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Home My WebLink About191-0321. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace TBG/Install kill string Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6848'feet 6355'feet true vertical 6296'feet None feet Effective Depth measured 6555'feet 6342'feet true vertical 6032'feet 5845'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" J-55 6337' 6371' 5840' 5870' Packers and SSSV (type, measured and true vertical depth)6342' 5845' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 325-468 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: BAKER HB Retrievable SSSV: None Brian Glasheen brian.glasheen@conocophillips.com (907) 265-6379 RWO/CTD Engineer 6473-6486', 6510-6515', 6524-6540', 6551-6562', 6562-6582' 5960-5971', 5992-5997', 6005-6019', 6029-6038', 6038-6056' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 115' Well Shut-In measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-032 50-103-20153-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025586 Kuparuk River Field/ Kuparuk Oil Pool KRU 2M-16 Plugs Junk measured Length 6806' Casing 6289'6841' 2894' 115'Conductor Surface Tie-Back String 16" 9-5/8" 74' 2929'2867' Burst Collapse Fra O s 6. A PG , g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:24 pm, Oct 06, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2025.10.06 13:05:17-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen RBDMS JSB 101625 J.Lau 11/10/25 Page 1/5 2M-16 Report Printed: 9/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/22/2025 14:00 8/22/2025 20:00 6.00 MIRU, MOVE MOB P Pull pits away from sub & stage on pad. Hang tree in cellar. Spot wellhead equipment behind cellar. Spot sub on pad. Raise derrick. Bridal down. Install dog bones. Pull TD out of rotary table. Spot sub over well. Set front mats and herculite. Set down sub. 0.0 0.0 8/22/2025 20:00 8/22/2025 21:00 1.00 MIRU, MOVE MOB P Spot pit T/ sub. Set mats and release truck. 0.0 0.0 8/22/2025 21:00 8/22/2025 23:00 2.00 MIRU, MOVE MOB P MU IBOP and install clamps. MU interconnect. Hang bridle linesin derrick and safe out rig floor. Prep pits for taking on fluids. Rig up cellar for well kill. Work on rig acceptance checklist. 0.0 0.0 8/22/2025 23:00 8/23/2025 00:00 1.00 MIRU, MOVE MOB P Begin taking on seawater to pits. Rig Accept at midnight. 0.0 0.0 8/23/2025 00:00 8/23/2025 04:00 4.00 MIRU, WELCTL RURD P Check TBG/IA and OA pressures 590/700/0 PSI, obtain RKB's, rig up lines to kill well, check line up, finish off loading 8.5 ppg SW to pits 0.0 0.0 8/23/2025 04:00 8/23/2025 05:45 1.75 MIRU, WELCTL KLWL P Blow air thru lines, flood lines to tiger tank, test lines to 250 low and 2500 high. open IA to choke 650 psi bleed to zero and SI, no psi build up. Line up tubing to tiger tank. Reverse circ 30 bbl Deep clean down IA taking returns up tubing to tiger tank. Chase with 275 Bbls 8.5 ppg SW 4BPM at 900 psi ICP. 790 PSI FCP. 0.0 0.0 8/23/2025 05:45 8/23/2025 07:15 1.50 MIRU, WELCTL OWFF P OWFF. Flow out IA diminishing to no flow. Perform 30 Min no flow. 0.0 0.0 8/23/2025 07:15 8/23/2025 07:30 0.25 MIRU, WELCTL MPSP P Install ISA BPV. 0.0 0.0 8/23/2025 07:30 8/23/2025 07:45 0.25 MIRU, WELCTL PRTS P PT BPV from below T/ 1000 PSI for 10 Min. 0.0 0.0 8/23/2025 07:45 8/23/2025 08:15 0.50 MIRU, WHDBOP RURD P B/D, R/D circ lines & tiger tank. 0.0 0.0 8/23/2025 08:15 8/23/2025 10:15 2.00 MIRU, WHDBOP NUND P Break bolts on tree adaptor spool. Verify TBG hanger not growing. N/D tree & adaptor spool. Inspect hanger neck threads - good. Function LDS. Install slip over blanking plug. 0.0 0.0 8/23/2025 10:15 8/23/2025 13:45 3.50 MIRU, WHDBOP NUND P N/U DSA & BOP. Striaghted stack. Install flow nipple. 0.0 0.0 8/23/2025 13:45 8/23/2025 14:30 0.75 MIRU, WHDBOP RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 8/23/2025 14:30 8/23/2025 17:30 3.00 MIRU, WHDBOP PRTS T LDS on TBG head leaking. Call out FMC. Suck out stack. Change out LDS. Then DSA to adapter leaking, tightened up. Fill stack w/ fresh water. Shell test BOPE. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/27/2025 Page 2/5 2M-16 Report Printed: 9/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/23/2025 17:30 8/24/2025 00:00 6.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, UVBR's, LVBR's on 3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38, FOSV, and IBOP. Tested 3-1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1600 PSI, 200 PSI attained =22 sec, full recovery attained = 121 sec. UVBR's= 5 sec, Annular= 22 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2150 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Josh Hunt. 0.0 0.0 8/24/2025 00:00 8/24/2025 02:30 2.50 MIRU, WHDBOP BOPE P Fail/Pass on HCR kill valve, changed out for a new one. 0.0 0.0 8/24/2025 02:30 8/24/2025 04:00 1.50 COMPZN, RPCOMP RURD P Rig down testing equipment. Blow down lines. Pull BPV. RU spooler to pull tubing hanger. 0.0 0.0 8/24/2025 04:00 8/24/2025 05:00 1.00 COMPZN, RPCOMP RURD P M/U landing joint. K/U. Set 10 down. BOLDS. 0.0 0.0 8/24/2025 05:00 8/24/2025 05:15 0.25 COMPZN, RPCOMP PULL P Pull hanger T/ RF. Pipe free @ 90K, PUW=83K. 6,307.0 6,270.0 8/24/2025 05:15 8/24/2025 05:45 0.50 COMPZN, RPCOMP OWFF P Fill stack w/ trip tank. Run trip tank outside T/ clean up diesel off top of hole. OWFF - No flow. 6,270.0 6,270.0 8/24/2025 05:45 8/24/2025 06:15 0.50 COMPZN, RPCOMP PULD P L/D hanger & landing joint. 6,270.0 6,270.0 8/24/2025 06:15 8/24/2025 07:15 1.00 COMPZN, RPCOMP PULL P Rack back 3 1/2" completion F/ 6270' T/ 5968''. PUW=83K. Lost control line on 2nd stand. Recovered control line on 3rd stand. 6,270.0 5,968.0 8/24/2025 07:15 8/24/2025 08:00 0.75 PROD1, WELLPR BHAH P Terminate control line on first single of 4th stand. RIH T/ 5999'. M/U BHA #1_ 6" string mill. 5,968.0 5,999.0 8/24/2025 08:00 8/24/2025 08:30 0.50 PROD1, WELLPR BHAH P RIH w/ sting mill attempt to drift wellhead. unsuccessful. 4.75" XO below mill stacked out in wellhead 27' below rotary. TOOH. L/D BHA #1. 5,999.0 5,999.0 8/24/2025 08:30 8/24/2025 09:00 0.50 PROD1, WELLPR BHAH P M/U BHA #2 On - Off tool. 5,999.0 5,999.0 8/24/2025 09:00 8/24/2025 09:30 0.50 PROD1, WELLPR SVRG P Service rig. Multiple die configurations to get TBG tons to bite on pipe. 5,999.0 5,999.0 8/24/2025 09:30 8/24/2025 11:00 1.50 PROD1, WELLPR TRIP P TIH on TBG F/ 5999' T/ 6301', SOW=72K. Set down to block weight, rotate T/ left. Drop TBG off w/ slick nipple @ `306' 5,999.0 6,307.0 8/24/2025 11:00 8/24/2025 11:30 0.50 PROD1, WELLPR TRIP P TOOH, L/D setting tool. 306.0 0.0 8/24/2025 11:30 8/24/2025 11:45 0.25 PROD1, WELLPR CLEN P Clean & clear RF. 0.0 0.0 8/24/2025 11:45 8/24/2025 12:00 0.25 PROD1, WELLPR RURD P Mobilize IBP T/ RF. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/27/2025 Page 3/5 2M-16 Report Printed: 9/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/24/2025 12:00 8/24/2025 12:30 0.50 PROD1, WELLPR BHAH P M/U BHA #3 IBP. 0.0 0.0 8/24/2025 12:30 8/24/2025 13:30 1.00 PROD1, WELLPR RGRP T TBG tongs not biting on pipe correctly. Try multiple die configurations. Change out TBG tongs. Try multiple die configurations again. 0.0 0.0 8/24/2025 13:30 8/24/2025 14:15 0.75 PROD1, WELLPR TRIP P RIH w/ BHA #3 T/ 128' COE. 117' Top of IBP. 0.0 128.0 8/24/2025 14:15 8/24/2025 14:45 0.50 PROD1, WELLPR MPSP P Fill pipe. Pressure up inflate IBP in 500 PSI increments. Abnormal pressure inicator. 128.0 128.0 8/24/2025 14:45 8/24/2025 15:45 1.00 PROD1, WELLPR TRIP T TOOH, L/D BHA #3. IBP did not set. 128.0 0.0 8/24/2025 15:45 8/24/2025 22:18 6.55 PROD1, WELLPR WAIT T Send IBP back to Dead Horse to be redressed & shipped back to location. Order 2 7/8" Pac HT DP T/ help get IBP in hole past swedge 7" CSG in wellhead. 0.0 0.0 8/24/2025 22:18 8/24/2025 23:18 1.00 PROD1, WELLPR TRIP T MU BHA #4 IBP. RIH T/128' COE. 0.0 128.0 8/24/2025 23:18 8/25/2025 00:00 0.70 PROD1, WELLPR MPSP T Fill pipe. Pressure up inflate IBP in 500 PSI increments. Abnormal pressure inicator. TOOH, L/D BHA #4. IBP did not set. 128.0 128.0 8/25/2025 00:00 8/25/2025 00:45 0.75 PROD1, WELLPR TRIP T TOOH, L/D BHA #4. IBP did not set. At 12:45. 128.0 0.0 8/25/2025 00:45 8/25/2025 01:45 1.00 PROD1, WELLPR TRIP T TIH and set IBP at 127' top / 134' COE 0.0 127.0 8/25/2025 01:45 8/25/2025 03:15 1.50 PROD1, WELLPR MPSP P PT IBP to 1000 PSI for 10 minutes. Pumped 5 strokes (0.2335 Bbls) to achieve pressure. Good test. 0.0 0.0 8/25/2025 03:15 8/25/2025 05:30 2.25 PROD1, CSGRCY NUND P ND BOP and rack back on stump. 0.0 0.0 8/25/2025 05:30 8/25/2025 06:00 0.50 PROD1, CSGRCY RURD P R/U Cameron casing tensioning tool. 0.0 0.0 8/25/2025 06:00 8/25/2025 11:00 5.00 PROD1, CSGRCY CUTP P Grow 7" CSG. Initial force 256K. Growth = 32". Wait 30 Min. Remove TBG head. Cut bottleneck off of top of 7". M/U 7" spear. Pull 100K to put 7" in 50K tension. Install new emergency slips. Stretch = 14". OAG = 46.5". Cut 7" off with WHACKS saw. 0.0 0.0 8/25/2025 11:00 8/25/2025 12:30 1.50 PROD1, WELLPR NUND P Install pack off. N/U original TBG head. 0.0 0.0 8/25/2025 12:30 8/25/2025 12:45 0.25 PROD1, WELLPR PRTS P PT pack off T/ 3000 PSI for 10 Min. 0.0 0.0 8/25/2025 12:45 8/25/2025 14:30 1.75 PROD1, WELLPR NUND P N/U BOP. Install flow nipple. 0.0 0.0 8/25/2025 14:30 8/25/2025 15:15 0.75 PROD1, WELLPR RURD P Fill stack w/ fresh water. R/U testing equipment. 0.0 0.0 8/25/2025 15:15 8/25/2025 16:30 1.25 PROD1, WELLPR PRTS P PT stack breaks T/ 250/3500 PSI. 0.0 0.0 8/25/2025 16:30 8/25/2025 17:30 1.00 PROD1, WELLPR MPSP P Suck out stack. Pull test plug. Install wear bushing. 0.0 0.0 8/25/2025 17:30 8/25/2025 18:00 0.50 PROD1, WELLPR BHAH P M/U BHA #6 IBP retrieval head. 0.0 14.0 8/25/2025 18:00 8/25/2025 18:15 0.25 PROD1, WELLPR TRIP P TIH F/ 14' T/ 124'. 14.0 124.0 8/25/2025 18:15 8/25/2025 18:30 0.25 PROD1, WELLPR MPSP P Equalize IBP w/ 5K down. Release IBP w/ 7K up. Allow element to relax for 10 Min. RIH past set depth. 124.0 120.0 8/25/2025 18:30 8/25/2025 18:45 0.25 PROD1, WELLPR TRIP P TOOH F/ 130' T/ 4'. 120.0 4.0 Rig: NABORS 7ES RIG RELEASE DATE 8/27/2025 Page 4/5 2M-16 Report Printed: 9/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/25/2025 18:45 8/25/2025 20:00 1.25 PROD1, WELLPR BHAH P L/D BHA #7 & IBP. 4.0 0.0 8/25/2025 20:00 8/25/2025 20:15 0.25 COMPZN, RPCOMP BHAH P M/U BHA #8 L-10, retrieval head. 0.0 0.0 8/25/2025 20:15 8/25/2025 21:00 0.75 COMPZN, RPCOMP STRP P TIH, engage slick nipple @ 306'. 0.0 306.0 8/25/2025 21:00 8/25/2025 23:00 2.00 COMPZN, RPCOMP PULL P L/D 3 1/2": completion F/ 6307' T/4633', PUW=83K SOW=70K. LD SSSV, RD Halliburton spooling unit. (Recovered 26 SS bands/ 9 left in hole) 6,307.0 4,633.0 8/25/2025 23:00 8/25/2025 23:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 4,633.0 4,633.0 8/25/2025 23:30 8/26/2025 00:00 0.50 COMPZN, RPCOMP TRIP P TOOH F/ 4633' T/ 4320'. Standing 3- 1/2" EUE back in the derrick. 4,633.0 4,320.0 8/26/2025 00:00 8/26/2025 03:00 3.00 COMPZN, RPCOMP TRIP P TOOH F/4320' T/1224'. Standing 3-1/2" EUE back in the derrick. Pulled up into a tight spot 5K. worked it free with 6K down. 4,320.0 1,224.0 8/26/2025 03:00 8/26/2025 05:00 2.00 COMPZN, RPCOMP PULL P Pulled out of the hole LD singles to the pipe shed. So we do not have to break connections and screw into the top drive several feet in the air. 1,224.0 0.0 8/26/2025 05:00 8/26/2025 05:30 0.50 COMPZN, RPCOMP PULL P Pre-rig RCT cut was a failed cut. We pulled the seal assembly out of the PBR. 0.0 0.0 8/26/2025 05:30 8/26/2025 06:30 1.00 COMPZN, RPCOMP PRTS P MIT-IA to 2500 psi for 30 min Good test. 0.0 0.0 8/26/2025 06:30 8/26/2025 07:00 0.50 COMPZN, RPCOMP RURD P Pull Wear ring. 0.0 0.0 8/26/2025 07:00 8/26/2025 07:30 0.50 COMPZN, RPCOMP SVRG P Service rig crown, blocks, topdrive and power tongs. 0.0 0.0 8/26/2025 07:30 8/26/2025 09:00 1.50 COMPZN, RPCOMP RURD P Empty 3.5" drill pipe from pipe shed. 0.0 0.0 8/26/2025 09:00 8/26/2025 11:00 2.00 COMPZN, RPCOMP TRIP P RIH with 3-1/2" EUE Kill string from the derrick. UWT = 62K/ SOW = 60 K F/surface T/3463' TQ connections to 2250 FT/LB Strap and tally as RIH. 0.0 3,463.0 8/26/2025 11:00 8/26/2025 15:30 4.50 COMPZN, RPCOMP PUTB P Process 35 used joints of 3.5" tubing in pipe shed. Process 60 joints of new 3.5" EUE tubing. 3,463.0 3,463.0 8/26/2025 15:30 8/26/2025 18:00 2.50 COMPZN, RPCOMP PUTB P RIH with 3.5" EUE Kill String. 3,463.0 6,328.0 8/26/2025 18:00 8/26/2025 19:30 1.50 COMPZN, RPCOMP HOSO P Space out completion. 6,328.0 0.0 8/26/2025 19:30 8/26/2025 20:00 0.50 COMPZN, RPCOMP THGR P PU tubing hanger and MU to string. Land hanger RILDS. PUWT=83K SOW=75K 0.0 0.0 8/26/2025 20:00 8/26/2025 21:00 1.00 COMPZN, RPCOMP CIRC P Circulate 240 BBL's corrosion inhibited seawater down IA take returns up tubing. 4 BPM at 625 PSI 0.0 0.0 8/26/2025 21:00 8/26/2025 21:30 0.50 COMPZN, WHDBOP MPSP P Set BPV, test under BPV to 1000 PSI for 10 minutes. 0.0 0.0 8/26/2025 21:30 8/27/2025 00:00 2.50 COMPZN, WHDBOP NUND P ND BOP's NU tree and adapter. 0.0 0.0 8/27/2025 00:00 8/27/2025 00:45 0.75 COMPZN, WHDBOP NUND P Tested tubing hanger void to 5000 PSI for 15 minutes. 0.0 0.0 8/27/2025 00:45 8/27/2025 02:45 2.00 COMPZN, WHDBOP MPSP P Spot in LRS and RU to test tree to 5000 PSI. Pulled BPV. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/27/2025 Page 5/5 2M-16 Report Printed: 9/16/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/27/2025 02:45 8/27/2025 04:30 1.75 COMPZN, WHDBOP FRZP P LRS Pumped 70 BBL's diesel down IA taking returns up the tubing at 3 BPM. U-Tube well for 1 hour. 0.0 0.0 8/27/2025 04:30 8/27/2025 06:00 1.50 DEMOB, MOVE DMOB P Demobolize from 2M-16. 0.0 0.0 8/27/2025 06:00 8/27/2025 13:30 7.50 DEMOB, MOVE DMOB T Prepare to mpve off 2M-16 and wait on rig mats to move to 2F-12. Off load water from brine storage tanks. Prep pits for rig move. Remove burning and cuttings box. Secure outlets on tree w/caps and gauges. Ready cellar for move. Band Baker tools. Re position manrider cable on ODS. Paint dog bones on topdrive, manrider post, CPAI XO. Finish Bridle up checklist. LD derrick. 0.0 0.0 8/27/2025 13:30 8/27/2025 14:30 1.00 DEMOB, MOVE DMOB P NES here and pulled the pits away from sub base. 0.0 0.0 8/27/2025 14:30 8/27/2025 16:30 2.00 DEMOB, MOVE DMOB P Rig backed off well. Folded up herculite and cleaning up location. Remove dance floor from around the 2M-16 well. 0.0 0.0 8/27/2025 16:30 8/28/2025 00:00 7.50 DEMOB, MOVE DMOB T Wait for mat placement, load out equipment and haul to 2F. Mobilize Office and shops to 2F. Stage pits at 2B untill remaining mats are laid. 0.0 0.0 8/28/2025 00:00 8/28/2025 03:30 3.50 DEMOB, MOVE WAIT T Wait for mat placement, load out equipment and haul to 2F. Mobilize Office and shops to 2F. Stage pits at 2B untill remaining mats are laid. 0.0 0.0 8/28/2025 03:30 8/28/2025 09:15 5.75 DEMOB, MOVE WAIT T Wait for rig mat placement. 0.0 0.0 8/28/2025 09:15 8/28/2025 11:00 1.75 DEMOB, MOVE MOB P Move rig from 2M to 4 corners. 0.0 0.0 8/28/2025 11:00 8/28/2025 23:30 12.50 DEMOB, MOVE WAIT T Wait for rig mat placement. 0.0 0.0 8/28/2025 23:30 8/29/2025 00:00 0.50 DEMOB, MOVE MOB P Mobilize sub base from 4 corners toward 2B pad. 0.0 0.0 8/29/2025 00:00 8/29/2025 00:30 0.50 DEMOB, MOVE MOB P Mobilize sub base from 4 corners to 2B pad. 0.0 0.0 8/29/2025 00:30 8/30/2025 00:00 23.50 DEMOB, MOVE WAIT T Rig at 2B rear of rig fell through pad. Place dunnage and mats under sub base. Move rig mats around rig to place ahead of sub and pits. 0.0 0.0 8/30/2025 00:00 8/30/2025 01:00 1.00 DEMOB, MOVE MOB T Wait on rig mats being placed on 2F access road and 2F pad. 0.0 0.0 8/30/2025 01:00 8/30/2025 03:00 2.00 DEMOB, MOVE MOB P Mobilized pit module and sub base to 2F -12. 0.0 0.0 8/30/2025 03:00 8/30/2025 06:00 3.00 DEMOB, MOVE MOB P MIRU spot sub over 2F-12. Release rig from 2M-16 at 0600. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/27/2025 Page 1/1 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA AFE / RFE / Maint.#:GKA.00197.E.W001.WI.RP Job Category:WELL INTERVENTION Primary Wellbore Affected:2M-16 Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:PW Contractor:PW Contractor:HES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:LRS Contractor:HES Contractor:LRS Contractor:LRS Contractor:HES Contractor:HES Contractor:HES Contractor:HES Contractor:HES Last 24hr Summary:ATTEMPT TO DRIFT TO PLUG @ 6354' RKB W/ 10' X 2.5'' DD BAILER BUT S/D @ 6312' SLM, RECOVER APPROX 1 GAL OF FILL. JOB IN PROGRESS. Report Start Date:9/27/2025 14:15 Report End Date:9/27/2025 20:00 Time Log End Time Start Time Dur (hr)Operation 14:30 14:15 0.25 *** START TICKET @ 14:00 *** MOVE OVER FROM 2M-41 TO 2M-16, INSPECT WORK AREA, LRS ON LOCATION 16:00 14:30 1.50 SPOT IN EQUIPMENT, PJSM, R/U .125'' WIRE (1.875'' TS = RS, QC, 5', QC, KJ, 5', QC, OJ, QC, KJ, LSS) 28' OAL) STACK PCE, P/U SSV, STAB ON WELL, R/U LRS TO P-SUB, PT W/ LRS TO 2500 PSI, INSTALL FUSIBLE, NOTIFY DSO 17:15 16:00 1.25 RIH W/ QC, 10' X 2.5'' DD BAILER W/ MSBB (OAL= 114'') DRIFT FREELY, S/D @ 6310' SLM, POOH & INSPECT TOOL (RECOVER APPROX 1/2 GAL OF ASPHALTINE) 18:30 17:15 1.25 PT W/ LRS RIH W/ SAME, S/D @ 6310' SLM, WORK BAILER 15 MIN TO 6312' SLM, POOH & INSPECT TOOL (RECOVER APPROX 1/2 GAL OF ASPHALTINE) 19:15 18:30 0.75 *** END TICKET @ 19:00 *** R/D SLKL, SECURE WELLHEAD, REMOVE FUSIBLE, NOTIFY DSO, INSPECT WORK AREA, LDFN 20:00 19:15 0.75 TRAVEL TO F-WING, TURN IN WELLFILE, SYNC CPU Secondary Job Type: BARRIER TESTING Page 1/2 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA AFE / RFE / Maint.#:GKA.00197.E.W001.WI.RP Job Category:WELL INTERVENTION Primary Wellbore Affected:2M-16 Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:PW Contractor:PW Contractor:HES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:LRS Contractor:HES Contractor:LRS Contractor:LRS Contractor:HES Contractor:HES Contractor:HES Contractor:HES Contractor:HES Last 24hr Summary:MAKE SEVERAL DD BAILER RUNS FROM 6311' SLM TO 6317' SLM (RECOVER APPROX 1-1/2 GAL OF FILL, METAL DEBRIS) JOB IN PROGRESS Report Start Date:9/28/2025 05:45 Report End Date:9/28/2025 19:45 Time Log End Time Start Time Dur (hr)Operation 06:30 05:45 0.75 MEET W/ CWG, OBTAIN WELL FILE, SYNC CPU, TRAVEL TO 2M-16, INSPECT WORK AREA, LRS ON LOCATION 07:15 06:30 0.75 PJSM, R/U .125'' WIRE (1.875'' TS = RS, QC, 5', QC, KJ, 5', QC, OJ, QC, KJ, LSS) 28' OAL) STACK PCE, HANG OVER PCE TRAY, SCAFFOLDING ON LOCATION, CONFER W/ SCAFFOLDING, STAND BY 09:30 07:15 2.25 *** START TICKET @ 07:00 *** STAND BY FOR SCAFFOLDING TO MODIFY SCAFFOLDING, SCAFFOLDING STANDBY FOR MORE MATERIAL, SCAFFOLDING SIGNED OFF 10:00 09:30 0.50 STAB ON, R/U LRS TO P-SUB, PT W/ LRS TO 2500 PSI, INSTALL FUSIBLE, NOTIFY DSO, STAND BY FOR SCAFFOLDING TO MODIFY SCAFFOLDING 11:15 10:00 1.25 STAND BY FOR SCAFFOLDING TO ADD ADDITIONAL TIER TO SCAFFOLDING 12:45 11:15 1.50 RIH W/ QC, 10' X 2.5'' DD BAILER W/ 2.65'' MSBB (OAL= 116'') S/D @ 6311' SLM, WORK BAILER 15 MIN TO 6314' SLM, PULL BIND, JAR UP, POOH & INSPECT TOOL (RECOVER APPROX 1/2 GAL OF FILL, NO METAL MARKS) 14:15 12:45 1.50 PT W/ LRS, RIH W/ SAME, S/D @ 6313' SLM, WORK BAILER 25 MIN TO 6315' SLM, PULL BIND, JAR UP, POOH & INSPECT TOOL (RECOVER APPROX 3/4 GAL OF FILL, NO METAL MARKS ON BTM) 15:30 14:15 1.25 PT W/ LRS, RIH W/ QC, 10' X 2.5'' PUMP BAILER W/ 2.65'' MSBB (OAL= 154'') S/D @ 6314' SLM, WORK BAILER TO 6315' SLM, SEE PUMP ROD STOP STROKING, POOH & INSPECT TOOL (RECOVER APPROX 1/4 GAL FILL, NO METAL MARKS ON BTM) 17:00 15:30 1.50 PT W/ LRS, RIH W/ QC, 10' X 2.5'' DD BAILER W/ 2.65'' MSBB (OAL= 116'') S/D @ 6315' SLM, WORK BAILER TO 6317' SLM, PULL BIND, JAR UP, POOH & INSPECT TOOL (RECOVER METAL BAND, BALL RETAINING PIN SHEARED IN MSBB) Secondary Job Type: BARRIER TESTING Page 2/2 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA Time Log End Time Start Time Dur (hr)Operation 18:30 17:00 1.50 PT W/ LRS, RIH W/ QC, 10' X 2.5'' DD BAILER W/ 2.5'' MSBB (OAL= 114'') S/D @ 6317' SLM, WORK BAILER 20 MIN, MAKE NO HOLE, POOH & INSPECT TOOL (METAL MARKS ON SIDE OF MSBB, BALL RETAINING PIN SHEARED IN MSBB) 19:15 18:30 0.75 *** END TICKET @ 19:00 *** R/D LRS, R/D SLKL, SECURE WELLHEAD, REMOVE FUSIBLE, NOTIFY DSO, INSPECT WORK AREA, LDFN 19:45 19:15 0.50 TRAVEL TO F-WING, TURN IN WELL FILE, SYNC CPU Secondary Job Type: BARRIER TESTING Page 1/2 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA AFE / RFE / Maint.#:GKA.00197.E.W001.WI.RP Job Category:WELL INTERVENTION Primary Wellbore Affected:2M-16 Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:PW Contractor:PW Contractor:HES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:LRS Contractor:HES Contractor:LRS Contractor:LRS Contractor:HES Contractor:HES Contractor:HES Contractor:HES Contractor:HES Last 24hr Summary:GET GOOD IMPRESSION OF MAGNA PLUG @ 6354' RKB. DUMP APPROX 11' OF SAND (EST. TOP @ 6343' RKB) DUMP APPROX 10' OF CEMENT (EST. TOP @ 6333' RKB). JOB IN PROGRESS. Report Start Date:9/29/2025 05:45 Report End Date:9/29/2025 19:45 Time Log End Time Start Time Dur (hr)Operation 06:30 05:45 0.75 MEET W/ CWG, OBTAIN WELL FILE, SYNC CPU, TRAVEL TO KIC, OBTAIN CEMENT, TRAVEL TO 2M-16, INSPECT WORK AREA, LRS ON LOCATION 07:45 06:30 1.25 PJSM, REPACK STUFFING BOX, R/U .125'' WIRE (1.875'' TS = RS, QC, 5', QC, KJ, 5', QC, OJ, QC, KJ, LSS) 28' OAL) STACK PCE, STAND BY FOR SCAFFOLDING TO BE SIGNED OFF 09:30 07:45 1.75 *** START TICKET @ 08:00 *** STAND BY FOR SCAFFOLDING TO BE SIGNED OFF, SCAFFOLDING ON LOCATION, STAB ON WELL, R/U LRS TO P-SUB, PT W/ LRS TO 2500 PSI, INSTALL FUSIBLE, NOTIFY DSO 11:15 09:30 1.75 RIH W/ QC, KJ, 2.50'' CENT, 3' X 1.5'' STEM, 2.50'' LIB (OAL= 68'') S/D @ 6317' SLM / 6354' RKB, TAP DOWN, POOH & INSPECT TOOL (IMPRESSION OF TOP OF MAGNA PLUG) 13:00 11:15 1.75 LOAD SAND IN BAILER PT W/ LRS, RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (1/8'' STEEL), K-JAR, 2.64'' CENT, 2.60'' CENT, BULLNOSE (OAL= 203'') LIGHTLY S/D @ 6317' SLM, PUH 50', WORK BAILER (SEE WEIGHT FLUTTER), RIH & S/D @ 6312' SLM, POOH W/ SHEARED DUMP BAILER 14:45 13:00 1.75 LOAD SAND IN BAILER PT W/ LRS, RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (1/8'' STEEL), KJAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') LIGHTLY S/D @ 6312' SLM, PUH 50', WORK BAILER (SEE WEIGHT FLUTTER) S/D @ 6306' SLM, POOH W/ SHEARED BAILER 16:45 14:45 2.00 MIX CEMENT FOR RUN PT W/ LRS, RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (1/8'' STEEL), K-JAR, 2.64'' CENT, 2.60'' CENT, BULLNOSE (OAL= 203'') LIGHTLY S/D @ 6306' SLM, PUH 50', WORK BAILER (SEE WEIGHT FLUTTER), WASH OUT BAILER, POOH W/ SHEARED BAILER Secondary Job Type: BARRIER TESTING Page 2/2 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA Time Log End Time Start Time Dur (hr)Operation 18:45 16:45 2.00 MIX CEMENT FOR RUN PT W/ LRS, RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (1/8'' STEEL) K-JAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') SEE TOOL WEIGHT LOSS @ 6301' SLM, PUH 50', WORK BAILER (SEE WEIGHT FLUTTER), WASH OUT BAILER, POOH W/ SHEARED BAILER 19:15 18:45 0.50 *** END TICKET @ 19:00 *** R/D LRS, R/D SLKL, SECURE WELLHEAD, REMOVE FUSIBLE, NOTIFY DSO, INSPECT WORK AREA, LDFN 19:45 19:15 0.50 TRAVEL TO F-WING, TURN IN WELL FILE, SYNC CPU Secondary Job Type: BARRIER TESTING Page 1/1 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA AFE / RFE / Maint.#:GKA.00197.E.W001.WI.RP Job Category:WELL INTERVENTION Primary Wellbore Affected:2M-16 Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:PW Contractor:PW Contractor:HES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:LRS Contractor:HES Contractor:LRS Contractor:LRS Contractor:HES Contractor:HES Contractor:HES Contractor:HES Contractor:HES Last 24hr Summary:DUMP BAIL 10 GAL ~32' OF CEMENT (EST TOC @ 6,301' RKB) PLAN TO RETURN IN ~ 3DAYS TO TAG & TEST. Report Start Date:9/30/2025 05:45 Report End Date:9/30/2025 20:15 Time Log End Time Start Time Dur (hr)Operation 06:30 05:45 0.75 MEET W/ CWG, OBTAIN WELL FILE, SYNC CPU, TRAVEL TO 2M-16, INSPECT WORK AREA 07:00 06:30 0.50 PJSM, R/U .125'' WIRE (1.875'' TS = RS, QC, 5', QC, KJ, 5', QC, OJ, QC, KJ, LSS) 28' OAL) STACK PCE, STAND BY FOR SCAFFOLDING TO BE SIGNED OFF 09:30 07:00 2.50 *** START TICKET @ 07:00 *** STAND BY FOR SCAFFOLDING, SCAFFOLDING SIGNED OFF, STAB ON WELL, R/U LRS TO P-SUB, PT W/ LRS TO 2500 PSI, INSTALL FUSIBLE, NOTIFY DSO 11:45 09:30 2.25 RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER, K-JAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') LIGHTLY S/D ON CEMENT @ 6292' SLM, PUH 50', WORK BAILER (SEE WEIGHT FLUTTER) WASH OUT BAILER, LET BAILER SIT 5 MIN, POOH W/ SHEARED BAILER 13:45 11:45 2.00 RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (~2 GAL CEMENT), K-JAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') LIGHTLY S/D ON SAND @ 6292' SLM, PULL UP 50' WORK BAILER FOR 10 MIN POOH W/ EMPTY BAILER 15:30 13:45 1.75 RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (~2 GAL CEMENT), K-JAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') LIGHTLY S/D ON SAND @ 6292' SLM, PULL UP 50' WORK BAILER FOR 10 MIN POOH W/ EMPTY BAILER 17:15 15:30 1.75 RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (~2 GAL CEMENT), K-JAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') LIGHTLY S/D ON SAND @ 6282' SLM, PULL UP 50' WORK BAILER FOR 10 MIN POOH W/ EMPTY BAILER 19:00 17:15 1.75 RIH W/ QC, 2-7/8 GR (OAL= 27'') W/ 10' X 2.5'' DUMP BAILER (~2 GAL CEMENT), K-JAR, 2.54'' CENT, 2.51'' CENT, BULLNOSE (OAL= 185'') LIGHTLY S/D ON SAND @ 6280' SLM, PULL UP 50' WORK BAILER FOR 10 MIN POOH W/ EMPTY BAILER 14 GAL CEMENT DUMPED TOTAL **END TICKET @ 19:00** 19:45 19:00 0.75 R/D LRS, R/D HES 760, REMOVE FUSABLE CAP & SECURE WELLHEAD 20:15 19:45 0.50 TRAVEL FROM 2M TO KOC, TURN IN WELL FILE, SYNC COMPUTER, END TICKET. JOB COMPLETE Secondary Job Type: BARRIER TESTING Page 1/1 2M-16 Report Printed: 10/6/2025 Well Progress Summary Report Job Type: ACQUIRE DATA ALASKA AFE / RFE / Maint.#:GKA.00197.E.W001.WI.RP Job Category:WELL INTERVENTION Primary Wellbore Affected:2M-16 Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:PW Contractor:PW Contractor:HES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:AES Contractor:HES Contractor:LRS Contractor:HES Contractor:LRS Contractor:LRS Contractor:HES Contractor:HES Contractor:HES Contractor:HES Contractor:HES Last 24hr Summary:DRIFT AND TAG TOP OF CEMENT @ 6272' SLM. PERFORM PASSING CMIT TO 2500 PSI. JOB COMPLETE. Report Start Date:10/5/2025 05:30 Report End Date:10/5/2025 15:00 Time Log End Time Start Time Dur (hr)Operation 06:30 05:30 1.00 MEET W/ CWG, PU WELL FILE, SYNC CPU, CONTACT DSO, TRVL TO 2M-16 07:30 06:30 1.00 ARRIVE, WU EQUIP, INSPECT LOC, PJSM , RU .125" WIRE & 1.875" TS = RS, QC, 5', QC, KJ, 5', QC, OJ'S, QC, KJ, LSS ( OAL 27' ), WAIT FOR SCAFFOLDING TO BE SIGNED OFF, INSTALL FUSIBLE CAP, *** START TKT @ 07:00 *** 10:45 07:30 3.25 WAIT ON SCAFFOLD TO BE INSPECTED 11:45 10:45 1.00 RU LRS, PT W/ LRS TO 2500 PSI, RIH W/ QC, 2' X 1.875" WB, XO, 2.48" CENT, 1.75" SAMPLE BAILER, SD @ 6272' SLM, TAP DOWN, POOH, OOH W/ 13:30 11:45 1.75 PERFORM MIT W/ LRS TUBING IA OA INITIAL 550 580 0 START 2500 2500 0 15 MIN 2450 2500 0 30 MIN 2450 2500 0 14:45 13:30 1.25 RDMO, REMOVE FUSIBLE CAP, SECURE WELL, PT TREE CAP, PJSM, CONTACT DSO, 15:00 14:45 0.25 TRVL TO W/L SHOP Secondary Job Type: BARRIER TESTING Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,555.0 2M-16 6/6/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bail sand & cement on plug. 2M-16 9/30/2025 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 2,928.6 2,866.8 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 6,840.5 6,288.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.1 Set Depth … 6,337.1 String Max No… 3 1/2 Set Depth … 5,840.2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.1 33.0 0.05 Hanger 6.980 FMC hanger GEN 4 FMC FMC Gen 4 2.920 6,323.4 5,828.2 28.44 Seal Assembly 3.000 Baker PBR seal assembly 10' stroke (1.34' off fully located) Baker 2.867 Top (ftKB) 6,328.4 Set Depth … 6,370.9 String Max No… 5 1/8 Set Depth … 5,869.9 Tubing Description Tubing – Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 3.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,328.4 5,832.6 28.45 PBR 5.125 BAKER PBR w/ 10' STROKE W/4" SEAL BORE BAKER 3.000 6,342.2 5,844.7 28.46 PACKER 6.062 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,358.5 5,859.0 28.48 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 6,370.2 5,869.3 28.49 SOS 3.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6863' SWS IPROF 12/23/2006 BAKER 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,343.7 5,846.0 28.46 SAND Dump bail sand on top of Magna Range Plug. Note: Cement dumped from 6343.7 up to 6301' rkb. See drawing. 9/29/2025 0.000 6,354.7 5,855.7 28.47 PLUG 2.19 MAGNA RANGE PLUG (MID ELEMENT @ 6,356') 1.90' OAL (PLUG IS NOT RETRIEVABLE, BUT IT IS MILLABLE) 4200- 219- AC- 001 1/7/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,473.0 6,486.0 5,959.7 5,971.2 C-4, UNIT B, 2M -16 2/7/1993 4.0 APERF 180° phase; Orient 11.5 deg. CCW; 4.5" Csg Gun 6,510.0 6,515.0 5,992.4 5,996.8 A-5, 2M-16 9/24/1991 4.0 IPERF 180° phase; Orient 17 deg. CCW; 2.5" Nav Pak Perf 6,524.0 6,540.0 6,004.7 6,018.9 A-4, 2M-16 7/5/1992 4.0 APERF 180° phase; Orient 28 deg. CCW; 2.5" Nav Pak Perf 6,551.0 6,562.0 6,028.6 6,038.4 A-3, 2M-16 9/24/1991 4.0 IPERF 180° phase; Orient 36 deg. CCW; 4.5" HJ II Csg Gun 6,562.0 6,582.0 6,038.4 6,056.1 A-3, 2M-16 9/24/1991 4.0 IPERF 180° phase; Orient 36 deg. CCW; 4.5" HJ II Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 141.0 35.0 141.0 Grouting / Top -Up Top Job 105 sx 15.8 ppg Class G **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 35.0 2,929.0 35.0 2,867.1 Primary – Full Bore Lead 700 sx 12.1 ppg Arctic Set IIITail 600 sx 15.8 ppg ... RU Dowell & test lines to 3000 psi. Pump 80 bbl H2O. Mix & pump 700 sxs ASIII @ 12.1 ppg. Follow w/ 600 sxs Class G Tail. Displ w/rig pump. Bump plug w/2500 psi - floats held. CIP @ 18:45. Lost returns 177 bbls into displacement. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 5,720.0 6,837.0 5,297.9 6,285.7 Primary – Full Bore Lead ... Pump 10 bbl ARCO Preflush, test lines to 3500 psi. Pump 35 bbl 11.2 ppg ARCO Spacer. Drop btm plug. Mix & Pump 250 sxs (51 bbl slurry) Gas Block @ 15.8 ppg. Drop top plug. Displ w/258 bbl 10.3 ppg brine. Move pipe every 5-10 min through displ. 10' to 15' strks. Full circ - no mud lost. ^^Csg OD=7 1,852.0 3,117.0 1,851.9 3,027.7 Squeeze – Behind Casing Squeeze Top Job 37 bbl 15.7 ppg Arctic Set I + Tail 55 bbl 7.3 ppg Arctic Pack... ArcticPak 9-5/8" x 7" annulus. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 6,301.0 6,343.7 5,808.5 5,846.0 Cement Cap Dump Bail cement on plug. 9/29/2025 2M-16, 10/6/2025 10:43:55 AM Vertical schematic (actual) PRODUCTION; 35.0-6,840.5 IPERF; 6,562.0-6,582.0 IPERF; 6,551.0-6,562.0 APERF; 6,524.0-6,540.0 IPERF; 6,510.0-6,515.0 APERF; 6,473.0-6,486.0 PLUG; 6,354.7 SAND; 6,343.7 PACKER; 6,342.2 Seal Assembly; 6,323.4 Cement Cap; 6,301.0 ftKB Primary – Full Bore; 5,720.0 ftKB SURFACE; 35.0-2,928.6 Squeeze – Behind Casing Squeeze; 1,852.0 ftKB Primary – Full Bore; 35.0 ftKB CONDUCTOR; 41.0-115.0 Grouting / Top-Up; 35.0 ftKB Hanger; 33.1 KUP INJ KB-Grd (ft) 35.00 RR Date 4/16/1991 Other Elev… 2M-16 ... TD Act Btm (ftKB) 6,848.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015300 Wellbore Status INJ Max Angle & MD Incl (°) 31.85 MD (ftKB) 3,300.00 WELLNAME WELLBORE2M-16 Annotation Last WO: End Date 8/27/2025 H2S (ppm) DateComment SSSV: TRDP STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2M-16 JBR 10/08/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 3-1/2" Test joint was used for UPR, LPR and Annular HCR Kill failed, greased again and failed again. Replaced and passed. The pit system was down while I was on the rig, PVT's were tested afterwards along with the new HCR Kill line valve. I received the test chart and video clip of PVT testing. N2 Precharge 11@ 1070 psi. Test Results TEST DATA Rig Rep:Shayne HackworthOperator:ConocoPhillips Alaska, Inc.Operator Rep:K. Barr/ R. Phillips Rig Owner/Rig No.:Nabors 7ES PTD#:1910320 DATE:8/24/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopJDH250824105256 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9 MASP: 3241 Sundry No: 325-468 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" T90 P #1 Rams 1 2-7/8" x 5" V P #2 Rams 1 Blinds P #3 Rams 1 2-7/8" x 5" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" Gate P HCR Valves 2 3 1/8" Gate FP Kill Line Valves 2 3 1/8" & 2"P Check Valve 0 NA BOP Misc 2 2-1/16" Gate P System Pressure P3050 Pressure After Closure P1600 200 PSI Attained P22 Full Pressure Attained P121 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2150 ACC Misc NA0 NT NTTrip Tank NT NTPit Level Indicators NT NTFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1           Operator test charts attached BOPE Test - Nabors 7ES KRU 2M-16 (PTD 1910320) AOGCC Insp # bopJDH250824105256 8/24/2025 KOOMEY DRAW DOWN TESTSTARTING PRESSURES MANIFOLD 15'io ACCUMULATOR 3050 PRESSURE AFTER ALL RAMS FUNCTIONED = UPPER RAM= 6 SECONDS LOWER RAM= b SECONDS ANNULAR= 27-SECONDS BLIND= b SECONDS HCR KILL= I SECONDS HCR CHOKE= \ SECONDS /600� ANNULAR looo SI 200 PSI RECOVER Y=L 2 FULL SYSTEM RECOVERY =I L I SECONDS SECONDS ELEC. PUMP RECOVERY= AIR PUMP RECOVERY= 5 Koomey bottles @ 21So Start Time of BOP Test: / 7: ) 0 Total Test Time;"'f Ir ,. ) ------ SECONDS 2 �AMS 1 HCR SECONDS 1 RAM 1 HCR PSI End Time of BOP Test: 61 '. � 0 DATE: B-1-Lf.1. 5 BOPE Test - Nabors 7ES KRU 2M-16 (PTD 1910320) AOGCC Insp # bopJDH250824105256 8/24/2025 BOPE Test - Nabors 7ES KRU 2M-16 (PTD 1910320) AOGCC Insp # bopJDH250824105256 8/24/2025 BOPE Test - Nabors 7ES KRU 2M-16 (PTD 1910320) AOGCC Insp # bopJDH250824105256 8/24/2025 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6848'N/A Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6473-6486' 6510-6515' 6524-6540' 6551-6562' 6562-6582' 6806' 5960-5971' 5992-5997' 6005-6019' 6029-6038' 6038-6056' 3-1/2" 7" 16" 9-5/8" 74' 2894' Perforation Depth MD (ft): MD 115' 2867' 115' 2929' 6289'6841' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6296'6555'6032'3241'6355' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 191-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20153-00-00 ConocoPhillips Alaska, Inc. KRU 2M-16 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Other: Replace TBG/Install Kill String Tubing Grade:Tubing MD (ft): Packer: 6342'MD/5845'TVD SSSV: 1783'MD/1783'TVD Perforation Depth TVD (ft):Tubing Size: J-55 6371' 8/12/2025 Packer: Baker HB SSSV: CAMCO TRDP 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian Glasheen brian.glasheen@conocophillips.com (907) 265-6379 RWO/CTD Engineer P s Oth 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:13 am, Aug 08, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E= brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.08 10:36:03-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen 325-468 SFD 8/11/2025 X X Subsequent Form: 10-404 AOGCC witnessed BOP Test to 3500 psi and annular to 2500 psi. AOGCC witnessed MITIA post injection. Follow attached procedure for unbolting tubing head adapter to ensure there is no upward force or movement. If upward force is encountered on TBA circulate in KWF per attachment. DSR-8/13/25JJL 8/11/25 *&: 8/14/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.14 09:49:41 -08'00' RBDMS JSB 081825 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 8, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 2M-16 (PTD# 191-032). Well 2M-16 was drilled and completed in April 1991 as a Kuparuk A-sands injector. The C-sands were perforated in 1993 as well. In 2021 the well was shut in due to tight spots in the tubing. Subsidence is expected on the well along with a surface casing leak at ~708'. This well was moved forward as a RWO candidate to address the subsidence issue. Once the subsidence issues are resolved and pending the extent of the repair a secure option may be consider. If you have any questions or require any further information, please contact me at +19075451144 A subsidence repair will be performed on the well. The tubing will be pulled. A grow and stretch will be performed on the casing to reduced the buckling in the casing and regain drift ID. If the drift ID is not achieved by the grow and stretch, the buckled 7.0" casing near surface will be pulled. New 7'' casing will be run and cemented to surface. A 3.5" tubing string with gas-tight threads and a stacked packer set below estimated TOC will be run. A variance is requested to 20 AAC 25.412 for packer setting depth. 2M-16 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 191-032 x-11Page 1 of 3 PPre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests 2. CMIT-TXIA 3000 psi Passed 3. Recut tubing at ~6312’ RKB per tally pre rig or during rig operation. 4. Tubing cut at ~1775’ RKB per tally above the SSSV pre rig or during rig operation. 5. CMIT-3000 psi/DDT-TxIA 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 2M-16. 2. Circulate SW. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500 psi. Test annular 250/2,500 psi. a. When ND tubing head adapter flange, back off nuts from the adapter flange to ensure they can move. Tighten the nuts back up to make contact with the flange face but allow them to remain loose. Backoff and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Call RWO ENGR and swap well over to KWF before continue to ND. After ND is completed and BOP’s are installed the well can be swapped back to SW if mechanical barriers are in place and the well passes a 30 min no flow to SW. If no additional tightness is observed, continue ND as planned Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. 6. If cut was made above SSSV drift 7” casing with mill prior to attempting to pull tubing section with SSSV. a. If drift is achieved, RIH and engage tubing stub and pull remaining tubing down to pre- rig cut above packer. b. If drift is not achieved, proceed with 7” Casing Subsidence Repair section. 7” Casing Subsidence Repair 7. Set storm packer or plug above SSSV or just above surface casing shoe at 2928’. PT to confirm plug is set. 8. ND BOPE. ND old tubing head. Grow casing as needed. Pull casing in tension and land in slips. NU BOPE. a. Test break as soon as practical once test plug can be installed. b. Attempt to drift 7” casing with mill after grow/stretch. If enough drift is obtained to pull SSSV, RIH and engage tubing stub and pull remaining tubing down to lower pre-rig cut. i. CMIT-2500 psi 2M-16 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 191-032 x-11Page 2 of 3 ii. Post grow and stretch, if able to regain drift ID and all the tubing is OOH down to pre rig cut at 6312. A secure option will be ran with a kill string down to 6312. iii. WBS attached with Secure plans to be completed Non-Rig 9. RU E-Line and log 7” casing from tubing stub to surface to verify free pipe. a. Estimated top of cement is 1852’ RKB. 10. RIH and cut 7” casing. Circulate out Arctic Pack diesel/slurry. 11. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections if necessary. 12. RIH with mills to ensure drift for overshot casing patch and cementer. a. Bore out 9-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, cementer, and new 7” casing. Engage overshot and PT casing to 2500 psi. 14. ND BOPE, set casing slips, cut excess 7” casing and install packoffs. NU new tubing head and BOPE. Test breaks to 250/2500 psi. 15. Cement 7” x 9-5/8” annulus to surface. 16. RIH and mill up cement. Perform additional cleanout runs if necessary. 17. RIH and wash sand from top of RBP. Retrieve RBP. 18. Pull remaining completion. Install 3-1/2” Completion with Stacked Packer 19. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 20. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLM. RIH to tubing stub. 21. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 22. Land tubing hanger, RILDS, PT packoffs and set packer. 23. Pressure test tubing to 3,500 PSI. 24. Pressure test IA to 3,000 PSI. ND BOP, NU Tree 25. Shear out SOV with pressure differential. 26. Install BPV and test. ND BOPE. NU tree. 27. Pull BPV and freeze protect well. 28. RDMO. PPost-Rig Work (WAG Status) 1. DMY GLM. 2. Pull any plugs and ball/rod used for setting packer. 3. Mill plug at 6354’ or tubing punch in tubing tail to allow injection. 4. Post-Rig Work (Secure Plan) 1. E-Line dump 35’ of Cement on top of plug at 6354’ 2. CMIT-2500 psi *AOGCC witnessed post-injection MITIA - JJL 2M-16 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 191-032 x-11Page 3 of 3 GGeneral Well Information: Estimated Start Date: 08/12/2025 Current Operations: Shut-In, secured with plug below packer Well Type: Injector Wellhead Type: FMC GEN IV, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3861 psi / 6200 TVD measured on 1/7/22 MPSP: 3,241 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above the SSSV, run a CBL, cut and pull 7” casing, replace casing with overshot casing patch and cement up OA. Install a new 3-1/2” completion and stacked packer. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) 2M-16 Proposed RWO Secure Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 2929 2867 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6841 6289 7 6.28 26 J-55 BTC BTC Tubing 6225 5742 3.5 2.992 9.3 L-80 HYD563 HYD563 PROPOSED 3.5" Kill string 3-1/2" 9.3# L-80 EUE Tubing to surface No sealing Overshot 6307' REMAINING COMPLETION LEFT IN HOLE Packer @ 6342' RKB (3.250" ID) D nipple @ 6359' RKB (2.75" ID) SOS @ 6370' RKBSurface Casing Production/Intermediate Casing Conductor A and C-sand perfs 9-5/8" SC Leak ~708' TOC~ 1852' TOC~ 5720 1991 CBT Permanent Plug 6354' 35' Cement Dumped post rig 2M-16 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 2929 2867 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6841 6289 7 6.28 26 J-55 BTC BTC Tubing 6225 5742 3.5 2.992 9.3 L-80 HYD563 HYD563 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 HDY 563 Tubing to surface 3-1/2" Camco MMG gas lift mandrel 3-1/2" x 7" Packer ~6200 2.813 X" nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot PROPOSED 7.0" Tie-Back 7.0", 26# L80, HYD563 to Surface 7.0" NCS sleeve 7.0" Sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6342' RKB (3.250" ID) D nipple @ 6359' RKB (2.75" ID) SOS @ 6370' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs 9-5/8" SC Leak ~708' TOC~ 1852' TOC~ 5720 1991 CBT Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,555.0 2M-16 6/6/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set hold open assembly across SSSV 2M-16 7/6/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/12/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 2,928.6 2,866.8 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 6,840.5 6,288.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 6,370.9 String Max No… 3 1/2 Set Depth … 5,869.9 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.0 33.0 0.05 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,783.2 1,783.1 1.03 SAFETY VLV 5.937 TRDP-4A SAFETY VALVE Camco TRDP- 4A 2.812 2,950.0 2,885.2 30.84 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,818.6 4,503.2 28.56 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.867 5,945.6 5,496.9 28.55 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,273.2 5,784.1 28.53 GAS LIFT 5.968 MMG Camco MMG 2.920 6,328.4 5,832.6 28.45 PBR 5.125 PBR w/ 10' STROKE W/4" SEAL BORE Baker 3.000 6,342.1 5,844.6 28.46 PACKER 6.062 HB RETRIEVABLE PACKER Baker HB 2.890 6,358.5 5,859.0 28.48 NIPPLE 4.540 D NIPPLE NO GO Camco D 2.750 6,370.1 5,869.2 28.49 SOS 3.500 SHEAR OUT SUB, TTL ELMD @ 6863' SWS IPROF 12/23/2006 Baker 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 284.0 284.0 0.43 TIGHT SPOT Tight Spot Identified with Slicking (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 450.0 450.0 0.48 TIGHT SPOT Tight Spot Identified with Slicking (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 550.0 550.0 0.48 TIGHT SPOT Tight Spot Identified with Slicking (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 600.0 600.0 0.48 TIGHT SPOT Tight Spot Identified with Slicking (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 760.0 760.0 0.51 TIGHT SPOT Tight Spot Identified with Slicking (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 1,350.0 1,350.0 0.60 TIGHT SPOT Tight Spot Identified with Slicking (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 1,783.0 1,782.9 1.03 OTHER 2.15'' BS W/ 1.81'' FN, FLOW THRU SUB, 1.75 XO, 2.84'' NO GO, 1.50'' ALUMINUM ROD (OAL 67") NOTE: ROD IS SET ACROSS FLAPPER KEEPING IT OPEN. UNABLE TO RUN TOOLS THRU THIS ASSEMBLY. 7/6/2023 0.000 6,307.0 5,813.8 28.43 CUT 1.75" RCT TBG CUT AT 6307' RKB 7/1/2023 2.992 6,354.7 5,855.7 28.47 PLUG 2.19 MAGNA RANGE PLUG (MID ELEMENT @ 6,356') 1.90' OAL (PLUG IS NOT RETRIEVABLE, BUT IT IS MILLABLE) 4200- 219- AC- 001 1/7/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,950.0 2,885.2 30.84 1 GAS LIFT DMY BK 1 0.0 9/24/1991 0.000 4,818.6 4,503.2 28.56 2 GAS LIFT DMY BK 1 0.0 9/24/1991 0.000 5,945.6 5,496.9 28.55 3 GAS LIFT DMY BK 1 0.0 9/24/1991 0.000 6,273.2 5,784.1 28.53 4 GAS LIFT OPEN OPEN 1 1/2 1/8/2022 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,473.0 6,486.0 5,959.7 5,971.2 C-4, UNIT B, 2M -16 2/7/1993 4.0 APERF 180° phase; Orient 11.5 deg. CCW; 4.5" Csg Gun 6,510.0 6,515.0 5,992.4 5,996.8 A-5, 2M-16 9/24/1991 4.0 IPERF 180° phase; Orient 17 deg. CCW; 2.5" Nav Pak Perf 2M-16, 8/8/2025 8:57:49 AM Vertical schematic (actual) PRODUCTION; 35.0-6,840.5 IPERF; 6,562.0-6,582.0 IPERF; 6,551.0-6,562.0 APERF; 6,524.0-6,540.0 IPERF; 6,510.0-6,515.0 APERF; 6,473.0-6,486.0 PLUG; 6,354.7 PACKER; 6,342.1 CUT; 6,307.0 Primary – Full Bore; 5,720.0 ftKB GAS LIFT; 6,273.2 GAS LIFT; 5,945.6 GAS LIFT; 4,818.6 GAS LIFT; 2,950.0 SURFACE; 35.0-2,928.6 Squeeze – Behind Casing Squeeze; 1,852.0 ftKB SAFETY VLV; 1,783.2 OTHER; 1,783.0 Primary – Full Bore; 35.0 ftKB TIGHT SPOT; 1,350.0 TIGHT SPOT; 760.0 TIGHT SPOT; 600.0 TIGHT SPOT; 550.0 TIGHT SPOT; 450.0 TIGHT SPOT; 284.0 CONDUCTOR; 41.0-115.0 Grouting / Top-Up; 35.0 ftKB KUP INJ KB-Grd (ft) 35.00 RR Date 4/16/1991 Other Elev… 2M-16 ... TD Act Btm (ftKB) 6,848.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015300 Wellbore Status INJ Max Angle & MD Incl (°) 31.85 MD (ftKB) 3,300.00 WELLNAME WELLBORE2M-16 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,524.0 6,540.0 6,004.7 6,018.9 A-4, 2M-16 7/5/1992 4.0 APERF 180° phase; Orient 28 deg. CCW; 2.5" Nav Pak Perf 6,551.0 6,562.0 6,028.6 6,038.4 A-3, 2M-16 9/24/1991 4.0 IPERF 180° phase; Orient 36 deg. CCW; 4.5" HJ II Csg Gun 6,562.0 6,582.0 6,038.4 6,056.1 A-3, 2M-16 9/24/1991 4.0 IPERF 180° phase; Orient 36 deg. CCW; 4.5" HJ II Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 141.0 35.0 141.0 Grouting / Top -Up Top Job 105 sx 15.8 ppg Class G **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 35.0 2,929.0 35.0 2,867.1 Primary – Full Bore Lead 700 sx 12.1 ppg Arctic Set IIITail 600 sx 15.8 ppg ... RU Dowell & test lines to 3000 psi. Pump 80 bbl H2O. Mix & pump 700 sxs ASIII @ 12.1 ppg. Follow w/ 600 sxs Class G Tail. Displ w/rig pump. Bump plug w/2500 psi - floats held. CIP @ 18:45. Lost returns 177 bbls into displacement. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 5,720.0 6,837.0 5,297.9 6,285.7 Primary – Full Bore Lead ... Pump 10 bbl ARCO Preflush, test lines to 3500 psi. Pump 35 bbl 11.2 ppg ARCO Spacer. Drop btm plug. Mix & Pump 250 sxs (51 bbl slurry) Gas Block @ 15.8 ppg. Drop top plug. Displ w/258 bbl 10.3 ppg brine. Move pipe every 5-10 min through displ. 10' to 15' strks. Full circ - no mud lost. ^^Csg OD=7 1,852.0 3,117.0 1,851.9 3,027.7 Squeeze – Behind Casing Squeeze Top Job 37 bbl 15.7 ppg Arctic Set I + Tail 55 bbl 7.3 ppg Arctic Pack... ArcticPak 9-5/8" x 7" annulus. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 2M-16, 8/8/2025 8:57:49 AM Vertical schematic (actual) PRODUCTION; 35.0-6,840.5 IPERF; 6,562.0-6,582.0 IPERF; 6,551.0-6,562.0 APERF; 6,524.0-6,540.0 IPERF; 6,510.0-6,515.0 APERF; 6,473.0-6,486.0 PLUG; 6,354.7 PACKER; 6,342.1 CUT; 6,307.0 Primary – Full Bore; 5,720.0 ftKB GAS LIFT; 6,273.2 GAS LIFT; 5,945.6 GAS LIFT; 4,818.6 GAS LIFT; 2,950.0 SURFACE; 35.0-2,928.6 Squeeze – Behind Casing Squeeze; 1,852.0 ftKB SAFETY VLV; 1,783.2 OTHER; 1,783.0 Primary – Full Bore; 35.0 ftKB TIGHT SPOT; 1,350.0 TIGHT SPOT; 760.0 TIGHT SPOT; 600.0 TIGHT SPOT; 550.0 TIGHT SPOT; 450.0 TIGHT SPOT; 284.0 CONDUCTOR; 41.0-115.0 Grouting / Top-Up; 35.0 ftKB KUP INJ 2M-16 ... WELLNAME WELLBORE2M-16 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Glasheen, Brian To:Coberly, Jonathan; Lau, Jack J (OGC) Cc:Dodson, Kate; Hobbs, Greg S; Nezaticky, Peter; Nabors 7ES Company Man; Klem, Adam Subject:RE: 2M-16 Additional Language - For 10-403 in process Date:Friday, August 1, 2025 11:40:05 AM Jack, Per conversation if we were to add the following to 2M-16 Sundry it will be the steps we take. Jonathan verbiage is meant to capture general wells not 2M-16 specifically. For 2M-16 this will be the plan forward: "When ND tubing head adapter flange, back off nuts from the adapter flange to ensure they can move. Tighten the nuts back up to make contact with the flange face but allow them to remain loose. Backoff and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Call RWO ENGR and swap well over to KWF before continue to ND. After ND is completed and BOP’s are installed the well can be swapped back to SW if mechanical barriers are in place and the well passes a 30 min no flow to SW. If no additional tightness is observed, continue ND as planned." Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Sent: Thursday, July 31, 2025 7:24 PM To: jack.lau@alaska.gov Cc: Dodson, Kate <Kate.Dodson@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Nezaticky, Peter <P.Nezaticky@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com>; Nabors 7ES Company Man <NSKRWO.CM@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com> Subject: 2M-16 Additional Language - For 10-403 in process Jack, Starting with 2M-16: In order to better predict the issue of tubing hanger growth during adapter flange removal and retain our abilities to react to the issue if it arises, we will put the following language in our subsidence repair scope programs and review it with onsite personnel as part of our lessons learned process. "When ND tubing head adapter flange, back off nuts from the adapter flange to ensure they can move. Tighten the nuts back up to make contact with the flange face but allow them to remain loose. Backoff and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Consult Engineering for plan forward on barriers. If no additional tightness is observed, continue ND as planned." If we determine that the surface barrier is compromised through this technique my team will evaluate the situation and add additional barriers like KWF if it is not already in the well. These KWF values are already known and planned as part of normal planning process and available if determined to be needed for the NU/ND of primary pressure control equipment or BOPE. I'm providing this language to better communicate how we intend to manage this risk in the future and it is to be taken in consideration for the 2M-16 Sundry review currently in process. Jonathan Coberly RWO Engineering Supervisor ConocoPhillips 907-538-8398 Sent from my Verizon, Samsung Galaxy smartphone Get Outlook for Android CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Coberly, Jonathan To:Lau, Jack J (OGC) Cc:Dodson, Kate; Hobbs, Greg S; Nezaticky, Peter; Glasheen, Brian; Nabors 7ES Company Man; Klem, Adam Subject:2M-16 Additional Language - For 10-403 in process Date:Thursday, July 31, 2025 7:23:59 PM Jack, Starting with 2M-16: In order to better predict the issue of tubing hanger growth during adapter flange removal and retain our abilities to react to the issue if it arises, we will put the following language in our subsidence repair scope programs and review it with onsite personnel as part of our lessons learned process. "When ND tubing head adapter flange, back off nuts from the adapter flange to ensure they can move. Tighten the nuts back up to make contact with the flange face but allow them to remain loose. Backoff and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Consult Engineering for plan forward on barriers. If no additional tightness is observed, continue ND as planned." If we determine that the surface barrier is compromised through this technique my team will evaluate the situation and add additional barriers like KWF if it is not already in the well. These KWF values are already known and planned as part of normal planning process and available if determined to be needed for the NU/ND of primary pressure control equipment or BOPE. I'm providing this language to better communicate how we intend to manage this risk in the future and it is to be taken in consideration for the 2M-16 Sundry review currently in process. Jonathan Coberly RWO Engineering Supervisor ConocoPhillips 907-538-8398 Sent from my Verizon, Samsung Galaxy smartphone Get Outlook for Android 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6848'N/A Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6473-6486' 6510-6515' 6524-6540' 6551-6562' 6562-6582' 6806' 5960-5971' 5992-5997' 6005-6019' 6029-6038' 6038-6056' 3-1/2" 7" 16" 9-5/8" 74' 2894' Perforation Depth MD (ft): MD 115' 2867' 115' 2929' 6289'6841' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6296'6555'6032'3241'6355' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 191-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20153-00-00 ConocoPhillips Alaska, Inc. KRU 2M-16 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Tubing Grade:Tubing MD (ft): Packer: 6342'MD/5845'TVD SSSV: 1783'MD/1783'TVD Perforation Depth TVD (ft):Tubing Size: J-55 6371' 8/15/2025 Packer: Baker HB SSSV: CAMCO TRDP 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian Glasheen brian.glasheen@conocophillips.com (907)545-1144 RWO Engineer P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:19 am, Jul 10, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E= brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2025.07.09 16:07:10-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen 325-412 JJL 8/125 X AOGCC witnessed BOP Test to 3500 psi and annular to 2500 psi. AOGCC witnessed MITIA post injection. Follow attached procedure for unbolting tubing head adapter to ensure there is no upward force or movement. If upward force is encountered on TBA circulate in KWF per attachment. X DSR-7/16/25 Subsequent Form Required: 10-404 A.Dewhurst 01AUG25GKC for GW 8/1/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.01 16:40:44 -08'00'08/01/25 RBDMS JSB 080525 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 9, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 2M-16 (PTD# 191-032). Well 2M-16 was drilled and completed in April 1991 as a Kuparuk A-sands injector. The C-sands were perforated in 1993 as well. In 2021 the well was shut in due to tight spots in the tubing. Subsidence is expected on the well along with a surface casing leak at ~708'. This well was moved forward as a RWO candidate to address both subsidence and the SC leak. If you have any questions or require any further information, please contact me at +19075451144 A subsidence repair will be performed on the well. The tubing will be pulled. Then the buckled 7.0" casing near surface will be pulled. New 7'' casing will be run and cemented to surface. A 3.5" tubing string with gas-tight threads and a stacked packer set below estimated TOC will be run. A variance is requested to 20 AAC 25.412 for packer setting depth. 2M-16 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 191-032 x-11Page 1 of 2 PPre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests 2. CMIT-TXIA 3000 psi 3. Recut tubing at ~6312’ RKB per tally pre rig or during rig operation. 4. Tubing cut at ~1775’ RKB per tally above the SSSV pre rig or during rig operation. 5. CMIT-3000 psi/DDT-TxIA 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 2M-16. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. 6. If cut was made above SSSV drift 7” casing with mill prior to attempting to pull tubing section with SSSV. a. If drift is achieved, RIH and engage tubing stub and pull remaining tubing down to pre- rig cut above packer. b. If drift is not achieved, proceed with 7” Casing Subsidence Repair section. 7” Casing Subsidence Repair 7. Set storm packer or plug above SSSV or just above surface casing shoe at 2928’. PT to confirm plug is set. Dump sand on top of plug. 8. ND BOPE. ND old tubing head. Grow casing as needed. Pull casing in tension and land in slips. NU BOPE to casing head. a. Test break as soon as practical once test plug can be installed. b. Attempt to drift 7” casing with mill after grow/stretch. If enough drift is obtained to pull SSSV, RIH and engage tubing stub and pull remaining tubing down to lower pre-rig cut. 9. RU E-Line and log 7” casing from tubing stub to surface to verify free pipe. a. Estimated top of cement is 1852’ RKB. 10. RIH and cut 7” casing. Circulate out Arctic Pack diesel/slurry. 11. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections if necessary. 12. RIH with mills to ensure drift for overshot casing patch and cementer. a. Bore out 9-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, cementer, and new 7” casing. Engage overshot and PT casing to 2500 psi. 14. ND BOPE, set casing slips, cut excess 7” casing and install packoffs. NU new tubing head and BOPE. Test breaks to 250/2500 psi. -See attached ND procedure from Brian Glasheen - JJL 2M-16 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 191-032 x-11Page 2 of 2 15. Cement 7” x 9-5/8” annulus to surface. 16. RIH and mill up cement. Perform additional cleanout runs if necessary. 17. RIH and wash sand from top of RBP. Retrieve RBP. 18. Pull remaining completion. Install 3-1/2” Completion with Stacked Packer 19. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 20. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLM. RIH to tubing stub. 21. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 22. Land tubing hanger, RILDS, PT packoffs and set packer. 23. Pressure test tubing to 3,500 PSI. 24. Pressure test IA to 3,000 PSI. ND BOP, NU Tree 25. Shear out SOV with pressure differential. 26. Install BPV and test. ND BOPE. NU tree. 27. Pull BPV and freeze protect well. 28. RDMO. PPost-Rig Work 1. DMY GLM. 2. Pull any plugs and ball/rod used for setting packer. 3. Mill plug at 6354’ or tubing punch in tubing tail to allow injection. General Well Information: Estimated Start Date: 08/15/2025 Current Operations: Shut-In, secured with plug below packer Well Type: Injector Wellhead Type: FMC GEN IV, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3861 psi / 6200 TVD measured on 1/7/22 MPSP: 3,241 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above the SSSV, run a CBL, cut and pull 7” casing, replace casing with overshot casing patch and cement up OA. Install a new 3-1/2” completion and stacked packer. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) 2M-16 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 2929 2867 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6841 6289 7 6.28 26 J-55 BTC BTC Tubing 6225 5742 3.5 2.992 9.3 L-80 HYD563 HYD563 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 HDY 563 Tubing to surface 3-1/2" Camco MMG gas lift mandrel 3-1/2" x 7" Packer ~6200 2.813 X" nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot PROPOSED 7.0" Tie-Back 7.0", 26# L80, HYD563 to Surface 7.0" NCS sleeve 7.0" Sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6342' RKB (3.250" ID) D nipple @ 6359' RKB (2.75" ID) SOS @ 6370' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs 9-5/8" SC Leak ~708' TOC~ 1852' TOC~ 5720 1991 CBT 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6848'N/A Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Wells Engineer Tubing Grade: Tubing MD (ft): Packer: 6342'MD/5845'TVD SSSV: 1783'MD/1783'TVD Perforation Depth TVD (ft): Tubing Size: J-55 6371' Packer: Baker HB SSSV: CAMCO TRDP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 191-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20153-00-00 ConocoPhillips Alaska, Inc. KRU 2M-16 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6296' 6555' 6032' 3136 6355' MD 115' 2867' 115' 2929' 6289'6841' 16" 9-5/8" 74' 2894' Perforation Depth MD (ft): 6473-6486' 6510-6515' 6524-6540' 6551-6562' 6562-6582' 6806' 5960-5971' 5992-5997' 6005-6019' 6029-6038' 6038-6056' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 7/18/2023 By Grace Christianson at 10:42 am, Jul 06, 2023 323-375 BOP test to 3500 psig Annular preventer test to 2500 psig X MDG 7/17/2023 XX VTL 7/27/2023 10-404 DSR-7/6/23JLC 7/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:11:12 -05'00'07/18/23 RBDMS JSB 071823 2M-16 RWO Procedure Kuparuk Injector PTD #191-032 Page 1 of 3 Remaining Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT. 2. MIT-OA. 3. Install hold-open sleeve in SSSV as necessary. 4. Open lowest GLM in upper completion. Dummy off the rest. 5. Cut the tubing nominally at ~6315 RKB in the middle of the first full joint above the production packer. 6. Prepare well within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors N7ES on 2M-16. (No BPV will be installed due to risk assessment done for MIRU/RDMO on N7ES w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3500 psi. Test annular 250/3500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~6315’ RKB). a. If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7”, then pull remaining completion. Pull Subsided 7.0” Casing 6. Set storm packer or plug in 7” casing and PT to confirm as barrier. a. Set additional IBPs in 7.0” casing and dump sand as necessary. 7. Swap lower ram to 7.0” casing ram and test to BOPE test pressure if not already done so. 8. ND BOPE. ND old tubing spool. NU BOPE and test flange break as soon as possible. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. b. Shell test to 3000 psig when flanges with 3000 psi rating are exposed to shell tests. 9. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. 10. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry as needed. 11. Pull 7.0” casing down to cut (~2000’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. b. If any 3.5” tubing was left downhole. Pull 3.5” tubing to clear wellbore for liner running. 12. *Depending how 7.0” Casing pulls/removed, go to “Contingency for 7.0” Tie-Back Subsidence”. Run New 3.5” x 5.5” Tie-back Liner 13. RIH with 3.5” overshot, Nipple profile, 3.5” x 7.0” packer, 3.5” x 5.5” crossover, 5.5” x 7.0” packer, and 5.5” tie- back liner to surface. (Crossover to 7.0” at surface for last joint if needed for wellhead termination.) 14. Reverse circulate in CI fluid and freeze protect as needed. 15. Pressure up on tubing to set both the 3.5” x 7.0” and the 5.5” x 7.0” packers. 16. RU SL and RIH to pull isolation sleeve across communication ports in top of PBR assembly. a. Communication port allows pressure communication from 3.5” x 5.5” annulus down to 3.5” x 7.0” annulus. Covered up on initial install to allow packer setting. b. If SL not available, then finish steps below to terminate 5.5” and get new tubing spool on. Then RIH and pull sleeve with tubing. 17. PT 5.5” liner to 3000 psig for 30 minutes and chart. (This is the new IA envelope.) 18. Set 5.5” RBP near surface. PT to confirm as barrier. 2M-16 RWO Procedure Kuparuk Injector PTD #191-032 19. ND BOPE. Finish 5.5” termination. NU new tubing spool. NU BOPE. Test flange breaks. 20. Swap lower ram to VBRs for running 3.5” tubing. Test same to BOPE pressure. 21. Pull 5.5” RBP. Install new 3-½” Completion 22. MU 3 ½” slim completion with seals, nipples, and GLMs. RIH with completion. 23. Once on depth, stab in seals and space out as needed. Circulate in CI fluid at opportune time. 24. Pressure test tubing to 3500 psi for 30 minutes and chart. 25. Pressure test inner annulus to 3000 psi for 30 minutes on chart. ND BOP, NU Tree 26. Confirm pressure tests, then shear out SOV with pressure differential. 27. Install BPV. 28. ND BOPE. NU tree. PT tree. 29. Pull BPV, freeze protect well, and set BPV if necessary. 30. RDMO. Post-Rig Work 31. Pull BPV 32. Pull dual flapper valve. 33. Install GLD. Contingency for 7.0” Tie-Back Subsidence Bore out 9-5/8” and run 7.0” Tie-Back Subsidence instead of 5.5” x 3.5” tie-back 1. PU mills and bore out 9-5/8” as necessary to obtain drift for new 7.0” tie-back. a. As drift is regained, pull any additional 7.0” or 3.5” tubing as needed to get 7.0” removed down to cement in OA. 2. Run new 7.0” tie-back casing with overshot. 3. Test casing to 2500 psig. 4. Cement OA to surface. 5. Perform 30 minute no flow test, split stack and land slips, cut excess casing and install IC packoffs. Land stack and MU to casing flange. a. Test flange break to BOPE test pressure. 6. Mill plugs in cementer. 7. Circulate out sand on IBP or any lower plug. 8. Swap lower ram to VBRs for running 3.5” tubing. Test same to BOPE pressure. 9. Pull any lower plugs or remaining 3.5”. 10. Return to “Install new 3-1/2” Completion”. General Well info: Wellhead type/pressure rating:FMC Gen IV. 7-1/16” 5M psi top flange x 11” 3M psi bottom flange Production Engineer:Natalie Dye Reservoir Development Engineer:Mandy Pogany Estimated Start Date:7/18/2023 Workover Engineer:Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Page 2 of 3 2M-16 RWO Procedure Kuparuk Injector PTD #191-032 Page 3 of 3 Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Pull buckled 7.0” casing near surface. Run new 3.5” x 5.5” tie-back liner with dual packers deep. Run slim new 3-1/2” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 1/8/2022 CMIT-TxIA Passed 1/11/2022 MIT-OA Passed 1/18/2008 IC POT &PPPOT N/A TBG POT &PPPOT N/A MPSP: 3136 psi using 0.1 psi/ft gradient Static BHP: 3737 psi / 6005’ TVD measured on 1/7/2022 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,555.0 6/6/2021 2M-16 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Magna Range Plug & Pull DV 1/8/2022 2M-16 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 2,928.6 Set Depth (TVD) … 2,866.8 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,840.5 Set Depth (TVD) … 6,288.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.0 Set Depth (ft… 6,370.9 Set Depth (TVD) (… 5,869.9 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 33.0 33.0 0.05 HANGER 3.500 8.000 FMC GEN IV TUBING HANGER 1,783.2 1,783.1 1.03 SAFETY VLV 2.812 5.937 CAMCO TRDP-4A CAMCO TRDP-4A SAFETY VALVE 2,950.0 2,885.2 30.84 GAS LIFT 2.920 5.390 CAMCO KBUG CAMCO KBUG 4,818.6 4,503.2 28.56 GAS LIFT 2.867 5.390 CAMCO KBUG CAMCO KBUG 5,945.6 5,496.9 28.55 GAS LIFT 2.920 5.390 CAMCO KBUG CAMCO KBUG 6,273.2 5,784.1 28.53 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG 6,328.4 5,832.6 28.45 PBR 3.000 5.125 BAKER BAKER PBR w/ 10' STROKE W/4" SEAL BORE 6,342.1 5,844.6 28.46 PACKER 2.890 6.062 BAKER HB BAKER HB RETRIEVABLE PACKER 6,358.5 5,859.0 28.48 NIPPLE 2.750 4.540 CAMCO D CAMCO D NIPPLE NO GO 6,370.1 5,869.2 28.49 SOS 2.990 3.500 BAKER BAKER SHEAR OUT SUB, TTL ELMD @ 6863' SWS IPROF 12/23/2006 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 284.0 284.0 0.43 TIGHT SPOT TIGH SPOT IDENTIFIED WITH SLICKLING (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 450.0 450.0 0.48 TIGHT SPOT TIGH SPOT IDENTIFIED WITH SLICKLING (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 550.0 550.0 0.48 TIGHT SPOT TIGH SPOT IDENTIFIED WITH SLICKLING (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 600.0 600.0 0.48 TIGHT SPOT TIGH SPOT IDENTIFIED WITH SLICKLING (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 760.0 760.0 0.51 TIGHT SPOT TIGH SPOT IDENTIFIED WITH SLICKLING (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 1,350.0 1,350.0 0.60 TIGHT SPOT TIGH SPOT IDENTIFIED WITH SLICKLING (CAN PASS WITH FULL OD 1' ASSEMBLY) 6/7/2021 6,354.7 5,855.7 28.47 PLUG 2.19 MAGNA RANGE PLUG (MID ELEMENT @ 6,356') 1.90' OAL (PLUG IS NOT RETRIEVABLE, BUT IT IS MILLABLE) 1/7/2022 0.000 4200-219-AC- 001 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,950.0 2,885.2 30.84 1 GAS LIFT DMY BK 0.000 0.0 9/24/1991 2 4,818.6 4,503.2 28.56 1 GAS LIFT DMY BK 0.000 0.0 9/24/1991 3 5,945.6 5,496.9 28.55 1 GAS LIFT DMY BK 0.000 0.0 9/24/1991 4 6,273.2 5,784.1 28.53 1 1/2 GAS LIFT OPEN OPEN 1/8/2022 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,473.0 6,486.0 5,959.7 5,971.2 C-4, UNIT B, 2M -16 2/7/1993 4.0 APERF 180 deg. phase; Orient 11.5 deg. CCW; 4.5" Csg Gun 6,510.0 6,515.0 5,992.4 5,996.8 A-5, 2M-16 9/24/1991 4.0 IPERF 180 deg. phase; Orient 17 deg. CCW; 2.5" Nav Pak Perf 6,524.0 6,540.0 6,004.7 6,018.9 A-4, 2M-16 7/5/1992 4.0 APERF 180 deg. phase; Orient 28 deg. CCW; 2.5" Nav Pak Perf 6,551.0 6,562.0 6,028.6 6,038.4 A-3, 2M-16 9/24/1991 4.0 IPERF 180 deg. phase; Orient 36 deg. CCW; 4.5" HJ II Csg Gun 6,562.0 6,582.0 6,038.4 6,056.1 A-3, 2M-16 9/24/1991 4.0 IPERF 180 deg. phase; Orient 36 deg. CCW; 4.5" HJ II Csg Gun Notes: General & Safety End Date Annotation 11/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2M-16, 1/9/2022 7:09:04 AM Vertical schematic (actual) PRODUCTION; 35.0-6,840.5 IPERF; 6,562.0-6,582.0 IPERF; 6,551.0-6,562.0 APERF; 6,524.0-6,540.0 IPERF; 6,510.0-6,515.0 APERF; 6,473.0-6,486.0 SOS; 6,370.1 NIPPLE; 6,358.5 PLUG; 6,354.7 PACKER; 6,342.1 PBR; 6,328.4 GAS LIFT; 6,273.2 GAS LIFT; 5,945.6 GAS LIFT; 4,818.6 GAS LIFT; 2,950.0 SURFACE; 35.0-2,928.6 SAFETY VLV; 1,783.2 TIGHT SPOT; 1,350.0 TIGHT SPOT; 760.0 TIGHT SPOT; 600.0 TIGHT SPOT; 550.0 TIGHT SPOT; 450.0 TIGHT SPOT; 284.0 CONDUCTOR; 41.0-115.0 HANGER; 33.0 KUP INJ KB-Grd (ft) 35.00 Rig Release Date 4/16/1991 2M-16 ... TD Act Btm (ftKB) 6,848.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015300 Wellbore Status INJ Max Angle & MD Incl (°) 31.85 MD (ftKB) 3,300.00 WELLNAME WELLBORE2M-16 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 2M-16 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 2929 2867 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6841 6289 7 6.28 26 J-55 BTC BTC Liner 6315 5821 5.5x3.5 4.95 15.5 L-80 HYD563MS HYD563MS Tubing 6225 5742 3.5 2.992 9.3 L-80 HYD563 HYD563 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface 5-1/2" x 7.0" Packer PBR for 3-1/2" Seals (with port to IA covered with sleeve on install) 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" x 7" Packer 2.75" D-landing nipple at xxxx' RKB (2.75" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6342' RKB (3.250" ID) D nipple @ 6359' RKB (2.75" ID) SOS @ 6370' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs 9-5/8" SC Leak ~708' 2M-16 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top)Thread (btm) Conductor 115 115 16 15.06 62.58 H-40 Welded Welded Surface 2929 2867 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6841 6289 7 6.28 26 J-55/L80 BTC/HYD563 BTC/HYD563 Liner Tubing 6225 5742 3.5 2.992 9.3 L-80 HYD563 HYD563 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrel @ TBD 3-1/2" x 7" Packer 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot PROPOSED 7.0" Tie-Back 7.0", 26# L80, HYD563 to Surface 7.0" Cementer 7.0" Sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6342' RKB (3.250" ID) D nipple @ 6359' RKB (2.75" ID) SOS @ 6370' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs 9-5/8" SC Leak ~708' MEMORANDUM TO: Jim Regg 1? P.I. Supervisor kefq L I%LI r zo FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2M-16 KUPARUK RIV UNIT 2M-16 Src: Inspector Reviewed By: P.I. Supry _5(3i7— Comm Well Name KUPARUK RN UNIT 2M-16 API Well Number 50-103-20153-00-00 Inspector Name: Adam Earl Permit Number: 191-032-0 Inspection Date: 6/12/2020 Insp Num: mitAGE200617104234 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-16 Type Inj N - TVD 5844 Tubing 200 1200 1200 1200 PTD JBBL 91os2o Type Test srr Test psi 560 - IA Sao 000 - 900 820 Pumped: t5 'BBL Returned: 1.5 OA 60 - 60 - 60 60 ' �— In 4vRTST p/F --- — P Notes: MIT IA Shut in for curtailment _ Wednesday, June 17, 2020 Page 1 of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Regg (f-` P.I.Supervisor '\ CL � �jt f t, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-16 FROM: Jeff Jones KUPARUK RIV UNIT 2M-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-16 API Well Number 50-103-20153-00-00 Inspector Name: Jeff Jones Permit Number: 191-032-0 Inspection Date: 6/5/2016 Insp Num: mitJJ160608091759 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-16 Type Inj W'TVD 5844 Tubing 2057 2056, 2046 • T 2050 - PTD 1910320 Type Test SPT Test psi 1500 - IA540 2920 - 2780 2750 - Interval 4YRTST P/F P OA 80 - 80 - 80 - 80 Notes: 1 well inspected,no exceptions noted. scoot) DEC 2 9 2016 Thursday,June 09,2016 Page 1 of 1 ~. ~~~: Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~Il ~~ ~~?9 4. ~~~4 ~e ~ LX N'ai :v ~_ a a,- `; ~ ~5 -'s.-.. .. . .. N0. 5138 r? ,I ii ~ Company; Alaska Oil & Gas Cons Comm ~, j Attn: Christine Mahnken 333 West 7th Ave, Suite 100 `~.!~•,.~~~- Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 03/18/09 2A-26 B04C-00011 OH EDIT (PEX,SSCANNER & CHFR) -0941. ~y 02/14/09 6 1 1 E-170 ANHY-00057 PRODUCTION PROFILE ~ ^' 03/06/09 1 1 1A-11 ANHY-00058 LDL - (.t 03/08/09 1 1 3G-04 ANHY-00060 PRODUCTION PROFILE Q_ 03/10/09 1 1 3B-15 ANHY-00061 INJECTION PROFILE J - ~ 03/11/09 1 1 1 R-10 ANHY-00063 INJECTION PROFILE C 03/13!09 1 1 2M-16 ANHY-00064 INJECTION PROFILE / 03/14/09 1 1 2G-15 ANHY-00065 PRODUCTION PROFILE f G(~ ! 03/15/09 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. • • BEM®~N~~M To: Jim Regg "~ P.I. Supervisor ~~~1 ~ f l~I~XJ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA [NC 2M-16 KUPARLJK RIV i1NIT 2M-16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `f~j7~-- Comm Well Name• KUPARUK RN UNIT 2M-16 Insp Num: mitJJ080610124909 Rel Insp Num: API Well Number: so-to3-zo1s3-oo-0o Permit Number: 191-032-0 :.% Inspector Name• Jeff Jones Inspection Date: 62/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2M-16 TYPe Inj.~ ~i 'I'mo I seas = IA 900 ! z9zo ~~ z8so i zsao p.T I ~9loszo IT eTest sPT i Test si ~ yP P Isoo ter" OA 200 I 400 - L 400 a00 ~I j Interval 4YRTST p~F, P ~% Tubing ~ zozo zoos Ii i99o zooo NOteS• 2.5 BBLS diesel pumped; no exceptions noted. Wednesday, June 1 1, 2008 Page 1 of 1 ~..~~- - Schlumbel'gel' ll\ 1- 03d- sCANNED j\jN ~ 1 2007 06/14/07 UXC- NO. 4300 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ."--- , q9mPanyf·....;,(rás·ka Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~þ 0. ') (1[1'1 ., \, L JUt Field: Kuparuk Well Job# CD Log Description Date BL Color 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07107 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 28-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . (] 1i ~ ~~_~~~~n_~ .~~""-~ ./< 01/02/07 Schlumbel'gel' NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 :¡GANNED JAN 0 8 2007 UIC.- I c¡ I -ð3 (7- Field: Kuparuk Well Job # Log Description BL Color CD Date 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 1D-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1 G-16 11551836 INJECTION PROFILE 12/19/06 1 1 D-1 03 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~{/;t-1f' ?¿'4 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admln.state.~ .us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2M DATE: 06/28/04 OPERATOR REP: Sauvageau 1 Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2M-03 Type Inj S T.V.D. 5939 Tubing 2400 2400 2400 2400 Interval 4 P.TD. 1911410 Type Test P Test psi 1500 Casing 1250 1800 1770 1760 P/F P Notes: Well 2M-14 Type Inj G T.V.D. 6025 Tubing 3550 3550 3550 3550 Interval 4 P.TD. 1920630 Type Test P Test psi 1506 Casing 550 1920 1910 1910 P/F P Notes: Well 2M-16 Type Inj S T.V.D. 5845 Tubing 2300 2300 2300 2300 Interval 4 P.TD. 1910320 Type Test P Test psi 1500 Casing 900 2910 2850 2840 P/F P Notes: Well 2M-17 Type Inj G TV.D. 6005 Tubing 3580 3580 3580 3580 Interval 4 P.TD. 1910180 Type Test P Test psi 1501 Casing 2800 1600 1620 1620 P/F P Notes: Drawdown test due to high IA initial pressure Well 2M-19 Type Inj S TV.D. 5856 Tubing 2000 2000 2000 2000 Interval 4 P.TD. 1911320 Type Test P Test psi 1500 Casing 135 2600 2600 2600 P/F P Notes: Well 2M-23 Type Inj N TV.D. 1551 Tubing 100 100 100 100 Interval 4 P.T.D. 1910340 Type Test P Test psi 1500 Casing 0 1800 1750 1720 P/F P Notes: Class 2 disposal well. IA & OA common via circ string Well 2M-26 Type Inj G TV.D. 5971 Tubing 3100 3100 3100 3100 Interval 4 P.TD. 1920550 Type Test P Test psi 1500 Casing 1550 2320 2300 2300 P/F P Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe In notes) MIT Report Form Revised: 05/19/02 2004-0628_MIT _KRU_2M-26.xls 7/13/2004 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2 2000 P M E E L E W A T E R IA L U N D E THIS MARKER R C:LORIhMFILM.DOC ARCO Alaska, Inc.:---% Post Office; 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 MaY 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION Stimulate ,'?~- ~,-~ 2M-18 Stimulate Stimulate :i? !~?.. 2M-19 Stimulate Stimulate ,~-~-? ~: _¢.~ 2M-20 Stimulate Stimulate ~:; ~;_,-~ 2M-21 Stimulate Stimulate q~.~q~'t 2M-22 Stimulate Stimulate ~;_ 50 2M-24 Stimulate Stimulate c1,_ ¢~ 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051696 (w/o atch) AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate X Change approved program _ Pull tubing _ Variance _ Perforate _ 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 114' FSL, 354' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1722' FSL, 1671' FWL, SEC 27, T11N, R8E, UM At effective depth 1814' FSL, 1752' FWL, SEC 27, T11N, R8E, UM At total depth 1846' FSL, 1781' FWL, SEC 27, TllN, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 6848' 6295' feet Plugs (measured) f e e t None measured 6747' feet Junk (measured) true vertical 6 2 0 4' feet None Length Size Cemented 8 0' 1 6" 250 Sx AS I 2894' 9-5/8" 700 Sx AS III & 600 Sx Class G 6 8 0 2' 7" 250 Sx Class G measured 6510'-6515', 6524'-6540', 6551 '-6582', 6473'-6846' true vertical 5992'-5996', 6004'-6018', 6029'-6055' 6. Datum elevation (DF or KB) RKB 141 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2M-16 9. Permit number 10. APl number 50-103-20153 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measureddepth Trueverticaldepth 115' 115' 2929' 2867' 6837' 6285' 4 SPF, 180° Phasing, Oriented Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 6371' Packers and SSSV (type and measured depth) Camco TRDP-4A-RO SSSV @ 1783', Baker HB Retrievable Packer @ 6342' 5959'-5971' RECEIVED MAY 2 0 IJ J'T 13. Stimulation or cement squeeze summary Intervals treated (measured) 6551 '-6582' A!~ska 0il & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure See Attached Summary 14. Prior to well operation Subsequent to operation 5/1 7/92 Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure None 2035 1420 2 1300 94 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ at present, was oil well when treatment was pumped Oil _ Gas Suspended Service Signed17. I he~/,ertify, if ~~)/that the~foregoing is true and correctTitle SENIOR ENGiNEERtO the best of my knowledge. Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 04/14/92 GELLED SEAWATER DATAFRAC/FRAC W/DS YF140D. PUMPED 100 BBL BREAKDOWN @ 25 BPM. LAST WHTP=3877 PSI, ISIP=1570 PSI, FG=.70 PSI/FT, EXCESS FRIC=l192 PSI, CLOSURE PRESSURE=3800 PSI (FIELD EST.). PUMPED 50 BBL BREAKDOWN @ 25 BPM. LAST WHTP=3753 PSI, ISIP=1565 PSI, FG=.70 PSI/FT, EXCESS FRIC= 1073 PSI, CLOSURE NOT ESTIMATED. PUMPED 50 BBL BREAKDOWN @ 25 BPM. ONE TURBINE DID NOT STALL WHEN DS SHUT DOWN, SO ISIP WAS NOT VALID. PUMPED 367 BBL DATAFRAC @ 25 BPM. LAST WHTP=3490 PSI, ISIP= 1666 PSI, FG=.72 PSI/FT, EXCESS FRIC=709 PSI, FLUID EFF. NOT CALCULATED. PUMPED 500 BBL PAD @ 25 BPM, LAST WHTP=3918 PSI. PUMPED 102.5 MLBS 12/18 CL IN 2 TO 12 PPA STAGES. SCREENED OUT 27 BBLS INTO FLUSH. TOT PROPPANT: DESIGNED 105.4 MLBS, IN FORM 91.0 MLBS W/12.5 PPA @ PERFS. TOT FLUIDS: WATER 1329 BBLS, DSL (FLA + FLUSH) 45 BBLS. ALL GEL SAMPLES LOOKED GOOD AND BROKE WITHIN 11 HOURS. (CORBELL/BRADLEY) RECEIVED MAY 20 1994 A.!~ska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALAUKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon Suspend Alter ca~ing _ Repair wel"[ Change approved program _ Operation Shutdown Re-enter suspended well_ _ Plugging _ Tim~" extension_ Stimulate _ Pull tubing _ Variance_ Perforate _ Other X 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 114' FSL, 354' FWL, SEC27, T11N, At top of productive interval 1722' FSL, 1671'FWL, SEC 27, T11N, At effective depth 1814' FSL, 1752' FWL, SEC 27, T11N, At total depth 1846' FSL, 1781' FWL, SEC 27, T11N, R8E, UM ReE, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6848' feet Plugs (measured) 6295' feet None Effective depth: measured true vertical 6747' feet Junk (measured) 6 2 0 4' feet None RKB 141 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2M-16 9. Permit cumber 91-32 / c/2,- ISIF 10. APl number 50-103-20153 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" ,~ .250 SxAS I 2894' 9-5/8" 700 SxAS III & 600 Sx Class G 6802' 7" 250 Sx Class G measured 6510'-6515', 6524'-6540', 6551'-6582', 6473'-6846' true vertical 5992'-5996', 6004'-6018', 6029'-6055', Measured depth True vertical depth 115' 115' 2929' 2867' 6837' 6285' 4 SPF, 180° 5959'-5971' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 6371' Packers and SSSV (type and measured depth) Camco TRDP-4A-RO SSSV @ 1783', Baker HB Retrievable Packer @ 6342' Phasing, Oriented 13. Stimulation or cement squeeze summary Intervals treated (measured) "None associated with conversion" Treatment description including volumes used and final pressure V~"',,'¢-'4'%"(' ~0~-4, ~ 14. Represer'Itative D~ily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf- Water-Bbl ' Casing Pre~,uL~ i ~, ~,~t~ n~ g L,~ Pressure Prior to well operation Subsequent to operation 2OO8 1430 0 4990 BWIPD 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector X Daily Report of Well Operations __ Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. J U L - 8 Alaska 0ii & Gas Cons. Anchorage Service Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO. Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 9, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action Anticipated Start Date 2M- 16 Convert to Water Inj. July 20, 1992 2M- 19 Convert to Water Inj. July 20, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering CC: Hool h ..mt. ~'°~ S.P. a a,, ATO-1226 KOE1.4-9 (w/o attachments) (w/o attachments) RE EJV£D J U L 1 4, !99~ Alaska 0il & Gas Gons, GommiSSiOD Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpan? STATE OFALASKA 0 /{ I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program i Pull tubing _ Variance i Perforate _ Other 6. Datum elevation (DF or KB) 5. Type of Well: Development Exploratory Stratigraphic Service 99510 4. Location of well at surface 114' FSL, 354' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1722' FSL, 1671' FWL, SEC 27, T11N, R8E, UM At effective depth 1814' FSL, 1752' FWL, SEC 27, T11N, At total depth 1846' FSL, 1781' FWL, SEC 27, T11N, 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical R8E, UM R8E, UM 6848' feet Plugs (measured) 6295' feet None 6747' feet Junk (measured) 6 2 0 4' feet None Length Size Cemented 8 0' 1 6" 250 Sx AS I 2894' 9-5/8" 700 Sx AS III & 600 Sx Class G 6 8 0 2' 7" 250 Sx Class G RKB 141 7. Unit or Property name Kuparuk River Unit Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8. Well number 2M-16 9. Permit number 91 -32 10. APl number 50-103-20153 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool RECEIVED d U L 1 4 !992 Alaska Oil .& Gas Cons. Commission Measured depth ~l~O¥~{;~t~cal depth 115' 115' 2929' 2867' 6837' 6285' measured 6510'-6515', 6524'-6540', 6551'-6582', 4 SPF, 180° Phasing, Oriented true vertical 5992'-5996', 6004'-601 8', 6029'-6055' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 6371' Packers and SSSV (type and measured depth) Camco TRDP-4A-RO SSSV @ 1783', Baker HB Retrievable Packer @ 6342' 13. Attachments Description summary of proposal X Detailed operation program X BOP sketch _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: July 20, 1~)~)2 Oil __ Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service Water Iniector 17. I hereby certify~the ' is true correct to mngthat and the best of my knowledge. Signed ~"~- ~,b). ~eg Title Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test ~ Subsequent form require 10- ~./)~ Approved by order of the Commission Form 10-403 Rev 09/12/90 Original Signed By David W. Johnston Commissioner IApproval No. Approved Cop;y/" Returned '7- - cig, Date "7' J'7'(~2 SUBMIT IN TRIPLICATE Well 2M-16 Conversion to Water Injection ARCO Alaska requests approval to convert Well 2M-16 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6473' MDRKB and 6582' MDRKB This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED d UL 1 4 !~J92 Alaska Oil & Gas Cons. Gomrnission Anchorage Drill Site 2M General Procedure for Initial Water Injection Conversions AFC #996572 Downhole Work: K83339 The following general slickline procedure should be utilized for all of the initial producer-to-injector conversions on Drill Site 2M. The initial ten (10) producing wells are unlifted to date, though all are outfitted with dummied off mandrels. Copies of the individual wellbore schematics are attached for reference. . Obtain a final 12-hour well test. Notify J. B. Kewin (x-6806) to insure that the sundry notice for converting the well to water injection has been approved by the AOGCC. 2. SI well and MIRU slickline and hot oil pump truck. 3. RIH and set SV in the "D" nipple. Pressure test the tubing/DV's to 1500 psi. 4. RIH and pull the bottom 1-1/2" DV and replace it with a CV. , Rig up hot oiler to the 3-1/2"x 7" annulus, and reverse circulate the annulus to diesel while taking returns from the tubing. Fill the annulus with diesel to the bottom GLM. Annular capacity is .0264 Bbls/Ft. 6. RIH and pull the CV in the bottom mandrel and replace with a 1-1/2" DV. 7. Pressure test the tubing to 1500 psi to ensure that the DV's are set. 8. RIH and pull the SV. 9. RDMO slickline. Notify the State for witness of the Mechanical Integrity Test. 10. Conduct MIT test. Packer depths and 7" annular pressures required are shown below. Pressures must be held for 30 minutes with no more than a 10% decline. Bleed the annulus to 500 psi after completing each test. Well Packer TVD DePth Reo'd Casing Pressure for MIT 2M-16 5832' 2100 psi 2M-19 5855' 2110 psi 11. Initiate water injection at approximately 500 BWPD and gradually ramp up rate until the WHP reaches 1500 psi. Keep the injection rate constant until KPE can conduct a step' rate. Once the step rate test is complete, the wells will be opened up to maximum permissible injection pressure, or maximum header pressure available (if lower). RECEIVED J U L 1 4. !997 Alaska Oil & (Sas Cons. Anchorage WELL 2M-16 PRODUCER APl # 5010320153 SURFACE LOCATION: 114' FSL, 354' FWL, SEC. 27, T11N, R8E, UM TOP OF KUPARUK: 1722' FSL, 1671' FWL, SEC 27, T11N, R8E, UM TD LOCATION: 1846' FSL, 1781' FWL, SEC 27, T11N, R8E, UM DEPTHS: REFERENCED TO 0' RKB ALL DEPTHS MD-RKB WELL TYPE: PRODUCER TUBING SPOOL RKB=33.00' 16": 62.5# H-40 @ 115' J 9.625": 36# J-55 @ 2929' Baker PBR: @ 6328' @ 6342' @ 6358' Baker HB PKR: CAMCO D NIPPLE: 2.75" ID Baker SHROUT: @ 6370' L S~ C Top@6473' A5 A4 A3 7": 26# J-55 @ 6837' VOLUME: 0.0383 BBL/FT PBTD: 6747' PBTDSS: 6068' SPUD: 4/8/91 COMPLETION' 9/24/91 SSSV · CAMCO TRDP-4A @ 1783' GLMI: GLM2: GLM3: GLM4: 2950'/CAMCO KBUG/1.0"/DV 4819'/CAMCO KBUG/1.0"/DV 5946'/CAMCO KBUG/1.0"/DV 6273'/CAMCO MMG/1.5"/DV RECEIVED J U L. ~ 4 ?[192 Alaska Oil & Gas Cons. Comrnission Anch0ra~e 3.5" 9.3# J-55 EUE, @ 6371' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 27 DEGREES MAX. HOLE ANGLE = 31.5 DEGREES @ 3300' VOLUME TO TOP PERF = 62 BBLS 6510'-6515' 6524'-6540' 6551'-6562' 6562'-6582' ( 5'), 4 SPF, 180 o @ 17 o COW (16'), 4 SPF, 180 o @ 28 o CCW (11'), 4 SPF, 180 o @ 33 o CCW (20'), 4 SPF, 180 o @ 32 o CCW LAST TAG DATE' 7/5/92 @ 6702' REVISION: 7/7/92 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS r-~ SUSPENDED [~ ABANDONED r-~ SERVICE [--~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-32 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20153 4 Location of well at surface 9 Unit or Lease Name 114' FSL, 354' FWL, SEC 27, T11N, R8E, UM ~ ~:~.,:~:~: ~.. :~: :~'~ ............. KUPARUK RIVER At Top Producing Interval i ~~'~i .i '!/~]J:t[[~ 10 Well Number 1722' FSL, 1671' FWL, SEC 27, T11N, RSE, UM - ~ ~ ~ 2M-16 AtTotal Depth ~ ~.~:;~i-~. '-i 11 Field end Pool 1846' FSL, 1781' FWL, SEC 27, T11N, RSE, UM ¢ .......... '~- ' ~ ...... ' KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 141', PAD 106' GLJ ADL 25586, ALK 2672 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore J 16 No. of Completions 04/07/91. 04/13/91. 09/25/91. NA feet M SLI 1 17 Total Deplh (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6848' MD, 6295' TVD 6747' MD, 6204' TVD YES I~] NO I-'-I 1783' feet MD 1400' APPROX 22 Type Electric or Other Logs Run D IL/SP/GR/LDT/CNI/CET/CBL/GCT 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 225 SX ASll 9-5/8" 36# J-55 SURF 2929' 12-1/4" 700 SX ASlII, 600 SX CLASS G 7" 26# J-55 SURF 6837' 8-1/2" 250 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) 3-1/2" 6371' 6342' 6551' -6582' W/4-1/2" CSG GUN ~ 4 SPF MD 6030'-6058' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,,, 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,,~ 28 CORE DATA mt Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 011 & Gas Cons. C0mmtSslea An h0rage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GE(]_OGIC IVlARKB:~ FORMA'FI(~ TESTS NNVlE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 6473' 5960' NA KUPARUK C BO'FrOM 6487' 5972' KUPARUK A TOP 6503' 5986' KUPARUK A BOTTOM 6654' 6120' . . : 31. LISTOF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~, '~' ~/~ ~ Title AREA DRI I F,~ ENGIqEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: '~,~ttacl~ed sdpPleme~tal records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: U~t~!~ ~fiOP~ation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ject'~r~¢~qs~-Injection, Shut,in, Other-explain. Item 28: If o~cb¥~'S't~al~en, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-16 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20153 91-32 ACCEPT: 04/07/91 SPUD: 04/07/91 RELEASE: 04/15/91 OPERATION: DRILLING RIG: DOYON 14 AFE: AK5709 WI: 55.252072 04/08/91 ( 1) TD: 1510' (1510) SUPV:JCP 04/09/91 (2) TD: 2950' (1440) SUPV:JCP 04/10/91 ( 3) TD: 2950'( SUPV:JCP o) 04/11/91 ( 4) TD: 5580' (2630) SUPV:JCP 04/12/91 ( 5) TD: 6405' ( 825) SUPV:JCP 04/13/91 ( 6) TD: 6848' ( 443) SUPV:PDW 04/14/91 ( 7) TD: 6848'( SUPV:PDW o) DRILLING AT 1510' MW: 9.0 VIS: 52 MOVE RIG FROM 2M-23 TO 2M-16. ACCEPT RIG AT 12:00 NOON 4/7/91. NU DIVERTER, SPUD AT 18:00 HRS, DRILL TO 1510' -- DAILY:S55,041 CUM:$55,041 ETD:S55,041 EFC:$1,130,000 LOGGING SURFACE HOLE 9-5/8"@ 2929' MW: 9.4 VIS: 49 DRILL FROM 1510' TO 2950' SHORT TRIP AND POOH. RU SCHLUMBERGER, RUN TRIPLE ~OMBO. RUN #2 WITH LONG SPACED SONIC. DAILY:S58,143 CUM:$113,184 ETD:S113,184 EFC:$1,130,000 RIH TO DRILL OUT SHOE 9-5/8"@ 2929' MW: 9.2 VIS: 42 FINISH RUN #2- LONG SPACED SONIC. RD SWS, RIH FOR WIPER TRIP. RUN 70 JTS 9-5/8" CASING, PUMP 80 BBL WATER SPACER, 700 SX ASIII AT 12.1 PPG LEAD CEMENT, 600 SX CLASS G WITH 2% S-1 AT 15.8 PPG TAIL CEMENT, DISPLACE WITH WATER, BUMP PLUG TO 2500 PSI, FLOATS OK, LOST RETURNS AT 177 BBL DISPLACED. ND DIVERTER PUMP 105 SX TOP JOB. MU CASINGHEAD AND BOPE, TEST BOPE. RIH WITH PDC BIT AND TURBINE. DAILY:S254,136 CUM:$367,320 ETD:S367,320 EFC:$1,130,000 DRILLING AT 5580' 9-5/8"@ 2929' MW: 9.4 VIS: 38 TAG FLOAT COLLAR, DRILL CEMENT, TEST CASING TO 2500 PSI, DRILL SHOE AND 10' OF NEW FORMATION, CHANGE TO 9.2 PPG MUD. TEST SHOE TO 12.5 PPG EMW, NO LEAK-OFF. DRILL TO 5580 WITH PDC BIT AND TURBINE. DAILY:S62,541 CUM:$429,861 ETD:S429,861 EFC:$1,130,000 DRILLING AT 6405' 9-5/8"@ 2929' MW:10.2 VIS: 44 DRILL FROM 5580' TO 6297', SHORT TRIP TO CASING SHOE, PERFORM INTEGRITY TEST TO 10.7 PPG EMW, OK, NO LEAK-OFF. RIH AND CONTINUE DRILLING TO 6405'. DAILY:S69,518 CUM:$499,379 ETD:S499,379 EFC:$1,130,000 SHORT TRIP FOR LOGS 9-5/8"@ 2929' MW:10.2 VIS: 36 DRILL TO 6485', TRIP FOR BIT, LD TURBINE, CHANGE TO ROTARY BHA. DRILL TO 6848 CBU AND MAKE WIPER TRIP FOR LOGGING. DAILY:S62,986 CUM:$562,365 ETD:S562,365 EFC:$1,130,000 RIH FOR WIPER TRIP 7"@ 6837' MW:10.3 VIS: 37 POOH FOR LOGS. LOGGING TOOLS WOULD NOT GO BELOW 4330', POOH WITH LOGGING TOOLS, RIH WITH BIT, WIPER TRIP TO 6848' RUN SCHLUMBERGER TRIPLE COMBO AND SHEAR WAVE SONIC. NO SIGNIFICANT COLVILLE. RD LOGGERS, RIH FOR WIPER TRIP PRIOR TO RUNNING CASING. DAILY:S152,115 CUM:$714,480 ETD:S714,480 EFC:$1,130,000 WELL: 2M-16 OPERATION: DRILLING RIG: DOYON 14 PAGE: 2 04/15/91 ( 8) TD: 6848'( SUPV:PDW 04/16/91 ( 9) TD: 6848'( SUPV:PDW o) o) ND BOPE 7"@ 6837' MW:10.3 VIS: 0 RIH FOR WIPER TRIP, CIRC DIESEL PILL ON BOTTOM, POOH LDDP FOR FINAL TIME. RUN 164 JTS 7" CASING, WASH AND CIRC TO BOTTOM. PUMP 10 BBL ARCO PREFLUSH, 35 BBL ARCO SPACER AT 11.2 PPG, 250 SX CLASS G CEMENT WITH 2 GAL/SX D-600 (DOWELL GAS-BLOCK SLURRY), DISPLACE WITH 258 BBL 10.3 PPG BRINE. RECIP PIPE THRUOUT DISPLACEMENT, FULL RETURNS. SET SLIPS, ND BOPE. DAILY:S188,600 CUM:$903,080 ETD:S903,080 EFC:$1,130,000 RIG RELEASED 7"@ 6837' MW: 0.0 VIS: 0 ND BOPE, NU AND TEST TREE. RELEASE RIG AT 15:00 HRS ON 4/15/91. MOVE RIG TO WEST SAK 24 PAD FOR STACKING. DAILY:S19,390 CUM:$922,470 ETD:S922,470 EFC:$1,130,000 DATE: RECEIVE'D JAN 2 4 t99~ Alaska Oil & 6as Cons. Commission Anchorage ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-16 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20153 91-32 ACCEPT: 09/24/91 SPUD: RELEASE: 09/25/91 OPERATION: COMPLETION RIG: NORDIC AFE: AK5709 WI: 55.252072 09/24/91 (10) TD: 6848 PB: 6747 SUPV:GB/SW 7"@ 6837' MW:10.4 NaBr MOVE RIG F/2M-25 TO 2M-16,ACCEPT RIG AT 2400 HRS 23-SEP-91 ND TREE AND NU BOPE TEST BOPE TO 3000 PSI,NO FAILURES,RU SWS TEST LUBRICATOR TO 750 PSI,RIH W/GR AND JB FOR 7" CASING TO 6740'WLM, POH, LD GR/JB,MU PERF GUN #1 FOR A SAND PERFS DAILY:S21,037 CUM:$943,507 ETD:S943,507 EFC:$1,130,000 09/25/91 (11) TD: 6848 PB: 6747 SUPV:GB/SW RELEASED RIG 7"@ 6837' MW:10.4 NaBr MU/RIH WITH PERF GUN#I,4SPF, 180 DEG PHASING, 36 CCW POSTION/ORIENT/SHOOT F/6562 -6582'WLM, POH, MU/RIH WITH PERF GUN#2,4SPF, 180 DEG PHASING, 36 CCW, POSTION/ ORIENT/SHOOT F/6551-6562'WLM, POH, RD SWS,TWO SHOTS MISFIRED ON GUN#I,SEVEN SHOT ON GUN#2 NOT ALIGNED,RIG FLOOR TO RUN COMPLETION, RIH WITH COMPLETION AS PER PROCEDURE,?U SSSV, FLUSH/TEST C-LINE TO 5000 PSI F/10 MIN, OK,CONT RIH, PU FMC G4 3-1/2" TBG HGR AND LANDING JT,DROP PACKER SETTING BALL, MU HGR AND C-LINE TEST C-LINE TO 5000 PSI F/10 MIN, OK, LAND TBG, RILDS,PRES UP TBG TO 2500 PSI TO SET PKR, HOLD PRES F/10 MIN, HOLD PRES ON TBG AND PRES ANNULUS TO 1000 PSI F/10 MIN, BLEED OFF ANNULUS AND BOLDS,PU 91K# WITH 1200 PSI ON TBG AND SHEAR PBR, BLEED OFF ALL PRES,RELAND TBG, RILDS,PRESS TBG AND ANNULUS TO 1000 PSI,CLOSE SSSV, BLEED TBG TO 500 PSI AND TEST SSSV F/15 MIN OK, EQUALIZE PRES AND OPEN SSSV, PRES ANNULUS TO 2580 PSI F/15 MIN, LOST 15 PSI,HOLD ANN. PRES AND PRES UP TBG TO 4300 PSi TO SHEAR OUT BALL, BLEED OFF ALL PRES,CLOSE SSSV, LD LANDING JT, SET BPV, ND BOPE/NU TREE,TEST TREE TO 250/5000 PSI OK, OPEN SSSV, RU CIRC LINES AND DISPLACE ANNULUS WITH 12 BBLS DIESEL, BULLHEAD TBG WITH 4 BBLS DIESEL @ 1 BPM 1750 PSI,BLOW DN LINES,SECURE WELL,CLEAN CELLAR, MOVE RIG OFF WELL, SICP=0 SITP= 50 PSI,RELEASE RIG @ 0200 HRS 25-SEP-91 DAILY:S162,617 CUM:$1,106,124 ETD:S1,106,124 EFC:$1,130,000 DRILLI E DATE: SUB.$URFAC DIRECTIONAL ~]UIDANCE ~ONTINUOUS ~]OOL SURVEY RECEIVED JAN 2 4 ~992 Alaska Oil & Gas Cons. Commission ~,nchorage Company Well Name- Field/Location J__ob Ref, erence No_, 1 8- HA Y - 91 7 4 5 8 3 Computed Loclclecl B~ D E E S WARNER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH S~OPE, ALASKA SURVEY DATE: 1B-MAY-1991 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: D. WARNER Average~ Oeviation anO azimuth PROJECTED ONTO A TARGET AZIMUTH OF NORTH 39 DEG 12 MIN EAST COMPUTATION DATE: 28-MAV-91 PAGE 1 ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-MAY-1991 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER= D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N FEET DEG/IO0 FEET FEET FEET DEG 0 O0 0.00 -141.00 0 0 N 0 0 E 100 O0 100.00 -41.00 0 9 S 77 54 E 200 O0 200.00 59.00 0 26 N 84 30 E 300 O0 300.00 159.00 0 26 N 81 39 E 400 O0 399.99 258.99 0 29 N 83 36 E 500 O0 499.99 358.99 0 28 N 80 12 E 600 O0 599.98 458.98 0 29 N 76 26 E 700 O0 699.98 558.98 0 29 N 72 31 E 800.00 799.98 658.98 0 31 N 70 34 E 900.00 899.97 758.97 0 32 N 70 15 E 0 O0 -0 02 0 37 0 94 1 54 2 14 2 79 3 48 4.21 5.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.43 0.07 S 0.06 E 0.09 S 3'9 39 E 0.00 0.05 S 0.65 E 0.65 S 85 21 E 0.00 0.05 N 1.42 E 1.42 N 88 9 E 0.00 O. 16 N 2.25 E 2.25 N 86 2 E 0.00 0.27 N 3.06 E 3.07 N 84 59 E 0.00 0.44 N 3.89 E 3.91 N 83 37 E 0.00 0.66 N 4.70 E 4.74 N 81 59 E 0.00 0.92 N 5.53 E 5.61 N 80 32 E 0.00 1.23 N 6.39 E 6.51 N 79 5 E 1000 O0 999.97 858.97 0 35 N 70 46 E 1100 O0 1099.96 958.96 0 32 N 71 7 E 1200 O0 1199.96 1058.96 0 32 N 69 41 E 1300 O0 1299.95 1158.95 0 35 N 67 52 E 1400 O0 1399.95 1258.95 0 37 N 71 5 E 1500 O0 1499.94 1358.94 0 36 S 83 24 E 1600 O0 1599.94 1458.94 0 36 S 76 51 E 1700.00 1699.93 1558.93 0 35 S 75 4 E 1800.00 1799.93 1658.93 1 7 N 83 10 E 1900.00 1899.67 1758.67 7 2 N 47 8 E 5.82 6.65 7.46 8.31 9.21 9.99 10.51 10.94 11.51 17.58 0.00 0.00 0.00 0.19 0.00 0.09 0.00 0.00 2.32 6.24 1 .56 N 7.30 E 7.47 N 77 58 E 1.88 N 8.22 E 8.43 N 77 5 E 2.20 N 9. 10 E 9.36 N 76 23 E 2.57 N 10.01 E 10.33 N 75 37 E 2.94 N 10.96 E 11.35 N 74 59 E 3.09 N 12.01 E 12.40 N 75 34 E 2.91 N 13.06 E 13.38 N 77 26 E 2.65 N 14.06 E 14.31 N 79 19 E 2.45 N 15.21 E 15.41 N 80 50 E 6.11 N 20,32 E 21.22 N 73 15 E 2000.00 1998.36 1857.36 10 43 N 50 1 E 2100 O0 2096 29 1955 29 12 18 N 50 51 E 2200 O0 2193 63 2052 2300 O0 2290 04 2149 2400 O0 2385 07 2244 2500 O0 2479 26 2338 2600 O0 2572 66 2431 2700 O0 2664 49 2523 2800 O0 2754 38 2613 2900 O0 2842 03 2701 33.44 53.27 63 14 21 N 45 45 E 75.84 04 16 50 N 41 48 E 102.25 07 19 7 N 37 51 E 133.34 26 20 17 N 35 58 E 166.92 66 21 46 N 35 48 E 202.57 49 24 19 N 36 42 E 242.08 38 27 30 N 36 19 E 285.81 03 30 19 N 37 4 E 333.88 2.98 0.62 2.11 3.56 1 .57 1 .88 3.48 1 .56 1 .41 2.45 16.92 N 32.16 E 36.34 N 62 15 E 29.75 N 47.82 E 56.31 N 58 7 E 44 88 N 64.96 E 78.96 N 55 22 E 64 02 N 83.28 E 105.05 N 52 27 E 87 94 N 103.15 E 135,55 N 49 33 E 114 84 N 123.30 E 168.49 N 47 2 E 143 85 N 144.13 E 203.63 N 45 3 E 175 71 N 167.59 E 242.81 N 43 39 E 210 89 N 193,64 E 286.30 N 42 33 E 249.53 N 222.31 E 334.19 N 41 42 E 3000.00 2927.77 2786,77 31 21 N 37 40 E 385 32 3100.00 3013.01 2872 01 31 40 N 37 53 E 437 59 3200,00 3098.10 2957 10 31 42 N 37 58 E 490 11 3300.00 3183.10 3042 10 31 51 N 38 8 E 542 78 3400.00 3268.24 3127 24 31 10 N 37 57 E 595 21 3500.00 3354.16 3213 16 30 36 N 38 24 E 646 37 3600.00 3440.24 3299.24 30 31 N 38 30 E 697 26 3700.00 3526.76 3385.76 29 46 N 38 55 E 747 39 3800.00 3613.63 3472.63 29 40 N 39 0 E 796 93 3900,00 3700,50 3559.50 29 44 N 39 8 E 846.46 0.45 0.21 0.15 0.16 1 . 44 0.18 0.60 0.15 0.02 0.18 290.41 N 253.58 E 385 53 N 41 8 E 331.75 N 285.60 E 437 373.17 N 317,90 E 490 414.67 N 350.35 E 542 455.97 N 382.67 E 595 496.17 N 414.32 E 646 536.04 N 445.96 E 697 575.14 N 477.33 E 747 613.66 N 508.49 E 796 75 N 40 43 E 23 N 40 26 E 86 N 40 12 E 27 N 40 0 E 41 N 39 52 E 30 N 39 46 E 42 N 39 41 E 95 N 39 39 E 652.12 N 539.70 E 846.49 N 39 37 E COMPUTATION DATE: 28-MAY-91 PAGE 2 ARCO ALASKA, INC, 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-MAY-1991 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3787.34 3646.34 29 43 N 39 8 E 896.06 4100 O0 3874.18 3733.18 29 43 N 39 2 E 945.63 4200 O0 3961.06 3820.06 29 38 N 39 0 E 995.15 4300 O0 4048,19 3907.19 29 7 N 39 23 E 1044.23 4400 O0 4135,68 3994.68 28 55 N 39 17 E 1092.65 4500 O0 4223.22 4082.22 28 48 N 39 21 E 1141.00 4600 O0 4310.95 4169.95 28 36 N 39 9 E 1189.00 4700.00 4398.78 4257.78 28 32 N 39 16 E 1236.80 4800,00 4486.62 4345.62 28 33 N 39 21 E 1284.59 4900,00 4574,47 4433.47 28 36 N 39 35 E 1332.37 0.08 0.14 0.22 0.56 0,33 0.40 0.10 0.08 0,18 690.58 N 571.01 E 896.08 N 39 35 E 729.07 N 602.26 E 945.65 N 39 34 E 767,54 N 633.43 E 995.16 N 39 32 E 805,61 N 664,41 E 1044.24 N 39 31 E 843.06 N 695.11 E 1092.67 N 39 30 E 880.44 N 725.78 E 1141.02 N 39 30 E 917.61 N 756,14 E 1189.01 N 39 29 E 954.66 N 786,34 E 1236,81 N 39 29 E 991.64 N 816.61 E 1284,60 N 39 28 E 0.34 1028.53 N 846.98 E 1332.39 N 39 28 E 5000.00 4662.30 4521.30 28 29 N 39 39 E 1380,17 5100.00 4750.20 4609.20 28 27 N 39 11 E 1427.86 5200.00 4838.08 4697,08 28 33 N 38 59 E 1475.58 5300.00 4926.04 4785.04 28 15 N 38 33 E 1523.15 5400,00 5014.39 4873.39 27 41 N 37 31 E 1569.98 5500,00 5103.00 4962.00 27 31 N 36 46 E 1616,31 5600,00 5191.64 5050.64 27 41 N 37 23 E 1662.54 5700.00 5280.07 5139.07 27 56 N 38 35 E 1709,24 5800.00 5368.40 5227.40 27 55 N 38 11 E 1756.11 5900.00 5456.67 5315.67 28 21 N 38 30 E 1803.09 0 19 1065.35 N 877,47 E 1380 19 N 39 29 E 0 20 1102,16 N 907,78 E 1427 87 N 39 29 E 0 O0 1139.22 N 937.84 E t475 59 N 39 28 E 0 33 1176.30 N 967.64 E 1523 16 N 39 26 E 0 92 1213,17 N 996.55 E 1569 99 N 39 24 E 0 14 1250.16 N 1024.48 E 1616 31 N 39 20 E 1 48 1287.19 N 1052,24 E 1662 55 N 39 16 E 0 30 1323.85 N 1081.17 E 1709.24 N 39 14 E 0 42 1360.61 N 1110.26 E 1756.11 N 39 13 E 1.42 1397.54 N 1139.31 E 1803.09 N 39 11 E 6000.00 5544.45 5403.45 28 48 N 40 4 E 1850.99 6100 O0 5632.02 5491.02 28 51 N 40 10 E 1899.27 62OO 6300 64OO 6500 660O 670O 6800 6848 O0 5719.65 5578.65 28 50 N 40 24 E 1947.45 O0 5807.44 5666.44 28 25 N 40 31 E 1995,32 O0 5895.33 5754.33 28 31 N 40 39 E 2043.00 O0 5983.37 5842.37 28 8 N 41 2 E 2090.40 O0 6071.93 5930.93 27 10 N 40 59 E 2136.82 O0 6161.59 6020.59 25 18 N 41 4t E 2181.08 O0 625t.99 6110.99 25 18 N 41 41 E 2223,76 O0 6295.39 6154.39 25 18 N 41 41 E 2244.25 0 22 1434.52 N 1169.75 E 1850.99 N 39 12 E 1 13 1471 40 N 1200,93 E 1899.27 N 39 13 E 0 46 1508 22 N 1232.01 E 1947.45 N 39 15 E 0 36 1544 62 N 1263.11 E 1995.32 N 39 16 E 0 66 1580 88 N 1294.09 E 2043.00 N 39 18 E 0 67 1616 71 N 1325.16 E 2090.40 N 39 20 E 1 11 1651 76 N 1355.63 E 2136.83 N 39 23 E 0 73 1685.06 N 1384.83 E 2181.09 N 39 25 E 0.00 1716.94 N 1413.27 E 2223.78 N 39 28 E 0.00 1732.26 N 1426,91 E 2244.28 N 39 29 E COMPUTATION DATE: 28-MAY-91 PAGE 3 ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-MAY-1991 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -141.00 0 0 N 0 0 E 0.00' 1000.00 999.97 858.97 0 35 N 70 46 E 5.82 2000.00 1998.36 1857.36 10 43 N 50 1 E 33.44 3000.00 2927.77 2786.77 31 21 N 37 40 E 385.32 4000.00 3787.34 3646.34 29 43 N 39 8 E 896.06 5000.00 4662.30 4521.30 28 29 N 39 39 E 1380.17 6000.00 5544.45 5403.45 28 48 N 40 4 E 1850.99 6848.00 6295.39 6154.39 25 18 N 41 41 E 2244.25 0.00 0 O0 N 0.00 E 0.00 N 0 0 E 0.00 1 56 N 7.30 E 7.47 N 77 58 E 2.98 16 92 N 32.16 E 36.34 N 62 15 E 0.45 290 41 N 253.58 E 385.53 N 41 8 E 0.08 690 58 N 571.01 E 896.08 N 39 35 E 0.19 1065 35 N 877.47 E 1380.19 N 39 29 E 0.22 1434 52 N 1169.75 E 1850.99 N 39 12 E 0.00 1732.26 N 1426.91 E 2244.28 N 39 29 E COMPUTATION DATE: 28-MAY-91 PAGE 4 ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY= 1B-MAY-1991 KELLY BUSHZNG ELEVATION: 141.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -141.00 0 0 N 0 0 E 141.00 141.00 0.00 0 19 N 88 45 E 241.00 241.00 100.00 0 27 N 82 41 E 341.01 341.00 200.00 0 30 N 82 15 E 441.01 441.00 300.00 0 28 N 82 31 E 541.01 541.00 400.00 0 29 N 79 9 E 641.02 641.00 500.00 0 28 N 74 45 E 741.02 741.00 600.00 0 30 N 73 54 E 841.02 841.00 700.00 0 31 N 70 1 E 941.03 941.00 800.00 0 33 N 70 14 E 0 O0 0 08 0 59 1 17 1 79 2 40 3.07 3.77 4.53 5.33 0.00 0.35 0.00 0.18 0 02 0 O0 0 O0 0 O0 0 O0 0 O0 0.00 N 0.00 E 0.00 N 0 0 E 0.08 S 0.23 E 0.24 S 71 18 E 0.02 S 0.96 E 0.96 S 88 57 E 0.09 N 1.74 E 1.75 N 86 56 E 0.20 N 2.59 E 2.60 N 85 38 E 0.33 N 3.40 E 3.41 N 84 26 E 0.52 N 4.22 E 4.25 N 82 59 E 0.76 N 5.03 E 5.09 N 81 23 E 1.05 N 5.88 E 5.98 N 79 55 E 1.36 N 6.76 E 6.90 N 78 35 E 1041.03 1041.00 900.00 1141.04 1141.00 1000.00 1241.04 1241.00 1100.00 1341.05 1341.00 1200.00 1441.05 1441.00 1300.00 1541.06 1541.00 1400.00 1641.06 1641.00 1500,00 1741.07 1741.00 1600.00 1841.10 1841.00 1700.00 1941.76 1941.00 1800,00 0 34 N 71 11 E 0 32 N 68 57 E 0 34 N 68 5 E 0 34 N 67 29 E 0 38 N 74 37 E 0 37 S 80 21 E 0 35 S 75 41 E 0 34 S 72 45 E 2 47 N 58 59 E 9 9 N 46 28 E 6.18 6.98 7,8O 8.68 9.58 10.22 10.69 11.11 12.64 23.48 0.00 0.00 0.00 0.06 0.00 0.00 0.00 0.00 6.52 3.45 1.69 N 7.69 E 7.88 N 77 35 E 2 . 01 N 8 . 57 E 8.80 N 76 47 E 2.34 N 9.46 E 9.75 N 76 6 E 2.73 N 10.39 E 10.74 N 75 17 E 3.07 N 11.39 E 11.80 N 74 54 E 3.03 N 12.45 E 12.82 N 76 20 E 2.81 N 13.48 E 13.76 N 78 13 E 2.54 N 14.46 E 14.68 N 80 3 E 2.93 N 16.40 E 16.66 N 79 52 E 10.21 N 24.63 E 26.66 N 67 29 E 2043.47 2041 O0 1900.00 11 38 N 50 43 E 2145.82 2141 O0 2000.00 13 2 N 49 8 E 2248.98 2241 O0 2100.00 15 6 N 44 0 E 2353.48 2341 O0 2200 O0 18 18 N 39 34 E 2459.30 2441 O0 2300 O0 19 42 N 36 40 E 2566,00 2541 O0 2400 O0 21 2 N 35 35 E 2674.27 2641 O0 2500 O0 23 59 N 36 38 E 2784.96 2741 O0 2600 O0 27 8 N 36 22 E 2898.80 2841.00 2700 O0 30 18 N 37 4 E 3015,50 2941.00 2800 O0 31 25 N 37 42 E 41 70 63 09 88 22 118 45 153 05 190 19 231 58 278 96 333 27 393 39 2 52 2 72 3 O0 2 55 1 25 0 97 1 19 2 34 2.50 0.41 22.28 N 36 15 N 53 76 103 133 167 2O5 249 296 38.67 E 44.63 N 60 3 E 55.50 E 66.24 N 56 56 E 71 N 73.73 E 91 21 N 53 56 E 33 N 93.82 E 120 95 N 50 52 E 65 N 115 06 E 154 87 N 47 59 E 78 N 136 89 E 191 41 N 45 40 E 28 N 161 31 E 232 39 N 43 58 E 37 N 189 57 E 279 49 N 42 43 E 04 N 221 94 E 333 59 N 41 42 E 80 N 258 51 E 393 60 N 41 3 E 3132.90 3041.00 2900.00 31 42 3250.45 3141 O0 3000.00 31 48 3368.10 3241 3484.71 3341 3600.89 3441 3716.40 3541 3831.50 3641 3946.64 3741 4061.79 3841 4176.91 3941 O0 3100.00 31 34 O0 3200.00 30 37 O0 3300.00 30 31 O0 3400.00 29 44 O0 3500.00 29 41 O0 3600.00 29 44 O0 3700.00 29 44 O0 3800.00 29 40 N 37 57 E N 38 1 E N 37 59 E N 38 22 E N 38 30 E N 38 56 E N 39 2 E N 39 9 E N 39 4 E N 39 1 E 454.87 516.66 578.62 638.58 697.71 755.53 812.52 869.60 926.69 983.73 0.17 0.25 1 .11 0.17 0.61 0.12 0.00 0.00 0.06 0.00 345.38 N 296 22 E 455.01 N 40 37 E 394.10 N 334 442.88 N 372 490.07 N 409 536.39 N 446 581.47 N 482 625.77 N 518 670.06 N 554 714.35 N 590 758.67 N 626 24 E 516.75 N 40 18 E 46 E 578.68 N 40 4 E 49 E 638.63 N 39 53 E 24 E 697.75 N 39 45 E 45 E 755.56 N 39 41 E 31 E 812.55 N 39 38 E 31 E 869.62 N 39 36 E 32 E 926.70 N 39 34 E 24 E 983.74 N 39 32 E COMPUTATION DATE: 28-MAY-91 PAGE 5 ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 18-MAY-1991 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH · TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4291.77 4041.00 3900.00 29 9 N 39 21 E 1040,22 4406.07 4141.00 4000.00 28 56 N 39 18 E 1095,59 4520.29 4241.00 4100,00 28 44 N 39 18 E 1150.77 4634.22 4341.00 4200.00 28 33 N 39 9 E 1205.37 4748.06 4441.00 4300.00 28 33 N 39 16 E 1259 76 4861.89 4541,00 4400.00 28 32 N 39 29 E 1314 15 4975.76 4641.00 4500.00 28 30 N 39 39 E 1368 61 5089.53 4741.00 4600.00 28 28 N 39 15 E 1422 87 5203.32 4841.00 4700.00 28 33 N 38 59 E 1477 16 5316.96 4941.00 4800.00 28 8 N 38 26 E 1531 14 0,63 802.51 N 661.87 E 1040.24 N 39 31 E 0.40 845.33 N 696.97 E 1095.61 N 39 30 E 0.36 887.99 N 731.97 E 1150 79 N 39 30 E 0.14 930.31 N 766.47 E 1205 38 N 39 29 E 0.06 972.44 N 800.88 E 1259 78 N 39 28 E 0.14 1014,48 N 835.38 E 1314 17 N 39 28 E 0,13 1056.44 N 870.10 E 1368 63 N 39 29 E 0,29 1098.30 N 904.62 E 1422 88 N 39 29 E 0,01 1140.45 N 938.84 E 1477.18 N 39 28 E 0.77 1182.57 N 972.61 E 1531,16 N 39 26 E 5430.05 5041.00 4900.00 27 38 N 37 10 E 1583.93 5542.85 5141.00 5000.00 27 32 N 36 41 E 1636,09 5655.79 5241.00 5100.00 27 53 N 38 35 E 1688.54 5768.98 5341.00 5200.00 27 58 N 38 17 E 1741.58 5882.20 5441.00 5300.00 28 9 N 38 13 E 1794.66 5996.06 5541.00 5400.00 28 48 N 40 3 E 1849.10 6110.25 5641.00 5500.00 28 49 N 40 7 E 1904.21 6224.36 5741.00 5600,00 28 43 N 40 30 E 1959.17 6338.17 5841.00 5700.00 28 28 N 40 28 E 2013,49 6451.92 5941.00 5800.00 28 16 N 40 59 E 2067.68 0.54 1224,26 N 1005.01 E 1583,94 N 39 23 E 0.12 1266.03 N 1036.33 E 1636.09 N 39 18 E 0,67 1307.67 N 1068.25 E t688.54 N 39 15 E 0.44 1349.19 N 1101.27 E 1741.58 N 39 13 E 1.19 1390.93 N 1134.07 E 1794.66 N 39 11 E 0.28 1433.07 N 1168.53 E 1849.10 N 39 12 E 0.92 1475.17 N 1204.11 E 1904.21 N 39 13 E 0.47 1517.14 N 1239.61 E 1959.17 N 39 15 E 0.32 1558.44 N 1274.91 E 2013.49 N 39 17 E 0.33 1599.56 N 1310.24 E 2067.69 N 39 19 E 6565.17 6041.00 5900.00 27 32 N 41 0 E 2120.82 6677.19 6141.00 6000.00 25 43 N 41 28 E 2171.25 6787.84 6241.00 6100.00 25 18 N 41 41 E 2218,57 6848.00 6295.39 6154.39 25 18 N 41 41 E 2244.25 1.00 1639.68 N 1345.13 E 2120.83 N 39 22 E 2.47 1677.70 N 1378.31 E 2171.27 N 39 24 E 0.00 1713.06 N 1409.81 E 2218.59 N 39 27 E 0.00 1732.26 N 1426,91 E 2244.28 N 39 29 E COMPUTATION DATE: 28-MAY-91 PAGE 6 ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA MARKER BOTTOM 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD BOTTOM 7" CASING TD DATE OF SURVEY: 18-MAY-1991 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = t14' FSL & 354' FWL, SEC27 T11N RBE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2929.00 6473.00 6487.00 6503.00 6654.00 6700.34 6747.00 6837.00 6848.00 2867.00 2726.00 5959.57 5818.57 5971.91 5830.91 5986.02 5845.02 6120.17 5979.17 6161.89 6020.89 6204.08 6063.08 6285.44 6144.44 6295.39 6154.39 261.28 N 231.22 E 1607.09 N 1316.79 E 1612.08 N 1321.13 E 1617.78 N 1326.09 E 1670.06 N 1371,59 E 1685.17 N 1384,93 E 1700.02 N 1398.20 E 1728.75 N 1423,78 E 1732.26 N 1426.91 E COMPUTATION DATE: 28-MAY-91 PAGE 7 ARCO ALASKA, INC. 2M - 16 KUPARUK KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD DATE OF SURVEY: 1B-MAY-1991 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: D. WARNER SURFACE LOCATION = 114' FSL & 354' FWL, SEC27 T11N RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6473.00 6487.00 6503.00 6654.00 6747.00 6848.00 5959 57 5971 91 5986 02 6120 17 6204 08 6295 39 5818.57 5830.91 5845.02 5979.17 6063.08 6154.39 1607 O9 N 1612 08 N 1617 78 N 1670 O6 N 1700 02 N 1732 26 N 1316.79 E 1321.13 E 1326,09 E 1371o59 E 1398.20 E 1426,91 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6848.00 6295.39 6154,39 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2244.28 N 39 29 E SCHLUMBEROER O I REC T ]~ ONAL SUR V E Y COMPANY ARCO ALASKA, INC. 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"' · ..................... .... , ....... ,,...,....j,...., ........... ~ ...... .,...,...+....; ...... +-,-.,..., ....... , .............. ,j. ..... ? ..... ?...t...??r-.?...i..--r--?-.--t-..-~ ....... ???--r--t-..?.',-.~.--t ....... t-.-?t..-? ....... ?'"T'"t"": ....... ? ...... ?."'*..'"1'"'? ...... *.'-"~ ....... ?'"?'"?'"?'? ~ ~''.' ::' i ,JlJ !!J! ,!il.,:,:q::' ...... +'''~ '?'4. ........ )f'' ' iil ']'' .... t"t't"t"'~'"t"T"T"i ...... :'""..:"'T"'T ....... T"'~"T"? "'?tBnn'nT""r"'T'~ ...... ~'-?t'T"?"i'"?'! ....... i'"-i'"?'"'?"T"?'?! ....... ?'?'..'.'"fi':T"~'"'..' ....... ~'"'F'~"'~ ."T'"~'"'r'"'~ ....... T"r'"TT"."'r'"'~"T"~ .... PROJECTION ON VERTICRL PLANE 39. - 219. SCRLED IN VERTICRL DEPTHS HORIZ SCALE = I/S00 IN/FT AOGCC GEOLOGICAL MATERIALS INYENTORY LIST ~?-~ WELL NAME i~,~LN ~ fid-I ~ COMPLETION DATE q / ~S/0~ CO, CONTACT 'cl~eck off or list data as it is received.*list received date for 407. if not required list as NR 40~ !*Illin?_ d'riliinQ~histo~ v~i surveyJ ,~! welltests 0! cored,inie~ais core analysis d~ ditch inte~als digital data ,,, '~~i ~ -~ LOG TYPE RUN INTERYALS SCALE NO. [to thc nearest fooq (inchl100') i01' ' ' ' A~Co Alaska, Inc. Date: June 7, 1991 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitled here with are the following items. one signed copy of this transmittal. 11L-14 C~i.~ 2M-16 ql" 51 1L-20X Directional Survey Directional Survey Directional Survey Directional Survey Receipt Acknowledged' D&M Transmittal #: 8125 Please acknowledge receipt and return 5- 1 2-91 74592 5o 1 0-91 74584 5- 1 8-9 1 74583 5-1 3-91 74588 State of Alaska D~te: ARCO Alaska, Inc. Date: ? May 10, 1991 Transmittal #: 8090 RETURN TO: ' ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. 1L-20X DIL--5" X, 2 M- 1 6 Dipole Shear Sonic Imager x Receipt Please acknowledge receipt 4-27-91 4-27-91 4-13-91 1000-11836 1000-11836 2690-6795 Acknowledged- DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK ;.State of. Alaska(+Sepia). 7 ARCO Alaska, Inc. Date: April 25, 1991 Transmittal #: 8076 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. "2M-16 ~.2M-16 ' 2M-16 ~2M-16 ~...~W ~ 1L-17 -- 2M-23 ~'2M-23 ~2M-23 -... 2M-23 --. 2M-23 Dual Induction-SFL 5" Phasor Dual Induction-SFL 2" Phasor Litho Density-CNL-GR 2" & 5" Porosity Litho Density-CNL-GR 2" & 5" Density Dipole Sonic Log 2" & 5" Delta Time Dipole Sonic Log Coherance Log Cyberlook Compensated Dual Resistivity Compensated Density Neutron Gamma Ray High Resolution Induction DFL 2"/100' High Resolution Induction DFL 5"/100' Spectral Density Dual Spaced Neutron Raw Data Spectral Density Dual Spaced Neutron High Resolution Pass Spectral Density Dual Spaced Neutron Porosity Please acknowledge receipt 4-13-91 2928-6810 4-13-91 2928-6810 4-13-91 3000-6795 4-13-91 3000-6795 4-13-91 2928-6795 4-13-91 2928-6795 4-13-91 3000-6795 4-7-9-91 4565-8700 4-7-9-91 4565-8700 4-3-91 114-3519 4-3-91 114-3519 4-3-91 1400-3529 4-3-91 1400-3585 4-3-91 1400-3585 Receipt Acknowledged: ............................. Date' - ......... DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of. Alaska(+Sepia) ARCO Alaska, Inc. Date: April 19, 1991 Transmittal #: 8070 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2 M - 1 6 Compensated Neutron-Litho- 4 - 9 - 9 1 1 1 4 - 2 9 0 0 Density Raw Data 2 M - 1 6 Compensated Neutron-Litho- 4 - 9 - 9 1 1 1 4 - 2 9 0 0 Density Porosity 2 M - 1 6 Dual Induction-SFL 5" Phasor 4 - 9 - 9 1 I 1 4- 2 9 2 8 2 M - 1 6 Dual Induction-SFL 2" Phasor 4 ,- 9 - 9 1 1 1 4- 2 9 2 8 2 M - 1 6 Array Sonic with Waveforms 4 - 9 - 9 1 1 1 4- 2 91 0 2 M - 2 5 Dual Gamma Ray Electromagnetic 3 - 3 1 - 9 1 3 3 7 0 - 7 4 4 5 Wave Resistivity 2 M - 2 5 Compensated Neutron Porosity 3 - 3 1 - 9 1 3 3 7 0 - 7 4 4 5 Simultaneous Formation Density 2 M - 2 5 Dual Gamma Ray Electromagnetic 3 - 3 1 - 9 1 2 9 5 9- 6 4 0 2 Wave Resistivity 2 M - 2 5 Dual Gamma Ray Electromagnetic 3 - 3 1 - 9 1 2 9 5 9 - 6 4 0 2 Simultaneous Formation Density Receipt Acknowledged: ~~-- ~(- ~ ..... Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK ~;ii~. State of Alaska(+Sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOFY: (907) 276-7542 March 21, 1991 A Wayne McBride Area Drlg Engineer ARCO Alaska, Inc P O Box 100360 Anchorage AK 99510-0360 Re: Alternative cementing procedure for some Kuparuk River Field wells on Drill Site 2M. Dear Mr McBride: This is in reply to the meeting with the Commission on .March 8, and your letter of request dated March 11, 1991. The Commission has reviewed the conditions expected to exist on Drill Site 2M, and approves isolation of Colville Sands by down squeezing cement into the annular space between surface, and production casing. This will occur after the primary cement 3ob is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. If you have any questions, please feel free to call me. Sincerely, Lonnie C Smith Commissioner LCS/jo RECEIVED Oil & Gas Cons. GomlIIIS$[QI! Anchora§,~ "~" ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 29, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Applications for Permit to Drill KRU Field Well 2M Pad Addendum to Previously Approved Permits to Drill The attached correspondence is the Alaska Oil and Gas Commission's ruling which approves isolation of Colville Sands at 2M pad by down squeezing cement into the annular space between surface and production casing. This will occur after the pdmary cement job on the production casing is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. There have been four drilling permits which have already been approved prior to the ruling mentioned above. ARCO Alaska, Inc. requests that these four previously approved drilling permits also be included in the ruling. The four wells are' Well Permit NO. APl No. Approval Date 2M-15 91-33 50-103-20154 03/05/91 2M-16 91-32 50-103-20153 03/05/91 2M-17 91-18 50-103-20150 02/22/91 2M-18 91-19 50-103-20151 02/22/91 If there are any questions, please contact Tim Billingsley at 265-6575. Thank you for your assistance in this matter. Sincerely, A.W. Area Drilling Engineer RECEIVED MAR 2 Alaska Oil & Gas Cons. Anchoracja ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3~-6003-C ALASKA OIL AND GAS CONSERVATION COMMISSION March 5, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 2M-16 ARCO Alaska, Inc. Permit No. 91-32 Sur. Loc. ll4'FSL, 354'FWL, Sec. 27, TllN, RSE, UM Btmhole Loc. 1877'FSL, 1791'FWL, Sec. 27, TllN, RSE, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. David W.' JohnstOn, Chairman Alaska Oil ~a~ conServation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, ~Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,f:::kSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill ~( Redrill ~ I lb. Type of Well Exploratory~ Straligraphic Test _ Develop~e~ Oil I Re-Entry _ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 141', Pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 354' FWL, Sec. 27, T11N, R8E, UM Kuoaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1740' FSL, 1680' FWL, Sec. 27, T11N, R8E, UM 2M-16 #U630610 At total depth ~. Approximate spud date Amount 1877' FSL, 1791' FWL, Sec 27, T11N, R8E, UM 1-APR-91 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2M-15 (proposed) 6877' MD 3403' @ TD feet 25' at surface feet 2560 6292 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 828' feet Maximum hole an~lle 30° Maximum surface 1650 psi~l At total depth (TVD) 3280 psi~l @ 6292' 18. Casing program Setting Depth size specification Top Bottom Quantity' of cement Hole Casin~l Wei~lht Grade Coupling Length IVD TVD IVD 'I'VD (include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115° +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 2791 35' 35' 2826' 2781 950 Cu. Ft. AS III & HF-ERW 520 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 6842' 35' 35' 6877' 6292' 200 Cu. Ft. Class G Top 500' above Kuparuk 19. To be completed lot Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. Ft. Intermediate Production ,~ ~10 Liner ~; t7: ~;~ .-,- ~ 8 '~ ~ Perforation depth: measured true vertical ~:}~!,,~a .O.J~ & ~[S ~,'"' -:,'~' 20. Attachments Filing fee .~_ Property plat ~ BOP Sketch ~ Diverter Skelch ~ Drilling program X Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~//~~~~__' Title Area Drilling Engineer Date / ~ ' Commission Use Only[ ' '/ Permit Number I APl number [ Approval. date J See cover letter for ~'/-.'~ ~ so-/~,~ - ~z~ / 5',,~ 0 3 / 0 5 / 9 ]_ other re({uirements Conditions of approval Samples required ~Y e s ,~ N o Mud Icg required ~ Y e s N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ,~Yes ~ N o Required working pressure for BOPE ~2M; ~ 3 M; ~ 5M; ~ 1 0 M; ~ I 5 M Olhe~,~ by order of Appro~ ~"'""~__"-~' _~-,/. ~ Commissioner the commission DaI~a~ ~Z/~ Form 10-401 Rev. 7-24-89 in triplicate ARCO ALASKA, Structure · Pad 2M Well · 16 Field · Kuparuk River Unit Location · North Slope, Alaska ' '400 - ,,--. -6 soo o 1200 - ('" 1600- O_ - 2000- - 2400 - 0 2800- k-- - 3200- =5 - 4000- - - 5200- 6400- fCreated by : jones For: T BILLINGSLEY Dote plotted : 22-Feb-91 Plot Reference is 16 Version //5. oordinotes ore in feet reference slot //16. rue Verticol Depths ore reference wellheod I-]JJJJEASTMAN IZ/~CH RISTENSEN East =-> 200 0 200 400 600 800 1000 1200 1400 1 BDO I I I I I I I I I I I I I I I I I I I SEC. 27, T11N, RSE TARGET LOCATION:I 1740' FSL, 1680' FWL /' J SEC. 27, Tl lN, R8E J / / TARGET 3VD=5986 TMD=6525 DEP=20g8 NORTH 1626 EAST 13 N ,39 DEC 12 MINE 2098' (TO TARGET) RKB ELEVATION: 141 ' TB/ PERMAFROST TVD= 1391 UGNU SNDS '[VD=1451 KOP TVD=1828 TMD=1828 DEP=O 3.00 T/ W SAK SNDS TVD=2016 TMD=2016 DEP=9 9.00 BUILD 3, DEG/IO0 FT 1 5.00 21.00 B/ W SAK SNDS '1'VD=2581 TMD=2602 DEP=155 EOC / 9 5/8" CSG PT 'P/D=2781 TMD=2826 DEP=255 K-lO TVD=2851 TMD=2907 DEP=295 K-5 T%'D=4351 TMD=4637 DEP=1158 ISURFACE LOCATION: I 114' FSL, 554' FWL SEC. 27, TllN, RSE AVERAGE ANGLE 29 DEC 54 MIN - 2000 1800 ~1600 1200 1000 800 600 400 D -- C~ 200 .. o ~ Sc,3~ i : 200.00 Vertical ~flon ~1 39.20 ~'zlmufll with reference 0.00 N, 0.00 £ f~ slot i*> r:Ci:iVEO i i i i i i i i i t i i i i 0 4(K) 800 1200 1600 2000 2400 TARGET - T/ ZONE C TVD=5986 TMD=6525 DEP=2098 T/ ZONE A TVD=5999 TMD=6538 DEP=2106 B/ KUP SNDS'P/D=6119 TMD=6677 DEP=2175 TD / LOGGING PT TVD=6292 TMD=6877 DEP=2274 DRILLING FLUID PROGRAM (2M-16) Spud to 9-5/8" Drill out to Weight up surface casing weight UD toTD Density 8.6-1 0.0 8.6-9.6 1 0.3 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-1 2 8-1 0 4- 5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4- 7 10-1 2 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge o Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1650 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2M-16 will be 2M-15 (proposed). As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations will be pumped into a dedicated temporary disposal well or the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M PAD . . o . o . . o 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. ~JPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 5 HCR I 6 J 5 4 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 1~7' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER SRE ~6~0 .6 13 5/8" 5000 F,.,I BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 4 BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3(X)O PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 30(X) PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET ~N THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5(X)0 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 VICINITY MAP [ . .., , ..~, , ' ~6 ~,~48,98~. 93 487,?R~.~ ?001~'1~.87'?'' /~O°O~'~.ff~?'' //4 ' //t ' lOl.O' 104.9 / ~, ~ 48, ~88.83 4 ~7, 75~.61 ~0°/~' 1~.~6" / 50° 0~' ~$, $~6 '~ / t 4 ' SE' rOI.O' 104.9 NO. Y X LA?. ~ONG. ~&L. ~ ~,9~e,~05.~ ~O?,O~.~l' ?Oa/e' /O.S7~" /~O~O~'~.e30 ' 114' 14' 1~.9' I0~.1 ~ 5t94~9~5.$6 4~?~8~.31 ?Oel$'l~.~l?" 1~0°0~'~1.~0'' II~~ 89' IOQS' t05.4 ~ 5~~.?J 4~?,~,37 ?0Ol6~1~.3X~ '* I~0°0~'~0.?~0 '~ 114 ' 1t4 ' I00.?* I05.~ t~ ~,94~ 98~.85 488~ 0~9.4S ~O°le'l~,'~81" 180e 08'4~ff~4 " I 14 ' leg' 1~.5' 105.~ 13 ~,948~.74 4~8, I1~.~7 ~Oel~*l~.~l ~ t~0;05'~.919 " 114' ~79' t00.3' I05.6 14 5~948~0~,~ 480~ 144.4~ ?0°15't0.~83~ I~OeO~*4~, 18~*' t 14 ' 304 ' ~,2' 10~,6 16 a,~4O, 98E94 4aa,/~4.04 ~OO/~' lO.aO4" / aO°05'4a.7~" / t ~' 3~4' I~.t' toS.e .~0 5,~48~8~4 48Y~ ~4.0~ ?0°/~'/~,~8'' 1~0=0~'$0.~31" 114 ' 454' 99,8' 105.4 21 ~,~48~.~ 48~ $t~.1~ ?Oel~'lO.~05'' 1~0°0~"40,0~" I t4 ' 4?9' 99,7' 105.5 2~ 5~4~J0~77 400, 3~4.40 ?O°l~' tE.~O~" 150°0~'~,~4" It ~ ' 50~' 99.7' 105.0 ~ ~, 94ai ~E~.~ 4~a~ ~$~.~1 YO°16'/ff.~$, IEO°O~'~.6~O" i I ~ ' ~' 99.6' I04.9 R~ 5~94~,~7~ 4~, 3~4~9 ?O°IE'I~.~'' 1~0°0~'3~911" II $ ' 55~' 99.5' 104.9 R~ ~94~m9~ 4~4t~,~ ~Oel~'lE.~06/' t~OeO~'3~/O0 " 114' ~79' 99.4' 1~.9 ,S,, URVEYOR~ CERTI~CATE I HEREBY CERTIFY THaT I AM PROI~ERLY ARCO ALASKA, INC. DWG ~k NSDK. EMO0. CEA.D~.MX, 6~. I~t D 7 J ska, Inc'. LAN SURVtWN rile StArE Or A,AS A : ., .. Dr/Il Site 2. M Conductors I- ~.,~ .... :.~ ,.. ~t.~ . 'MADE BY ME OR UNDER MY DIRECT 3UPE~SlON~ -:~ ..~..~., ,, ¢~,'~ .- ~ / :~ / D= f · De · crier/on Oole.'R-It-9/ No. ' N~K 6 ~3 d7 i i il i i i i ........... I i i i i ii i~ CHECK LIST FOR NEW WELL PERMITS Company :/r~ Lease & Well No.. ITEM APPROVE DATE YES NO (1) Fee ~_, ~ 1. Is the permit fee attached .......................................... ~ (2) Loc (2 thru 8)' ' ' (8) (3) Admin ~' Z~f/~/ 9. ' "(9 thru ~3) 10. ~.~.,.~,~. ~-/~/ 11. (10 and 13) 12. 13. (4) Casg ~-,'~,~.'~?i 3-/-z~/ (14 thru 22) (23 th~u 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 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 fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ , , Does the well have a unique name and number ......................... ,~_ Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OdkO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. thru 31) (6) Add: Geology: Eu~ineerin~: DWJ .~_ LCS rev: 11/30/90 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. IINITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~?~/~ ~ D~.oz /- o,'/ ~?~ /':'1~o ~z~J Additional Remarks: , o ~ o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No .special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: Tape Subfile 2 is type: LIS LIS DEPTH CIDP CILD ILD IDQF IMQF IIXM SFLU MTEM MRES DRHO PEF LU LL LSHV SSHV CALI GRL RTNR TNPH RCFT CNTC DTLN DTLF TT4 LTT1 GRS TEND DTCO DTSM PR CHSH MTED MREI 6833.5000 402.9671 0.0000 5.7116 137.2535 0.0167 265.4265 1428.0508 2.8800 3.1667 710.6984 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6833.0000 402.9673 0.0000 5.7106 137.2535 0.0167 265.4265 1428.0508 2.8800 3.1667 710.6984 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6800.0000 391.1095 0.0000 10.4590 137.2535 395.6288 2.4816 0.0000 2.8153 0.1858 3.'4830 166.6632 1323.0996 110.5638 33.8481 2165.8159 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 395.6393 2.4816 0.0000 2.8153 0.1858 3.4830 166.6632 1323.0996 110.5638 33.8481 2165.8159 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 386.8033 2.5568 0.0000 2.9923 0.1858 3_4R30 IDPH CILM IIRD SP HTEN QLS LITH SlRH TENL TNRA CFTC TT1 LTT2 MTES DTSI RSHC HTED 2.5276 369.1623 330.5872 -20.0000 -312.5460 0.1017 82.3028 2.3052 2990.0000 2.9803 737.2534 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.5276 369.1623 330.5872 -20.0000 -330.1755 0.1017 82.3028 2.3052 2990.0000 2.9803 737.2534 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2. s53 379.3416 323.2988 -20.4375 486.6576 0.1016 CIMP ILM IIXD GR DPHI QSS SSl LSRH HTEL NPOR DT TT2 LTT3 MRED DTSP GRD 368.0808 2.7088 48.0409 110.5638 15.9817 0.0270 209.4733 2.3681 -312.5460 33.8481 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 368.0710 2.7088 48.0407 110.5638 15.9817 0.0270 209.4733 2.3681 -330.1755 33.8481 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 378.9185 2.6361 51.1529 110.5638 16.1786 0.0337 IMPH IFRE IIRM TENS RHOB LS SS2 LURH NPHI RCNT DTL TT3 LTT4 HTES DTSU TENI 2.7168 -999.2500 343.2725' 2990.0000 2.3863 299.3765 288.8273 2.4226 40.1607 2279.1064 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.7169 -999.2500 343.2725 2990.0000 2.3863 299.3765 288.8273 2.4226 40.1607 2279.1064 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6391 -999.2500 352.5021 4765.0000 2.3831 299.3765 1428.0508 2.88~ 3~667 71~.6984 ~99.2500 ~,,,~-999.2500 -999.2500 -999.2500 -999.2500 141.5408 6600.0000 191.1558 0.0000 -3.6612 138.3709 0.0028 275.8846 1428.0947 8.8447 3.0729 807.0568 -999.2500 -999.2500 -999,2500 95.7307 0.3045 142.6554 6400.0000 587.9426 0.0000 27.7945 136.6422 0.0878 131.9809 1428.4941 9.0806 4.2321 565.3521 -999.2500 -999.2500 -999.2500 100.0547 0.3275 140.1781 6200.0000 463.0871 0.0000 14.7211 134.0937 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 118.5208 0.3679 136.3711 110.5638 33.8481 2165.8159 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.1912 188.4839 5.2313 0.0000 6,5443 0.1879 2.5805 154.3559 1323.1169 82.4232 33.8392 2533.2944 -999.2500 -999.2500 -999.2500 184.1962 0.9590 0.1915 590.8571 1.7008 0,0000 6.0000 0.1871 8.6646 52.5722 1323.5789 76.6171 45.5142 1904.5940 -999,2500 -999.2500 -999.2500 202.7754 0.7768 0.1918 453.4462 2.1594 0,0000 2.5225 0.1868 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 268.0211 0.7445 0.1908 4765.0000 2.9803 737.2534 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 342.3373 5.3055 185.0570 164.5948 -26.0000 4i0.8640 0.0018 83.9233 2.3730 4655.0000 3.0005 857.8595 -999.2500 -999.2500 -999.2500 184.1962 1.8862 308.4762 1.6925 507.7541 465.3011 -23.5000 473.3787 -0.0616 24.0376 2.8409 4605.00'00 3.6817 515.5190 -999.2500 -999.2500 -999.2500 202.7754 1.9744 332.9058 2.2053 460.0677 381.3415 -27.9375 342.9277 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 268.0211 2.1874 386.1172 486.6576 33.8481 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 67.4805 183.5997 5.4037 14.4197 82.4232 15.8522 0.0199 201.4186 2.3841 410.8640 33.1499 -999.2500 -999.2500 -999.2500 -999.2500 180.5675 87.0680 495.7309 1.9695 107.8094 76.6171 -28.2877 -0.0125 183.2316 3.0264 473.3787 37.9033 -999.2500 -999.2500 -999.2500 -999.2500 197.5438 96.2220 464.2644 2.-1736 61.3751 162.7106 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 259.2568 147.1512 40.1607 2279.1064 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 4065.0000 5.4466 -999.2500 174.2000 4655.0000 2.3884 292.2982 279.7364 2.3972 33.5507 2711.4116 -999.2500 -999.2500 -999.2500 -999.2500 180.5675 4005.0000 2.0172 -999.2500 467.9001 4605.0000 3.1167 118.5627 229.3478 2.9946 45.6701 2354.0200 -999.2500 -999.2500 -999.2500 -999.2500 197.5438 3900.0000 2.1539 -999.2500 425.2684 4425.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 259.2568 4010.0000 0.0000 4.8213 131.8048 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 111.8867 0.3729 133.1108 5800.0000 270.0189 0.0000 1.2316 128.7992 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 101.7158 0.3558 129.4245 5600.0000 437.3300 0.0000 20.0842 126.6254 -999.2500 ~999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 94.9241 0.3715 126.8271 5400.0000 353.1443 0.0000 10.6947 125.0316 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~.00~! 0.0000 3.1455 0.1854 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 258.0348 0.9557 0.1900 269.7599 3.7034 0.0000 3.9438 0.1825 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 224.5786 0.9585 0.1879 434.0236 2.2866 0.0000 2.2607 0.1820 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 217.0014 0.9798 0.1877 350.7643 2.8317 0.0000 3.4678 0.1823 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 308,9056 -31.6250 357.8141 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 258.0348 2.2213 338.5804 3.7070 268.4336 230.7736 -34.6875 433.9020 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 224.5786 2.1136 332.9692 2.3040 429.3341 356.3774 -30.3750 328.0314 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 217.0014 2.2118 309.5795 2.8509 343.7368 294.5922 -58.8125 384.1572 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --QQQ 9~ 42.1546 109.4259 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 248.5391 105.2374 269.4059 3.7253 29.0122 115.6960 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 214.9890 104.5480 432.6678 2.3292 65.3571 99.3259 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 209.9488 97.6645 340.8829 2.9092 45.9235 82.5477 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 350.9796 4940.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 248.5391 3675.0000 3.7119 -999.2500 251.2776 4275.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 214.9890 3545.0000 2.3112 -999.2500 397.6543 4030.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 209.9488 3435.0000 2.9336 -999.2500 320.1657 3940.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 101.7039 0.3504 125.2037 5200.0000 489.7580 0.0000 21.2868 123.4415 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 113.3795 0.3769 122.5232 5000.0000 409.2466 0.0000 13.8395 121.3118 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 119.6246 0.3905 119.7658 4800.0000 682.8035 0.0000 47.3384 119.2774 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 119.7009 0.3883 116.8215 4600.0000 614.4652 0.0000 35.6599 116.8687 --~.~DUU 219.5048 0.9606 0.1872 477.9304 2.0418 0.0000 1.9767 0.1795 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 265.6292 0.9640 0.1848 405.9970 2.4435 0.0000 2.6797 0.1797 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 294.7999 0.9539 0.1840 670.2289 1.4646 0.0000 1.4254 0.1779 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 292.9769 0.9692 0.1822 601.4939 1.6274 0.0000 1.5785 0.1764 219.5048 2.0840 311.8851 2.0924 485.4711 390.0980 -40.2500 418.2732 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 265.6292 2.2496 346.0208 2.4631 409.8180 338.1858 -44.7500 376.4028 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 294.7999 2.3589 320.3757 1.4920 684.7571 523.5060 -55.1875 358.1033 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 292.9769 2.3401 289.5942 1.6625 623.6351 476.5668 -39.1875 401.9686 --QQQ D~ 211.9538 75.0238 480.4307 2.0599 68.3401 101.9466 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 255.0571 101.1196 411.6893 2.4401 58.4690 122.9269 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.'2500 -999.2500 282.1824 124.3769 684.6989 1.4604 116.2390 91.9017 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 280.1152 97.7854 617.7052 1.6035 89.2361 94.5220 -999.2500 --QQQ 211.9538 3070.0000 2.0815 -999,2500 448.0113 3975.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 255.0571 3100.0000 2.4290 -999.2500 380.0624 3940.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 282.1824 3285.0000 1.4605 -999.2500 623.9165 3790.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 280.1152 3185.0000 1.6189 -999.2500 570.4316 3610.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 117.1631 0.3906 114.4281 4400.0000 363.1383 0.0000 9.4595 114.8834 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 110.3765 0.3825 111.7589 4200.0000 299.5060 0.0000 3.9513 112.7388 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 106.6488 0.3680 109.4269 4000.0000 389.4774 0.0000 13.9461 109.8286 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 118.1833 0.3910 107.2728 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 288.5726 0.9579 0.1809 358.5114 2.7538 0.0000 2.5477 0.1749 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 262.3065 0.9387 0.1811 295.5896 3.3388 0.0000 3.3395 0.1747 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 241.5509 0.9778 0.1798 384.6130 2.5675 0.0000 2.5143 0.1742 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 290.8831 0.9727 0.1797 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 288.5726 2.3603 372.5261 2.7893 375.8071 299.7256 -44.1250 385.8242 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 262.3065 2.2923 373.4785 3.3831 309.4154 251.5917 -49.4375 416.4494 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 241.5509 2.1879 371.4457 2.6000 406.3084 321.1308 -60.4375 '414.3419 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 290.8831 2.3638 396.0081 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 276.5391 101.6562 375.9409 2.6609 43.6742 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O. --1. 99. --0. 407. 1417. 9. 3. 522. 0000 45~0 8126 2500 2500 2500 2500 2500 2500 2500 2500 2500 1339 3929 0807 0000 3636 0000 5415 3385 2500 2500 2500 2500 2500 2500 2500 2500 2500 1949 3696 0937 0000 2064 0000 4283 1024 2500 2500 2500 2500 2500 2500 2500 2500 2500 6265 3549 7980 0000 0422 0000 5770 1894 0027 6249 1716 6198 9365 3076 0.0000 2.3756 0.1706 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 288.5244 0.976© 0.1762 305.7171 3.2429 0.0000 3.0710 0.1686 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 260.2815 0.9830 0.1679 254.1885 3.9031 0.0000 3.4728 0.1685 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 261.9044 0.9759 0.1734 227.4374 4.3282 0.0000 3.9916 0.1769 3.0330 233.5077 1319.4790 91.5363 43.3089 2015.0227 303.8611 -64.1875 410.8815 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 288.5244 2.3808 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-~_~1~7 264,1740 0,9544 0,1798 202,5767 4,8868 0,0000 3,9356 0.1830 2,7241 236,5014 1318,4785 94.8717 44.4278 1965,6819 -999,2500 -999,2500 -999,2500 284,5137 0,9823 0,1814 179,5000 5,4766 0,0000 4,8789 4,3789 2,6914 232,7500 1352,0000 90,7500 44,9270 1776,7097 124.6000 1402,8000 1965,0000 275,9659 0,5520 0,1900 124,7500 8,0O0O 0,0000 11,3203 4,4219 2.8066 229,5000 1352,0000 91,7500 42,7897 1793,2966 124,6000 1426,0000 1970,0000 -999,2500 -999,2500 -999,2500 112,0625 8,8594 0.0000 7,5469 4,4922- 2.~543 264,1740 2,1769 420,0409 4,9364 223,5013 176,6245 -56,6250 433,4099 -0,0447 145,1970 2,2067 2660,0000 3,5927 539,2812 -999,2500 -999,2500 -999,2500 284,5137 2,2806 342,9255 5,5703 186,8750 157,6250 -41,9375 1242,0000 -0,0059 143,1250 2,1855 2335,0000 3,8216 466,4350 782,0000 1162,0000 63,2187 275,9659 2,1510 410,7635 8,0078 127.1250 112,0625 -47,2187 1188,0000 -0.0015 145,8750 2,2168 2190,0000 3,8483 490,6094 794,0000 1174,3999 62,8437 -999,2500 -999,2500 -999,2500 8,9141 118,1875 97,5625 -56,8437 1161,0000 0.0005 254.8223 92,2027 222,7943 4.4742 18,3855 94,8717 31,4735 -0,OO50 204,3931 2,1449 433,4099 44,5977 -999,2500 -999,2500 -999,2500 -999,2500 274,4419 87,1324 185,7500 5,3477 14,1484 90,7500 28,3274 0,0122 224,8750 2,1816 1242,0000 45,2772 124,2000 535,2000 1654,0000 4,4492 266,9970 55,1201 111,4375 7,8633 6,1562 91,7500 28.0494 0,0049 221,0000 2,1914 1188,0000 42,1844 150,3000 486,8000 1679,5999 4,5820 -999,2500 -999,2500 116,7500 8,4609 -2,4355 70,6250 28,7843 0.0044 254,8223 2300.0000 4,4884 -999,2500 209,8460 2660,0000 2,1307 445,1158 307,8093 2,1440 43.4355 2061,4414 -999,2500 -999,2500 -999,2500 -999,2500 274,4419 2140,0000 5,3789 20.0000 175,8750 2335,0000 2,1826 431,7500 3'30,7500 2,1895 44,6779 1776,2583 123,8000 1028,0000 1404,3999 881,5000 266,9970 1875,0000 8,9687 20,0000 120,1250 2190,0000 2,1872 425,0000 328,0000 2,1992 45,5202 1828,3020 122,4000 1032,0000 1426,8000 913,0000 -999,2500 -999,2500 8,5547 20,0000 111,7500 2150,0000 2,1751 430.2500 ~'/Ub .UUUU 12.9453 4.0179 440.9808 124.9000 789.6000 68.8125 -999.2500 -999.2500 -999.2500 2200.0000 98.6250 0.0000 48.2187 61.9375 -0.0082 423.7500 1705.0000 12.5625 4.0370 417.6680 130.7000 835.6000 73.6250 -999.2500 -999.2500 -999.2500 2000.0000 81.8125 0.0000 13.2734 61.0625 -0.0079 453.7500 1705.0000 12.3047 4.5476 353.1935 139.1000 852.4000 63.1875 -999.2500 -999.2500 -999.2500 1800.0000 51.5312 0.0000 -7.2266 61.7500 -0.0153 483.0000 1704.0000 12.6094 4.1190 312.3108 151.8000 934.4000 39.5312 -999.2500 -999.2500 -999.2500 £~Dzl. uuuu 70'.6250 43.3983 1799.4937 125.7000 1420.8000 1840.0000 -999.2500 -999.2500 -999.2500 95.5625 10.1328 0.0000 10.6641 4.5469 2.7617 249.5000 1352.0000 75.8750 43.2855 1717.1135 130.9000 1516.0000 1685.0000 -999.2500 -999.2500 -999.2500 78.8750 12.2187 0.0000 11.5703 4.5859 2.7988 262.0000 1352.0000 63.6250 50.2464 1640.3289 142.1000 1554.3999 1585.0000 -999.2500 -999.2500 -999.2500 51.0312 19.3906 0.0000 15.7500 4.5430 2.5918 292.5000 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