~U~ ~u~ sxz~ n. n PnOCE~S ID ~RDER # LOG TYPE CLASS MOD NUmB SAMP E~EM CODE (HEX) D~P? ;~ 548246 O0 000 O0 0 4 t 4 68 0000000 ~,OB HLD ~/C3 548246 O0 000 O0 0 4 1 ~ 4 68 0000000000 D~HO .LD G/C3 548246 O0 000 O0 0 4 1 I 4 68 0000000000 CC5 HLD V 548246 O0 000 O0 0 4 ! 1 4 68 0000000000 ss~ ~D ~/c3 s4~a6 oo ooo oo o 4 ~ ~ 4 6. oooooooooo bS~ HLD G/C3 548~46 O0 000 O0 0 4 ! I 4 68 0000000000 Gn .~o S~I ~.24~ oO oo0 ~o ~ ~ ~ ~ 4 ~. ~o00000o00 ** DATA ** BBRH,HLD 449 LSRH,HLD 2,521 GR,.HLD 62.000 -0.014 0,007 -0,~059 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E ~ EDIT .004 SERVICE : FLIC VERSION : 00tA07 DATM : 92/10/10 M~X REC SIZE : 10~4 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT D~TK : 92/10/10 O~I~IN : FbIC T~PE NAME : 92545 CO~TIN!!~TION # : 1 ~REVIOU$ TAPE : COMMENT : ARCO ALASKA. INC,,KUPARUK RIVER UNIT,2~-12,50-103-20181-O0 C # NOI. i~flNI&NOD O~:Ot ~66~-iD0-05 bu~%s~q uo~3eo~aA,eae& g~
