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Home My WebLink About184-222STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Anne Pryaunka at 8.16 am, Dec 02, 2022 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull TubingO Operations shutdown ❑ Performed: Install Whipstock ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Mod Artificial Lift ❑ Perforate New Pool ❑ Repair Well 21 Coiled Tubing Ops❑ Other: Replace Selective 0 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exioloratory ❑ Stratigmphic ❑ Service ❑ 184-222 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-029-21238.00.00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025642 KRU 2W-11 9. Logs (List logs and submit electronic data per 20AA025.071): 10. Field/Pool(s): NIA Kuparuk River Field/ Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6950' feet Plugs measured None feet true vertical 6174' feet Junk measured 6775' x3 feet Effective Depth measured 6780' feet Packer measured 5369', 6218', 6599' feet true vertical 6089' feet true vertical 5134', 5772', 5997' feet Casing Length Size MD TVD Burst Collapse Conductor 84' 16" 115' 115' Surface 2445' 10-3/4" 2476' 2475' Intermediate Production 6903' 7" 6926' 6162' Liner Perforation depth Measured depth 6360-6494', 6508-6514', 6696-6704', 6710-6760'. 6766-6782', 6786-6792', 6803-6810' feet True Vertical depth 58635942', 59495953', 6046-6051', 6054-6079', 6082-6090', 6092-6095', 6100.6104' feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6678' MD 6037' TVD Packers and SSSV (type, measured and true vertical depth) Packer. HLB MFT Feedthrough Packer 5369' MD 5134' TVD Packer. HLB MFT Feedthrough Packer 6218' MD 5772' TVD Packer: HLB MFT Feedthrough Packer 6599' MD 5997' TVD SSSV:None N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 910 165 Subsequent to operation: 367 1 1024 1 1534 1 1180 1 204 13b. Pools active after work: Kuparuk River Oil Pool 14. Attachments (reQuired per 20 AAC 25.070, 25.071, & 25.283) 15. Well Gass after work: Daily Report of Well Operations 0 Exploratory ❑ Development p Service❑ Stratigrephic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: by: 322-572 I'D�muftned Authorized Name and -`� ( Dec-01-2022 Digital Signature with Date: Contact Name: Jonathan Cobedy Contact Email: ionathan.cobedvCcDconocophillips.com Authorized Title: Staff RWO/ CTD Engineer Contact Phone: (907) 265-1013 Sr Pet Eng: ISr Pet Geo: I ISrResEng: RBDMS JSB 120822 Form 10-4D4 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitUng@alaska.gov Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CmamPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTime End Time our da) Phase Ac Ity Code Time P-T-X Operation Start Depth(flKB) End Depih(flKB) 10/21/2022 10/21/2022 8.00 MIRU, MOVE MOB P Pull sub off of well. Clean up around 0.0 0.0 00:00 08:00 cellar on 2W-02. Spread herculite, load 2W-11 w/ wellhead equipment. Hang tree in cellar. Spot sub over 2W-11. Spot pits to rig. Spot support equipment. Hook steam and air to the pits, Berm in Rig. Complete Acceptance checklist. Spot Vac Trucks and start taking on Fluid. 10/21/2022 10/21/2022 2.00 MIRU, WELCTL RURD P R/U circ manifold in cellar. Take on 9.6 0.0 0.0 08:00 10:00 PPG NaCl/Naar in pits. Air test tiger tank lines. Hook up tiger tank level sensor. Accept Rig @ 0800 hrs. 10/21/2022 10/21/2022 1.75 MIRU, WELCTL KLW L P Initial pressures T=400 PSI, IA=100 PSI, 0.0 0.0 10:00 11:45 OA=5 PSI. Bleed gas cap off IA. Bullhead 270 bbls down IA at 5 BPM, 340 PSI. 10/21/2022 10/21/2022 0.50 MIRU, WELCTL KLWL P Bleed gas cap off TBG. Bullhead 90 0.0 0.0 11:45 12:15 1 1 bbls down TBG at 3.5 BPM, 420 PSI. 10/21/2022 10/21/2022 0.75 MIRU, WELCTL OWFF P Observe well for flow. Well currently on 0.0 0.0 12:15 13:00 a vac. 10/21/2022 10/21/2022 1.00 MIRU, WELCTL MPSP P Set BPV in hanger. line up to test under 0.0 0.0 13:00 14:00 BPV for rolling test on BPV. Test under plug @ 2 BPM to 500 PSI. 10/21/2022 10/21/2022 0.50 MIRU, WHDBOP SVRG P Servic rig. 0.0 0.0 14:00 14:30 10/21/2022 10/21/2022 1.00 MIRU, WHDBOP RURD P Blow down cellar lines. RU lifting 0.0 0.0 14:30 15:30 equipment to tree. 10/21/2022 10/21/2022 2.50 MIRU, WHDBOP NUND P NO tree and adapter, inspect and install 0.0 0.0 15:30 18:00 blanking plug. 10/21/2022 10/21/2022 2.25 MIRU, WHDBOP NUND P NU DSA & BOP, install flow nipple. 0.0 0.0 18:00 20:15 10/21/2022 10/21/2022 1.25 MIRU, WHDBOP RURD P Fill stack w/ fresh water. R/U testing 0.0 0.0 20:15 21:30 equipment. Opened up IA pushing gas back. Pumped 40 Bbls down IA @ 3 BPM, 25 PSI. No pressure increase. Well on a vac again. 10/21/2022 10/22/2022 2.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 0.0 0.0 21:30 00:00 250/3500 PSI for 5 Min each, Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOR Test 2" rig floor Demco kill valves. 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. Witness waived by AOGCC rep Adam Ead @ 1:05 PM (Email) Filling hole w/ 10 BPH down IA. Page 1/12 ReportPrinted: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CmamPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTime End Time our da) Phase AclWity Code Time P-T-X Operation Start Depth(ftKB) End Depih(ftKB) 10/22/2022 10/22/2022 8.00 MIRU, WHDBOP BOPE P Continue Initial BOPE test. Tested 0.0 0.0 00:00 08:00 annular, UVBR's, LVBR's w/ 3 1/2" lest joints. Test 3 %" EUE FOSV. Test manual and HCR choke valves. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =18 sec, full recovery attained =115 sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular= 28 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =2050 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl @ 1:05 PM (Email) Issues with blanking plug, had to bump all lest up several times to achieve straight line. Filling hole w/ 10 BPH down IA. 10/22/2022 10/22/2022 0.50 MIRU, WHDBOP BOPE T HCR choke failed initial test. Greased 0.0 0.0 08:00 08:30 and functioned passed retest Annular failed intital test. Functioned annular and passed retest. 10/22/2022 10/22/2022 0.75 MIRU, WHDBOP RURD P RD testing equipment. 0.0 0.0 08:30 09:15 10/22/2022 10/22/2022 0.50 MIRU, WHDBOP SVRG P Service rig 0.0 0.0 09:15 09:45 10/22/2022 10/22/2022 1.00 MIRU, WHDBOP MPSP P Pull Blanking Plug. Attempt to engage 0.0 0.0 09:45 10:45 BPV and depress pop -it. Unable to latch into BPV. 10/22/2022 10/22/2022 2.00 MIRU, WHDBOP MPSP T Attempted to pull BPV w/ multiple pulling 0.0 10:45 12:45 tools. P/U joint of DP and wash on top of BPV @ 12 BPM, 50 PSI to attempt to wash and debris of top of plug. UD DP and attempt to engage BPV, well appeared to be pushing back. 10/22/2022 10/22/2022 0.75 MIRU, WHDBOP MPSP P Bullhead tubing @ 3 BPM, ICP=550, 0.0 0.0 12:45 13:30 FCP, 290. Verified tubing on vac. 10/22/2022 10/22/2022 1.25 MIRU, WHDBOP MPSP T Ran setting tool, verified setting tool 0.0 0.0 13:30 14:45 shifted exposing neck of BPV. Attempt T/ engage BPV w/ multiple pulling tools, got snapped into BPV P/U and sheared out of pulling tool. BPV not recovered. Consult w/ town. Decision made to pull hanger with BPV in place after verifying tubing on a vac and IA has 30 Min no - flow. 10/22/2022 10/22/2022 0.25 MIRU, WHDBOP OW FF T Fill stack w/ 9.6 PPG NaCl. Well taking 0.0 14:45 15:00 fluid. Monitor IA no flow. 10/22/2022 10/22/2022 1.00 COMPZN, RPCOMP PULL P PU landing joint and screw into hanger, 0.0 0.0 15:00 16:00 WU TD. BOLDS. Bullhead 20 Bbls down tubing @ 2 BPM, 35 PSI. Monitor IA- on a vac. 10/22/2022 10/22/2022 1.00 COMPZN, RPCOMP PULL P Pull hanger off seat @ 50K. Pipe free 6,159.0 6,061.0 16:00 17:00 @ 110K. PUW=80K. Fill hole w/ trip tank. Achieved returns, loss rate 300+ BPH over 5 min interval. UD hanger and landing joint. UD completion T/ 6061', PUW=80K. Consult w/ town. Decision made T/ cut brine weight F/ 9.6 PPG T/ 9.2 PPG. Feeding hole w/ 10 Bbls ever 30 min. Page 2/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our da) Phase AclWity Code Time P-T-X Operation Start Depth(flKB) End Depih(i1KB) 10/22/2022 10/22/2022 1.50 COMPZN, RPCOMP COND P Cut NaCl weight F/ 9.6 PPG T/ 9.2 PPG 6,061.0 6,061.0 17:00 18:30 w/ fresh water in pits. Feeding hole w/ 10 Bbls every 30 min. 10/22/2022 10/22/2022 1.00 COMPZN, RPCOMP PULL P L/D completion F/ 6061' T/ 5626', 6,061.0 5,626.0 18:30 19:30 PUW=80K. Feeding hole w/ 10 Bbls every 30 min. 10/22/2022 10/22/2022 1.50 COMPZN, RPCOMP BHAH P C/O elevators. P/U joint of DP M/U 6" 5,626.0 5,626.0 19:30 21:00 OD sting mill T/ string. RIH 30' T/ drift well head - Good drift. POOH. L/D mill and joint of DP. 10/22/2022 10/22/2022 1.75 COMPZN, RPCOMP PULL P POOH L/D 3.5" Completion to SSSV, 5,626.0 4,260.0 21:00 22:45 spooling up control line. 10/22/2022 10/22/2022 0.50 COMPZN, RPCOMP RURD P L/D SSSV. Secure Control Line to 4,260.0 4,260.0 22:45 23:15 Spooler and Move off Rig floor to containment. 10/22/2022 10/23/2022 0.75 COMPZN, RPCOMP PULL P Continue OOH L/D 3.5" Completion 4,260.0 3,330.0 23:15 00:00 F/4260' T/ 3330'. Recovered 32 Control Line Bands. 10/23/2022 10/23/2022 4.50 COMPZN, RPCOMP PULL P Continue OOH L/D 3.5" Completion 3,330.0 0.0 00:00 04:30 F/3,330' T/ surface. Cut joint recovered - dean cut. Started seeing excessive scale at Joint #166. Box end on TBG from Joint #177 to #188 had scale and signs of wear. Joint # 188 had quarter size hole close to the box end, estimated depth 6,005'. Feeding the hole w/ 10 Bbls every 30 Min. 10/23/2022 10/23/2022 1.00 COMPZN, RPCOMP CLEN P Unload Pipe Shed, clean and clear Rig 0.0 0.0 04:30 05:30 floor. R/D Power tongs. 10/23/2022 10/23/2022 0.75 COMPZN, RPCOMP RURD P Load Drill Collars and Baker Tools in 0.0 0.0 05:30 06:15 Pipe Shed & RF. 10/23/2022 10/23/2022 0.50 COMPZN, RPCOMP SVRG P Service rig. Greased IR draw works & 0.0 0.0 06:15 06:45 pipe skate. 10/23/2022 10/23/2022 0.25 COMPZN, RPCOMP SFTY P PJSM w/ Baker rep and rig crew on MIN 0.0 0.0 06:45 07:00 BHA. 10/23/2022 10/23/2022 1.50 COMPZN, RPCOMP BHAH P M/U BHA#2 junk mill, 7" casing scraper 0.0 229.0 07:00 08:30 & 6.125" string mill T/ 229', PUW=38K, SOW=38K. 10/23/2022 10/23/2022 5.00 COMPZN, RPCOMP PULD P RIH w/ BHA#2 PUDP T/ 6119', 229.0 6,153.0 08:30 13:30 PUW=132K, SOW=108K. RIH tag tubing stub @ 6153' set down 15K. Confirm tag depth. Feeding the hole w/ 10 Bbls every 30 Min. 10/23/2022 10/23/2022 0.50 COMPZN, RPCOMP OWFF P Fill hole w/ trip tank, caught fluid after 16 6,153.0 6,153.0 13:30 14:00 Bbls away. Loss rate keeping hole full 120 BPH. 10/23/2022 10/23/2022 0.50 COMPZN, RPCOMP CIRC P Ciro 28 Bbls, hi-vis 86 pill, followed by 6,153.0 6,153.0 14:00 14:30 58 Bbls 9.2 NaCl @ 3 BPM, 340 PSI. 3% return rate. 10/23/2022 10/23/2022 0.50 COMPZN, RPCOMP OWFF P OWFF, fluid level falling out of sight in 6,153.0 6,095.0 14:30 15:00 stack. Rack stand back. B/D TD. 10/23/2022 10/23/2022 2.25 COMPZN, RPCOMP TRIP P POOH F/ 6095' T/ 229', PUW=132K 6,095.0 229.0 15:00 17:15 10/23/2022 10/23/2022 1.50 COMPZN, RPCOMP BHAH P Standback Drill Collars and R/D BHA #2 229.0 0.0 17:15 18:45 10/23/2022 10/23/2022 1.00 COMPZN, RPCOMP BHAH P Load BHA#3 to Rig Floor and MU 0.0 37.0 18:45 19:45 Same. 10/23/2022 10/24/2022 4.25 COMPZN, RPCOMP TRIP P RIH w/ BHA#3 T/ 6153', 37.0 4,957.0 19:45 00:00 10/24/2022 10/24/2022 0.75 COMPZN, RPCOMP TRIP P PUW=120K, SOW=100K. Confirm tag 4,957.0 6,153.0 00:00 00:45 1 depth at TBG stub @ 6153' Page 3/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our da) Phase Activity Code Time P-T-X Operation Start Depth(flKB) End Depth(flKB) 10/24/2022 10/24/2022 0.50 COMPZN, RPCOMP MPSP P PUH and Set G-Plug at 6140' 6,153.0 6,140.0 00:45 01:15 10/24/2022 10/24/2022 1.00 COMPZN, RPCOMP CIRC P PUH 1 stand to 6085' Circulate bottoms 6,085.0 6,085.0 01:15 02:15 up @ 4 bpm, 450 psi. 10/24/2022 10/24/2022 1.00 COMPZN, RPCOMP PRTS P Set test packer @ 6063' center of 6,085.0 6,063.0 02:15 03:15 element. Pressure test between G-Plug and Test Packer to 2500 psi for 10 min's. Good Test. PT IA to 2500 psi, unable to maintain positive pressure. Able to Inject at 2500 psi. 10/24/2022 10/24/2022 0.50 COMPZN, RPCOMP PRTS P Blow down top drive. Move up hole one 6,085.0 5,966.0 03:15 03:45 stand to 5966' center of element and PT IA to 2500 psi. Unable to maintain positive pressure. Able to Inject @ 2300 psi. 10/24/2022 10/24/2022 0.50 COMPZN, RPCOMP PRTS P Move up hole one stand to 5872' center 5,966.0 5..872.0 03:45 04:15 of element and PT IA to 2500 psi. Unable to maintain positive pressure. Able to Inject at 2100 psi. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP PRTS P Move up hole one stand to 5777' center 5,872.0 5,777.0 04:15 04:30 of element and PT IA to 2500 psi. Unable to maintain positive pressure. Able to Inject at 2100 psi. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP PRTS P Move up hole one stand to 5683' center 5,777.0 5,683.0 04:30 04:45 of element and PT IA to 2500 psi. Unable to maintain positive pressure. Able to Inject at 2100 psi. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP PRTS P Move up hole one stand to 5574' center 5,683.0 5,574.0 04:45 05:00 of element and PT IA to 2500 psi. Unable to maintain positive pressure. Able to Inject at 2100 psi. 10/24/2022 10/24/2022 1.00 COMPZN, RPCOMP PRTS P Move up hole three stand to 5305' 5,588.0 5,305.0 05:00 06:00 center of element and PT IA T/ 2500 PSI For 30 Min - Good test. 10/24/2022 10/24/2022 1.00 COMPZN, RPCOMP PRTS P Release test packer. Run in hole 1 5,305.0 5,400.0 06:00 07:00 stand to 5400' COE. Set test packer. PT IA T/ 2500 PSI for 30 Min - Good test 10/24/2022 10/24/2022 0.50 COMPZN, RPCOMP PRTS P Release test packer. Run in hole 1 5,400.0 5,493.0 07:00 07:30 stand to 5493' COE. Set test packer. PT IA T/ 2500 PSI. Unable to maintain positive pressure. Able to Inject at 2100 psi. Release packer. 10/24/2022 10/24/2022 1.50 COMPZN, RPCOMP CIRC P Circ well @ 2 BPM, 160 PSI. B/D TD 5,493.0 5,496.0 07:30 09:00 1 land kill line. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow 5,496.0 5,496.0 09:00 09:15 10/24/2022 10/24/2022 2.25 COMPZN, RPCOMP TRIP P POOH F/ 5496' T/ 30, PUW=118K. 5,496.0 30.0 09:15 11:30 Filling hole continuously with trip tank. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP BHAH P L/D BHA #3. 30.0 0.0 11:30 11:45 10/24/2022 10/24/2022 1.25 COMPZN, RPCOMP BHAH P M/U BHA#4 Model L retrieving head. 0.0 2,024.0 11:45 13:00 20 stand of DP & storm packer T/ 2024', PUW=60K, SOW=60K 10/24/2022 10/24/2022 0.50 COMPZN, RPCOMP MPSP P Storm packer COE @ 111'. Set storm 2,020.0 0.0 13:00 13:30 packer. Release from storm packer. Pull 1 stand and rack back. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 13:30 13:45 10/24/2022 10/24/2022 0.50 COMPZN, RPCOMP PRTS P PT storm packer T/ 2500 PSI for 10 Min 0.0 0.0 13:45 14:15 1 - Good test. 10/24/2022 10/24/2022 0.25 COMPZN, RPCOMP RURD P B/D, R/D testing equipment, Suck out 0.0 0.0 14:15 14:30 stack. CA open to atmosphere. Page 4112 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our(hr) Phase AclWity Code Time P-T-X Operation Start Depth(flKB) End Depih(i1KB) 10/24/2022 10/24/2022 7.00 COMPZN, W HDBOP NUND P N/D BOP & DSA. RU Hydra -Tight 0.0 0.0 14:30 21:30 Equipment and Start growing TBG Head. Achieved 6-5/8" Growth and additional 19-5/8" after Re -landing in the emergency Slips. 10/24/2022 10/25/2022 2.50 COMPZN, W HDBOP CUTP T Remove packoff and RU WACHS saw 0.0 0.0 21:30 00:00 and cut excess 7" CSG. 10/25/2022 10/25/2022 3.00 COMPZN, W HDBOP CUTP T RU WACHS saw and cut excess 7" 0.0 0.0 00:00 03:00 1 1 CSG. Having Issues with cutter. 10/25/2022 10/25/2022 0.50 COMPZN, W HDBOP SVRG P Service rig, grease TO crown, blocks 0.0 0.0 03:00 03:30 and draw works 10/25/2022 10/25/2022 1.50 COMPZN, W HDBOP W WSP P Install new 9 518" x 7" casing packoff. 0.0 0.0 03:30 05:00 Damages seals. Mobilize new seals and install packoff. 10/25/2022 10/25/2022 1.50 COMPZN, W HDBOP NUND P NU new Gen 3 Tubing Head. Install 2nd 0.0 0.0 05:00 06:30 IA valve. 10/25/2022 10/25/2022 0.50 COMPZN, W HDBOP PRTS P PT packoff T/ 3000 PSI for 15 Min - 0.0 0.0 06:30 07:00 Good test. 10/25/2022 10/25/2022 1.50 COMPZN, W HDBOP NUND P Install test plug. N/U DSA & BOP. 0.0 0.0 07:00 08:30 10/25/2022 10/25/2022 0.25 COMPZN, W HDBOP RURD P R/U testing equipment. Fill stack w/ 0.0 0.0 08:30 08:45 fresh water. 10/25/2022 10/25/2022 0.75 COMPZN, W HDBOP PRTS P PT BOP breaks 250/3500 PSI for 5 min 0.0 0.0 08:45 09:30 each - Good test 10/25/2022 10/25/2022 1.00 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Pull test 0.0 0.0 09:30 10:30 plug. Install wear bushing. 10/25/2022 10/25/2022 1.25 COMPZN, RPCOMP MPSP P M/U storm packer retrieval head. RIH 0.0 2,015.0 10:30 11:45 w/ 1 stand. Equalize stone packer. Close annular. P/U 5'. 10/25/2022 10/25/2022 1.00 COMPZN, RPCOMP CIRC P Ciro 81 Bbls through open super choke 2,015.0 2,015.0 11:45 12:45 @ 2 BPM, 70 PSI. Overboard initial 25 Bbls of returns. 10/25/2022 10/25/2022 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow. Open annular. 2,015.0 2,015.0 12:45 13:00 10/25/2022 10/25/2022 0.25 COMPZN, RPCOMP RURD P Rotate to right place storm packer in 2,015.0 2,025.0 13:00 13:15 release position. B/D TD, choke & kill lines. 10/25/2022 10/25/2022 0.50 COMPZN, RPCOMP BHAH P Pull one stand. L/D storm packer. T/ 2,025.0 1,905.0 13:15 13:45 1 1905', PUW=60K. 10/25/2022 10/25/2022 1.75 COMPZN, RPCOMP TRIP P RIH w/ BHA # 4 G-plug retrieval tool F/ 1,905.0 6,067.0 13:45 15:30 1905' T/ 6067', SOW=108K 10/25/2022 10/25/2022 0.50 COMPZN, RPCOMP SVRG P Service rig, grease IR and pipe skate. 6,067.0 6,067.0 15:30 16:00 10/25/2022 10/25/2022 0.25 COMPZN, RPCOMP COND P Condition 9.1 PPG NEU down T/ 9.0 6,067.0 6,067.0 16:00 16:15 PPG NEU w/ fresh water. 10/25/2022 10/25/2022 1.25 COMPZN, RPCOMP CIRC P Circ 9.0 PPG NaCl around @ 4 BPM, 6,067.0 6,067.0 16:15 17:30 530 PSI 10/25/2022 10/25/2022 0.75 COMPZN, RPCOMP MPSP P RIH F/6,067 - Engage G-plug@6,133' 6,067.0 6,133.0 17:30 18:15 pumping 1.5 bpm 95 psi. PUW= 117k SOW= 110k 10/25/2022 10/25/2022 0.50 COMPZN, RPCOMP COND P Lower weight in the pits from a 9.0 to 6,133.0 6,133.0 18:15 18:45 8.9 ppg NaCl 10/25/2022 10/25/2022 2.50 COMPZN, RPCOMP TRIP P TOOH F/6,133'- T/ 20' 6,133.0 20.0 18:45 21:15 10/25/2022 10/25/2022 0.50 COMPZN, RPCOMP BHAH P L/D G-Plug 20.0 0.0 21:15 21:45 10/25/2022 10/25/2022 1.00 COMPZN, RPCOMP BHAH P P/U Overshot BHA #6 T/ 224' 0.0 224.0 21:45 22:45 10/25/2022 10/26/2022 1.25 COMPZN, RPCOMP TRIP P TIH F/224'-T/3.421 224.0 3,421.0 22:45 00:00 10/26/2022 10/26/2022 1.00 COMPZN, RPCOMP TRIP P Continue TIH F/3,421'- T/ 6,153 7,421.0 6,153.0 00:00 01:00 1 I I Page 5/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our da) Phase Ac iry Code Time P-T-X Operation Start Depth(flKB) End Depih(flKB) 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP FISH P Burn over tubing stub. F/6,153'- 6,153.0 6,120.0 01:00 01:30 T/6,158' PUW= 120k SOW= 110k ROT=122k 60 rpm 2.5 Tq. NO Pump. Engage fish @ 6,158' P/U 60k over, one Jar lick and seal assembly came free. 10/26/2022 10/26/2022 2.00 COMPZN, RPCOMP COND P Decrease brine weight from 8.9ppg. to 6,120.0 6,120.0 01:30 03:30 8.85 ppg NaCl. To help with losses. Top fill losses @ 120 BPH. 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP TRIP P TOOH F/6,158'=T/5334', PUW=125K 6,120.0 5,334.0 03:30 04:00 1 1 Gas breaking out at surface. 10/26/2022 10/26/2022 1.50 COMPZN, RPCOMP CIRC P Circ 360 Bbls @ 5 BPM, 660 PSI. 5,334.0 5,334.0 04:00 05:30 Sweep gas from well. Hole is static. 10/26/2022 10/26/2022 3.25 COMPZN, RPCOMP TRIP P POOH F/ 5334' T/ 225', PUW=110K. 5,334.0 225.0 05:30 08:45 Continuous hole fill. 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP BHAH P L/D BHA#6, PUW=38K. Cut joint and 225.0 0.0 08:45 09:15 seals below overshot. 10/26/2022 10/26/2022 0.25 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 0.0 0.0 09:15 09:30 10/26/2022 10/26/2022 0.75 COMPZN, RPCOMP PULL P Remove fish from overshot. LID 25.4' 0.0 0.0 09:30 10:15 cut joint and 4" OD seal assembly. 10/26/2022 10/26/2022 0.75 COMPZN, RPCOMP BHAH P M/U BHA#7 Spear. T/224', SOW=38K. 0.0 224.0 10:15 11:00 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP SVRG P Service rig. Adjust brake linkage. 224.0 224.0 11:00 11:30 10/26/2022 10/26/2022 2.25 COMPZN, RPCOMP TRIP P RIH F/ 224, T/ 6089', PUW=122K, 224.0 6,089.0 11:30 13:45 SOW=115K 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP FISH P Wash in hole F/ 6089' T/ 6188'. Set 6,089.0 6,116.0 13:45 14:15 down 1 OK fully engaged spear. Pumping @ 3 BPM, 525 PSI Pressure increase T/ 600 PSI. P/U fire jars @ 60K over 1 time. P/U pipe came free @ 225K. P/U T/ 6116', PUW=127K weight swing T/ 150K. 10/26/2022 10/26/2022 2.00 COMPZN, RPCOMP CIRC P Circ @ 3 BPM, 535 PSI. 145 Bbls away 6,116.0 6,116.0 14:15 16:15 gas to surface, cut rate T/ 2 BPM, 140 PSI. 155 Bbls away gas returns increasing. Close in annular, circulate through open choke through gas buster @ 2 BPM, 260 PSI. 250 Bbls away increase rate T/ 3 BPM, 530 PSI though gas buster. 290 Bbls total pumped. 60% return rate. 45 Bbls contaminated fluid over boarded to cuttings tank. 10/26/2022 10/26/2022 0.25 COMPZN, RPCOMP OWFF P OWFF-No flow. Open annular. Fluid 6,116.0 6,116.0 16:15 16:30 level falling in slack. Gas still breaking out at surface. 10/26/2022 10/26/2022 1.00 COMPZN, RPCOMP CIRC P Circ @ 3 BPM, 530 PSI 6,116.0 6,116.0 16:30 17:30 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP OWFF P OWFF (No Gas static loss rate 10bph) 6,116.0 6,116.0 17:30 18:00 Blow down equipment 10/26/2022 10/26/2022 1.00 COMPZN, RPCOMP TRIP P TOOH with FHL Packer F/6,116'- 6,116.0 5,040.0 18:00 19:00 T/5,040' 10/26/2022 10/26/2022 0.50 COMPZN, RPCOMP SVRG P Service Iron roughneck and crown 5,040.0 5,040.0 19:00 19:30 10/26/2022 10/26/2022 3.00 COMPZN, RPCOMP TRIP P Continue TOOH F/ 5,040'- T/225' 5,040.0 225.0 19:30 22:30 10/26/2022 10/27/2022 1.50 COMPZN, RPCOMP BHAH P L/D BHA and Fish (Blast Rings came 225.0 0.0 22:30 00:00 with the packer moblize hydro tight rep) Page 6/12 ReportPrinted: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our da) Phase AclWity Code Time P-T-X Operation Start Depth(flKB) End Depih(i1KB) 10/27/2022 10/27/2022 6.00 COMPZN, RPCOMP PULL P L/D fish: PBR, Packer, 2 full joints w/ 2 0.0 0.0 00:00 06:00 GLM's, partial cut in xo joint. 4 blast joints, 30.45' of lower XO joint. (Swiss cheese below blast rings on XO joint). 315.12' OAL fish. 10/27/2022 10/27/2022 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease IR, draw works. 0.0 06:00 06:30 10/27/2022 10/27/2022 0.75 COMPZN, RPCOMP BHAH P P/U PBR & Packer. Remove 4" spear 0.0 0.0 06:30 07:15 1 form PBR. UD PBR and packer. 10/27/2022 10/27/2022 1.00 COMPZN, RPCOMP RURD P Mobilize BHA 98 dress off assembly to 0.0 0.0 07:15 08:15 RF and pipe shed. 10/27/2022 10/27/2022 1.00 COMPZN, RPCOMP SHAH P M/U BHA98 dress off assemblyw/ 0.0 240.0 08:15 09:15 6.125" junk mill, 2 boot baskets and 2 string magnets T/ 240', SOW=40K. 10/27/2022 10/27/2022 3.00 COMPZN, RPCOMP TRIP P RIH F/ 240' T/ 6476', PUW=125K, 240.0 6,450.0 09:15 12:15 SOW=115K. Took 10Kweight. Overpull 20K. P/U T/ 6450' 10/27/2022 10/27/2022 0.50 COMPZN, RPCOMP REAM P M/U TD. Ream down @ 3 BPM, 320 6,450.0 6,496.0 12:15 12:45 PSI. 60 RPM 2.5K free Tq, 120K ROT W T F/ WO'T/ fish top @ 6496'. Ream back up and back down Tq through perfs 3-4K. 50% returns. 10/27/2022 10/27/2022 0.50 COMPZN, RPCOMP MILL P Mill fish top F/ 6496' T/ 6497. @ 3 BPM, 6,496.0 6,497.0 12:45 13:15 320 PSI. 60 RPM, 10K WOB, 2.5K free Tq, Tq on bottom 3.5-4.5K. 10/27/2022 10/27/2022 1.00 COMPZN, RPCOMP CIRC P Ciro 25 Bbls hi vis sweep chase w/ 115 6,497.0 6,475.0 13:15 14:15 Bbls 8.85 PPG NaCl. 50% returns. Rot & recipricate 6475' T/ 6495'. 10/27/2022 10/27/2022 2.75 COMPZN, RPCOMP TRIP P POOH F/ 6475' T/ 240', PUW 125K 6,475.0 240.0 14:15 17:00 10/27/2022 10/27/2022 1.50 COMPZN, RPCOMP SHAH P UD BHA #8, PUW=40K 240.0 0.0 17:00 18:30 10/27/2022 10/27/2022 1.50 COMPZN, RPCOMP SHAH P Pick BHA #9 Overshot T/ 225' 0.0 225.0 18:30 20:00 10/27/2022 10/27/2022 2.00 COMPZN, RPCOMP TRIP P TIH F/225 - T/5,900', SOW=115K 225.0 5,900.0 20:00 22:00 10/27/2022 10/27/2022 1.50 COMPZN, RPCOMP SLPC P Cut off 95' of drilling line 5,900.0 5,900.0 22:00 23:30 10/27/2022 10/28/2022 0.50 COMPZN, RPCOMP TRIP P TIHF/5,900'-T/6,428', PUW=130K, 5,900.0 6,468.0 23:30 00:00 SOW=120K 10/28/2022 10/28/2022 0.75 COMPZN, RPCOMP FISH P Wash and ream onto fish top @ 6499', 6,468.0 6,464.0 00:00 00:45 swallowed T/ 6504', @ 2 BPM, 160 PSI. 30 RPM, Tq off = 2.11 K. Set down 20K pressure spiked to 225 PSI. Tq increase T/ 3.3K. Shut of pumps and rotary. P/U T/ 6464'. PUW=132K 10/28/2022 10/28/2022 0.25 COMPZN, RPCOMP OWFF P OWFF- Fluid level falling in stack. 15 6,464.0 6,464.0 00:45 01:00 BPH loss rate w/ hole fill on. 10/28/2022 10/28/2022 2.75 COMPZN, RPCOMP TRIP P POOH F/ 6464' T/ 2874', PUW=132K. 6,464.0 2,874.0 01:00 03:45 Continuous hole fill 30 BPH loss rate. 10/28/2022 10/28/2022 0.25 COMPZN, RPCOMP CIRC P Well began to U tube. Ciro STB @ 3 2,874.0 2,874.0 03:45 04:00 BPM, 150 PSI. 10/28/2022 10/28/2022 0.25 COMPZN, RPCOMP OWFF P OWFF - Fluid level falling in stack. 2,874.0 2,874.0 04:00 04:15 10/28/2022 10/28/2022 1.25 COMPZN, RPCOMP TRIP P POOH F/ 2874' T/ 225', PUW=55K. 2,874.0 225.0 04:15 05:30 10/28/2022 10/28/2022 1.00 COMPZN, RPCOMP SHAH P UD BHA#9. No fish. Inspect grapple. 225.0 0.0 05:30 06:30 Wear pattern on top sub appeared to be 4.375". No wear on grapple. 10/28/2022 10/28/2022 0.75 COMPZN, RPCOMP RURD P Mobilize BHA #10 Spear to RF. 0.0 0.0 06:30 07:15 10/28/2022 10/28/2022 0.50 COMPZN, RPCOMP BHAH P M/U BHA #10 T/ 223', SOW=40K 0.0 223.0 07:15 07:45 Page 7/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our da) Phase AclWity Code Time P-T-X Operation Start Depth(flKB) End Depih(flKB) 10/28/2022 10/28/2022 1.75 COMPZN, RPCOMP TRIP P RIH F/ 223' T/ 2872', SOW=90K 223.0 2,872.0 07:45 09:30 Filling hole every 30 Min 10/28/2022 10/28/2022 0.50 COMPZN, RPCOMP SVRG P Service rig. Clean out screens on brake 2,872.0 2,872.0 09:30 10:00 cooling system. 10/28/2022 10/28/2022 1.50 COMPZN, RPCOMP TRIP P RIH F/ 2872' T/ 6466', PUW=128K, 2,872.0 6,466.0 10:00 11:30 SOW=123K Filling hole every 30 Min 10/28/2022 10/28/2022 0.50 COMPZN, RPCOMP FISH P Wash F/ 6644' @ 2 BPM, 560 PSI. Tag 6,466.0 6,466.0 11:30 12:00 fish top @ 6496'. Swallowed T/ 6503' w/ 20K down. P/U 25K over bleed jars. P/U T/ 180K pipe free. P/U weight swing F/ 128K T/ 145K. P/U T/ 6466' 10/28/2022 10/28/2022 3.00 COMPZN, RPCOMP TRIP P POOH F/ 6644' T/ 223', PUW=128K. 6,466.0 223.0 12:00 15:00 Continuous hole fill. 10/28/2022 10/28/2022 0.50 COMPZN, RPCOMP SHAH P L/D BHA#10 F/ 223', PUW=40K. Fish 223.0 0.0 15:00 15:30 on. 10/28/2022 10/28/2022 1.00 COMPZN, RPCOMP PULL P L/D completion: Blastjoint, GLM, 0.0 0.0 15:30 16:30 partially cut joint and seals recovered. 10/28/2022 10/28/2022 0.50 COMPZN, RPCOMP SHAH P Remove spear F/ blast joint. 0.0 0.0 16:30 17:00 10/28/2022 10/28/2022 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 17:00 18:00 10/28/2022 10/28/2022 0.25 COMPZN, RPCOMP OWFF P OWFF -fluid falling in stack. Turn on 6,466.0 6,466.0 18:00 18:15 trip pump- 20 BPH loss rate. 10/28/2022 10/28/2022 1.00 COMPZN, RPCOMP BHAH P P/U BHA 11 Milling assembly T/253', 0.0 253.0 18:15 19:15 SOW=40K. 10/28/2022 10/28/2022 2.25 COMPZN, RPCOMP TRIP P RIH F/ 253'- T/ 6,567'. PUW=125, 253.0 6,567.0 19:15 21:30 SOW=117K. Tagged top of packer. Set down 10K. 10/28/2022 10/29/2022 2.50 COMPZN, RPCOMP MILL P Mill packer @ 2BPM, 175 PSI. ROT 6,567.0 6,568.0 21:30 00:00 WT=120. 68 RPM, 3.2K Free Tq. WOB 24K. On bottom Tq= 3-6K. T/ 6568' 10/29/2022 10/29/2022 6.00 COMPZN, RPCOMP MILL P Mill packer @ 3 BPM, 375 PSI w/ 45 vis 6,568.0 6,568.5 00:00 06:00 NaCl. ROT WT=120. 35-85 RPM, 3.2K Free Tq. WOB 0-32K. On bottom Tq= 3 -6.5K. T/ 6568.5'. Quit making footage unable to achieve Tq. Circ 25 Bbls hi- vis pill 105 vis around. Decision made T/ POOH and change mill. 10/29/2022 10/29/2022 0.50 COMPZN, RPCOMP OWFF P OWFF- Fluid falling in stack. Turned on 6,568.5 6,568.5 06:00 06:30 trip pump 8 BPH loss rate. 10/29/2022 10/29/2022 4.50 COMPZN, RPCOMP TRIP P POOH F/ 6569' T/ 253', PUW=130K 6,568.5 253.0 06:30 11:00 10/29/2022 10/29/2022 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease crown, blocks, IR 253.0 253.0 11:00 11:30 and draw works. 10/29/2022 10/29/2022 1.00 COMPZN, RPCOMP SHAH P L/D BHA # 11. Magnets had fine metal 253.0 0.0 11:30 12:30 shavings. Junk baskets had scale and metal. Mill leading edge was smoothed Off. 10/29/2022 10/29/2022 0.75 COMPZN, RPCOMP SHAH P M/U Rerun BHA#12 w/ new Packer mill 0.0 254.0 12:30 13:15 T/ 254', SOW=40K. 10/29/2022 10/29/2022 2.50 COMPZN, RPCOMP TRIP P RIH F/ 254' T/ 6567', PUW=130K, 254.0 6,567.0 13:15 15:45 1 SOW=118K 10/29/2022 10/29/2022 1.25 COMPZN, RPCOMP MILL P Mill packer @ 3 BPM, 345 PSI w/ 50 vis 6,567.0 6,588.0 15:45 17:00 NaCl. ROT WT=125. 45-60 RPM, 3K Free Tq. WOB 5-30K. On bottom Tq= 3.5-6.5K. Packer gas seen at surface. Chase packer down T/ 6588'. 10/29/2022 10/29/2022 0.75 COMPZN, RPCOMP REAM P Wash in hole @ 4 BPM, 580 PSI. F/ 6,588.0 6,679.0 17:00 17:45 6588' T/ 6679'. Took 25K. P/U ream down @ 60 RPM, 3K free torque. Took 25K. @ 6679'. Page 8/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our da) Phase AclWity Code Time P-T-X Operation Start Depth(flKB) End Depth(flKB) 10/29/2022 10/29/2022 1.50 COMPZN, RPCOMP CIRC P Pump 42 Blois h-vis sweep @ 3.5 BPM. 6,679.0 6,679.0 17:45 19:15 Chased out of hale % BPM, 820 PSI. 10/29/2022 10/29/2022 1.00 COMPZN, RPCOMP TRIP P TOOH F/6,679'-T/4,952' 6,679.0 224.0 19:15 20:15 10/29/2022 10/29/2022 1.00 COMPZN, RPCOMP CIRC P Circ. gas out @ 4 bpm 450 psi. 4,952.0 4,952.0 20:15 21:15 10/29/2022 10/29/2022 0.75 COMPZN, RPCOMP OWFF P Fingerprinted well. First 15 min gain 1 4,952.0 4,952.0 21:15 22:00 bbl. second 15 min gained .75 bbl and last 15 min .65 bbl. 10/29/2022 10/29/2022 1.50 COMPZN, RPCOMP TRIP P Continue TOOH F/4,952'-T/224' 4,952.0 224.0 22:00 23:30 10/29/2022 10/30/2022 0.50 COMPZN, RPCOMP BHAH P L/D BHA #12 224.0 0.0 23:30 00:00 10/30/2022 10/30/2022 1.00 COMPZN, RPCOMP BHAH P Pick BHA #13 spear 0.0 255.0 00:00 01:00 10/30/2022 10/30/2022 2.50 COMPZN, RPCOMP TRIP P TIH F/255'-T/6,619', PUW=130K, 255.0 6,619.0 01:00 03:30 SOW=115K. 10/30/2022 10/30/2022 2.00 COMPZN, RPCOMP CIRC P Close annular circ. gas out though gas 6,619.0 6,619.0 03:30 05:30 buster. 2 bpm, 330 PSI 10/30/2022 10/30/2022 0.50 COMPZN, RPCOMP OWFF P OWFF - No flow. Open annular. Fluid 6,619.0 6,619.0 05:30 06:00 falling in stack. 10/30/2022 10/30/2022 0.50 COMPZN, RPCOMP FISH P Wash in hole @ 2 BPM, 290 PSI. T/ 6,619.0 6,685.0 06:00 06:30 6619' T/ 6685' set down 20K. Pump pressure increase T/ 600 PSI. P/U weight swing F/ 135K to 140K. S/O confirm lag. Circ 2 BPM, 560 PSI, 4 BPM, 1100 PSI. 10/30/2022 10/30/2022 0.50 COMPZN, RPCOMP PMPO P Pump OOH F/ 6685' T/ 6305' @ 4 BPM, 6,685.0 6,305.0 06:30 07:00 1 11000 PSI. PUW=130K. 10/30/2022 10/30/2022 0.50 COMPZN, RPCOMP OWFF P OWFF-Fluid level static. Attempt to 6,305.0 6,305.0 07:00 07:30 pull on elevators. Swabbing. 10/30/2022 10/30/2022 0.75 COMPZN, RPCOMP PMPO P Pump OOH F/ 6305' T/ 5742' @ 3 BPM, 6,305.0 5,742.0 07:30 08:15 750 PSI. PUW =125K. Attempt T/ pull on elevators. Swabbing 10/30/2022 10/30/2022 0.75 COMPZN, RPCOMP CIRC P Circ BU @ 4 BPM, 1070 PSI. 5,742.0 5,742.0 08:15 09:00 10/30/2022 10/30/2022 3.50 COMPZN, RPCOMP PMPO P Attempt to pull on elevators- swabbing. 5,742.0 3,378.0 09:00 12:30 Pump OOH F/ 5742' T/ 3378, PUW=120K 10/30/2022 10/30/2022 1.00 COMPZN, RPCOMP OWFF P Fingerprint well. 1st 15 Min= 1.54 BMs. 3,378.0 3,378.0 12:30 13:30 2nd 15 Min= 1.3 Bbls. 3rd 15 Min= 1.2 Bbls. 4th 15 Min= 1 Bbls. 10/30/2022 10/30/2022 5.00 COMPZN, RPCOMP PMPO P Pump OOH F/ 3378' T/ 255' PUW=92K. 3,378.0 255.0 13:30 18:30 10/30/2022 10/30/2022 3.50 COMPZN, RPCOMP OWFF P Monitor flow back on well, 2 bbl. every 255.0 255.0 18:30 22:00 15 min. it was decided to go back to bottom to fix the problem. 10/30/2022 10/30/2022 1.00 COMPZN, RPCOMP TRIP P TIH F/255'to 2,487, encountered gas 255.0 2,497.0 22:00 23:00 returning @ 30 %. Shut in well with 501b. on the choke 10/30/2022 10/31/2022 1.00 COMPZN, RPCOMP CIRC P Circ. gas out though choke at 559pm 2,497.0 2,497.0 23:00 00:00 220 psi. 10/31/2022 10/31/2022 1.25 COMPZN, RPCOMP CIRC P Continue Circ. gas out though choke @ 2,497.0 2,497.0 00:00 01:15 55gpm 220 psi. 10/31/2022 10/31/2022 1.25 COMPZN, RPCOMP TRIP P Open annular and continue TIH to the 2,497.0 6,306.0 01:15 02:30 top of the perls F/2,497' - T/6,306' 10/31/2022 10/31/2022 2.00 COMPZN, RPCOMP CIRC P Continue Circ. gas out though choke at 6,306.0 6,306.0 02:30 04:30 55gpm 380 psi. Light weight fluid returns. 10/31/2022 10/31/2022 0.50 COMPZN, RPCOMP OWFF P OWFF-30 PSI @surface. 6,306.0 6,306.0 04.30 05:00 Page 9/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our(hr) Phase AclWity Code Time P-T-X Operation Start Depth(flKB) End Depih(WB) 10/31/2022 10/31/2022 3.00 COMPZN, RPCOMP CIRC P Circulate BU through gas buster @ 6,306.0 6,306.0 05:00 08:00 2BPM, 290 PSI. 8.8 PPG in and out. 10/31/2022 10/31/2022 0.50 COMPZN, RPCOMP OWFF P Monitor with closed choke. TBG & IA 6,306.0 6,306.0 08:00 08:30 O=PSI initial. After 30 Min Tbg & IA=O PSI 10/31/2022 10/31/2022 1.50 COMPZN, RPCOMP COND P Conditioning non vis 8.8 PPG NaCl T/ 6,306.0 6,306.0 08:30 10:00 9.0 PPG NaCl in pits. OWFF- No flow. Open annular. 10/31/2022 10/31/2022 1.50 COMPZN, RPCOMP DISP P Circ 9.0 PPG NaCl around well @ 6,306.0 6,306.0 10:00 11:30 1 13BPM, ICP=860, FCP=990. 10/31/2022 10/31/2022 1.00 COMPZN, RPCOMP OWFF P OWFF- Fluid level falling in stack. 6,306.0 6,306.0 11:30 12:30 B/D circulating equipment. Turn on trip pump -50 BPH loss rate. 10/31/2022 10/31/2022 3.25 COMPZN, RPCOMP TRIP P POOH F/ 6306' T/ 255', PUW=130K 6,306.0 255.0 12:30 15:45 Continuous hole fill. 10/31/2022 10/31/2022 0.50 COMPZN, RPCOMP BHAH P L/D BHA#12 & 27.82' of fish. SBE, D 255.0 0.0 15:45 16:15 Nipple & WLEG. 10/31/2022 10/31/2022 1.00 COMPZN, RPCOMP PRTS P PT annular, CMV #7, 8 & 13, HCR Kill T/ 0.0 0.0 16:15 17:15 250/3500 PSI for 5 Min each. 10/31/2022 10/31/2022 0.50 COMPZN, RPCOMP RURD P Pull wear test plug. Insafl wear bushing. 0.0 0.0 17:15 17:45 10/31/2022 10/31/2022 1.50 COMPZN, RPCOMP BHAH P Pickup clean out BHA 0.0 299.0 17:45 19:15 10/31/2022 10/31/2022 1.00 COMPZN, RPCOMP TRIP P TIH F/299'-T/2152 299.0 2,152.0 19:15 20:15 10/31/2022 10/31/2022 0.50 COMPZN, RPCOMP SVRG P Service Draw works and Iron roughneck 2,152.0 2,152.0 20:15 20:45 10/31/2022 10/31/2022 1.25 COMPZN, RPCOMP TRIP P Continue TIH F/2,152'-T/5,350 2,152.0 5,350.0 20:45 22:00 10/31/2022 11/1/2022 2.00 COMPZN, RPCOMP WASH P Wash and ream F/ 5350'-5,580' @ 3 5,350.0 5,580.0 22:00 00:00 bpm 328 psi. 50 rpm. 1.8 Tq. Wob 31k. 11/1/2022 11/1/2022 1.00 COMPZN, RPCOMP WASH P Continue Wash and ream F/5,580'- 5,580.0 5,900.0 00:00 01:00 T/5,900 @ 3 bpm 328 psi. 55 rpm. 1.8 Tq. Wob 3 to 5k. 11/1/2022 11/1/2022 0.50 COMPZN, RPCOMP TRIP P TIH F/5,900'- T/ 6,150' 5,900.0 6,150.0 01:00 01:30 11/1/2022 11/1/2022 7.00 COMPZN, RPCOMP REAM P Ream 6150 nto 6775' 65 RPM 3 BPM 6,150.0 01:30 08:30 3450 PSI, 125K Rot 11/1/2022 11/1/2022 2.00 COMPZN, RPCOMP CIRC P Circ. swap around @ 3bpm. 350psi.15 6,775.0 6,775.0 08:30 10:30 rpm. 1.81k Tq. 11/1/2022 11/1/2022 0.50 COMPZN, RPCOMP OWFF P Monitor well 6,775.0 6,775.0 10:30 11:00 11/1/2022 11/1/2022 3.50 COMPZN, RPCOMP TRIP P POOH F/6,775' - T/255.83' 6,775.0 255.8 11:00 14:30 11/1/2022 11/1/2022 2.00 COMPZN, RPCOMP BHAH P LD BHA#13. Large pieces of metal 255.8 0.0 14:30 16:30 recovered on magnets. 11/1/2022 11/1/2022 2.00 COMPZN, RPCOMP CLEN P Remove wear ring install test plug. 0.0 0.0 16:30 18:30 Wash BOP Stacck 11/1/2022 11/2/2022 5.50 COMPZN, RPCOMP PUTB P Rig up to run 3 % completion per tally on 0.0 370.0 18:30 00:00 DP T/5312' torque all connections to 2240 FULbs Use Run-NSeal pipe dope. RIH with lower completion make up X nipple and blast joints. 11/2/2022 11/2/2022 6.00 COMPZN, RPCOMP PUTB P Rig up to run 3 % completion per tally on 370.0 4,750.0 00:00 06:00 DP T/5312' torque all connections to 2240 FULbs Use Run-NSeal pipe dope. RIH T/370' MU blast joints. RIH T/4750' 11/2/2022 11/2/2022 1.50 COMPZN, RPCOMP PUTB P Continue to RIH with lower completion 4,750.0 6,555.7 0600 07:30 on DP to 6555.74' 11/2/2022 11/2/2022 0.50 COMPZN, RPCOMP RURD P RU circulating equipment. 6,555.7 6,555.0 07:30 08:00 Page 10/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 2W-11 9.6 RIG RELEASE DATE 11/5/2022 CnnomPhaiipe Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our de) Phase Activity Code Time P-T-X Operation Start Depth(flKB) End Depth(i1KB) 11/2/2022 11/2/2022 1.25 COMPZN, RPCOMP CIRC P Reverse circulate100 BBL's 9# Cl. NaCl 6,555.0 6,555.0 08:00 09:15 follow with 90 BBL's non inhibited 99. 3 BPM at 200 PSI. 11/2/2022 11/2/2022 0.75 COMPZN, RPCOMP PACK P RIH to 6690' on a single drop ball and 6,555.0 6,555.0 09:15 10:00 rod 6.75' OAL MU pump lines to set packer and test. PU to 6677.71' Top of PBR at 5335.49'top of upper packer at 5368.91' PUW=122K SOW=115K 11/2/2022 11/2/2022 3.00 COMPZN, RPCOMP PACK P Set packer with 2000 PSI on DR 6,555.0 6,555.0 10:00 13:00 stacked out 50K on packer and continued to pressure up to 3500 PSI. held for 30 minutes. bled pressure off DR Shut in annular. pressured up on backside of DP and top of packer to 2500 PSI for 30 minutes. 11/2/2022 11/2/2022 0.50 COMPZN, RPCOMP RURD P RD testing and pump lines. 6,555.0 6,555.0 13:00 13:30 11/2/2022 11/2/2022 0.25 COMPZN, RPCOMP PULD P LD DP F/5335.49 PUW=105K T/5150 5,335.5 5,150.0 13:30 13:45 11/2/2022 11/2/2022 0.50 COMPZN, RPCOMP OWFF P Well flowing. Fingerprinted well, gained 5,150.0 5,150.0 13:45 14:15 5 BBL's 11/2/2022 11/2/2022 2.50 COMPZN, RPCOMP CIRC P Circ.9.0 ppg NaCl, though the choke 5,150.0 5,150.0 14:15 16:45 @31bpm 11/2/2022 11/2/2022 2.50 COMPZN, RPCOMP COND P Build Volume 200bbl. of 9,2 ppg. NaCl 5,150.0 5,150.0 16:45 19:15 11/2/2022 11/2/2022 1.00 COMPZN, RPCOMP CIRC P Circ.9.2 ppg NEU, Surface to Surface 5,150.0 5,150.0 19:15 20:15 though the choke @31bpm 350 psi 11/2/2022 11/2/2022 1.25 COMPZN, RPCOMP KLWL P Shut in choke, monitor pressures build 5,150.0 5,150.0 20:15 21:30 up 0 pressure build up. Open annular (No Flow) 11/2/2022 11/3/2022 2.50 COMPZN, RPCOMP PULD P POOH U/D Drillpipe F/ 5,150' - 3,500 5,150.0 3,500.0 21:30 00:00 11/3/2022 11/3/2022 3.00 COMPZN, RPCOMP PULD P POOH L//D Drillpipe F/ 5,150' - 50 3,500.0 50.0 00:00 03:00 11/3/2022 11/3/2022 0.50 COMPZN, RPCOMP SHAH P L/D Running tool 50.0 0.0 03:00 03:30 11/3/2022 11/3/2022 2.50 COMPZN, RPCOMP RURD P Rig up to rnn 3 % completion per tally 0.0 0.0 03:30 06:00 11/3/2022 11/3/2022 2.00 COMPZN, RPCOMP BOPE P RU to test annular preventer. RIH 0.0 0.0 06:00 08:00 W/3.5" test joint and BOP test plug. Set test plug. Test Annular to 3500 PSI. LD test joint and test plug. 11/3/2022 11/3/2022 0.50 COMPZN, RPCOMP SVRG P Service Top Drive 0.0 0.0 08:00 08:30 11/3/2022 11/3/2022 12.00 COMPZN, RPCOMP PUTS P Run 3 %completion per tally F/surface 0.0 5,336.0 08:30 20:30 T/5,336.0 11/3/2022 11/4/2022 3.50 COMPZN, RPCOMP CIRC P Circulate 230 bbls of Cl down the TBG 5,336.0 5,336.0 20:30 00:00 while taking returns up the IA. 2 bpm, 150 psi. 11/4/2022 11/4/2022 0.50 COMPZN, RPCOMP CIRC P Circulate 230 bbls of Cl down the TBG 5,336.0 5,336.0 00:00 00:30 while taking returns up the IA. 2 bpm, 150 psi. 11/4/2022 11/4/2022 0.50 COMPZN, RPCOMP HOSO P Land Hanger 5,336.0 5,336.0 00:30 01:00 11/4/2022 11/4/2022 1.50 COMPZN, RPCOMP PRTS P PT Tubing to 3500 psi for 30 mins and 5,336.0 5,336.0 01:00 02:30 chart same. Bleed down TBG pressure to 2000 psi and PT IA to 3000 psi for 30 mins and chart same. Dump TBG pressure to shear the SOV. Circulate through SOV. Good Test on TBG & IA. 11/4/2022 11/4/2022 0.50 COMPZN, RPCOMP RURD P UD landing joint, blow down equipment. 5,336.0 5,336.0 02:30 03:00 Page 11/12 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) 9.6 2W-11 RIG RELEASE DATE 11/5/2022 CmamPhaiips Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTime End Time our (hr) Phase Activity Code Time P-T-X Operation Start Depth (flKB) End Depth (flKB) 11/4/2022 11/4/2022 1.00 COMPZN, W HDBOP MPSP P Install BPV test to 1000 psi 5,336.0 5,336.0 03:00 04:00 11/4/2022 11/4/2022 8.00 COMPZN, W HDBOP SVRG P Perform between well maintenance. 5,336.0 5,336.0 04:00 12:00 11/4/2022 11/4/2022 2.00 COMPZN, W HDBOP NUND P ND BOPE rack on stump and secure. 5,336.0 0.0 12:00 14:00 11/4/2022 11/4/2022 3.00 COMPZN, W HDBOP NUND P Set HP-BPV dart, NU adapter and tree. 0.0 0.0 14:00 17:00 Test adapter void to 5000 PSI for 10 minutes. Spot in LRS and tie into cement manifold in cellar. 11/4/2022 11/4/2022 0.50 COMPZN, W HDBOP PRTS P Test tree to 5000 PSI. Pull HP-BPV 0.0 0.0 17:00 17:30 11/4/2022 11/4/2022 1.50 COMPZN, W HDBOP FRZP P Pump 75 BBLS diesel down IA taking 0.0 0.0 17:30 19:00 returns up the TBG. 2 BP 11/4/2022 11/4/2022 1.00 DEMOB, MOVE OTHR P Alow well to U-Tube 0.0 0.0 19:00 20:00 11/4/2022 11/5/2022 4.00 DEMOB, MOVE CLEN P Secure well and prepare to move off 0.0 0.0 20:00 00:00 Page 12/12 Report Printed: 11/29/2022 2W-11 RWO Summary of Operations DTTMSTART JOBTYP SUMMARYOPS 6/9/2022 ACQUIRE DATA DRIFT TO SLIP STOP @ 6174'RKB & EQUALIZE K-3 PLUG. PULL SLIP STOP FROM 6174' RKB. PULL K3 PACKER EMERGENCY RELEASE. PULL THE K-3 INNER MANDREL APART FROM THE F-COLLAR STOP. RDMO FOR HIGHER PRIORITY WORK, PLAN TO RETURN. 6/14/2022 ACQUIRE DATA PULLED THE REMAINDER OF THE K3 PLUG FROM 6176'RKB.TAGGED RBP @ 6219'RKB. READY FOR COIL 7/12/2022 ACQUIRE DATA (PRE-RWO) FUNCTION TEST TUBING & IC LDS/GN, ALL FUNCTION NORMALLY, T POT PASS, T PPPOT PASS, IC POT FAIL, IC PPPOT PASS. MITOA TO 1800 PSI PASS 8/28/2022 SUPPORT OTHER (STANDBY 4 HOURS FOR VALVE CREW) SET SLIP STOP CATCHER @ OPERATIONS 4363' RKB; PULLED GLVS @ 4065', 3425', 2943', & 1955' RKB. SET DV'S AT SAME & PULL CATCHER @ 4368' RKB. READY FOR CTU. 8/29/2022 ACQUIRE DATA PUMPED 100 BBLS HOT DIESEL LATCHED FISH JARRED 50 TIMES 8/30/2022 ACQUIRE DATA HAD 117 TOTAL JAR HITS AND PULLED OUT OF FISHING NECK WITH 26K OVERPULL, FOUND ONE OF THE DOGS BROKEN ON 2.5" GS, RIH WITH 3" GS BUT UNABLE TO LATCH THE RDW FISHNECK, RUN A VENTURI AND CAME BACK EMPTY, RIH WITH 2.5" GS, LATCH INTO INNER MANDREL AT 6192' CTMD AND PULLED OUT AGAIN WITH 6K OVERPULL, JOB IN PROGRESS. 8/31/2022 ACQUIRE DATA TAG RDW AT 6193' CTMD AND TRY SHIFTING INNER MANDREL DOWN AGAIN, RIH WITH 3' GS TO FISH RDW NO FISH RIH W / 1.75" VZ TO GET INSIDE OF INNER MANDREL JARRED DOWN ON INNER MANDREL 5 TIMES AND TEMPRESS DOWN / RIH W / TAPERED LIB, LIB SHOWS THAT THE 3" FISHNECK IS BROKEN, RIG DOWN CTU 14, JOB SUSPENDED. 9/5/2022 SUPPORT OTHER RECOVERED RDW SPEAR FROM RBP @ 6221' RKB. READY FOR COIL TO OPERATIONS MILL RBP. 9/25/2022 MAINTAIN WELL PUMPED 21 BBLS METH DOWN FL 9/29/2022 SUPPORT OTHER Move from 3G-13 to 2W-11. Spot CTU#14, rig up and P/U milling BHA to mill OPERATIONS RBP @ 6221' 9/30/2022 SUPPORT OTHER Start Milling top of RBP @ 6221' RKB with burn over show, mill a total of 2.8FT OPERATIONS (16.5 HRS). RBP started to move downhole, pushed it down 8 FT to D nipple @ 6238' RKB. stacked 4K weight down, POOH for fishing BHA. P/U Limar Spear BHA assembly. RIH. 10/1/2022 SUPPORT OTHER RIH with Limar Spear down to top of RBP @ 6229' RKB. Latched into fish, saw OPERATIONS 1 OK overpull. Let elements relax, then POOH with fish. CT at surface, RBP was receovered. Freeze protect well, shut in swab, notify DSO and RDMO CT#14. *** full set of packer elements (3) did not come to surface with fish*** 10/2/2022 SUPPORT OTHER BRUSH n' FLUSHED & GAUGED TBG W/ 2.72" TO TAG PATCH @ 6229' RKB. OPERATIONS ATTEMPT TO TEST TBG W/ HOLEFINDER @ 6165' & 6157' RKB (ABLE TO PRESSURE UP BUT DROPS RIGHT OFF). SET 3.5" SLIP STOP @ 6177' RKB. SET 3.5" D&D PLUG @ 6175' RKB (ABLE TO GET CMIT TEST PRESSURE BUT ALL FAILS). EQUALIZED & PULLED D&D PLUG @ 6175' RKB. PULLED SLIP STOP @ 6177' RKB. IN PROGRESS. 10/3/2022 SUPPORT OTHER ((UTILIZING 1.69" DPU)) SET 3.5" QUADCO RBP (DAL 9' / S#CPP35103 / OPERATIONS S#CPEQ35031) @ 6161' RKB (ME @ 6165' RKB). LRS PERFORM CMIT TO 2500 (ABLE TO PRESSURE UP BUT FAILS AFTER 15 MINS). EQUALIZE & PULL 3.5" RBP @ 6161' RKB. SET 3.5" QUADCO RBP (OAL 58" / S#CPP35388 / S#CPEQ35042) @ 6223' RKB (ME @ 6225' RKB). LRS PERFORM CMIT TO 2500 (SAME RESULTS AS BEFORE). READY FOR E- LI N E. 10/5/2022 SUPPORT OTHER ACOUSTIC LEAK DETECTION LOG WITH READ CASED HOLE, RIH ON OPERATIONS BASE -LINE, ENCOUNTERED DIFFICULY W/ TOOLS, POOH & SWAP OUT TOOLS, PERFORM ACOUSTIC LOG FROM 6225' TO SURFACE,NO OBVIOUS LEAK POINT DETECTED. RBIH TO PLUG @ 6225', PERFORM ADDITIONAL STATION STOP, AGAIN, NO OBVIOUS LEAK POINT DETECTED. JOB READY FOR PLAN FORWARD. 10/7/2022 SUPPORT OTHER (AC EVAL) CMIT T x IA (FAIL) LLR OF 5.7 GPM @ 2500 PSI OPERATIONS 10/11/2022 SUPPORT OTHER EQUALIZED 3.5"RBP @ 6225'RKB. IN PROGRESS OPERATIONS 10/12/2022 SUPPORT OTHER PULLED 3.5" RBP @ 6225' RKB; ATTEMPT TO TAG TD W/ 2" BAILER & OPERATIONS ENCOUNTER OBSTRUCTION IN TBG @ 6497' RKB (LARGE PIECES OF SCALE IN BAILER); BREAK THRU BRIDGE @ 6497' RKB W/ 1.75" BAILER & TAG TD @ 6701' RKB; MEASURE BHP @ 6701' RKB; ATTEMPT TO DRIFT W/ 2 1/8" DRIFT & ENCOUNTER OBSTRUCTION @ 6522' RKB. JOB SUSPENDED DUE TO RIG MOVE. 10/12/2022 PUMPING PUMP 22 BBLS METH DWN FL FROM BLIND @ PIT VALVE TRACKING ONLY 10/14/2022 SUPPORT OTHER DRIFT W/ 10' X 1.75" BAILER WITH NO ANOMALIES DOWN TO 6703' RKB; OPERATIONS BRUSH n' FLUSH TBG FROM 6229'-6571' RKB; DRIFT W/ 2" X 10' OF BAILER WITH LIGHT BOBBLE @ 6495' & CLEAN DOWN TO 6703' RKB; DRIFT W/ 2.125"STEM X 10' AND HAVE TO TAP THRU AREA @ 6598' RKB & CLEAN DOWN TO 6703' RKB. READY FOR E-LINE. 10/15/2022 SUPPORT OTHER CUT TUBING WITH RCT AT 6553.2' RKB, CCL TO CUTTER = 13.2', CCL OPERATIONS STOP DEPTH = 6540.0'. ATTEMPT TO POOH, TOOLS STUCK AFTER CUT IN BOTTOM TBG PATCH. ABLE TO WORK TOOLS FREE AFTER MULTIPLE ATTEMPTS. CONTINUE POOH, TOOLS STUCK IN UPPER TBG PATCH. ATTEMPT TO WORK TOOLSTRING THROUGH UPPER TBG PATCH WITH NO SUCCESS. BREAK WEAKPOINT AND LEAVE TOOLSTRING DOWNHOLE (OAL —38'), TOP OF FISH SHOULD BE AT —6215' RKB. 10/16/2022 SUPPORT OTHER RECOVERED E-LINE FISH @ 6190'. JOB COMPLETE & READY FOR E-LINE OPERATIONS TBG CUT'S. 10/17/2022 SUPPORT OTHER CUT TUBING W/ 1.75" RCT AT 6337.3', CCL TO CUTTER = 14.3', CCL STOP OPERATIONS DEPTH = 6323.0' CUT TUBING W/ 2.0" RCT AT 6159.2', CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6146.0' JOB COMPLETE, READY FOR RIG 10/19/2022 ACQUIRE DATA (PRE RWO) BLED OA TO 0 PSI, OA BUR (IN PROGRESS) 10/19/2022 SUPPORT OTHER PUMP 150 BBLS BRINE FOLLOWED BY 50 BBLS DSL DOWN IA OPERATIONS PUMP 75 BBLS BRINE FOLLOWED BY 17 BBLS DSL DN TBG. 10/19/2022 SUPPORT OTHER WELL KILL OPERATIONS PUMPED 216 BBLS BRINE DWN IA PUMPED 64 BBLS BRINE DWN TBG 10/20/2022 ACQUIRE DATA (PRE RWO) BLEED OA TO 0 PSI (COMPLETE) OA VALVE RELOCATION (COMPLETE) 10/21/2022 RECOMPLETION Pull sub off of well. Clean up around 2W-02 cellar. Hang tree, stage wellhead equipment in cellar. Spot rig over well. Spot pits to rig. Spot auxiliary equipment. Hook up steam and air to pits. Berm in rig. Complete acceptance checklist. Take initial pressures T/IA/OA. Rig up circ manifold in cellar. Offload 9.6 PPG NaCl into pits. PT circ manifold & tiger tank T/ 3500 PSI. Bullhead kill well w/ 9.6 PPG. 30 Min no flow test. Install ISA BPV. Rolling test from below for 10 Min. Nipple down tree, install blanking plug. Nipple up BOP. Testing BOPE as per sundry. 10/22/2022 RECOMPLETION Continue test BOPE as per sundry. Pull blanking plug and attempt to pull BPV. Bullhead tubing volume through BPV. Confirmed well on a vac. Make up landing joint. BOLDS. Unseat Hanger. Pull hanger to rig floor. Rig up HES spooling unit to stainless steel control line. Lay down completion F/6,159' T/ 6061'. Condition KW F F/ 9.6 PPG T/ 9.2 PPG. Lay down completion T/ 5626'. Make up BHA #1 6" OD string mill. Drift through the tubing head. Lay down drift. Continue to lay down tubing to SSSV from 1899'. Continue lay down completion T/ 3330'. 10/23/2022 RECOMPLETION Continue POOH UD 3.5" Completion to Cut section from 6,159'. Make up BHA #2 junk mill, 7" casing scraper and 6.125" string mill. Run in hole and tag fish top @ 6153' on DP. Pump hi-vis pill. Pull out of hole and lay down BHA #2. Make up BHA #3 7" G-Plug and test packer. Pick up remaining drill pipe is shed and run in hole to 6,140' on DP. 10/24/2022 RECOMPLETION Set G-Plug and PUH and set test packer and PT CSG between packers T/ 2,500 psi. PT back side to test packer. Identify leak in 7" CSG below 5400'. Circulate bottoms up. Pull out of hole, lay down BHA #3. Make up BHA #4 G-plug retrieval tool. Run T/ 1900'. Make up storm packer, run in hole and set storm packer @ 111' COE. Pressure test storm packer to 2500 PSI for 10 Min. Nipple do BOP. Nipple down tubing head. RU Hydra -Tight Equipment and Start growing TBG Head. Achieved 6-5/8" Growth and additional 19-5/8" after Re - landing in the emergency Slips. Cut excess 7" CSG. 10/25/2022 RECOMPLETION Install new Packoff & Gen 3 TBG Head and pressure test same. Nipple up BOP and pressure test breaks. Release storm packer. Circulate well. Run in hole T/ 6030'. Displace well with 9.0 PPG NaCl. Engage G-Plug and release. Contrition fluid to 8.9 PPG NaCII. Pull out of hole F/ 6153' T/ 3063'. 10/26/2022 RECOMPLETION Continue pulling out of hole lay down G-plug. Make up BHA # 6 Overshot, Run in hole and engage tubing stub. Jar seals free. Circulate gas out of well with 8.85 PPG NaCl. Pull out of the hole and lay down BHA #6, cut joint and seals recovered. Make up BHA #7 Spear. Run in hole, engage PBR, Jar free, Circ. Gas out, Pulling out of hole. 10/27/2022 RECOMPLETION Lay down BHA #7. Lay down fish, recovered 315' PBR, Packer, 2 full joints with 2 GLM's, partial cut in xo joint. 4 blast joints, 30.45' of lower XO joint. Makeup BHA #8 dress off assembly. Run in hole ream through perfs. Mill 1' of 4 1/2" blast joint. Circulate hi-vis pill. Pull out of hole. Lay down BHA #8. Makeup BHA #9 Overshot. Run in hole T/ 6468' 10/28/2022 RECOMPLETION Engage fish. No over pull. Observe well for flow. Pull out of hole. Lay down BHA #9 - No fish. Make up BHA 910 Spear. Run in hole and engage fish. Over pull and drag noted. Pull out of hole and lay down BHA #10. Lay down fish 75.57' recovered partial cut recovered seals. Make up BHA #11 Milling assembly. Run in hole, tag top of packer. Mill packer F/ 6567' T/ 6568' 10/29/2022 RECOMPLETION Continue to mill packer. Quit making footage. Pump hi-vis sweep. Pull out of hole. Lay down BHA #11. Makeup BHA #12 Packer mill. Run in hole, tag top of packer. Mill packer F/ 6568'. Push packer to 6679'. Circulate well. Pull out of hole and lay down BHA 911. 10/30/2022 RECOMPLETION Make up BHA #12 Spear. Run in hole T/ 6619'. Circulate gas out of well. Run in hole and spear SBE. Pump out of hole T/ 5700'. Circulate bottoms up. OWFF - static. Pump out of hole T/ 3380'. Fingerprint well- returns diminishing. Pump out of hole to BHA. Fingerprint well- returns did not diminish. Decision made to run back in hole. Run in hole T/ 2500' gas breaking out. Shut in and circ out gas. 10/31/2022 RECOMPLETION Continue circ out gas. Open up run in hole T/ 6300'. Circ out gas and light weight through gas buster. Check for PSI - 0 PSI. Condition fluid form 8.8 PPG T/ 9.0 PPG. Circulate well. Pull out of hole. Lay down BHA #13 and fish. Pull wear bushing. Test annular as per sundry. Set wear bushing. Make up BHA #14 clean out assembly. TIH, Wash and ream F/ 5350'-5580' 11/1/2022 RECOMPLETION Continue Wash and ream F/5,580'- "6,800', Pump Hi vis sweep, leave 9.Oppg Nacl with no vis. In the hole. POOH rack back 54 stands in the derrick, lay down the rest. Rig up and run 3'/2lower completion. 11/2/2022 RECOMPLETION Rig up to run 3'% completion per tally on DP T/5312' torque all connections to 2240 FVLbs Use Run-N-Seal pipe dope. L/D drill pipe, rig up to run upper completion 11/3/2022 RECOMPLETION L/D drill pipe, Rig up to run upper completion. Test Annular, Space out completion. MU new tubing hanger on landing joint. Swap the entire wellbore over to a corrosion inhibited KWF by reverse circulating to surface. 11/4/2022 RECOMPLETION Land the tubing hanger and RILDS. PT T-PO's to 5,000 psi. PT tubing to 3,000 psig for 30 minutes . PT IA 2,500 psig for 30 minutes, Shear the SOV ,install BPV, end of well maintenance, N/U Tree & Adaptor, test to 5000 psi. freeze protect. 11/8/2022 SUPPORT OTHER CIRC OUT OPERATIONS PUMPED 250 BBLS DSL DWN IA UP TBG TO WELL 2W-12 ( JOB COMPLETE) 11/9/2022 SUPPORT OTHER SET CATCHER ASSEMBLY @ 6552' RKB; PULLED SOV & SET OV @ 5275' OPERATIONS RKB; PULLED DV & SET GLV @ 2718' RKB; PULLED CATCHER ASSEMBLY @ 6552' RKB; PULLED BALL n' ROD & RHC PLUG @ 6628' RKB. JOB COMPLETE. 11/12/2022 MAINTAIN WELL FREEZE PROTECT PUMPED 25 BBLS DIESEL DOWN FLOWLINE JOB COMPLETE 11/18/2022 ACQUIRE DATA (WC) MIT-OA TO 1800 PSI (PASSED) 11/19/2022 ACQUIRE DATA (AC EVAL) TIFL (PASS) KUP PROD WELLNAME 2W-11 WELLBORE 2W_11 COr1000Plllllps Alaska, Inc. c.mlrarc Henan: SURFACE: AUnR9-GPS Man rai lamard-BPS UI: asIs.s IPERF 636nW,494.0 IPERF, a... E14.0 Mewo-axi 9,5C4.t nation a.59a.9 N.pde -x. 6628.7 IPERF; 6.166.06 T020 FISH: 6.]E TA� E13H. ET]EAHER. Flnrri WERE 6.T8306.i92.0- IPERF: a,W3D&e 10.0--r PRODUCTION. 2iae,92&2- Well Attributes Max Angle & MD TO riUPNama WeI16de R%IUWI WMIhon aram. 1'l, KUPARUK RIVER UNIT 500292123800 PROD 9.02 Mp I take 6,700.00 Alum IXKBI 6,950.0 Ldnment X35ppml Gale MnMelbn Last WO: Entl Gale K6Grtl L1I2004 33.80 IRI RR Gott 12123/198 OIM1er Ekv... Annotation Gepin line) WenWre End Data Last Mod By Last Tag: RKB 6,J80.0 2W-11 10131/2018 raffep Last Rev Reason MnManon W2leore End Date Last Mod By Rev Reason: Set GILD &Pulled RHC Plug 1,ameno, Notes: General & Safety Attndats End Data Last Mod By NOTE: Well worked Over last note is irrekvent 11/4/2022 nakrvmcm Note: No SSSV In wall. Field is looked and not editable 11/4/2022 zembaaj NOTE: Casing Leak detened brain 5400.6063' MD during RWO wrest packer&Grid, lW24/2022 conkba NOTE: 2 RIGS RKB DIFFERENCE ACCOUNT FOR PROD CSGrI USING OVERLAP APPEARANCE 1015QO12 astral NOTE View Schematic w/ Alaska Schelretic9A 12/15/2010 ON. NOTE: WAVERED WELL: IAx OA COMMUNICATION 3/16/2004 Imoshor General Notes: Last 3 entries Can Data I WtMod By Tubing freeze Protected to 2001 ...4/2022 IA free.. protected to "On 9.2# Cl in tubing and IA from 2000' MD to 66J]75' in IA and tubing nskpwocm WAVERED WELL: IAx GACOMMUNICATION 3116/2004 Admin Drift tubing with dummy patch to MOO RKB 1212ili lAdmin Casing Strings care Des oG(in) lie) Top (We) Set Di seat pi ONTROMKII) Depth WULeneKa) Grade Too Tn.eaa CONDUCTOR 16 1 061 31.01 115.0 115.0 8250 H-d0 WELDED SURFACE 103/4 9.79 3U.2 I 2,4J5.6 2,475.5 45.50 Jd5 BUTT PRODUCTION T 6.28 23.5 1 6,925.2 6,162.3 1 2G00 }Eb lbull Tubing Strings: string max indicates LONGEST segment of string Top IXKRI 320 SetDeplh...SetDeplh... S35T.0 5124.8 Stang Ma... 3112 Tubing Geacription WidpM) Gratle Tubing- Completion Upper 9.30 L-BO Top Lonneaion IGIin) EUE 299 Completion Details: excludes tubing, pup, space out, thread, RKB... Top IXKBI IF ITVD) (MB) Topind (°) hem Des OD Nominal (In) Co. Make aft, Nominal IDpi 32.0 32.0 0.05 Hanger 7.000 FMC GEN IV Tubing Hanger FMC Gen4 2.900 437.3 437.3 0.29 Nipple -X 3.770 3.5"281"X-nipple. HES XNipple 2.813 2,718.4 2,718.2 0.67 Mandrel - GAS MFT S375 3.5"x 1.5"Camco MMG GLM. SLB MMG 2920 5,27SO 5,059.2 37.32 Mandrel -GAS uFT S375 3.5"x 1.5'Camco MMG GLM. SLB MMG 2992 S334.2 5, 106.4 361 Locator 1500 Baker Locator BAKER 80-40 2992 513356 5,107.5 36.50 Seal Assembly 3.500 Baker BC-60 Seal Assembly BAKER (Locator 8.53' from No-go) 8040 2992 Top IflKG) Sat GaplM1...$at GepN... String Ma... Tunlne GescalNlon 5,319.8 6,6]].8 6,03].3 31/2 Tubing -Completion vn earn) Grade Top Cmnectlon ID(In) Lower 9.30 L-80 EUE-M Z99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top IXKG) Tap ITVG) InKB) Topind (°) hem Des OD Nominal (in) Co. Meke Model Nominal IDan) 5,319.8 5109" 36.87 PER 5810 Baker BAR selling extension Baker Liner Setting Sleeve 5250 5,335.5 5,107.4 36.51 PER &000 &Y 80.40'PBR"Polish Bore Baker Receptacle, Hyd 563 pin 80-e0 PBR 4.000 S363.9 S1M.4 35.74 Packer 6.280 3.5"x7-Helllbunon MET Halibun Feedthmugh Packer, on MET Packer 2.897 5,429.8 5,184.2 35.20 Nipple-X 3.770 3.5"x 2.81"X-nippk, Halibun on XNipple 2.831 6,217.9 5,]]21 48.75 Pecker 5280 3.5" x J' Hdllbunon MET Hallibun Feedthmugh Packer MET Packer 2.8W 6,247.6 5,791.6 49.32 Nip a-X 3770 "X-nip Hallibun on XNippe 2.831 6,316.E 5,8359 50.81 Mandrel -GAS LIFT S970 Camco MMG GLM. SLB MMG 2.920 6,544.1 5,969.0 5].J4 S ve- (ding 42J0 SliilgeveRunln Baker ition. Z CMU SlidingSleeve6,598.9 2.812 5,99J.5 59.49 Packer S280 allibunon MET Hallibun h Pecker MFT Packer6,628.] 289] 6,0126 59.61 Nipple-X 3.9]0 3", X-Nipple Hallibun XNipple 2831 6,67.3 6,037.1 39.J5 Whdm Guitle 4.500 3-1/2'WLED end EUE Box Baker WLEG 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top IRKB) Top On IXKBI Tap bill (°I Gea Com Make Model SIN Run Data ID (in) 6,J]5.0 6,0852 59.82 FISH Lock Ring &Spring From DV- Lost Downbde 1120/1989 6,J]5.0 6,086.2 59.82 FISH 111i Dropped in Rathde 412/1989 6,7J5.0 6,086.2 59.82 FISH 1112"CV Dropped in rathde 1129/1993 Mandrel Inserts : excludes pulled inserts Top IttKGI Top(TVD) IXKBI Top last I') at aft an Na saki Valve Typo I Latch Type OD Ii TRO Run flan, Run Gate Co. Make ModN Paa Stre (In) 2718.4 2,]18.2 0.61 GLV RK 1112 1. 3 ft 11/9/2022 I ScNumb .,at MMG 1 0.125 ® KUP PROD WELLNAME 2W-11 WELLBORE 2W-11 DocuSign Certificate Of Completion Envelope Id: 160B5Cl25OB2440BAD1866FC16B559D6 Subject: Here is your signed document: KRU 2W-11 (PTD184-222) 10-404 RWO.pdf Source Envelope: Document Pages: 20 Signatures: 1 Certificate Pages: 5 Initials: 0 AutoNav: Disabled Enveloped Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) Record Tracking Status: Original 12/1/2022 7:26:39 PM Signer Events Jonathan Cobedy Jonathan.Cobedy@conocophillips.com Security Level: Email, Account Authentication (None) Electronic Record and Signature Disclosure: Accepted: 10/21/2021 1:38:44 PM ID: 816074ce-6d9-4a8e-a803-d7ca1a5695a7 In Person Signer Events Editor Delivery Events Agent Delivery Events Intermediary Delivery Events Certified Delivery Events Carbon Copy Events Amy Conklin Amy.A.Conldin@conocophillips.com Security Level: Email, Account Authentication (None) Electronic Record and Signature Disclosure: Not Offered via DocuSign Witness Events Notary Events Envelope Summary Events Envelope Sent Certified Delivered Signing Complete Completed Payment Events Holder: Jonathan Cobedy Jonathan.Cobedy@conomphillips.com Signature [oxusie� M: 6WD478MFO. Signature Adoption: Pre -selected Style Using IP Address: 138.32.8.5 Signature Status Status Status Status Status COPIED Signature Signature Status Hashed/Encrypted Security Checked Security Checked Security Checked Status Status: Completed Envelope Originator: Jonathan Cobedy 600 N Dairy Ashford Rd Houston, TX 77079-1100 Jonathan. 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From:Coberly, Jonathan To:McLellan, Bryan J (OGC) Cc:Regg, James B (OGC); Loepp, Victoria T (OGC); Rixse, Melvin G (OGC); Senden, R. Tyler Subject:Notification of BOP use on Nabors 7ES on 11/2/2022 Date:Wednesday, November 2, 2022 4:24:54 PM Attachments:2W-11 BOPE Letter 11_2_2022.doc You don't often get email from jonathan.coberly@conocophillips.com. Learn why this is important Bryan, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on well 2W-11 (PTD 184-222). Please let me know if you have any questions. This is the 3rd unique notification for well 2W-11. Thanks, Jonathan Coberly | Staff RWO/CTD Engineer | ConocoPhillips Alaska O: 907-265-1013 | C: 907-538-8398 | 700 G Street, Anchorage AK, 99501 (ATO-678) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 2, 2022 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 11/2/2022 at 14:48 hours Well Location: 2W-11 API Number: 50-029-21238-00 PTD Number: 184-222 Rig Name: Nabors 7ES Operator Contact: Jonathan Coberly. (o) 907-265-1013. (c) 907-538-8398. Jonathan.Coberly@conocophillips.com Operations Summary: After setting the lower completion production and scab packers we obtained passing tests on the tubing (3,500 psig) and inner annulus (2,500 psig). We released the liner setting tool and tripped out of hole 6 joints. At that point we noticed pit gain and decided to trip back in hole to just above the lower completion at 5,300’ RKB. We shut in the annular and are currently (16:00 hours) conditioning the well to circulate any potential gas out the gas buster. BOPE Used: Annular Reason for BOPE Use: The annular was closed to condition the fluid after noticing pit gain. Actions To Be Taken: We will circulate out any potential gas out the gas buster and weight up if needed before tripping out of hole to surface. The Annular will be retested on 3.5” OD to 3,500 psig once the drillpipe and BHA is out of the hole. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Jonathan Coberly Rig Workover Engineer CPAI Drilling and Wells From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOPE Use - Nabors 7ES Date:Friday, December 2, 2022 2:13:06 PM Attachments:KRU_2W-11_well_control_Nabors7ES_2022-1102.pdf KRU 2W-11 (PTD 1842220) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 1 Regg, James B (OGC) From:Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Sent:Monday, October 31, 2022 12:44 PM To:McLellan, Bryan J (OGC) Cc:Regg, James B (OGC); Loepp, Victoria T (OGC); Rixse, Melvin G (OGC); Senden, R. Tyler; NSK RWO CM Subject:Notification of BOP use on Nabors 7ES on 10/30/2022 - 10/31/2022 Attachments:2W-11 BOPE Letter 10_31_2022.doc Bryan & Mel, Please see attached document in response to Bulletin 10‐003 in order to document the use of BOP equipment on 2W‐ 11. This is a notice for the second usage of the annular on this well. Please let me know if you have any questions. Thanks, Jonathan Coberly | Staff RWO/CTD Engineer | ConocoPhillips Alaska O: 907‐265‐1013 | C: 907‐538‐8398 | 700 G Street, Anchorage AK, 99501 (ATO‐678) Some people who received this message don't often get email from jonathan.coberly@conocophillips.com. Learn why this is important 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. KRU 2W-11 PTD 1842220 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 31, 2022 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 10/30/2022 at 22:00 hours Well Location: 2W-11 API Number: 50-029-21238-00 PTD Number: 184-222 Rig Name: Nabors 7ES Operator Contact: Jonathan Coberly. (o) 907-265-1013. (c) 907-538-8398. Jonathan.Coberly@conocophillips.com Operations Summary: After tripping out of hole with the milled lower production packer to 255’ RKB we monitored the well for flow. The well showed 2 bbls /15 min gain so the decision was made to trip back in hole to condition the fluids. At 2,487’ RKB we encountered gas breaking out and decision was made to shut-in the well via the annular and circulate the gas through the gas buster. We tripped in hole down to the top of the perforations and conditioned the hole while circulating out gas as needed. We swapped the well up to a 9.0ppg brine from the 8.85ppg brine and proceeded out of hole. We plan to retest the annular upon pulling the drillpipe and BHA with fish to surface. BOPE Used: Annular Reason for BOPE Use: The annular was closed to circulate out gas while tripping in hole to condition the well. Actions To Be Taken: The Annular will be retested on 3.5” OD to 3,500 psig once the drillpipe and BHA is out of the hole. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Jonathan Coberly Rig Workover Engineer CPAI Drilling and Wells       J. Regg; 11/28/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOPE Use Report - Nabors 7ES Date:Monday, November 28, 2022 1:04:15 PM Attachments:KRU_2W-11_well_control_Nabors7ES_2022-1030.pdf KRU 2W-11 (PTD 1842220) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 1 Regg, James B (OGC) From:Cozby, Kelly <Kelly.Cozby@nabors.com> Sent:Monday, October 24, 2022 12:17 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); NSK RWO CM Cc:White, Bradley; Henson, James; Kneale, Michael L; Hobbs, Greg S; Morales, Tony; Marmon, Jim; Yearout, Paul Subject:Nabors 7ES BOP report 10/22/22 Attachments:Nabors 7ES 10-22-22 .xlsx Thanks, Kelly Cozby Nabors Alaska Drilling Rig 7ES Rig Manager Office 907‐670‐ 6132 Cell 907‐715‐9055 ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 2W-11 PTD 1842220 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:10/22/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1842220 Sundry #322572 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1478 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 FP Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8' x 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate FP System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)115 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@2050 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:11.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/20/22 12:11PM Waived By Test Start Date/Time:10/21/2022 21:30 (date)(time)Witness Test Finish Date/Time:10/22/2022 8:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Test with 3 1/2" jnt. Annular FP new element fucntioned & retest - Pass. HCR choke was FP greased & re-test - Pass Kelly Cozby / Jim Marmon ConocoPhillips Dale Rowell / Kevin Barr KRU 2W-11 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1022_BOP_Nabors7ES_KRU 2W-11     322-572         J. Regg; 11-25-2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Nabors 7ES Date:Friday, November 25, 2022 1:29:01 PM Attachments:2022-1022_BOP_Nabors7ES_KRU 2W-11.pdf KRU 2W-11 (PTD 1842220) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-05_20248_KRU_2W-11_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20248 KRU 2W-11 50-029-21238-00 LeakPoint Survey 05-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:184-222 T37164 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.17 15:54:11 -08'00' ! 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) n Color items: [] Diskettes, No. [] Maps: [3 Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: · NOTES: [] Logs of various kinds [] Other ~si Project Proofing BY: BEVERLY BREN(:~~ SHERYL MARIA LOWELL ScanningPreparation ~ x30= q~ BY: BEVERLY BREN~SHERYL MARIA LOWELL III Illllllllll II III --- TOTAL PAGES~ ' Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~:~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ NO Stage 2 IF NO ~N STAGE 1, PAGE{S) D~SCREPANC~ES WERE ~OUND: YES NO (SCANNING IS COMPLE'~B.&Z,.,~NIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: DATE: /SI Quality Checked {done) 10/25/02Rev3NOTScanned.wpd ! WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Shut-in Bottom Hole Pressure: 2W-11 Run Date: 6/29/2009 August 28, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2W-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21238-00 . •~; r`, °4 ; ,._ " ~ ~i ~.~::P PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. ' ~L~ _ a~ ~ Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton ~ ,~,~,~ r t.,,~~.,~ Date: SEp b ~ 200~3 ~~sk~ ~Iit ~ Gas Gar~s. ~or~°~ivsinr? ~ An~hara~~ l '~~19Y ~ Signed: i • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2009 _, P; _ ~ - '_r_ _ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 ,.. ~ , ~~ ~ ~' ~t'~'~~.~~-; ~1A~ K ' ^CD~ Dear Mr. Maunder: ~~~ ,~~~ avJ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18t" and January 24t", 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23`d , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~!~~ C M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21" 1/24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 ~. ' ~ -~~ ~ ~ rte:; ~.r ~f.~~ ~~ `~ i'(7U~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~N~~ S~t~ ~ ~~~~ Log Description NO.4852 yr , k~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 08/28/08 2W-11 12100437 PROD PROFILE ~ - 08/06/05 1 1 1 F-14 12096521 PROD PROFILE / - ~ 08/08/08 1 1 1 Y-05 12096520 LDL J ~ 08/07/08 1 1 30-02A 12097415 SBHP SURVEY p"~-- a 08/10/08 1 1 1 E-114 12096524 INJ PROFILE - 08/10/08 1 1 2A-24 12097417 PROD PROFILE - ~ ~- 08/11/08 1 1 iG-10A 12097418 PROD PROFILE ~ 08/12/08 1 1 1 L-14 10228963 INJ PROFILE q 1- 10 08/12/08 1 1 30-17 11966273 SBHP SURVEY ~ ~ - 08/15/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ty , - - --- .. _. __ - • ~rr ~~ ~ ~ - t7~r~~~~~s~~ ~ ~~~a~~ a', ti~ t ~~r~~ NO. 4639 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oii & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/20/08 2W-11 11996609 LDL - 03/17!08 1 3J-19 11996610 PROD PROFILE - ~~( 03/18!08 1 2Z-O1A 11994631 PROD PROFILE 03/11/08 1 1E-08 11994632 INJECTION PROFILE 03/12/08 1 2U-12 11994638 PROD PROFILE - 03/16/08 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ) ') 'r"V(" ~.~:\ i ¡, I ",,';:1 \ ! ., J "11, i, ~,' ' ,i ì\ \ I, l% '~, L\ ' U\liN FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 9, 2005 ''Y~ L\';~ \C6 W..-A\ ~."',, ,",' , ~ Mr. Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve systen1 (SVS) at Kuparuk River Unit 2W ("KRU 2W") pad on October 2, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Commission approved fail-safe automatic surtàce SVS capable of preventing uncontrolled flow by shutting ofT f10w at the wellhead and shutting down any artifìciallift system where an overpressure of equipment may occur. If installed, a subsuríàce safety val ve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS con1ponent tàilure rate of 15 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a íàilure rate exceeds 10 percent. EfIective October 2,2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2W must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, ~' , ,.--, ,11'1/i0j b. K~c(,' James B. Regg Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors $(;AN~E'[) NOV 1 7 2005 Safety Valve & Well Pressures Test Report Reviewed By: P.l. Suprv Comm Pad: KRU__2W Insp Dr 10/2/2005 Inspected by John Crisp Interval 90 Days InspNo svsJCr051004204247 Field Name KUPARUK RlVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason 180-Day Src: Inspector r - -------ii;~IID~t;------r-- ------p¡j~/~~-1 SSVISSSV Sh;tJll.Di¡ HiellTJ'pe L--,rell Pressures ~I QasLift ¡jJlab~----c--~~nufienÙ Well Permit Separ Set LIP Test Test Test Date SI Oil, WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI Yes/No Yes/No - -2W::Oj--- .-- --1850IOO~- -95--70--65- ----P-----p u_~____ ----- --uI~OIL - --~rI400- ---720----- 230 ~---yes--- -- -Y~;--IAx OA _u______ - - ~--- ____ _____._~ __ __.____________ ___u___ _ __ __________________ __ ___ _________~______I-----.------.------- -------------.- .-----~--- ------------ ~---~------------- ~ ------- 2W-03 1850110 95 70 50 P P I-OIL ¡ - ~2W-05 1841910 -2650---ioõü- 2000 p--~p----~- -----WAGIN----'-- --- --- ~------ ____________________n~ -------- ------- ----- r- iW-06 -- -~-I¡¡4i940- 95 70 - - ¿S----p- __p__u_ ----- ----]~ÒIL ----- ~-i2S0---- 1000--230---- --y~~-- -- -y~~--IA-xOA-- -- ---- -- - ----- 2W-07 ~~~O~_~_____ 9~_ ___?~_ __5~__ 10 P ____ ~---I~~~-- _ _39~___~~___25~__~---No-------yes--~A.~()~----- ___________ 2W-ll 1842220 95 70 65 P P - I-OIL I -iW~2 -- --i8422"4ö-- 95------70- 50 --I;-----P- U_ -u-----------I=DIC---- ---------------¡- ------ ------_._.-._-~-------_..._- . --_..~-----------_._---_._~----------- ~--- - ------------------ .~------- ~-- --- ----------- 2W-13 1842360 95 70 50 P P I-OIL _ 2~-~~_~--_~-: 18~23~~_-_~~2i50 __20ÕO:-__~~~J~=~=~~~-~-~-=_~~~-___-_-=[ ~~Gí~_=_____==__~=--_u~____~_m___u_u_ __-=_--=-:=-_~_____~ _ ------------4 __ _~~i~_. __I~'!.2~_~_ __95 __ 7~___?~____p__!._____ ___L____ _ ~___I-OIL____L_J_40~_~_~~__~80 ___ ~e~____ 'yes ~~~<?~__________~______J -- ---- ---- -~-- - ____ u_ _._ Comments Performance -------------- --- -------- -- ---.---- -- --"----------------- Wells Components Failures Failure Rate __19_ ___ . _ _ _.2º__ ___ __ ...ì________JjrQ.___ ---.-----.-- -- ------------ - -- ----------- ---- --------- - r 0 p V '= f: Wednesday, October 05, 2005 STATE Of ALASKA ~ OIL AND GAS CONSERVATION COMMI~:k~ON ~//~ REPORT OF SUNDRY WELL OPERATIONS . 1. Type of Request: Operation Shutdown m Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 468' FNL, 258' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1028' FSL, 912' FEL, Sec. 28, T12N, R9E, UM At effective depth 1387' FSL, 1062' FEL, Sec. 28, T12N, R9E, UM At total depth 1473' FSL, 1098' FEL, Sec. 28, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6950' 6174' feet feet Effective depth: measured 6 84 4' true vertical 6027' feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 90' 16" 2476 10 3/4" 6926' 7" measured 6. Datum elevation (DF or KB) 95' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-11 9. Permit number/approval number 84-222 10. APl number 50-029-21238 11. Field/Pool Kuparuk River Oil Pool t~et Plugs (measured) Cement: 6844'-6950' Junk (measured) None Cemented Measured depth True vertical depth 265 Sx CS II 90' 90' 750 Sx AS III & 2476 2496 300 Sx Class G 610 Sx Class G & 6926' 61 62' 246 Sx AS I 6360'-6494' 6508'-6514' 12 SPF 60 6766'-6782', 6786'-6792, 6803'-6810' true vertical 5769'-5847', 5855'-5860'. 5952'-5957', 5965'-5984', 5987'-5995', Tubing (size, grade, and measured depth) 3.5" J-55 set at 6603' Packers and SSSV (type and measured depth) Baker FHL @ 6200', Baker FB-1 @ 6572'; OTIS FXE WRDP @ 1899' degree phasing ; 6696'-6704', 6710'-6760', 4 SPF 120 degree phasing 13. Stimulation or cement squeeze summary Hydraulically fractured the A Sand with crosslinked gelled water and 12/18 M~Sh"" -Ca(~9.~l[eu~,~ ...... Intervals treated (measured) ; '" Pumped 58298 # 12/18 Mesh Carbolite and 694 bbl gelled water. Final treating ph~~V~ 3726 Treatment description includinc~ volumes ~Jsed and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1087-~ 645-' 0 800 194 Subsequent to operation 3670 / 3980.~ 1 67 1050 247 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned''~~ /~' ~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE WELL ARCO Alaska, In(: Subsidiary of Atlantic Richfield Company ;ONTRACTOR REMARKS ,~)/./ iPBDT FIELD. DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT JDAYS iDATE / ?-? - ?o 0 07oo lO,5 I--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK j Signed ,.. knot, I ~.~,~ ~ STATE OF ALASKA '"' '~''~ :''-' ~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 468' FNL, 258' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1028' FSL, 912' FWL, Sec. 28, T12N, R9E, UM At effective depth 1387' FSL, 1062' FWL, Sec.28, T12N, R9E, UM At total depth 1473' FSL, 1098' FWL, Sec. 28, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB ~)4 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2W-11 9. Permit number 84-222 10. APl number 5o-029-21 23~ 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical 6 9 5 0' feet 61 7 4' feet Plugs (measured) Cement: 6844'-6950' Effective depth: measured 6844' feet Junk (measured) true vertical 602 7' feet None Casing Length Size Cemented Structural Conductor 9 0' 1 6" 265 Sx CS II Surface 2476' 10 3/4" 750 Sx AS III & Intermediate 300 Sx Class G Production 6 9 2 6' 7" 610 Sx Class G Liner 246 Sx AS I Perforation depth: measured RECEIVED AUG 2 1990 0il & Cons. maiss Measured dep~ T~~I depth ~ 90' 90' 2476' 2496' 6926' 6162' 6360'-6494', 6508'-6514' 12 SPF 6766'-6782', 6786'-6792', 6803'-6810' true vertical 5769'-5847', 5855'-5860', 5952'-5957', 5965'-5984', Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6603' Packers and SSSV (type and measured depth) BAKER FHL @ 6200', BAKER FB-1 @ 6572'; OTIS FXE WRDP @ 1899' 60° phase ; 6696'-6704', 6710'-6760', 4 SPF 120° phasing 5987'-5995', 6006'-6010' TVD 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch_ Bottomhole pressure 8000 psi, No BOP - a tree saver will be used, No workover fluid will be used 14. Estimated date for commencing operation J 15. Status of well classification as: September 1, 1~)~)0 J Oil 16. If proposal was verbally approved Name of approver Date approved Service _P r o d u c e r 7. I he~~~t the for~egoing is true and correct to the best of my knowledge. ,~ned"~/~'"'~' ~ Title FOR COMMISSION USE ONLY Suspended _ Date ~" '" ~) "' ~:~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance w Mechanical Integrity Test M Subsequent form require 10- ~ ~ IApprov~l No.__ Approved by the order Commission Form 10-403 Rev 5/03/89 0RI~INAL S!GNE0 BY LONNIE C. SMITH APproved Copy Returned /, -, ' ~~~r (~Date SUBMIT IN TRIPLICATE Messrs Bundy and Job August 16, 1990 Page 3 Kuparuk Well 2W-ll 'A' Sand Re-Fracture Procedure Charge Code: AFE No. K81158 PRE-FRAC SLICKLINE 1. Obtain a 24 hour well test. 2. MIRU Slickline Unit. 3. RIH, pull WRDP and run 2" gauge ring to tag bottom. 4. RIH with 2.79" gauge ring to check for scale. NOTE: If scale is found consult with Operations Engineering about pumping an acid wash prior to fracturing. 5. RIH and pull GLV's at 1955', 3425', 4514', 5120', 5602', 6960' and 6145' MD RKB. Replace with DV's. 6. RIH with Standing Valve and set in CAMCO 'D' nipple at 6590'. Pressure test tubing to 4500 psi. Pull SV. 7. RDMO Slickline Unit. NOTE: Fill was last tagged on 1/21/88 at 6757' MD RKD' - covering part of the A3 perforations. Consult with Operations Engineering when fill is tagged. A pre- refrac CTU cleanout is anticipated. 8. CTU cleanout well (expected). 9. RU Slickline Unit and run Petredat gauge the day before the treatment. The gauge should be run in the bottom GLM at 6145' and set to take 15 second readings during the frac. PROPPANT FRACTURE TREATMENT 10. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. NOTE: Work with the service company to rig up a pressure gauge to the SSSV control line. 11. Carry out all fluid quality control procedures (On-site Operations Engineer). Obtain samples of: Clean proppant - Pre-pad, pad, 2, 6, 10, & 12 ppa stages, and flush 12. Record proppant weight before and after the frac. Pump the 150 bbl pre-pad. Shut down for ISIP and 10 minuteJ rE u Jf - lD Calculate tubing and perforation friction from step rate data. AUG 2 1990 ~laska 0il & Gas Cons..~mmissio Anch0rag~ Messrs Bundy and Job August 16, 1990 Page 4 13. Pump fracture treatment per the attached schedule: WHTPE = Fracture Gradient = Tubing Friction = Recommended Max. WHP 4000 psi 0.70 6070' TVD 160 to 250 psi/1000' - 6600' MD (Dependent on vendor selected) 5500 psi If treating pressure during the job exceeds 5000 psi, reduce the rate to 15 bpm. 14. Rig down frac equipment. POST FRAC 15. RU Slickline Unit, tag fill and pull Petredat gauge. 16. Follow attached flowback schedule. After well has completed flowback, obtain a 24 hour test. The well should be left on 'A' Sand only production. Obtain a 24 hour well test at one week intervals. Contact Operations Engineering for a new gas lift design following evaluation of the increased productivity. STAGE FLUID DESCRIPTION KUPARUK WELL 2W-ll 'A' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 8/16/90 CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME BBLS BPM PPG DESCRIPTION LBS STG/CUM HIT PERFS BBLS GW PRE-PAD 80.0 20 0 - - 0 801 80 25.0 25 0 - - 0 25 105 20.0 20 0 - - 0 20 125 15.0 15 0 -- 0 15 140 10.0 10 0 -- 0 10 150 --- SHUT DOWN 10 MINS FOR ISIP; TUBING AND PERFORATION FRICTION CALCULATIONS; FRACTURE CLOSURE PRESSURE MEASUREMENT --- GW PAD 300.0 20 0 - - 0 3001 450 GW wi2 PPG 55.1 20 2 12/18 M CARBO-LITE 4632 601 510 GW wi4 PPG 25.5 20 4 12/18 M CARBO-LITE 4285 301 540 GW w/6 PPG 31.6 1 5 6 12/18 M CARBO-LITE 7972 401 580 GW wi8 PPG 37.0 1 5 8 12/18 M CARBO-LITE 12421 501 630 GW wi10 PPG 41.6 20 10 12/18 M CARBO-LITE 17491 601 690 GW w/12 PPG 26.2 20 1 2 12/18 M CARBO-LITE 13186 401 730 SUCK DIESEL FLUSH 58.0 +SV 20 0 - - 0 58 / 788 71 221 521 581 611 651 701 761 NOTES: TOTAL GELLED WATER TOTAL CLEAN DIESEL TOTAL SLICK DIESEL 644.6 BBLS 22.5 BBLS 58.0 BBLS +SV 12/18 M CARBO-LITE = 59987 LBS Stages 1 through 8 are Gelled Water. '- --' Stages 1&2 are Gelled Water with 5% Arctic Diesel with enough breaker for a 4 hour break. Stages 3 through 8 are Gelled Water with 4 hour breaker and without diesel. I~pondent on th~ vendor, contact Oporation~ Engino~'ing to ~ if a delayod or encapsulated breaker should Stage 9 {flush) should in¢ludo a ¥olumo adiustmont for surface oquipmont botwoon the wellhoad and densimeter. ~._. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained at + 90° F on the surface. ARCO Alaska, Inc. Post Office L .. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Kuparuk River Field Production Surveys Dear Mr. Chatterton' In compliance with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey informa- tion for the fourth quarter of 1986. Production survey information is shown in Attachment 1; information being submitted this quarter is denoted by an asterisk in the far right column. Other information listed has previously been submitted and is included to show the well history. If you have any questions concerning the information reported, please contact me at (907) 263-4364. Sincerely, F. K. Paskvan Operations Engineer FKP-SPT:pg'O053 Alaska 0il & Gas Commission Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ATTACHMENT 1 WELL APl NUMBER 1A-O1 50-029-20590 KUPARUK RIVER FIELD CONSERVATION ORDER 173, RULE 9 SUBMISSION - 4TH QUARTER 1986 INITIAL DATE OF TYPE OF REASON FOR PRODUCTION PROFILE OR PROFILE OR PROFILE OR WELL DATE SURVEY SURVEY SURVEY COMPLETION 12/81 1H-O3 50-029-20792 07/82 1H-04 50-029-20880 07/82 1H-06 50-029-20741 09/82 2U-12 50-029-21304 05/85 2U-13 50-029-21261 03/85 2U-15 50-029-21263 03/85 2V-02 50-029-21037 05/84 07/29/81 12/86 08/26/82 09/25/86 10/25/86 08/13/82 12/24/86 06/21/82 09/26/86 10/28/86 07/29/85 08/14/85 06/18/86 09/03/85 09/06/85 12/01/86 09/06/85 09/08/85 10/02/86 05/17/84 07/14/84 08/01/85 01/18/85 03/26/85 05/01/85 12/15/85 2V-O8A 50-029-2112801 09/84 ~ 1~1~~50~-029-21238 ~ C ,ED SPINNER INITIAL A&C S SURVEY POST FRAC A A/C1/ C2, 3,4 SS SPINNER INITIAL A&C S SURVEY POST FRAC A A&C SS SURVEY INITIAL C SS A&C SS SPINNER INITIAL A&C S SURVEY INITIAL Cl SS A/Cl/C3 SS SPINNER INITIAL A&C S SURVEY POST FRAC A A/Cl/C3 SS SURVEY INITIAL Cl SS A/Cl/C$ SS SURVEY POST FRAC A A&C SS SURVEY INITIAL C A&C SS SURVEY GOR CHANGE A&C SS SURVEY POST FRAC A A&C SS SURVEY INITIAL C A&C SS SURVEY GOR CHANGE A&O SS SURVEY POST FRAC A A&C SS SURVEY INITIAL C A&C SS SURVEY GOR CHANGE A&O SS SURVEY INITIAL A A&C SS SURVEY INITIAL C A&C SS SURVEY POST FRAC A A&C SS SURVEY I N ITIAL A&C A&C SS SURVEY A&C SS SURVEY POST FRAC A A&C SS SPINNER INITIAL A&C SS w'-rl ZONES PROD- UCING A&C A PRODUCTION OIL WATER GAS BOPD BWPD MSCFD 390 0 200 A A 272 0 363 A&C 553 0 1751 A&C A&C1 634 0 1623 A&C A 604 2 352 A&Cl 785 0 2649 A 1894 0 1596 A&C 2339 0 1692 A&C 1171 0 4668 A A&C A&C 866 0 2314 2464 0 3534 1488 0 16085 A&C A&C 1756 0 6817 A 143 0 64 ( EST ). A 750 0 525 A 266 0 129 a&c 3588 0 2494 a 1720 0 1892 A 995 0 1421 A&C 1720 0 1626 A&C 1181 0 6755 ARCO Alaska, Inc. Post Office Box"' $0 Anchorage, Alaska :~9510 Telephone 907 276 1215 November 14, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation- Commission 3001 Porcupine Drive, Anchorage, AK 99501 SUBJECT: conductor As-Built Location Plats - 2W Pad Wells 1-8, 9-16- Dear Elaine: Enclosed are as-built location plats for the subject.wells. you have any questions, please call me at 263-4944. . Sincerely, Gruber Associate Engineer ,. JG/tw · GRU2/L93 Enclosures If AUG 0 1 I~B§ ~,, ~. b~s Cons. Commission Anchorage ARCO Alaska. Inc. I,~ a Subsidiary of AtlanticRIchfleldCompany PHASE 3~ AS-BUILT WELLS 9 Thru 16 28 27 34 p~H ASE l' AS-BUILT WELLS I Thru 8 (NSK 9.05.22_3di) LOCATED IN PROTRACTED SECT IONS $3 & 34 TOWNSHIP 12 N., RANGE 9 E.,.,.UMIAT MER. NO SCALE NOTE- ., BASIS OF POSITION IS MONUMENTATION 2W NORTH AND P..W SOUTH PER LHD i~ ASSOCIATES. TH I S SURVE iiELL 9 Y - $,97g,g~3.a$ LAT. 70°2[g23.3353w X . 5~8,782.6Z LOIG. [~9°50'50.86~7" PAD ELEV. 63.8 G.G. [LEV. 59.7 30~ FEL 579 FNL $£C. 33 WELL [0 Y - 5,;80,039.~9 LAT. 7002~'23..8630" X - 5[8.905.09 LONG. t~;°50'53.2033" ~&O ELE¥. ~3.6 O.G. ELEV. 28! FEL 523 FNL SEC. 33 WELL !! I - 5,;80,095.05 L~T. x , 518.327.6! LCNG. PaO £L[V. 53.8 0.~. ELEV. 50.2 ~58 FEL k68 rNL SEC. 33 ~ELL 12 ¥ . 5,g80,150.70 LAT. 7G°Z!'2~.g757" X , 518,850.03 LONG. PaD ELEV. 53.; O~G. ELEV. 59.8 235 =EL ~12 FNL SEC. 33 NELL 13 ¥ - 5,g80,315.55 La?. '?0~2~'23.63~0', X . 519.183,71 LONG. P~ EL[¥. 52.7 O.S. EL[V. $7.7 )8 FWL %8 ;~L SEC. 3G WELL 1~ Y - $.;71,9§0.05 LAT. 70°2~'Z3.C927'' x . $19,!5X,31 L~NG. PAD ELEV. 6~.9 O.S. ELEV. 57.7 75 F~L 503 wELL 15 Y - $,g79,~O~.~a L~T. 70021'22.~467', X . 519.138.80 LONG. PA0 ELEV. 53.0 0.3. ~L£V. 5B.0 52 ?WL §5~ FUL WELL 15 ¥ - S,97g.g~8.Sg- LAT. 7002[~22.0005" X , $zgo1!6.25 LONG. PaD £LEV. 52.g 0.G. EL£¥. 29 FWL 715 FNL RECEIVED AUG 0 ~ ~B5 OJJ & G~.$ O::F:S (~;J.';:I'R)SSIOI~ Anchar:~.,~. DAVID F:I 5276- i ~C.~CSv C£;" cF --C- I AM PROPE~L'¢ REC~S~'ERED LICENSED "") ~RCC"'iCE L~,I'JD %UF, VFV'NG IN THE STATE OF A'.ASKA ;,:JO *HAT T~.IS "'-'_AT ~PF. iE2EI'JTS A SURVEY MADE UNDER MY F..)RECT. SUF'-_-RV;$~ON ;,r;[ IHAT ALL. DETAILS ,:,RE CjF-.~ECT AG '}'F OCTOBER 14, 1984. assag, ARCO Alosko, Inc. ='rOleC' ~jor?h SlODe ~'r,il DRILL SITE 2W CONDUCTOR AS-BUILT LOCATIONS Dote Oct. 23, 1984 I Stole AS SMOWN NEW PROJECTS ENGINEERING · FEOM: L. K. SEIT~/P. S. BAXTER MELL NAME: ~0-! / TRANSMITTED EEREWITH A_RE THE FOLLOWING: PL~.ASE NOTE: BL - BLUELINE, S - SEPLA., F - FI!.~, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: ....,,_.,--- / .A,----- / DATE: PLEASE RETURN EECEIPT TO: ARCO ALASKA, INC. ATTN: PATSY S. BAXTER P. 0. BOX 100360 -ANCHORAGE, AK 99510 .Alaska 0/I & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Alaska Alaska Off and Gas Conservation Commission 3001 Porcnp/ne Drive Anchorage, Alaska 99501 RE: Receipt of the following material which was transmitted via ~1~. .~_~!'/ ~ is hereby acknowledged: Q,,UANTITY DESCRIPTION d W-II ¢tcd RECEIVED: DATED Copy sent to sender YES .. NO _~ ARCO Alaska, Inc. ARCO Explor-~ion - Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 277 5637 HAND CARRIED SAMPLE TRANSMITTAL SHIPPED TO: ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PROKCUPINE' DRIVE 55901 ANCHORAGE, ALASKA 99501 ATTN: MIKE MINDER OPERATOR: ARCO CORE PLUGS ENDS SAMPLE TYPE: SAMPLES REQUESTED BY RENEE .BOYER ATO 10.86 DATE: MAY 20.,lg85 KUPARUK 2W-11 NAME: NUMBER OF BOXES: 14 DRY DITCH BOXES PLEASE SEE ATTACHED LIST UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND /~IL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN R. L. BROOKS ~, ~-C · ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.' '-~" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I)A'T'E: 0.~-07-85 TRAN~MIT'f'AL N0:5~78 I:;:ET UI;.:N l'O' ARCO AI_A.S'KA, INC, Al'TN: RECOI:;~I)S CLERI( A 'l" O- t 1 t .5 [4 1::',,0,, BOX t00S60 ANCHOF~AGE, Al< 99510 TI:;;ANSHI'I'TEb i"II'Zi:;~[':WII'H ARli:' fl'-Iii;. I:"'OI...LOWING RECEIF'T AND RIFTUF,:N ONI""' SIGNED CCIF'Y 01'":' ::'L.i"i;A2E ACK NOI4L. EI)bE '1' i"112 'r R A i',l 3 M I T'I' A L, I::'ZNAL PRI CBL ' S/$CHLUMBEI:ZGEF;~ t E--t 5;-", I 0'-30-84 RLJN ~,:t 7300-7895" . "~C-t 3 ~ 0 ''~ - 05 -- iii 5 R tJ N.,,- ...... .._~ 5500" 72,52 2C-'t 4 ~ 02-06-85 RUN "'C- t 5 "'"" 02 0"" = RU ':: ~'" o--8.> N t 54 0--7f 20 "~C-t 6 ~ 0.,-..-u8-85 RUN :~:t ; t 75 8280 ,,:.. ~ ~ -', .,. 2(;-t 5 I 0"27-84 RUN :~'t 4'790-6882 ~'. I..'~ · I:' S!G-t 6 ~ t 0-~7-8'1 RtJN .i:t ...,.o..>0-7736 2t.l-t 5 ~""/" 02-t 0-8.5 RtJN :11:1 6400-,5985 '.i.2~4.-9 '''/ 0t-0t-85 i:;:UN~:t 5700-7786 "~W--I t~'"' Ot-0''~-n~'~' RUN ~,",-'t 2'"';66-6640 .-:.W- t...':-~'~"(-)t-'0'~-85~. RUN :'-': t ..o640-79'7t -.">W--t 6'''/' 02-0t -85 I'?tJN.,. .... t 4?;86-6982 "2X-t 4'''''"'~ t t -t ',"'-8'1 RUi',I:,~:t 4396-7874 _- RECE ]'i:'T ACI<NOWI_EI)GEI) · BF'AE ~,~'DI:;:ll I..IN[;'-BI... W. I::'ASI-IER ~ I' " ~" '"N . I.::, CURRI[.:'R L ,.JJl..lr4.::,'[O~i EXXON C I--1E V R 0 N M (3 B ] I. F'I"I I 1..1_ I F:' S 01 L D & M ~(' N 5' K '3 L 1":: R K -' BI .... J, R A'i" H MI'Z L. L 19%. PATE: Alaska Of 8. &:'~s Con'..;. Oornmi.%ior. · x.S'T'A'F E (.:iF ,f,' 0 I..I I 0 /.S' E UNION -x-I(. TULI N/VAULT--F I L.H ~ AP~CO · CO~'B{ENTS / CORRECTIONS ' THIS LIST EXCEPT AS' NOTED IN COMMEMTS AND CORRECTIONS, REPRESENTS A COMPLETE LIST OF SAMPLES DUE THE STATE OF ALASKA, PLEASE SIGN AND RETURN THIS FOP~ TO i' E.A.. ENDICOTT, ABV-100 ARCO Alaska, Inc. Date: MAY 8, 1985 Internal Correspon¢ ';e Subject: KUPARUK 2W-11 PLUG ENDS FOR THE STATE OF ALASKA From/Location: To/Location: EVA ANN ENDICOTT PALEO LAB MI,.,. ,,,.RNER-IATO i-0-6~' ID~ ~ DEPTHS 2552 2597 ~--_ 2ss3 2554 2599 2555 2600 2336 2601 2337 2602 2338 2603 2339 2604 2360 2603 2361 2606 2362 2607 2363 2608 2364 2609 2363 2610 2366 2611 2367 2612 2568 2613 2569 2614 2570 2615 2571 2616 2572 2617 2373 2618 2374 2619 2373 2620 2376 2621 2377 2622 2378 2623 2379 2624 2380 2623 2581 2626 2627 2583 2584 2585 2586 2587 2588 2589 2590 2591 2628 2629 2630 2631 2632 2633 2634 2635 2636 2637 2638 2639 2640 2683.8 2641 2684 2642 2685 2643 2686 _.~ 2644 2687 2645 2688 2646 2689 2647 2690 2648 2691 2649 2692 2650 2693 2651 2694 2652 2695 2653 2696 2654 2697 2655 . 2698 .~265~6~ t'2t__~. 2699 2657 2700 2658 2701 2659 2702 2660 2703 2661 2704 2662 2705 2663 2706 2664 2707 2665 2708 2666 2709 2667 2710 2668 2711 2669 2712 2670 2713 2671.3 2714 2672 2715 2673 2716 U 2674 '--2-717---- 2675 2718 2676 2719 2677 2720 2678 2721 2679 2722 2680 2723 2681 2724 2682 2723 2683.3 2726 2727 2728 2730 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchlieldCompany Am~m_mnnl 2731 2732 2733 2734 2735 2736 2737 2738 2739 2740 2741 2742 2743 2744 2745 2746~ 2747 2748 2749 2750 2751 2752 2753 2754 2755 2756 2757 2763 2764 2765 2766 2767 2768 2769 2770 2771 2772 2773 2774 2775 2776 2777 2778 2779 2780 2781 2782 2830 2783 2831 2784 2832 2785 2833 2786 2834 2787 2835 2788 2836 2789 2837 N.S. 2790 2838 2791 2839 N.S. 2792 2840 2793_,~..~.,.~. 2841 2794 2842 2795 2843 2796 2844 2797 2845 2798 2846 2799 2847 2800 2848 2801 2849 2802 2850 2803 2851 2804 2805 2853 2806 2854 2807 2855 2808 2856 2809 2857 2810 2859 2811 2860 2812 ~1 -- 2813 2862 2814 2865 2813 2864 2816 2863 2817 2866 2818 2867 2868 2869 lO 2870 2871 2823 2872 2824 2873 2825 2874 2826 2875 2827 2876 2828 2877 2829 2878 2879 'ARC(J KUPARUK 2W-11 PERM PLUG ENDS DEPTHS 288O 2881 2882 2883 2884 2885 2886 2887 2888 2889 . j ~ Bill Sheffield, ' ;ELEPHOHE(IO~ Z~l-14JJ :to, ~AI~O ._~. LtI.fKA T_NC. _ ~ ~~n.'~B E CK Y . ~T~NE~ ~ ~.~ - '~'.. /. · ~l)ich our recorde. ~,,at¢~a ~ completed,/~-~~~' ~ Article 536(b) of Title 20, 'Ch,pter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above miosing materta.l. · · lc~C.024 ARCO Alaska, Inc. Post Officx'~ox 100360 Anchorage=, Alaska 99510-0360 Telephone 907 276 1215 DATE: APRIL n.,'~ t985 TRAN,?MITTA[. NO' Si4!!! ""E'FURN TO' ARCO ALASKA, Ih'C. ATTN: RECORDS CLERK ATO--i t i.SB F:', 6.1, BOX i 0'F.:'366' ANCHORA(;E, -Al< 99~'I¢ , ' .~- T" . hit .......... , "~ ¢' * .. TRA,~P. MT. FTc..,' HERE ....... TI"I AF<E' TI'iF F'OI..l Fi[:J_IN~ ITEM~?, FI_E.H~:-E' ~C'I'..'.NOI,,J/_EI)[;E -.,'-F- .. T ND .... n.'. I-,,.:: .... E'rF' A RE'TII N ON[[ ,.?,.TGI'4EI) COF'Y OF THIS TRANSMI'FTAL, .~ (JE/l N ,'=OE/F'ROD LOG & 'A' SAND F'BU :?OE/F'BU (INITIAL F'RE35'URE) YOE/F'BU £OE/F'BU $OE/F'BU ~f]lY// I i - ~ ~,,.. C SAND F'BU I'I:!RMITTENT' LIFT PRESSURE 'C' SANDS SOE/SBI-IF' - 'A I STATIC BHP DATA STATIC BHF' DATA STATIC BHF' DATA STATIC BHF' DATA STATIC BHP DATA STATIC-BHP DATA STATIC BHP DATA STATIC BFIF' DATA STATIC BHF' DATA STATIC BHF' DATA STATIC. ~"' ' .. ::,,-IFDATA STATIC BHF' DATA STATIC BHP DATA 3TATIC BHP DATA S'TATZn [~,-.IFOATA ~TATIC ~'~.~P OATA STAT~ZC - ~,,~'""~',, DATA ~TATiC BHF' DATA STATIC BHP DATA ~TATIC BHF' DATA ~"rATTC BI'IP B~,~ ~TATIC BHF' DHT~ SURVEY :::','E CE l F'T AP.':NOL!LEDGED_,..,. · :..'ISTRIBU'Fi ON: DRILLING W~ F'ASHER L :n'--'X'~TON =VVFIN ~ --..~,~ t i i ~,.~. I.. ~"-, ~% ..ii. MOBIL F'HILLIF'S OIL NS!< CLERK J. RATHMELL ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 416-7/85 3/i i/85 '. ~/-~ ~/o5 · 312/85 3t~/85 3/4/85 3/J 8/85 J/24/85 J/24/8~ 3/3/85 3/2/8~ 3/2/85 3/2/85 S/J 9/85 3/~ 9/85 J/2J/o~ 3/24/8~ ~;/26/8~ i/2D/BY i/Si '~ f/~/85 i/f t/8~ t/24-/8~; RECEIVED APR 2 5 1985 Alaska Oil & Gas_~Cons. Commission : Anch~a~C l 0 N TWI_ I N/VA U L T STATE OF ALASKA ALASt. _ OIL AND GAS CONSERVATION COMk_ SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate !~ Plugging [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360, Anchoracle, Alaska 99510 4. Location of well at surface 468' FNL, 258' FEL, Sec. 33, TZ2N, RgE, UM At top of productive interval :1028' FSL, 912' FEL, Sec. 28, T12N, R9E, UH At effective depth FEL, Sec. 28, T12N, R9E, UM 6844' 6121' feet Plugs (measured) feet At total depth 1473' FSL, 1093' Junk(measured) Perforate [] Pull tubing 5. Datum elevation (DF or KB-"~et 22,68 6. Unit or Property name Kuparuk River Unit 7. Well number 2W-11 8. Approval,number 9. APl numb'er 5O-- 029-21238-00 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 6844' feet true vertical 6121' feet 10. Pool Kuparuk River Oil Pool 14. Attachments Subsequent to operation 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 321 139 5 1380# 166# 603 298 13 1450# 162# Daily Report of Well Operations (A Sand Only Rates) Prior to well operation Packers and SSSV (type and measured depth) Baker FHL @ 6200'; Baker FB-1 @ 6572', SSSV Baker FVL @ 1899' 12. Stimulation or cement squeeze summary 271 BBL gelled diesel 20580# 20/40 Mesh Sand. Intervals treated (measured) 6696'-6704', 6710'-6760' 6766'-6782' 6786'-6792' 6803'-6810' Treatment description including volumes used and final pressure ' ' ' Tubing (size, grade and measured depth) true vertical 3 1/2", 9.3 lb/ft, J-55, 6603' Perforation depth: measured 6360'-6494' 6508'-6514' 6696'-6704' 6710'-6760' 6766' -6782' 6786' -6792' 6803' -6810' MD Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~,~...4/f.C~c~'~~,.~'CtCf/¢,,.,,.¢~.-/~ Title .~ ¢/,~,,E~.x,~/~.¢.~;~-~ ~'.~-~' Form 10-484 F~ev. 12¢/'85 Submit in Duplicate Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 90' 16" 265 Sx C.S. II 90' 90' Surface 2476' 9-5/8" 750 Sx A.S. III & 2476' 2476' Intermediate 300 Sx Class "G" Production 6926' 7" 610 Sx Class "G" 6926' 6162' Liner AR CO Alaska, . -? Subsidie~y of Atlantic Richfield Comp~ CONTRACTOR ~:~" TI T~ M/,,~O GEA 5 REMARKS ... IFIELD - DISTRICT- STATE oPERATI(~'N AT REPORT :rIME WELL SERVICE REPORT / -~ .. · ; / ¢~ ,,o,,~ /JO 4t /,a o /,3 o - ,~/~ /~' a ~ z '~." ' /~ " ,.. . [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK We~herRel~.~rt Temp' "F Ichill Fact°r vlsibility'F miles Iwind vel' .. . ARCO Alaska, Inc. Post Office Bo.~ ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Revised Well Completion Reports Dear Mr. Chatterton- Enclosed are revised Well Completion Reports for the following wells' 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 2198§ Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany ,~-"- STATE OF ALASKA .... ALASKA .L AND GAS CONSERVATION Cf. ~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well R £V I S I ON OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-222 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21238 4. Location of well at surface 9. Unit or Lease Name 468' FNL, 258' FEL, Sec.33, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1028' FSL, 912' FEL, Sec. 28, T12N, RgE, UM 2W-11 At Total Depth 11. Field and Pool 1473' FSL, 1095' FEL, Sec.28, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 94' RKBI ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ( 15. Water Depth, if offshore (16. No. of Completions 12/11/84 12/20/84 12/23/84J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6950'MD,6174'TVD 6844'MD,6121 'TVD YES [~X NO []I 1900 feet MD 1460' (Approx) 22. Type Electric or Other'Logs Run GR/SP/DIL/LSS, SHDT, LDT/CNL/GR~, EPT/ML/GR~ FDC/CNL/GR, D IL/Cal, .Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASiNGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 90' 24" 265 sx Cold Set II 10-3/4" 45.5# J-55 Surf 2476' 13-1/2" 750 sx AS III & 300 sx Class C 7" 26.0# J-55 Surf 6926' 8-1/2" 610 sx Class C & 246 s~ AS I 24. Perforations open to Production (MD+TVD of Top and BOttom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6810' - 6803' 6508'-6514' 3-1/2" 6602' ~;201' & ~;~;7~' 6792' - 6786' 6360'-6494' w/12 spf, 6782' - 6766~ ' 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6760' - 6740' w/4 spf, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6740' - 6730' 120° phasing N/A 6730' - 6720' 6720' - 6710' 6704' - 6696' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO ITEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~las~a 0il & Gas,_ _....¢°~s' (;0mm~Ssi0r" Form 10407 JMM2/WC27 t~I~ut~u'~u' Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · :~ -% ~'. ~¢~'~ ~' :~' ¢~: ,;' ~";': .'- -'-~'1-~ ¢~ :~-.' ~-~- ..~-.~ ~ .... : ' r., ~. ¢-~ ~ ? ' ~ . NAME Include interval tested, pressure data, all fluids reCover~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6384' 5878' N/A ,~.~ , ~ "'~' ~se Upper Sand 6~9fi~ 59~3~ . .. '~?~ :~ .: :: - ... . · :. ~ .~: 2 ,;~ ~ . . : . . ,-.~.. . ., . .~. , 31. ~IST OF~TTACHM~TS .. 32.' ..... I herebg ceriifg that ~he forenoon~ 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". TO: DATE: / - TRANSMITT-XD EERE%'ITH ARE TEE YOL~O%qiN~: PLF. kS E NOTE: FROH: L. K. SMITH/P. $. BA1/rER ATO/.5tD7 ./ ARCO ALASKA, INC. ATTN: PATSY S. B:-D~iER P. 0.' B'0X'100360 >.NCHORAGE, AK 99510 ARco Alaska, Inc. Post Office ~,.,x 100360 Anchorage, Alaska 99510-0360 'Telephone 907 276 1215 (' L"l i",[ E c c) F:' Y 0 F:' E r.':i C I"1 ) .. . , I) "-'T',":; · .... ,.5/ '..: ," i i .... i'll ,;.. ' S' iii H r ci -,, · Lib] ]; o:,, ','. ......... I...i il.' .~, -- ,~ .¥.[!! '!'-, ~,.,, :~, -,.. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 2, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2W-11 Dear Mr. Chatterton' Enclosed is a copy of the 2W-11 Well History (Completion Details) to include with the Well Completion Report dated 02/20/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L82 Enclosure ?,ECEjVED Alaska Oil & Gas Cons. Anchora,o,oe ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Post Offic~ ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 I:." ..;. I (')-:5 ',' ,::' "I" '"l I"" ":/~E Y J. ! ,.':- ... i':; ~.'~' ! '", ~, ,' I'" '*" t.., ~ '. ': iZ. ~' 'r ~::'"," '? ~ i ;;' :,,/r' ~.-- ,.~ ~ ~.;-...,; . ,... , .,'-":',, .? !... ]] F:' T ':"1 ~ ~:;' ',,;' F:i Y' '-':' 'T' ][ ........ "" ][ CI ~ ........................ ~-i .... L. il 5;! lc' c,,r..]] F:' F;.'. ........ i~]j ,-.. l"l... "r, :-'1';l=-'l:;.~::ii'~. ~'-"-'~, .!. ...... :-~¥'.', r='"' r'. ~--~ ,--.-.. ~-~ .,':ti , . ;..- U ._.l Ii!:-."::; T ]1: r:) i',J ,:k! i'_) E,' ,~i::' !-( ,..n !,.I i',! ~'~ ,;.. ,::' ~::' r';.. -:" .; ....... '~' T-,' F:: I":' D U N; 2 I':' 5/.i-'; l:i .L' ..... -. .. ...... ,~,J. I";.. Ii-,' I--I F' !... V ' 5; ;.. '[ 'r'-, .......... C *'"':'J i:'i ['_'. 0 (-.! ",," .T. Z 0 'T' :I: ,~{.' C] T'I ;~-...' "' :"- -',.'~ I '" ! '" J.... r'l ~ · ....- ,...1 [..il .I. ,.':. CI 'i" ]; ,!;' :B .... ~ I. !U C-,.! IE,?..' · I' r i'l" .~. ,? "'" '"-:[ ,i';' I" [:':i i"'i I"' i", ...... . %., " 'L' C: r.:~ H,.: I ?, i"'i !.1 I~' I ..' %., '.-'-! h.. I.,. L.. ..-' '...- .~ i... ~., ~.- ~;] '!-]; 5/ 'q . I I"I! l ii. ~ ' c' ','. I}: ,.J I I L.I (;~ !.-I E,?;' () 'i" ;[ C ;::; i"i !.~ O C;/:'..' i"'i C: C) ~"~ '~' ;I; '" ... ,.;- [1i T .[ ;!-7 (3 '~' ]; ,!';' C~ i" ii; ,i,.' 1.9 T ]i ,!;' I"'I ·i" 'r -.'- .... ,. ~.;. , -. I:;:F.. C !!?. I F:' T A N D . R E T Ui? N--, 0 N. IE. 5' I (; NI!'" D. C, 0 F' Y .. . . ARCO Alaska, Il> - , ' Post Ollice I](~x 360 ...... Anchorage, Alaska 99510 Tele.phone 907 277 5637 ., .. . A F:,' C i:) l.".~1... A,.~ i< A, ' I i",! C' l':.'i'i' l' iq ' '" ......... ' I::. I'~ K I'~i:: L, UI'~ I)5' Cl...' ' .... ',ATO .... ~l'iSB · F:'.O,, ]BOX Ai",ICH(]F::A(.;I.:.', Al( ~79'.5 t (') H I:!: R Ii!: [4.]: T I't- .. i F:' I... I!i: A 5' Iii: A C I< iq CI [4 !..: I!i: I) C Iii: ..... ,. , · · , ., -,, , ~ ,.! 2t, J .... i 3 ,")il '3, !::' (-" F;: (] , , , · . . ,, F:: A I,,I I::' I.'] I:(: 0 !:;: A (,J F:' O I:~: I:;: A tJ F;: IZ (] I!!: I F:' 'F. A C Iz, i"-.! (:) 14 I_ Ii.". I) (] I!~. !): ' ............. ' ............. "" i:; !:i! :ii;":f i!; ii :i: '!i: ;:'i ....................... · . I ~-.~,.;lil:.l", .F,F'Fii!E -:,(- I) l::: I i... I... ]: !',~ (.-:- ( t "' I?.l... ) t,.!., "-"( ...... ¥:' I:;: '"'"" ~,.,,, C U i:;: ]: ,.:.l,, I..[' -,.!'()1 Ibl f/T C) N l::'.. ).':. X [:) CI II'!:\/I.':.:()H i'lO)] I I... F:'I--! :[ I...I... I F'2 (] "I... · ~' I) · C~. Iii :5 .'i.:; 0 ..- 9 0 -5) 6 41"4 4.'"' 9i t Ii) lii."j~ 5 0 .... 9 0'9 6 8.3'5 (') .... 9 0 :? 6 4 t 'ii.,. 4'.,-9. i t ":',., .,4t44 .... 9.ti!ii 8'.:5'5 0 .... ";.;' 0 5 (> · . · ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-11 Dear Mr. Chatterton' Enclosed is an addendum to the 2W-11 Well History to include with the Well Completion Report dated 02/20/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L39 Enclosure RECEIVED 2 6 1985 Alaska Oil & GaS Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany DATE: ~-it- ~._~ . - TRANSMITTED HEREWITH ARE. THE FOLLOWING: FROM: L K. SMITH/P. S. BAXTER pLEASE NOTE: BL - BLUELINE, S ' SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Alaska Oil & Gas Cons. Commission Anchorage RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: , AE~ALASKA, INC. '~TTN: PATSY S. BAXTER P. O. BOX 100360 ATO/507 ANCHORAGE, AK 99510 DATE: ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-11 Dear Mr. Chatterton: Enclosed is a copy of the 2W-11 Core Description to include with the Well Completion Report, dated 02/20/85. If you have any questions, please call me at 263-4944. Sincerely, · . Gruber Associate Engineer JG/tw GRU5/L14 Enclosure P, ECEiVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B'6'~J360 Anchorage, Alaska 99510 Telephone' 907 277 5637 Date: 03/07/85 Transmittal No: 5079 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 _~rage,~/. AK 99510 · f,~ansmitted herewith are the following items. Wand return one signed copy of this transmittal. Please acknowledge receipt .Open Hole FINALS (One * of each item listed below) Schlumberger 2E-11 2" DIL/SFL-GR 12-16-84 Run #1 5" DIL/SFL-GR 12-16-84 Run #1 2" Density/Neutron-GR 12-16-84 Run #1 5" Density/Neutron-GR 12-16-84 Run #1 2" Density/Neutron-GR 12-16-84 Run #1 5" .Density/Neutron-GR 12-16-84 Run #1 ' 5" Cyberlook 12-16-84 Run #1 4079-8358 4079-8358 4079-8~58--(Raw Data) 4079-8358--(Raw Data) 4079-8358--(Porosity) 4079-8358--(Porosity) 4079-8358 2W-11 Gamma Ray log 01-04-84 Run #i 6413-6839 Receipt Acknowledged: DISTRIBUTION B. Currier BPAE * Drilling (blueline) ,. W. Pasher ,. Geolog~L. Johnston Exxon Sohio Chevron * D & M(blueline) Mobil NSK Drill Clerk (blueline} Phillips Oil ~J. Rathmell Union * K. Tulin/Vault(Films) ARCO Alaska, Inc. Post Office Bb..,,~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 25, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-11 Dear Mr. Chatterton: Enclosed is the 2W-11 Core Description to include with the Well Completion Report, dated 02/20/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L184 Enclosure RECEIVED FEB 2 7 1985 Alaska 0il & Gas Cons. Commissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany ARCO Alaska, Inc.. Post Office B'~'~x '100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 20, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-11 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2W-11 Well History covering the completion details or the core description. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L160 Encl osures Al~f~ora£e' Oo~rai~ion ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~,r~--AND GAS CONSERVATION CO~..vllSSION WELL COMPLETION OR RECOMPLETIO# I:IE ORT AND LOG 1. Status of Well Classification of Service Well . OIL [~X GAS I-1 SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-222 3. Address B. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21238 4. Location of well at surface I 9. Unit or Lease Name 468' FNL, 258' FEL, 5ec.33, T12N, R9E, UM !' Kuparuk River Unit At Top Producing lnterval tc~r~ ~ i.f ~. , 10. WellNumber 2W-11 '~l ..r~ · ' ---------i At Total Depth 11. Field and Pool 1473' FSL, 1095' FEL, Sec.28, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 94' RKBI ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/11/84 1 2/20/84 1 2/23/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21. Thickness of Permafrost 6950'MD,6174'TVD 6844'MD,6121 'TVD YES [-~X NO [] 1900 feet MD 1460' (Approx) 22. Type Electric or Other Logs Run GR/SP/DIL/LSS, SHDT, LDT/CNL/GR, EPT/ML/GR, FDC/CNL/GR, D IL/Cal , Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 90' 24" 265 sx Cold Set !1 10-3/4" 45.5# J-55 Surf 2476' 13-1/2" 750 sx AS Ill & 300 sx Class G 7,, 26.0# J-55 Surf 6926' 8-1/2,, 610 sx Class G - · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6810' - 6803' 6508'-6514' 3-1/2" 6602' 6201' & 6573' 6792' - 6786' 6360'-6494' w/12 spf, 6782' - 6766' 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6760' - 6740' w/4 spf, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6740' - 6730' 120° phasing N/A 6730' - 6720' __~6720' - 6710' 6704' - 6696' 27. N/A PRODUCTION TEST Date First Production Method of Operation (FloWing. gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER~BBL CHOKE SIZE GA'S-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED~ OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Will be submitted when received. Alaska Oil & Gas Cons, Commiss'~ Anchorage Form 10407 GRU4/WC40 Submit in duplicate _ Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... ' GEOLO~i'~..MARK[=R~ ;-:'"' ::':~' :;' '::'"':I~'~:'R~-AT~N:~'E~TS:: '~ ~.::: -:" --'-:: '_:: · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, a0dtime of each phase. Top Upper Sand 6384' 5878' N/A Base Upper Sand .6496' 5943' 31. LIST OF ATTACHMENTS wol~ ............ ~ .... J, n _ ........ . ~ q ........ (2 cep,.'es) 32. I hereby certiG ~'h~ ...... ' foregoing is true and correct to the best of my knowledge Signed ~ ~/~ ,~-,~(('k/-/L--' Title Associate Engirleer Date ~'~(~'~'~' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached Supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Inslmcflone: Prepare and submit the 'lnlllel Reporr' on the first Wednesday after a well is spudded or workover operations are started. Daily wori( prior to SPUdding should be summarized on the form giving inclusive dates only, District Alaska Field Kuparuk River Auth. or W.O. no. AFE 203645 Roll'N #4 Operator ARCO Alaska, Inc. ICount, parish or borough North Slope Borough ILe~eorUnit ADL 25642 ITitle Completion State Alaska JWell no. 2W-11 API 50-029-21238 ARCO W.I. Pr or status if a W.O. Spudded or W.O. begun Complete IDate 2/4/85 I"°ur Date and depth as of 8:00 a.m. 2~04/85 2/05/85 2/06/85 2/07/85 2/08/85 Complete record for each day reported 0000 hrs. 7" @ 6926' 6847' PBTD, 6950' TD, Load 2-7/8" pipe on racks 10.2 ppg NaC1/NaBr Accept ri~ @ 0000 hrs, 2/4/85. ND tree, NU &tst BOPE. 7" @ 6926' 6847' PBTD, 6950' TD, RIH w/csg scrpr 10.0 ppg NaC1/NaBr RIH w/2-7/8" tbg. CO cmt to 6886', circ, POH. Chg BHA, RIH. 7" @ 6886 10.0 Circ SPF, 6782 6926' ' PBTD, 6950' TD, Perf'g ppg NaC1/NaBr to cln brine. Tst csg, POH. RU WL, perf w/4" csg gun, 4 120° phasing. Perf f/6810'-6803', 6792'-6786', '-6766', 6760'-6710', 6704'-6696'. 7" @ 6926' 6886' PBTD, 6950' TD, Bldg 3½" compl jewelry 10.0 ppg NaCl/NaBr RIH w/4" csg gun, 4 SPF/120° phasing, perf f/6720'-6730'. RIH w/5" csg gun, 12 SPF/120° phasing, perf f/6508'-6514', 6360'-6494'. Rn 6.125" gage ring/JB to 6650', POH. RIH w/FB-1 perm pkr & tailpipe assy, set pkr @ 6572' WLM (top). RIH w/3½" CA. 7" @ 6926' 6886' PBTD, 6950' TD, Displ'g well to crude 10.2 ppg NaC1/NaBr Rn 197 jts, 3½", 9.3#, J-55 IPC 8RD EUE tbg, circ hole, set pkr. Shear out of PBR & lnd tbg. Set BPV, ND BOP, NU tree. Pull BPV, set tst plug &tst tree. Displ well w/crude. FB-1 Perm Pkr @ 6572.75' - "D Nipple @ 6590.90' TT @ 6603' - FHL Retrv'l Pkr @ 6200.67' 56.24% The above is correct Signature For form preparation and dlstrlbut~n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 3/4/85 JTitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday attar allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is 'available. I Accounting District County or Parish ~ State Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25642 Auth. or W.O. no. ~T t e AFE 203645 I Completion cost center code Alaska no. 2W-11 Roll' N t14 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 2/11/85 API 50-029-21238 A.R.Co. W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well Date IHour J Prior status if a W.O. 214/85 / 0000 hrs. ] Complete record for each day reported 7" @ 6926' 6886' PBTD, 6950' TD, RR Diesel/Crude Find displ'g well to crude. Tst top of pkr, SSSV & orifice vlv; OK. Set BPV. RR @ 1000 hrs, 2/8/85. Old TD New TD Released rig Date lO00 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth 6950 ' IKind of rig 2/8/85 I IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 6886' PBTD Rotary Well no. ~ Date Reservoir Producing interval Oil or gas Test time Production Oil on' test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date I Title ~ ~ 3/04/85 Drilling Superintendent For form preparation anti'distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 12/31/84 2W-11 Arctic Pak w/250 sx AS I, followed w/86 bbls Arctic Pak. Drilling ~uperint~ndent RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ' - v Date 2W-11 CORE DESCRIPTION Core #1 Core #2 Core #3 Core #4 Core #5 Core #6 Core #7 Core #8 Core #9 Core #10 Core #11 Core #12 Core #13 2552' - 2582'; recovered 8' interbedded silty sandstone & sandstone 2582' - 2597'; recovered 31' 13' very fine grained sandstone; interbedded silty sandstone and mudstone 2597 - 2627'; recovered 29.5' mudstone and siltstone 2627 - 2657'; recovered 33.5' mainly sandstone with interbeds of mudstone 2657 - 2687'; recovered 22.5' 10' sandstone; interbedded siltstone and mudstone 2687 - 2717'; recovered 34' 10' sandstone; interbedded siltstone and mudstone 2717 - 2747'; recovered 11.5' interbedded siltstone and sandstone 2747 - 2763'; recovered 31.5' 8' sandstone; interbedded siltstone and mudstone 2763 - 2793'; recovered 29.5' 8' sandstone; interbedded siltstone, silty mudstone and sandstone 2793' - 2823'; recovered 25.5' 11' sandstone; interbedded silty sandstone and mudstone 2823' - 2853'; recovered 14' interbedded silty mudstone and silty sandstone 2853' - 2860'; recovered 24' 5' sandstone; interbedded siltstone and mudstone 2860' - 2885'; recovered 29' finely interbedded sandstone and siltstone GRU5/CDO2:tw RECEIVED A{ask2 Oil & Gas Cons. Commission Anchorage, ARCO Alaska, Inc. Date: Subject: Internal Correspond.~ ~. · February 19, 1985 Report of Kuparuk 2W-11 Core for State of Alaska From/Location: To/Location: S. A. Schreiber - ATO/1084 J. Gruber - AT0/1478 A total of 334' of core was cut in the West Sak Sands interval, with 97% cumulative recovery. Coring began at 2552' MD and ended at 2885' MD. The top of the West Sak is at 2620' MD, and the base of the interval coincides roughly with the K-12 marker at 2959' MD. The West Sak interval consists of moderate to thinly layered sands interbedded with siltstone and mudstone. CORE # CUT RECOVERED 1 2552-2582 2552-2560 2 2582-2597 2560-2593 3 2597-2627 2597-2626.5 4 2627-2657 2627-2660.5 5 2657-2687 2660.5-2683 6 2687-2717 2683-2717 7 2717-2747 2717-2728.5 8 2747-2763 2728.5-2760 9 2763-2793 2763-2792.5 10 2793-2823 2792.5-2818 11 2823-2853 2823-2837 12 2853-2860 2837-2861 13 2860-2885 2861-2890 REC£tVED Sue Schreiber Geologist ~ ~ 7 ~9~ ,~-,-~ 0it & Gas ~o~,~. ~ommtsst0n SAS/kb .. ~0~--_~ -'-~,' _'~Bchorag6 cc: Wellfile - Shallow Sands KRU 2W-11 -- ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRichfieldCompany A I:lRl~-Rfl('ll AtlanticRichfieldCompany Daily Well History-Initial Report Inalrucllone: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be sumrnadzed on the form giving inGlusive dates only. District I County or Parish I Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. ITitle I AFE 203645 North Slope Borough ADL 25642 Drill, Complete & Perforate IState Alaska Well no. 2W-11 Parker 141 API 50-029-21238 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate I Spudded Date and depth as of 8:00 a.m. 12/11/84 12/12/84 12/13/84 12/14/84 Complete record for each day reported I A.R.CO's 56.24% W.I. IHour IPrior status if a W.O. 12/11/84 0645 hrs Accept rig @ 0300 hrs, 12/11/84. NU diverter sys. 10-3/4" @ 2476' 2490' (2380'), ND Diverter Sys Wt. 9.4, PV 8, YP 9, PH 8.5, WL 18.6, Sol 8 Spudded well @ 0645 hrs 12/11/84. Drl 13½" hole to 2490', 10 std short trip, POH. RU to rn 62 its 10-3/4" 45.5 ppf, J-55 Butt csg to 2476'. M&P 750 sx AS III w/ 1/2#/sx D-29, followed by 300 sx CL "G" w/2% S-1 & .2% D-46 @ 15.8 ppg. Displ using rig pmps, bump plug. tIP @ 0515 hrs, 12/12/24. Floats held. Good rets thruout job, cmt rets to surf. ND diverter sys. 10-3/4" @ 2476' 2587' (97'), Coring Wt. 8.7+, PV 8, YP 8, PH 10.5, WL 14.3, Sol 3.2 ND diverter sys. NU &tst BOPE. PU BHA, RIH, tag FC @ 2394', tst csg to 1500 psi. Drld cmt & float equip + 10' formation to 2500'. Tst form to 12.5 ppg EMW. Displ spud mud w/polymer sys. Control drl to 2552', POH. PU core bbl, RIH, core #1 f/2552'-2582', rec'd 8-1/2'. Core #2 f/2582'-2587'. 10-3/4" @ 2476' 2704' (117'), Coring @ 2704' Wt. 8.9, PV 10, YP 10, PH 11.0, WL 11.2, Sol 4.3 LD core #2, rec 31' (part of core #1). Core #3 f/2597'-2627' rec 29-1/2'. Core #4, 2627'-2657', rec'd 33.5'. Core #5, 2683'-2687', rec'd 22.5'. Core #6 f/2687'-2704'. RECEIVED 0il & Gas Cons. Commi~l~ An~0rage The above is correct For form preparation and d atrtbutlon,/~ see Procedures Manual, Section 10, v Drilling, Page~ 86 and 87. IDate I Title 1/2/85 Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructione: This form is used during drilling or workover operations. If testing, coring, or per/orating, show formation name in describing work performed. tVum~er all dritl stem tests sequentiaJ;y. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. J County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25642 Complete record for each day while drilling or workover in progress 12/15/84 thru 12/17/84 12/18/84 12/19/84 IState Alaska JWell no. 2~-11 10-3/4" @ 2476' 3271' (567'), DD Wt. 9.2, PV 10, YP 10, PH 9.5, WL 10.2, Sol 6 Fin Core #6, 2692'-2717', rec'd 34'. Core #7, 2717'-2747' , rec'd 11-1/2'. Core #8, 2747'-2763', rec'd 31-1/2'. Core #9, 2763'-2793', rec'y not avail @ rpt time. Core #10 f/2793'-2823', rec'y not avail @ rept time. Core #11 f/ 2823'-2853', rec'd 14'. Core #12, 2853'-2860', rec'd 24'. Core #13, 2860'-2885', rec'd 29'. MU bit, RIH, drl to 3020', circ for logging rn, POH. RU Schl & log f/3022'-2478' w/GR/SP/DIL/LSS w/waveform digitizing. Rn LDT/CNL/GR f/3022'-2478'. Rn EPT/ML/GR f/3022'-2478' WLM. Rn SHDT f/3022'-2478' WLM. Shot 30 SWC'S. PU BHA, RIH, attempt to orient DD. Gearhart tool went out. Chngd out same. RIH. Orient DD. DD to 3271'. 3145'MD 6° N29.3W 3145'TVD 7.6'VS N6.6 4.7W 10-3/4" @ 2476' 4504' (1233'), DD Wt. 9.3, PV 12, YP 11, PH 9.5, WL 8.8, Sol 7.5 DD & surv 8½" hole to 3757', POH. PU angle bldg rotary assy, RIH, drl to 4247'; could not achieve good angle bldg rate, POH. ?U DD + 2° bent sub, RIH, DD to 4504'. 3268'MD 10.8° N25W 3266'TVD 26'VS N23 12W 3516'MD 18.1° N28W 3506'TVD 88'VS N80 38W 3912'MD 21.5° N25.5W 3878'TVD 225'VS N201 103W 4212'MD 23.9° N28W 4154'TVD 341'VS N307 151W 10-3/4" @ 2476' 5760' (1256'), Drlg Wt. 9.4, PV 13, YP 11, PH 9.5, WL 8.9, Sol 9 DD & surv to 5469', POH. PU rotary angle bldg assy, rm 5015'-5045', drl to 5760' 4480', 26.7°, N27W, 4389 TVD, 452 VS, 407N, 201W 4794', 31.5°, N24.5W, 4663 TVD, 605 VS, 544N, 268W 5072', 36.5°, N28W, 4894 TVD, 759 VS, 682N, 338W 5383', 35.4°, N24W, 5144 TVD, 943 VS, 849N, 421W 5614', 37.7°, N27W, 5331 TVD, 1078 VS, 970N, 482W 5708', 39.6°, N22.5W, 5405 TVD, 1137 VS, 1023N, 506W The above is correct Signature For form preparation a~'d di~rib[Jt~j~n -- ~ see Procedures Manual Section 1~, Drilling, Pages 86 and 87 IOate 1/2/84 ITM Drilling i V E D A/aska Oil -& Gas Cons, Commission Anchorage ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH ddt~ stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnferlm" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25642 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. Alaska Well no. 2W-11 12/20/84 12/21/84 The above is correct 10-3 6766 Wt. Drl @ 63 tst 6766 5833 6135 6209 6411 /4" @ 2476' ' (1006'), Drlg 10.2, PV 12, YP 11, PH 9, WL 8.1, Sol 10 to 6325', circ gas cut mud. Drl to 6434', lost 60 bbls mud 25'. Chg swivel packing, drl to 6447', POH, LD GO tls. PU tls, tst BOPE. PU BHA, RIH, precautionary rm 30'. Drl to I · ', 41.4°, N21W, 5499.84 TVD, 1216.71VS, 1098.68N, 536.25W ', 46.5°, N20W, 5717.26 TVD, 1422.98 VS, 1295.00N, 609.65W ', 48°, N21.5W, 5767.49 TVD, 1476.50 VS, 1346.06N, 628.24W ', 52.9°, N23.5W, 5902.52 TVD, 1630.66 VS, 1489.96N, 687.85W 10-3/4" @ 2476' 6950' (184'), Chg logging tls Wt. 10.2, PV 10, YP 13, PH 9, WL 7.2, Sol 11 Drl to 6925', C&C, POH. RU Schl, rn DIL/FDC/CNL; unable to get below 6670', POH, btm stab off lqgging tl left in hole. RD Schl. RIH to 6925', drl to 6950', C&C, spot Lub 106 pill, POH. RU Schl, RIH w/triple combo; unable to get below 6700', POH. Remove hole finder on btm of tls, repl w/std off tl. RIH; unable to wrk below 6360', POH, remove std off tl, repl w/hole finder & add 300# sinker bar to tls. RECEIVED Signature For form preparat~n~d ~st~i~u~i~n~ .... ~ see Procedures Manual Section 10, ~ Drilling, Pages 86 and 87 IDate 1/2/85 ITM ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is avadable. I Accounting cost center code District . I County or Parish J State Alaska I North Slope Borough I Alaska Field ILease or Unit I Well no. Kuparuk River ADL 25642 2W-11 Auth. or W.O. no. ~Title AFE 203645 I Drill, Complete & Perforate Parker 141 API 50-029-21238 Operator AR.Co. W.I_ ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 12/11/84 Complete record for each day reported Date and depth as of 8:00 a.m. Old TO 1400 hrs Released rig 12/22/84 thru 12/26/84 I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well our I Prior status if a W.O. 0645 hfs 7" @ 6926' 6844' (0'), RR RIH w/triple combo tls to 6662', POH, LD tls. RIH w/bit to 6910', wrk out tight spot @ 6720', POH. RU Schl, RIH w/triple combo tls; unable to wrk tls past 6644', POH, RD Schl. RIH, rm & cond hole f/6600'-6950', circ hole, POH. RU Schl, RIH w/triple combo; unable to wrk tl below 6600', POH. Chg out tls, RIH w/DIL/GR; unable to get below 6400', POH. Rn DIL/CAL f/6635'-2475'. Rn FDC/CNL/GR f/6635'-5200', RD Schl. RIH, C&C hole, LD DP & BHA. Chg rams to 7". RU &Cn 170 jts, 7", 26#, J-55 butt csg to 6926'. Cmt w/210 sx C1 "G" w/1.5% D-79, 1.2% D-112, .5% D-65, .2% D-46 & .25% D-13, followed by 400 sx C1 "G" w/3% KCl, .8% D-60 & .2% D-46. Pmp 270 bbls brine, bump plug. Press to 3000 psi; OK. ND BOPE, set 7" csg slips, cut off & dress 7" csg. ND BOPE, NU &tst tree to 3000 psi. RR @ 1400 hrs, 12/23/84. INewTO 6950' (12/21/84) Oate 12/23/84 PB Oepth Kind of rig 6844' Rotary Classifications (oil, gas, etc.) Oil Producing melhod Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Oate Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day REZEIVED Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date c ..... ted FE~ 2 I ~ .... Alaska Oil & t;;~ e._-__- The above is correct ,~..~.-'. 4. ~mmi ~si0t~ Signature ~_ [ Date Title ~ .~_/:/~.,,, 112185 For form preparation ;n-d dis~butio-n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, ' -',--ula§e Drilling Superintendent $ UB-$ URFA CE DIRECTIONAL SURVEY ~-~] UIDANCE [~ONTINUOUS Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2W-11 (468' FNL, 258' FEL, S33, T12N, R~E, UM) KUPARUK) NORTH SLOPE ~ ALASKA Job Reference No. 69992 Lo{3~3ed By: NURTLAND RECEIVED Alaska 011 & Gas Cons. Commission Date 22-JAN-1985 Computed By: STEVENS GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR, ARCO ALASKA~ INC. 2W-11 KUPARUK No SLOPEr ALASKA SURVEY DATE: 3-JAN-85 ENGINEER: MURTLAND ,METHODS OF COMPUTATZON TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH ""~:~P~LAT[DN: LINEAR ..... ~aQJECTEO ONTO A TARGET AZIMUTH OF NORT'H 30 DEG 43 MIN WE.ST RCO ALASKA, INC. UPARUK . SLOPEr ALASKA COHPUTATI3N DATE: 2Z-JAN-SS DATE OF SURVEY: 3-JAN-85 KELLY 3USHING ELEVATION: ENGINEER: MURTLANO INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH PAGE ',34.00 FT ~ TRUE SUB-SEA COURSE ~SURED VERTICAL VERTICAL OEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG M~N 0o00 0.00 -94.00 0 0 N 0 0 E 100.00 100.00 6.00 0 9 N' 20 54 bi ZO0.O0 200.00 106.00 0 14 N 15 I E 300.00 300.00 206.00 0 19 N 64 22 E 400.00 400.00 306.00 0 18 5 88 44 E 500.00 499.99 405.99 0 17 S 80 22 E 600.00 599.99 505.99 0 17 S 43 35 E 700.00 699.99 605.99 0 16 S 4 1' E 800.00' 799.99 705.99 0 17 S 24 15 14 900.00 899.99 805.99 ,0 18 N 87 11 W 000.00 999.99 905.99 0 19 100.'00 1099.99 1005.99 0 5 gO'OD00 1199.99 1105.99 0 19 300.00 1299.98 1205.98 0 18 400000 1399.98 1305.98 0 9 500o00 1499.98 1405.98 0 18 600°00 1599,.98 1505.,98 0 23 700.00 1699.98 1605.98 0 43 800.00 1799.97 1705o97 0 54 900°00 1899.95 1805.95 I 0 000.00 1999'93 1905.93 100.0.0 2:099.89 20,05.89 ZO0.O0 2199.86 2105.86 300.00 2299.85 2205.85 400.00 2399.84 2305.84 500.00 2499.83 2405.83 600.00 2599.82 2505.82 700.00 2699.81 2605.81 800.00 2799.81 2705.81 900.00 2899.80 2805.80 000.00 2999~79 29.05°79 0 36 100.00 3099'67 3005.67 5 4 200000 3198090 ,,3104.90 8 59 300.00 12 45 4,00000 3394~07 3300.07 15 25 500.00 3489.82:3395.82 18 14 600°00 3584.Z$ 3490,25 19 53 700.00, 367.8.10 3584.10 20 3 800°00 3772.07 3678°07 ZO 16 900.00 3865°60 3771.60 2! 17 N 67 3& bi N 51 55 E S 3 13 E S 88 33 ~ N 13 5~ W SaO 13 ~ S 45 0 E S 77 3 ~ S 89 33 E N 79 27 ~ I 30 N 82 12 E I 25 N 74 15 E I 13 N'75 16 E ,0 49 N 68 12 E 0 51 ,N 62 2½ E 0 47 .N 78 46 E O. 43 N 86 31 E 0 41 N 58 47 E 0 37 N 61 58 ~ 0 39 N 55 5& E N 22 7 E N 2.5 34 W N 22 44 bi N Z1 It bi N 25 47 W N 28 15 W N 28 26. bi N 28 14 bi N 27 3r,.bi VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH F~ET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0,00 0.00 N 0.00 0.18 0.57 0.17 N 0.08 0.41 0.16 0.43 N 0.07 0.58 0.12 0.81 N 0.23 0.40 0.22 0.93 N 0.78 0.10 0.12 0.88 N 1.30 -0.29 0.3.0 0.69 N 1.74 -0.75 0.15 0.25 N 1.89 -1.13 0.2,1 0.22 S 1.84 -1.17 0.32 0.50 S 1.45 0..00 N 0 0 E 0.19 N Z5 25 bi 0.44 N 8' 53 W 0.85 N 15 58 E 1.22. N 39 54 E 1.57 N 55 42. E 1.88 N .68 I7 E 1-91 N 82 2.3 E,' 1.85 $ 83 9 ~. i' 1.53 S 70 55 E -0.?,6 0.19 0.34 S 0.92 -0.36 1.57 0.07 S 0..60 -0.78 0.11 0.55 S 0.61 -1.03 0.0'9 0.97 $ 0.37 -0.76 0.97 0.90 S 0.03 -0.81 O.7Z 0.7'4 S 0.34 -1.40 0.23 1.15 S 0.79 -2.16 0.34 1.58 S 1.56 -3.02 0.94 1.79' S 2.90 -3.73 0.11 1.62. S 4.58 0°98 S 70 I E 0.60 S 83 29 E 0o82 S 48' 0 E 1.04 S 20 59 E 0.90 S 2. O W 0'.82 S, 2.4 Ia' E 1.40 S 34 27 E Z.,.2Z S 44 37 E. 3.41 S 5,~ 22 E 4.8&, $ 70 33 E -,4.54 0.91 1.29 S 6.72 -5.44 0.48 0.79 S 9.3Z '-6.13 0'87 O.ZO S 11.65 -6.54 0.21 ,0.31 g 13.32 -6068 0.14 0.91 N 14.60 -6.76 2.06 1.55, N 15.84 -7034 0.69 1.63 N 17',10 -7.61 0.18 1.98 ,N 18.24 -7.68 0.40 2.51 N 19.26 -7.67 0.24 3.12 N 2002~ 6.84 S 79 8 E 9.35 S 85 10. E 11.66 S 88 59 13.32 1'4.63 N 86 25 15.92 N 84. 23 E 17.18 N 84 34 18.34 N 83 48 19,,42 N 82 34 20.49 N 81 14 E -7.44 1.52 3.84 N. -3.33 4.06 7.8i N 80'7'7 3.54 18.90 N 27.36 3.30 36.34 N 51.39 3.19 59.1'7 N 80.01 2.62 85.54 N 112.84 1.05 114.76 N 147032. 0.95 145.08 N 181.49 0.79 175.18 N 216.82 1.48 2 Db. 44. N Il-e3 E 21-*37 N 79 38 E 19.61'~ E 21.16 N 68 21 E' 14,6.4 E 23.90 N 37 45 E 7,,60 E 37.13 N 1.04 W 59.17 N I 0 W 12~,68 14 86.47 N 8 2,5 W 27.76 W 118.07 .N 13 35 44.24 bi 151067 N 16 57 bi 60.47 bi 185.32 N 19 Z W 77' 03 ~t 22.0.34 N 2.0 27 W RCO ALASEAt INC. UPARUK. · SLOPEe ALASKA COHPUTATZON DATE: 22-jAN-85 DATE OF SURVEY:: 3-JAN-85 KELLY BUSHING ELEVATION: ENGINEER: MURTLAND INTERPOLATED VALUES FOR EVEN ZOO FEET DF MEASURED DEPTH .TRUE SUa-SEA COURSE ASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG HIN DEG MIN 000.00 3958037 3064037 22 '28 100.00 4050.¢8 3956.48 Z3 25 200.00 4141.95 4047.95 24 14 300.00 4232062 4138062 25 27 ¢00.00: 4322.70 4228070 26 8 500000 4412.04 4318.04 27 25 600.00 4500.24 4406.24 28 49 700.00 4587.03 4493003 30 36 800000 4672.30 4578030 32 23 900.00 4756.33 4662.33 33 31 000.00 4838070 4744.70 35 23 100.00 4919.40 4825.40 3.6 40 200.00 .6999.32 490.5.32 37 20 300.00 5078.70 4984.70 37 19 400.00 5159.56 5065.56 35 Z 500°00 524'1.53 $147.53 35 36 600.00 5321.50 5227.50 37 58 700.00 5399021 5305021 39 49 800000 5.475052 5381.52 40 57 900°00 5549,89 5455.89 42 47 PAaE 0~)0. O0 5622021 5528.21 4.4 18 100o00 5692.54 5598.54 46 27 ZO0.O0 5760.14 5666.14 48 24 300°00 5825.29 5731.29 50 20 400000 5887.15 5793.15 53 13 500.00 5945.06 5851.06 56 20 600.00 5997098 5903098 59 31 7'00.00 6'068.28 59.54028 59 49 800,,00 6098°55 6004.55 59 49 900.00 6148.82 6054.82 59 49 94. O0 FT 950.00 6173o95. 6079.95 59 49 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/lOO FEET FEET FE~T OEG MIN N 26 47 Id 254.09 lo09 N 26 10 W 292.93 0.95 N 25 28 Id 333017 1.25 N 24 38 Id 375.14 0075 N 23 41 Id 418.28 1.06 N 24 12 W 462.89 1.63 N 23 25 W 509.67 1.80 N 23 8 W 558091 1.60 N 23 22 W 610.68 1.54 N 25 1'3 W 664.55 2.46 239.68 N 94.05 d 257.47 N 21 25 W 274.52 N 111.44 W 296.27 N 22 5 W 310089 N 129.01 W 336060 N 22 32 W 349.06 N 146.94 W 378073 N 22 49 W 388.70 N 164.68 W 422.15 N 22 57 W 429.74 N 1B2092 W 467.06 N 23 3 W 472.91 N 201.86 W 514.19 N 23 6 W 518.4B N 221057 W 563.84 N 23 8 W 566.53 N 242.04 W 616.07 N 23 8 W 615098 N 264.27 W 670028 N £3 13 W N 26 6 W 721.03 N 26 4 w 779.87 N 27 11 W 83'9.83 N 25 44 W 900.48 N 24 L W 958.97 N 25 41 W 1015096 N g5 5 W 1075.74 N 23 46 W 1138028 N 23 10 W 1202.39 N 22 40 Id 126a.62 lo64 1.11 1.18 1.95 1.19 2058 Z 003 1.39 2.17 2.13 667.01 N 288.95. W 726'.91 N 23 25' W 720.14 N 314.72 W 785.91 N 23 36 W 773.69 N 342.00 W 845.91 N 23 5'0 W 828.19 N 369.00 W 906068 .N 2~ 0 W 881.61 N 393.60 w 965.48 N 24 3 W 933.53 N 417.79 W 1022.76 N 24 6 W 987.70 N 443064, W 108;2.76 N 24 11, W 1045000 N 469.64 w 1145.68 N 24 11 W 1104.29 N 495.35 w 1210.31 N 24 9 W 1165085 N 5Z104Z W 12:77o14 N 20 S W N 22 1L W 1336.96 N ZZ 8 W 1407.26 N 21 33 W 1480.05 N 21 18 W 1554.92 N 21 33 Id 1632041 N 22 30 W 1713.00 N 22 30 W 1796097 N 22 26 W 1882.50 N 22 26 ~ 1968005 N 22 26 ~ 2053059 104'7 2.39 1085 2.32 2.46 3.46 2.3~ 0.00 0.00 0 o00 1229.6'~ N 547.80 W 1346.I? N 2.4 0 W 1Z'95.48 N 574.66 W 1417.22 N 23 55 W 1363.88 N 602005 W 1490.85 N 23 49 W 1434.51 N 629.74 W 1566.65: N 23 42 W 1507071 N 658°24 W 1645.].3 N 1583o22 N 6B8092 Id 1726061 N 23 30 Id 1661.55 N 721049 W 1.811.,43 N 23 28 W 1741.43 N 754045' 1821.34 N 787.48 1901,24.N 820.47 W 2070.72 N 23' 20 W N 22 26 W 2096.37 0..00 1941.19' N 836.96 W 2113.94 N 23 19' W RCD ALASKA, ZNC. W-11 UPARUK . SLOPEr ALASKA CDHPUTATIDN DATE: 2Z-JAN-S5 BATE GF SURVEY:' 3-JAN-85' KELLY BUSHING EL~VATZON:' ENGINEER: NURTLAND INTERPOLATED VALUES FDR EVEN 1000 FEET OF MEASURED DEPT 94..00 FT TRUE SUa-SEA COURSE ASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG HIN 0.00 0.00 -94.00 0 0 000o00 999.99 905.99 0 19 000.00 1999.93 1905o93 1 30 000.00 2999.79 2905.79 0 36 O00..O0. 3958.37 3864.37 21 28 000.00 ~838.70 474~.70 35 13 000.00 5622.21' 5528.21 ~4 18 950.00 6173.95 607 9.95 ~9 49 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 0 E 0.00 67 38 H -0.76 82 12 E -4.54, 22 T E -T. ~4 26 4'7 Id 254,.09 2.6 ~, W 7ZL.O3 ZZ 11 W 1336.96 22 26 Id 2096.3'7 0.00 0.19 0o91 1 1.09 1.64, I 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.34 S 0.9Z E O.Va S 70 I E i. 29 S 6.72 E 6084 S 79 8 E 3.84 N 21.03 E 2.1.37 N 79 38 E 239.68 N 94.05 ii 257.47 N 21 25 W 66T.,0[ N 288.95 W 726.91 N 23 15 W 1229.67 N 567.80 W 1366.17 N 24 0 W 1941.19 N 836.96 W 2113.94 N 23 19 W ~ CDMPUTATION DATE.: 2Z-JAN-85 PAGE '~. ,RCD ALASKA, INC. :W-11 ,UPARUK SLOPE, ALASKA OATE OF SURVEY: J-JAN-a5 KELLY BUSHING ELEVATION: ENGINEER: MURTLAND 94 o O0 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE !ASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEP~'RTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DXST. AZIMUTH FEET DEG/IO0 FEET FEET FEET 0o00 0.00 -94. O0 0 0 N 0 0 E 94.00 94.00 0.00 0 10 N 17 13 W 194.00 194000 100000 0 13 N 13 40 E 294.00 294.00 2..00.00 0 19 N 62 4'3 E 394.00 394000 300.00 0 19 S 89 37 E 494.01 494.00 400,00 0 17 S BO 3~ E 594001 594.00 500.00 0 17 5 47 15 E 694.01 694.00 600.00 0 16 S 5 41 E 794.01 .794.00 700.00 0 17 S 21 40 W 894.01 894.00 BO0.O0 0 18 S 89 21 W 0.00 0.00 0.00 lq 0.00 0.17 0.27 0.15 N 0.07 0.39 0.17 0.41 Il 0.07 0.58 0.15 0.80 N 0.220 0.42 O.ZO 0.93 N 0.75 0.12 0.10 0.89 N 1.27 -0.27 0.28 0.72 N 1.72. -0.72 0.18 O.Za a 1.8~ -1.11 0.£7 0.19 S 1.85 -1.19 0.32 0.50 S 1.48 0..00 N 0 0 E 0.17 N 26 16 W 0.42 N 10 10 W 0.-82 N 1~ 13 E 1.20 N 38 38 E lo55 N 54 54 E 1.87 N 67 26 E 1.91 N 8t 322 E 1.86 S 8,~ 2. E( 1.56 S 71 17 E 994.01 994.00 900.00 ,094o01 1094.00 1000.00 .194o01 1194.00 1100.00 ,294.02 1294.00 12200000 .394002 1394.00 1300.00 ,49~.02 1494.00 1400000 :594.02 1594.00 1500.00 :694o02 1694.00 1600000 :794.03' 1794.00 17.00.00 1894.05 189,4.00 1800.00 0 19 N 66 2~ W -0.79 0 5 N 83 58 E -0.37 0 19 $ Z 0 E. · -0.7'5 · 018 S 87 XB W -1.04 0 9 N 20 21 W -0.77 0 18 S 87 17 E -0.79 0 23 S 43 ZZ E -1.36 0 42 S 75 ZB E -2.10 0 51 $ 87 53 E -2.97 0 59 N 79 22 E -3.70 0.17 0.35 S 0.95 1.11 0.07 $ 0.60 0.1,3 0.51 S 0.60 0.14 0097 S 0.41 0.97 0.91 S 0.03 0.81 0.74 S 0.31 0.41 1.12 S 0.76 0.49 1.56 S 1.49 1.00 1.79 S 2.81 0.13 1.64 S 4.48 1.02 S 69 54 E 0.60 S 82 57 E 0.7'9 S 49 4l E 1.05 5 2222 4.1 E O. 91 S I 39' W 0.80 S 12, 33 E. 1.36 S 34 .6 E 2.16 S 43 34 E 3-33 S 5'/' 33 E 4.TI' S 69 55 E 1994.07 1994. O0 1900.00 I 27 :094..11 2094.00 ZO00.O0 I 27 !194.13 2194.00 2100.00 I 16 ~.294.. 15 2Z94. O0 2200.00 · 0 50 ~.394016 2394.. O0 23,00.00 0 51 :49,4.17 Z4*94. O0 240 O- 0:0 0 49 ~. 594.18 2594..00 2500.00 0 41 ~.694.19 269~.00 2.600.00 0 4*0 ~.794o 19 Z794.00 2700000 0 37 ~.8'94**20 2896.00, 2800.00 0 39 N 73 41 E -5.40 N 75 47 E .-5.09 N 68 3~ E -6.53 N 62 4q. E -6.67 N 74 a E -6.73 N 86 4'0 E -7.31 N 59 ZZ E -7.6Z N 62 38 E -Z.68 N 56 30 E -7.67 0.74 1.31 S 6.57 0.45 0.83 S 9.18 0.80 0.24 $ 11.53 0.32 '0.27 N 13.24* 0.15 0.87 ~i 14.53 1.69 1.53 N 15.75 0.4Z 1.62 N 17". 0 3 0.37 1.94 N 18.18 0.26 2.48 N Ig,ZO 0.15 3.0~ N ZO.20 6.70 S 78 43 E 9oll S 84 50 6 11..53 S 88 49 E 13.l,4 N 88 4,8 E 14.5,5 N' 86 34 .E 15.83 N 84. 226 E 17oXX ,N 84 33 E 18.28 N 83 54 E · 19.36 N 82 38 E,( 20.43 N 81 19 ~.994,,21 2994*00 ,2900.00 ,0 34 J094o31 3094o00' 3000.00' 4 49 ~195.04 3194e00 :',3100o00 8 48 JZ96082 32'94,&00:~' .,3200.00 12 39 )399.92 3394,00 3300.00 15 25 3504o4.1 34.94o O0 34,00000 18 21 ~610,.38 .3594..00 ,3500.00 20 0 )716.92 3694.00 3600.00 19 55 )823-39 379,4.. O0 3700.00 20 26 ~930o52 3894.. O0 3800.00 21 43 N 2.8 6 E -7.47 N 25 '9 W -3.83 N 22 50 W 8.01 N 21 15 W 26.67 N ll 26 W 51.37 N 25 57 W 81.39 N 28 22 W ' 116037 N 28 19 W 153.11 N 18 3 W 189.61 N 27 16 W 227.99 1.30 3.79 N 4.81 7.36 N 3.46 18.19 N 3.51 35.69 N 3.20 59.15 N 2065 86.T9 N 0.93 117.87 N 0.73 150.17 N 0.72 182.35 N 1.33 116.37 N Zl.O0 E 21.34 N 73 46 E 19.88 E 21.20 N 69 41 E 14.'93,,E 23.54 N 39 2:2 E 7o8~?E 36.54 N 1Z 224 E 1'03 W 59.16 N 0 59' W ~3'28 W 87.80 N 8 41 W 29.4.4 W 121.49 N 1% 1 W 46-99 W 157.35 N 17 Z2 Wi 64.31 W 193.36 N 19 Z$ W 82.18 W 231 45 N gO %7 W RCD ALASRAt INC. W-11 UPaRUK . SLOPE~ ALASKA COMPUTATION DATE: 22-JAN-S5 PAGE DATE OF SURVEY: 3-JAN-SS KELLY &USHING ELEVATION: ENGINEER:' MURTLAND INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 94~. O0 FT TRUE SUa-SEA COURSE ASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH D~G VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ.. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEO/lO0 FEET FEET FEET DEG 038.61 3994.00 3900.00 22 46 147.51 q094.00 4000.00 23 48 257.27 ~194.00 410.0.00 25 4 368.07 ~294000 4200.00 25 50 ~79o71 ¢394.00 4300.00 27 5 59Z. 89 ~494.00 ~00o00 28 42 708010 ~$94.00 4500.00 30 44 825.75 4694000 4600.00 32 38 945o~7 4794.00 4700000 3~ 2'7 0680.36 4894.00 4800000 36 29 N 26 35 W Z68.93 N 25 48 ~ 311o91 N 2.5 8 W 356.9.5 N 23 56 W 40~.39 N 24 17.. W 453°67 N 23 25 W 506.~8 N Z3 S ~ 563.01 N 23 ~ ~ 62~.~3 N 25 45 ~ 193,.29 4994.00 4900.00 37 1.9 319.19. 5094.00 SO00oO0 36 50 441.97 5194.00 5100000 3a 47 565°25 5294.00 5200000 37 18 693.20 5394000 5300000 39 ~ 824056 5494.00 5400000 ~1 30 960074 5S94o00 5500°00 43 5.:~ 102012 5694. O0 5600.00 46 30 ,Z51.48 5794.00 5'700.00 49 22 ,411.50 5894000 5800000 53 28 N 27 19 W 835.77 N 25 23 W 912.02 N 24 SO W 982.80 N 25 25 W 1054o59 N 23 49 W 1133o95 N 23 3 W 1Z18.~2 N 22 25 W 1309096 N 22 7 W 1408.78 N 21 23 W 1518.33 ,~92o1Z 5994°00 5900°00 59 22 ,790.95. 6094.00 6000000 59 4'9 ,950000 6173.95 6079095 59 49 N 22 32 W 1790025 N Z2 26 W 1960.3.0 N 22 26 ~ 2096.37 0.62 0.70 1.47 0.93 1.68 1.65 ! 1.11 2o00 1.0'7 1.06 3.19 1.7.3 2.14 1o64 2.32 lo03 2.37 1.93 2.21 252.96 N 100.7~ W 272o2~ N 21 42 W Z91.6~ N 119.79 W 315o29 N 22 19 W 332.47 N 139.24 id 360°45 N 27. 4.3 W 375.89 N 159.0~ ~21.Z9 N 179.11 W ~57.78 N 23 1 W a69.77 N 200.50 522.28 N 223.19 W 567.97 N 23 8 W 579.2~ N 2~7.5Z W 629.93 N 23 8 W 638.93 N Z75.27 W 695.70 N 23 18 W 703.15 N 306.50 W 767..05 N Z3 33 W~ 770.06 N 340.14 W 841.84 N 23 49 W 838064 N 374.01 W 918.26 N 2~ 2 W 903.46 N 403.4a w 9a9.46 N 2~ 3 W 968.49 N ~3~.57 W 1061.52 N 2~ 9 W 10~1.00 N 467.89 W 11~1.32 N 24 12 W 1119.17 N 501.71 W /Z26.~8 N 2~ 8 W 120~.~1 N 537.~6 W 1318.89 N 2~ 2 W 1296.90 N 5?5.24 W ~8.75 .N 2~ 55. W 1399.98 N 616.23 W 1529.60 N Z3 45 W 1516.Z9 N 661.64 W 1654.36 N Z3 34 W 3.30 1655.27 N 718.89: W 1.804.64 N Z3 2.8 W 0.00 1814.10 N Ta&.49 W 1976..&6 N 23 23 W 0.00 194.1.19 N .836.96 W Zl13.94 N 23 I9' W RCO ALASKA~ INC. W-ll UPARUK · SLOPEr ALASKA MARKER TOP UPPER SAND BASE UPPER SAND PSTD TOTAL D~PTH CDMPUTATION DATE: 22-JAN-85 PAG~ DATE OF SURVEY: 3-JAN-35 KELLI hUSHING ELEVATION: ENGINEER: MURTLANO -3~ o 0 0 FT INTERPOLATED VALUES FOR CHOSEN HORIZONS FROM KB MEASURED DEPTH &ELO~ KB 6384.00 5877°52 6496.00 594IDa5 6864.00 6120.67 6950·00 6/73.95 SURFACE LOCATION AT ORIGIN= 4.6J~e FNL, 2.58e FEL~ SEC 33~ T1,ZN,~ RgF.~ UM TVD RECTANGULAR COORDINATES SUB-SEA NORTH/S~UTFI EAST/WEST 5783.52 1695.8! N, 653.51 ~ 5868.85 1580.Z3 N 687.65 W 6026,.67 1856.69 N 80[·99 id 6079.9.5 1961.19 N 836.96 ~ RCO ALASKA, INC. W-ll UPARUK . SLOPE, ALASKA MARKER TOP UPPER SAND BASE UPPER SAND PBTD TOTAL DEPTH COMPUTATION DATE: II-JAN-a5 DATE OF SURVEY: 3-JAN-85 KELLY BUSHTNG ELEVATION: ENGINEER: MURTLAND PAG~ '~ 9,~. 00 FT ************ STRATIGRAPHIC MEASURED DEPTH BELOW KB 6384.00 6496.00 6844.00 6950.00 SUMMARY SURFACE LOCATION AT ORIGIN: 468' FNL~ Z58' FEL~ SEC 33, TIZN, ROE, UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 5877.52 5783.52 1495o81 N 653o51 W 5942.a5 5848.85 1580.13 N 687°65 W 6120.67 6026.67 1856o~9 N 80~.99 W 6173o95 6079.95 1941.19 N ~3~o96 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEP£H DEPTH 6950.00 6173.95 6079.95 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MI.N 2113o9~ N 23 19 W SCHLUMBEROER ARCO ALASKA. 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R~ , ~-~"::~;~' Yes ,.,- ,, , , , , , , , .t ARCO Alaska, Ir Post Offib'~,.Jox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/22/85 Transmittal No: 498 ~ RETURN TO: ARCO ALASKA, INC. TTN: Records Clerk TO-1115B .0. Box 100360 chorage, AK 99510 ' Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES Schlumberger #69930 2C-15 ..... 12/30/84 Run 1 · . , #69925 2W-I2 12/29/84 " 3090 - 7178 2705 - 8064 (Computed 1/19/85) (Computed 1/18/85) #69923 2W-11 ~-'~ 12/22/84 Run 2 / ~/69956 2W-13'~ .1/06/85 Run 1 #69944 1Qill / 1/04/85 ~' #69943 2E-9-j' 1/04/85. 2467 - 6660 (Computed 1/16/85) 4117.5-9151.5 (Computed 1/21/85) 3625 --7723.5 (Computed 1/21/85) 3856.5-8143 (Computed 1/20/85) ,. /cat ._ /--~ . ~ / --- ~_.~. ~ .... -7/ . Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher State of BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files &o,*"~ AI~I,=, I,~' i~ · ~,,h,~idi~rv of AtlantJcRJchfieldCommanv ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports - December, 1984 Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' DS 6-11 (Workover) . 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 2X-9 2X-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L68 Enclosures ARCO Alaska, Inc. is a Subsidiary o! AtlanticRIchfieldCompany RECEIVED JAN (~as Cons. Comndsdmm Anchorage STATE OF ALASKA ALASKA O~,AND GAS CONSERVATION COk..,tlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-222 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21238 468' 4. Location of Well at surface FNL, 258' FEL, See.33, T12N, R9E, UM I6. Lease Designation and Serial No. ADL 25642 For the Month of December 5. Elevation in feet (indicate KB, DF, etc.) 95' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2W-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0645 hfs, 12/11/84. Drld 13-1/2" hole to 2490'. Ran 10-3/4" csg. f/2552' - 2885', recovering 13 cores. Drld 8-1/2" hole to 3020'. Ran OH logs Drld 8-1/2" hole to 6950'TD (12/20/84). Ran OH logs. Ran 7" csg. PBTD @ 6844". well & RR ~ 1400 hfs, 12/23/84. Cored & SHDT. Secured 13. Casing or liner ru.n and quantities of cement, results of pressure tests · 16" 62 5#/ft, H-40, weld conductor set @ 90' Cmtd w/265 sx CS II 10-3/4", 45.5#/ft, J-55, BTC csg w/FS ~ 2476'. Cmtd w/750 sx AS Ill & 300 sx Class "G" emt. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 6926'. Cmtd w/610 sx Class "G" cmt. 14. Coring resume and brief description Cored interval f/2552' - 2885' f/3022' - 2478', A detailed core description will w/30' core barrel . Recovered 13 cores. Shot 30 SWCs be submitted with the completion report. 15. Logs run and depth where run GR/SP/DIL/LSS f/3022' - 2478'WLM; SHDT f/3022' - 2478'WLM. LDT/CNL/GR f/3022' - 2478'WLM EPT/ML/GR f/3022' - 2478'WLM FDC/CNL/GR f/6635' - 5200'; DIL/Cal f/6635' - 2475', 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED J AN 1 19 § Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repor~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 IMM/Mi~/~ 1 Submit in duplicate MEMORANDUM State-of AlaSka ALASKA OIL AND GAS CONSERVATION COt. R~ISSION TO: C.V.~er~on Chai~ .~.~-~ ~ ,--. ~ THRU: Lonnie~C Smith -//~' '~ - / Co~issioner DATE: December 14, 1984 F,LENO: D.51.83 TELEPHONE NO: FROM: Edgar W. Sipple, Jr.~~..~' SUBJECT: Petroleum Inspector Witness BOPE Test on ARCO' s Kuparuk 2W- 11, Sec. 33, T12N,R9E,IR~i, Permit No. 84-,222 Parker Rig 141. Tuesday_: .December 11, 1984: I traveled this date from ARCO's Kuparuk 2X-9 '(Subject of another report) to ARCO's Kuparuk 2W-!I, Parker Rig 141, to witness a BOPE test. The drilling contractor was in the process of finishing the hole. Wesnesday, December 12, 1984: The BOPE test commenced at 11:15 am and was c0heluded' at"12 20 pm. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO"s Kuparuk 2W-Il, Parker Rig 141. Attachment 02-O01A(Rev. 10/79) O&G 5/$4 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Ins p e c t o r L~/~/ ~,~/,' ~//~.~/~ Operator /4/~ jd~z~ ~ Well ~--~ ~ri~n~ Con~or Location, General ~ Well Sign~ General Housekeeping~ Rig Reserve Pit ~ ~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Sta~k Ad'ar Preventer I~iyams ~f<- Blind Rams ~ C~o~>~ine V~v~s ~.~.~. Valve 0 Kill Line Valves O~ Chec~lve ~ Test Pressure I ~oo Date / Z~ /Z~ Well ~2~- ~t Representative ~ ~erm~ ~ ~~ZZ ~ /~Casing Set @ ~ ~ ~ ft. Ri #/~ Representative ~ R~/<- '' ACc~LATOR SYST~ Full Charge Pressure 3~' psig Pressure After C~osure/~O ~s~g Pump incr. clos. pres. 200 psi~ ~ min~sec. ~un~ CU~r~: ~=~u~,A~t~n~ :~ ,~ ~ m~na? s~. N2 ~7~ ~S~ ~.~.~ '~~zS~ Psis Controls: Master Remote ~ Blinds switch cover %(~ , Kelly and Floor Safety Valves Upper Kelly ~ Test Pressure Lower Kelly~f ~est Pressure Ball Type ~ ~st Pressure . Inside BOP ~~est Pressure ~ Choke Manifold ~ Test~ressure Valves No. flanges ~ ~ ~~ Adjustable Chokes / ~$' : Hvdrauically operated choke ~ /~ Test Results: Failures ---0 ------' Test Time , / hrs. ~ /~/~ Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified, t Remarks:~ ---/ ?~; . . //,v Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector November 28, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2W-11 ARCO Alaska, inc. Permit No. 84-222 Sur. Loc. 468' FNL, 258' FEL, Sec. 33,' T12N, RgE, UM. Btmhole Loc. 1563' FSL, 1465' FEL, Sec. Dear }~r. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, Velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject t° AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations-promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention I~lr. Jeffrey B. Kewin Kuparuk River Unit 2W-11 -2- November 28, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the con~uctor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COM~ISSIOM lc Enclosure CC: Department of Fish & Game, Habitat Section w/o enclo Department of Environmental Conservation w/o encl. Doug L. Lowery ARCO Alaska, Inc. Post Office 'L~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2W-11 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2W-11, along with a $100 application fee Diagrams showing the proposed horizontal, and' vertical projections of the wellbore o A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on December 7, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. JBK/JG/tw GRU2/L96 RECEIVED g]ov 1 6 Alaska 0il & Ga.s Cons. Commission Anchorage Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~TL AND GAS CONSERVATION CO~MISSION ERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL [~]X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SERVICE [] SINGLE ZONE MULTIPLE ZON E;~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 468' FNL, 258' FEL, Sec.33, T12N, RgE, UM (Approx.) At top of proposed producing interval 1211' FSL, 1257' FEL, Sec.28, T12N, PgE, UM At total depth 1563' FSL, 1465' FEL, Sec.28, T12N, RgE, UM Kuparuk Ri vet 10. Well number 2W-11 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 95', PAD 65' ADL 25642 ALK 2573 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3815' @ TD feet 2W-10well 60' @ surface feet 16. Proposed depth (MD & TV D) 17. Number of acres in lease 18. Approximate spud date 7122' MD, 6238' TVD fec. t 2560 12/07/84 I 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 2732 psig@~Surface KICK OFF POINT 3040 feet. MAXIMUM HOLE ANGLE 44 o (see 20 AAC 25.035 (c) (2) 3137 ..psig@ Gdqc, ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE SETTING DEPTH QUANTITY OF CEMENT I Hole 124" I- I1 2-1/4" 8-1/2" Casing Weight 16" 62.5# 10-3/4" 45.5# 7" 26.0# CASING AND LINER Grade I Coupling: H-40 I Weld I J-55 ] BTC HF-ERW J-55 I BTC HF-ERW Length MD TOP TVD 80' 29' I 29' 2446' 29' I 29' I 7094' I 28' I 28' MD BOTTOM TVD 109~ 109' 2475'1 2475' I 7122'1 6238' I I (include stage data) ± 200 cf Poleset 750 sx AS III & 300 sx Class G ~'sx Class G neat'~- 22. Describe proposed program: e/~F~i,~ ~ ~~'~ ! ARCO Alaska, Inc., proposes to drill a Kuparuk Riv ld development well to approximately 7122 MD (6238' TVD). A 20", 2000 psi annular diverter will .be.i~§talled on the 16" conductor while drilling the surface hole. The 10-3/4" casing will be set through the~ sands at approximately 2475' MD(2475' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). The West Sak interval will be cored with oil-based mud. Expected maximum surface pressure is 2732 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge CONDITIONS OF APPROVAL DATE Samples required Mud log required [~]YES ~NO [~YES APPROvEDPermit num ber~~~,B ~Appr°val date~ Form 10-401 GRU2/PD33 Directional Survey required APl number ¢L~Es ~NO 5O- ~ ~ ~- ~ ~ ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 28, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2W-11 installed and tested upon completion of the job. 2W-11 will be 60' away from 2W-10 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 5536'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 10-3/4" x 7" annulus. The 10-3/4" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. Alaska Oil & Gas Oons. Gor,~;iss%on A~chomg~ ~ TOPT ,,TAROET CNTR ! TVD~5948 !TMD=6?I 6 DEP--2080 --KUP'-$ND$-'-! TVD~6Og5 TMD--Sg22 DEP--2223 ,(LO0-. PT)..i .~ FVD-82381TlfiD-?--122 D£P=2383 · : ........ ~., ......... l.-- SCALE,-._,.,_IN ..... ,.. ] - -; .... i ........ ~ ...... ARCO. ALASKa. - ..... '. .... ~ ......... j ....; PAD; 2W;; WELL; NO~ __~; ] :~_L .:C. $ ~: Z_~J.]]i:_:'-~-.L._KUP ARUK ~.FI ELD .--NOR .......... i .......... : ........ ~ ' , ~ ~ ' j ~ ' . - ~ · I - -. ' .............. t -t ..... t .... ~ -t ....... : . , ..... 3000 _ , , ] , ~ .... ' , ~ - ' :-' ! '~ ........... " ' J ...... ~' -7'' ~ :._. ~! ....... ~':'::~- ::': ~ ..... :---:--J ....... i ............. ~ ~' -~ ......... ~ ..... t ...... i ........... i ....... i ....... -( ......... ~--'-~ .... -k- ........ ~-~--'-~ ....... ~ ........... ~ ........... ~ ...................... ~ .................... ~ ................ + ...... + ................. ~ ........ i ......... ~ ..... _. '~ ....... ~ .......... + .............. ~ ....... ; .............. ~ ...... ~ .............. j ...... ~ ........~ ..... . . ~.. " ~ ' - ._[:~:.~L~_~_~-~ ..... , ........... - .......t .................. i ........ __ ~ ....... ~ ....... ,. ........... ~ .................. f .......... , ~ ...... i .....................~ :-~ ~..- .............. ~" ~.~ ..-/ ... ........................... {.-: ............... ~- ~ .... ~ . . . ~ . .,. ~ ' ~ , , .~ ... . _ - . ' { ........ + .... .:-30:' DEG 43-': HI N ....... ~ ........ ~ ...... . . . ; ... ~ ................ ~ .... ~ ...... ....... ; ....... . ~ :_~ ,. ~ ~ ~ , , . ...... ; .... ; ....... t ....... - ..... .... . .-~ ..... ~ .........i ...... 1 .............. ~ ....: ............ ~' ":- t ..... ~ i J · - ......~ .................. ~ ......... t .... ~ ...... ~ - - ~ , - - - r - ..... ~ ......~ ....... ~ .............................. [ ......... ~ ........ ~:~ ....... :---~ ....... ' .... ~ ........... 1 ........ ~ ....... ~ .... ....... + ............ + ..................... ~ ...... , ......... ~__:.___~. , .... .... ~ .... ~ ' : .... ~ ....... [ ....... ~ ' .- ~T_ ~_.~ ~'.~'~'-~ ~ ) .._~ _~._', ~... i -- ~'' ' t ..... t ...... T .... ; ' '' [-' ~ , _j -'-T .... ~ .....t-":--~-'J ....; .....i''; ;~;~-:-'-~ ' ~-:; t ..... = = : ........ ; ' : "' i ' ~ ' - ~'-- m' : : . - ~ ~ . .~.. ~ -~ .... ~_. ~ ~j...'''~ .] Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO" si de outlets. lC" ball valves, hydraulically actuated, w/lC" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. 5 Maintenance & O~eration 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid ¢low to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECeiVED Alaska Oil & ' ANNULAR 9 PIPE BLIND · ~,~ DRILLI G DIAGRAM fl 13-5/8" 5OO0 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco 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 x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 12-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACI'I'Y TEST ~1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WII'H 1500 PSI DOWNSTR~ 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 NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND ~/'AL¥~S UPSTR~ DON~T TEST AGAINST CLOSF. D CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO i800 PSI AND HOLE FOR !0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR i0 B. ~,~'PP~SSD~[E DOWN&~REAM OF .CHO~ ISOLATION ~AL_V~S.- TO ZERO PSI TO TEST VALVES. TEST RE~tAINING UNTESTED MANIFOLD .VALVES, IF ANY, WITH 3000 PSI UPSTRF.~J'I OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PI PE RAMS. 1D. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLDSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE ~,tANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WiTH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFOP, M COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. .ECE VE OF CHOKES. D AlasKa Oi) & Gas Cons. Commissior~ Anchom.qe CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE Loc ~.,'2 thru 8) (3) Admin . ~. ~t,--;',:¢'}¥ 9. (9 thru 12) 10. .ffi/_,T,/]- ?/-/'~ -~¢/ 11. (10 and 12) 12. (4) Casg ~2,,7/¢ (13 thru'" 21) YES NO 1. Is the 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 and is wellbore plat included ................ ./~. 7. Is operator the only affected party .................................. ,""~-,~ 8. Can permit be approved before ten-day wait .......................... 13. 14. 15. 16. 17. 18. 19. 20. 21. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ./,~_~ Is conductor string provided ................................ Is enough cement used to circulat;'~n c~ductor and ;u;face . .. Will cement tie in surface and intermediate or production strings .. Will cement cover all known productive horizons .................... Will surface casing protect fresh water zones .................... Will all casing give adequate safety in collapse, tension and b~st. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate wellbore separation proposed ........................... REMARKS (22 thru 26) 22. 23. 24. 25, 26. 27. Is a diverter system required .. ..................................... .~ Are necessary diagrams of diverter and BOP equipment attached . .. Does BOPE have sufficient pressure rating - Test to ~,¢.'~'P Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ,~-~ 0 Geolosy:/,Bngineerins: HWK /-'~LCS~BEW_____~. jAfF%_,_MTM~ff ' rev: 10/29/84 6.CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effod has been made to chronologically organize this category of information. LYP 01.0,~t0~ VE,gIFlCATI..t~i~ .[.,IST~.~,!G PAGE 1 ** REEl, HE.~OF.R SER¥~CF W A~.~ E DATE ;~5t01./16 ORIGIN : REEL N~,ME :1.42'1~1 CONTINUATION ~ PR~VIOI~S REEl, CO~MFnTS :LIBRARY ** TAPE ~EADER ** SERVICE hlA~E :EDIT DATE: :85/01/16 ORIGIN :0000 TAPE NAME :q923 CONTIN[IATION ~ -'01 PREV IO~!S T~PM : C.r]~MENTS .:LIBRARY TAPE ********** EOF ********** ** FILE NE.~DER ** FILE NAME :~DIT .001 VERSION # : ~ATE : ~AXIMU~ LEMGTH : 1024 FILE TYP~ : PREVIO~S FILF ** II~FOR~.~A'rlON. REC[RDS CN ! ARCO AbASK~ INC. R~NG: TOWN: SECT~ COUN~ NORT}~ SLOPE ST.~T~ CTRY~ U$~ MNEM COMTMMTS PR~S: E ** COM~EMT$ ** UNIT TYPE CATE SIZE ooo oog 000 O0 065 000 000 00~ 065 000 000 002 065 000 000 004 065 000 000 O02 065 000 000 01,2 065 000 000 00b 065 000 000 003 065 UNIT TYPE CATE SIZE CODE 00 O 000 00 :I 065 [,VD OlO,H02 VER.I~'ICATIOi~ iL, I'STING PAGE 2 * $CH L i.,.l ~ BERGER * * lb~$KA COMPUTIMG CF, NTER * ************************************************************************************ COMPANy = ATbANTIC ~ICHFIEbD COMPANY WEI, b = 2W - 1I FIELD = K !.lp i~. R II K COUNTY = NONTH SbDPE bOROUGH STATE = AT, ASK a ,70B NU~[~ER AT .~CC: 699~3 RUN #2, ~ATE bOGgED: LDP: CFW CASI~G TYPE FI,UID DENSITY VISCOSITY ~H FLUID LOSS 10,750" @ 2477' ' i~IT SIZE : ~,5" TO 6925' POLYMER 10,2 LB/G R~ : 5,400 ~ 58 DF 38,0 S R~F = 5,810 ~ 58 DF 9,0 R~C T : 4,820 0 58 DF 8,1 C3 R~ A. BHT = 2,420 ~ 138 DF MATRIX SANDSTONE ********************************************************************************* LVP O10.}407 VEPlFIChTION i~TSTING PAGE 3 * * * * * * * * * * * * * * * ~ ,* ~ * * ~ $ * $ * ~ $ * * * g * * SCHb{{~RERGER LOGS INCLUDED ~.~T{4 THIS M;~GNETIC TAPE:: * , * * DUAL INDIICTION SPHERICALLY ~'OCUSED LOG [DIL) * ~ W[)P~ATION DENSITY CO~PENSATED LOG (FUN) * , * ~ , * * , , , , * , , , , , , , , , , , $ * , , , * , $ $ * ** DATA FORM.aT RECORD ** ENTRY BLOCK5 TYPE SIZE; REPR CODE ENTRY ~ ! 66 0 4 8 4 73 60 9 4 65 ,lin 1,6 0 I ~6 0 DATUM SPECIFICATION ~%LOCKS ~NEM SERVICE SERVICE Ut.~TT API A. DI AP1 ApI FILE SIZE SPL REPR ID DEPT SFLU OIL ILO SP OIL ~R GR FUN CALI FDN RHOB R~O FUN R,~T RMRA FUN ~P~I F'DN PROCESS ORDER # LOG TYPE Cb~:SS MOD NO. 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I 8,9844 RNRA 3,2422 T..b~ 17.6719 CALl 8. 6406 RNRA 3,6406 IL~ 2,3301 CALl 9,9453 RNRA 4,1406 I'LM 2. 5664 CALl 10 6875 RNRA 4 ~.24~2 .98~4 IbM 03.078i 3750 CALI 1, ,69~ 5254 RNRA 3,7266 ,0000 ,3086 ,0000 ,6523 .5000 ,4~92 .7500 ,3730 .5000 ,0000 ,1250 .4238 Ib~ 2,3555 CALl 9,3.359 RN~A 3,5195 IbM 3,6055 CALl 10Z6563 RNRA 3~9160 II~ 4. 1523 CALl 10,~188 ~'NR.A 3, ' 50 LVP olf~.lt02 VERIFICATION [.~ISTIMG PAGE 5 MPHI 4~..7969 MCN.h DEPT 5700 0000 SFLU 5Po, -3512500 GR RH,B ~ 3926 DRHD NPHI 44. 1895 NC~'L DEPT 5600.0000 SFLU SP -34 7500 GR RHO5 2!406] DRHO NPNI 37 6953 NCML DEPT 5500 0000 SFI,,U SP -33io687 ~R RHOB 2 4277 DR~O ~PHI 37 ~070 MC~!L DEPT 5400.0000 SFLU SP -33,0000 dR RHOB 2.427'1 BRiO NPHI 47.3145 ~CI,tb DEPT 5300 0000 SFLU SP -,4~i0000 GR RHOB 2 ~691 DRHO MPHI 45 45~0 MC~Ii., nEPT 5200 0000 SFLU SP -4t~5000 GR RHOB 2,421.'9 DRHO ~PHI 41.,0~45 NCNb DEPT 5100, O0 S~l,J SP '48, O0 GR RHOB 2,4180 DRHO ~PHI 49.2i87 NCNL DEDT 5000.0000 SFI.,U SP -3~.0000 GR RHOB ,3262 DRHO NPHI 45.0195 NCNb DE ~I 4900,0000 SFLU SP -36. 5000 NPt4I 42,7246 NC~i DEPT 't~00.0000 SFI..,U SP 36,7500 GR RHOB 2.33?0 DRHO NPHI 38,62.30 NCNb DEPT 4700. 0000 SFLU SP 38' .~500 GR 1841.0000 PCNL 3,74~2 ~25,5000 GR O.OOq8 NRAT 1905,0000 PCNL 4.8398 1.1,2.8750 GR 0,0386 NRAT 2010,0000 FCNL 3,8945 ~11.3125 0,0298 NRAT 21.34,0000 MCNL 1~4 8125 GR T 0:0195 MRA 196~.0000 FCNL 3,1.1()2 ?LD 129,.~250 GR 0,0171 NRAT 1881,0000 7539 ILD 1.17'~ 875 GR 306 MRAT 2082,0000 ~CNb 4,0234: IbD 116'I 875 GR 0,037 · CNL 9043 ILl') 1..3125 GR ,012?, 1,911 . 0000 FCNL 2 5098 97 2500 GR 0 0659 2000 0000 FCNL ~ 4,7~7 73 ~875 ~ 029 1994 0000 2,953~ 8~.875 GR NR~T GR 507.7500 3 244:1 125:5000 3.5547 50~,5000 3,6016 112.8750 502,5000 3.6875 i11.,3125 3,1738 711.,5000 2,7598 ~.24.8125 ~.7266 506.7500 3,2969 129,1250 3,6230 454,00o0 3.6543 117,6875 3,3848 569,5000 3,7813 1.16,1875 ],828! 417.5000 1,.7109 95.3125 3.5996 444,2500 2,2754 97; 2500 3,4746 543.0000 2.4551 7], 6875 649 ,2500 .5000 2,~598 750 I L g CALl RNRA ILM CALl RNPA IbM CALI RNRA CALl RNRA IUM CALl RNRA IbM IL.M CALf RNRA CALI RNRA IbM CALi RNRA CAbi RNRA CA LI 3,3379 10,1484 3,7910 3,6641 0 1250 14:0000 3 8164 10i5859 2 9980 2,8184 1~,9844 ,8691 3,3477 11,1953 4,1406 7090 ~.6543 3,8652 11,2344 4,4727 1,803~ ,49:22 ..,3008 ,3125 ,8594 3,6816 ,4961 ~,9844 3,0684 ~:7598 804.7 LvP OlO,H{)P, VERIF'ICATI(]N LISTING PAGE 6 RHO6 2,3359 DRHO NPHI 36. 2305 HC.NL DEPT 4600,0¢)00 SF[,O SP -41 5!)00 C,R NPHi 35.5469 NCNb OE~T 4500 0000 SFLU SP -43:0000 RHOB 2.3555 NPNI 3R'6230 ~tCNL D£PT 4400 nO00 SFLU , SP -42.5000 GR RHOB ~.2969 DRHO NPMI 37,5977 NCNb DEPT 4~00,0000 SFLU SP 45,7500 GR RHOB ~.3203 DR~O ~P~I 42.2363 NC*~L DEPT 4200 o000 SFLU SP -46i250U GR RHOB ~ ~027 MPHI 41.6504 NCNb DEPT 4~00,0000 SFI.,L.I SP -46,75n0 CR RHOB ~2,~988 D~HO NPNI ~2, 71.1 MCNL DEPT qO00 0000 SP -48 2500 RHOB 2 3359 DRMO NPN! 47 ~168 NCNb OEPT 3C00.0000 SFLU SP 52,0000 GR ~P~I 42.0808 NCN.L DEPT 3700,0000 SFI. 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RHOB ~,~285 DRHO NPHI 48 .... 910 NCb~L O E: P T 3600.00 o 0 $ FI.., U 0 02~3 NRAT 2016: 0000 FCHb 2.9414 89.8125 dR 0.0225 WRiT 1960.0000 FCNL 2.75'78 IBD 95.9375 o oog~ 1~49:ooOo 3 1309 68:1250 GR 0.0386 1854.0000 FCND 2.3984 lbo ~3,0000 GR 0,0146 NRAT 2060.0000 FCNL. 2 ~371 ILD B7,3125 GR -~,0015 NRAI 2050.0000 FCNL 2 4922 82'0625 0,0034 NRAT 1934.0000 FCNL 2,601. 6 I L D 82,5625 GR o,:0425 ~R. ~T 2o5o.oooo CNL 2,6582 lbo H9.1250 (;R 0,00~4 NRAT t925.0000 FCNb 2 9785 , -0, 02 NRAT 1754, 0000 FC 3 ~562 ,~ O5 250 00132 NRAT 2011. 0000 3.6855 ILl) 3,i211 537,5000 2,68~,6 89,8125 3.0820 540.5000 2 6426 95~9375 3 2520 582:5000 3.1270 68,1250 3,1953 558.5000 2.5117 83,0000 3 4492 642:5000 2,4805 3, 60 579,0000 2 6172 82:0625 3,4824 505.~500 2,94,34 82,5625 3.7188 540.50O0 2,.6367 89,~250 3,8066 458,2500 2.9102 107.1875 3,4395 501,2500 3,7801 I05,..,250 3,7~93 474,5 O0 2.9785 RNRA IBM CALI RNRA CAI.I RNRA I6~ CALl RNRA IbN CALI RNRA CALl RNRA I6~ CALl RNRA II'~M CAbI RNRA '.AI. I RNRA IbM CALl RNRA CA L I RNRA 3,7500 2.7168 9 03~I 262 o 2,6934 8,9844 3,3457 3,0879 8,3594 3,3184 2,4805 9,1.719 3,2051 2,507B 9,4531 3.5391 2,5859 9,2031 3,8262 2,B047 ,1875 .79~0 ,2,6289 2891 2,8477 4980 0176 '9297 4,2344 3.0410 LVP 010 w02 VERiF1CAT[n~ ,,,,IS lNG PAGE 7 SP -61,2500 NPHI 43,7988 OEPT 3500. 0000 SELU SP -61.7500 GR RHOB 2.2422 DRHO DEPT 3400,0000 SFLU SP -61 7500 NPHI 51 ,~066 NCP~L DEPT 3300,0000 SFLU Sp -60,2500 GR RHOB 2,2246 DR}JO ~PHI 43.~641 OEPT 3200.0000 SFLU SP -65,2500 GR RHflB 2,~129 DRHO NPHI 43.359.4 NCNb DEPT 3100 0000 SFLU Sp -B3iO00o OR RHOB 2 1152 DRHO WP~I 46.o238 wCNL DEPT 3000 0000 aFI,U 36 n R H 0 RHOB 2'9'185 NCNb ~PHI 52. 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VERiFICATIO!'~ I,ISTI~'!G PAGE DEPT 2500.00o0 SFLU 1,1.531,3 SP -80.0000 ~N 55.06~5 RH~B 2.1465 DRH('J 0,0068 NR.~T MPHI 47.6{)74 NCNb 17~1.0000 FCML OEPT 2467.0000 SF[.,Lt 11,~984 ILD SP -20,7500 ~R 34.2187 GR RH~B 1 9]36 Dado -0.7612 MRA. T ~P}{I 5~3438 MC~!b 1384.0000 wCML ** FIL~', TRIlLEp ** FILE N~{~E :EDIT .001 SERVICF NA~IE VERSI[]M ~ DATE : ~AXIMUM LENGTH : 1024 ~ILE TYPFi : NEXT FILE MA~E : EOF ******~*** 7,6914 Ih~ 5~,0625 CALl 3.7402 RNRA 376.2500 34.2187 4.0000 304,7500 7.726~ 6250 2000,0000 9,4063 4,53~1 ** TAPF TRalLEP ** SERVICE NAME :EDIT DATE :~5/0~t16 ORIGIN :O00O TAPE NA;~F :q9~3 CONTINUATION # :0! ~EXT T~PE MA~E : C[]MMENTS :LIBRARY TAP~ ** RMEL TRAILER ** SERVICE NA~E :EDIT DATE :85!01./i6 REEL Nl~E :t4~7~1 CUNTINUATION # :01 NE×T REEl, MA~E : COMMMNTS :~,IBRIRY TAPE EOF L'VP 010'HO2"VERIFICATi3N LISTING *~,REEL' 'ME'ADER SERVICE NAME :EDIT 3RIGIN : REEL 'NAME :__ CONTINUATION ~. PRE¥IOUS' REEL' COMMENTS :L~.i~RARY TAPE ~'~T<A'p,E,~.HE.ADER SERVICE NAME :COiT O.IT'E ORIGIN :0000 T~'PE:NAME :9910 CONTINUATIgN m :~1 PR!'E¥'~O'U$ TAP E COMMENTS :Li,SRAR¥ E3F ~,"~!!I~"~:~ ~E r~'ir :M'E Ii DER FILE NAME :EDIT $'EtI~'~C'E..'' :NAME VERSION · MA,XiMUM ,LENGTH : F ~'~:'E:';~';'.~T ypE'~,~,, : PREVIOUS PiLE ,,. ,X~ :.,~',!h' '",~'~, ',.~7 , '" ~ i~FO~MATIoN RECORDS .-,,~,]~ M N'E'M'' C ON T 'E N'T S CN : ARCO ALASKA FN : WEST S. AK R',~9~:~'?:'~''~'~''~::!~'E'~ ' TOWN: COUN~ N.~LoPE CTR~: USA ,~]S~ ~:~'~,"~ ~.,,~,,,.~ ~.,~., ,~ ~,,~?..Ls~ ...... .. M'~:~ M CONTENTS UNIT UNiT 'TYPE 000 000 OJO 000 000 000 000 000 000 T¥OE 000 CATE 000 000 000 000 OOO 000 COg OOO 000 CATE OOC P~GE I JUN 0 ? ],985 ~/Orc?.qe, [tlnliS$iori SIZE 0O6 002. OO~ 002 003 SIZE 001 CODE 0 5.5 O,55 065 ' _¥P 910.H02 .]Ec~iF-I"A"£ON LiSTiNG ,~A.,~.: / OMP.6NY 'IELD ::,TAT ,E NUMB:ER AT ~CC: 6:~'~10 STE'PH4N F. ST,_-V :N~ 247,5' SIZE : 9,875" TO 30£Z' RM : ?.ZSO @ ~5.0 OF RMC = ~,.300 $ 58.0 DF Rt,I ,~T GMT = ~.5£.~ 2, C~O.O OF .VP OJ.O:~HltJ:'E?,V'ERIFICATIDN LISTING PAGE , SCHLUMa~RG'~R LOGS ZNCLUDED WITH TH:'S MAGNETIC TAPE: :~ OUAL INDUCTlfON SPHERICALLY FOCUSED LOG (OIL) ':."?:'~?~m'.?.':'!':' ..'~:% .': ' , M I C R 0 L A T E R L 0 G ( M ~ L ) ~ ~.ONG SPACED SONIC ,LOG (LSS) "??",~,,~,,,'~r.; ..... 'i";?;'.,, LITH'O OENSITY CO';MPENiS~'TED :LOG" CLOT) ~ ELECTROMAGNETIC PROPAGAT.ION TOOL (EPT) .......... ::"."': ?:: ' ~'~ NATURAL GAMMA T~O.L (NOT) EltT-R"T~.:""i:B.'I~O~.K $ ..... . . TYPE S~f.E REPR CODE ENTRY ~ 1 65 1 9 ~ 65 .liN '~'?'"¥ ...... 1 '6 1 66 1 0 1 65 0 ~'E~":SE~tZCE'SER~JCE UN[T ~P[ AP'[ A~[ ~P[ FILE S[[E SPL REPR ~O ORO~R ~ LOG TYPe CLASS MOO ?:~]~ .... ' ...... 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' .r: ..... ~.,i, cVP"'~'O~:i'O"~H'0:2' VER"IFICATIgN LISTING P~,r_ -, ~R DZL- SGR L:D'T :AL~ LOT qH08 LOT JRHO LOT ANR~ LOT ~EF LOT ~CHL LOT GAP£ O0 310 01 IN O0 2.80 G/C3 O0 350 C,/C3 O0 3'55 01 O0 ~+20 01 ~0 000 O0 PU O0 890 O0 O0 355 CPS O0 330 3,1 CPS O0 330 30 GAPI O0 310 O1 GAP1 O0 .310 O1 PU O0 719 50 PU O0 719 50 PPM O0 790 50 PPM O0 792. 50 GAPI O0 31r0 01 ,3API O0 310 O1 US/F O0 520 BO US/F O0 520 80 IN O0 280 01 iN O0 280 01 GAPI '00 310 Ol 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 O. o 0 0 0 0 0 0 0 0 0 0 OOOO000000000O 00000000000000 O000000000000;J 00000000000000 00000000000000 00000000000000 O000000000000O 00000000000000 00000000000000 O0000OO0000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 03000000000000 O00000000000OO 00000000000000 00000000000000 00000000000000 00000000000000 tj'['~'~"" ...... ' "'~'"~4,' SO00 SFLU ~N~ t.asol ~HO SGR lZ[. 5625 CGR THOR' :16' 203'1 URAN DT -999.2500 DTL gEPT ..... ': '"'" '"" '3"00'0 ~"O'O 0 0 SP -244.50C0 RI~OB ................... Z * 136 T NPH I 4 ~. i 895 $~R? '~{: ............ ~' ~'-' ~',g ~:~ 56 Z 5 T'HOR 10. 4706 1963.0000 '~?F~?'~;~~':~ ~ s:.~ .,~:~. "~. ,?" ~' - 2.1953 ~]~t~"';:';:''~,?; ...... ? ~;~'~ 1"05 SGR 77.1815 .... .7500 ~,~,.;... ~,: ,~,- ;.. .... ,:. 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